20240403Direct Hackett (REDACTED).pdf

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER
COMPANY’S APPLICATION FOR A
CERTIFICATE OF PUBLIC CONVENIENCE
AND NECESSITY FOR THE BOISE BENCH
BATTERY STORAGE FACILITY.
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CASE NO. IPC-E-24-16
IDAHO POWER COMPANY
DIRECT TESTIMONY
OF
ERIC HACKETT
RECEIVED
Wednesday, April 3, 2024 4:50 PM
IDAHO PUBLIC
UTILITIES COMMISSION
HACKETT, DI 1
Idaho Power Company
Q. Please state your name and business address.1
A. My name is Eric Hackett. My business address2
is 1221 West Idaho Street, Boise, Idaho 83702. 3
Q.By whom are you employed and in what capacity?4
A. I am employed by Idaho Power Company (“Idaho5
Power” or “Company”) as the Projects and Design Senior 6
Manager. 7
Q. Please describe your educational background.8
A. I graduated in 2003 from Boise State9
University, in Boise, Idaho, receiving a Bachelor of 10
Science Degree in Civil Engineering. I am a registered 11
professional engineer in the state of Idaho. In 2010, I 12
earned a Master of Business Administration from Boise State 13
University. 14
Q. Please describe your work experience with15
Idaho Power. 16
A. From 2005 to 2007, I was employed as an17
engineer in Idaho Power’s Transmission Engineering group. 18
In 2007, I became a Project Manager leading transmission 19
and distribution line and station infrastructure projects. 20
In 2012, I was promoted to Engineering Leader where I 21
managed the Cost and Controls group supporting project 22
management. In 2015, I changed leadership roles and managed 23
the Stations Engineering and Design group as an Engineering 24
Leader. In 2018, I was promoted to Senior Manager of 25
HACKETT, DI 2
Idaho Power Company
Projects overseeing Project Management and Cost and 1
Controls, which later became my current role of Senior 2
Manager of Projects and Design in 2021, adding Power 3
Production Design and Project Management. In addition, I am 4
currently leading a team of internal employees and 5
consultants in development and evaluation of Idaho Power’s 6
Request for Proposals for Peak Capacity and Energy 7
Resources. 8
Q. What is the Company’s request in this case?9
A. Idaho Power is requesting the Idaho Public10
Utilities Commission (“Commission”) grant the Company a 11
Certificate of Public Convenience and Necessity (“CPCN”) to 12
acquire new dispatchable energy storage with 150 megawatts 13
(“MW”) of operating capacity necessary to meet the 14
identified capacity deficiency in 2026. 15
Q.What is the purpose of your testimony in this16
proceeding? 17
A. The purpose of my testimony is to provide an18
overview of the competitive resource acquisition process 19
undertaken to meet Idaho Power’s identified capacity 20
deficiency in 2026, as described by Mr. Jared Ellsworth in 21
his testimony. First, I will provide an overview of the 22
extensive Request for Proposals (“RFP”) process undertaken 23
in accordance with the Public Utility Commission of 24
Oregon’s (“OPUC”) competitive bidding rules and used to 25
HACKETT, DI 3
Idaho Power Company
evaluate the various resources that competed to provide a 1
combination of peak capacity and energy resources to help 2
meet Idaho Power’s electric energy needs in 2026. I will 3
then explain how the resulting least-cost, least-risk 4
resources were selected through the fair and competitive 5
RFP process, one of which is the new dispatchable energy 6
storage facility for which Idaho Power is requesting the 7
Commission grant a CPCN in this proceeding. 8
Q. Is this the same competitive resource9
acquisition process followed that led to the selection of 10
the least-cost, least-risk resources through the fair and 11
competitive RFP process discussed in Case No. IPC-E-24-12, 12
Idaho Power’s Application for Approval of a Market Purchase 13
Agreement, filed on March 18, 2024? 14
A. Yes, it is.15
Q.Have you prepared any exhibits?16
A. Yes. Exhibit No. 1 is London Economic17
International LLC’s (“LEI”) Observations on Idaho Power 18
Company’s Draft 2026 All Source Request for Proposal for 19
Peak Capacity and Energy Resources: Independent Evaluator 20
Assessment Report dated March 1, 2023 (“March 2023 LEI 21
Report”). Exhibit No. 2 is LEI’s Observations on Idaho 22
Power Company’s Updated Draft 2026 All Source Request for 23
Proposals for Peak Capacity and Energy Resources: Second 24
Independent Evaluator Assessment Report dated May 10, 2023 25
HACKETT, DI 4
Idaho Power Company
(“May 2023 LEI Report”). Confidential Exhibit No. 3 is 1
LEI’s Review of the Idaho Power Company’s benchmark bids, 2
submitted in response to the 2026 All Source Request for 3
Proposals for Peak Capacity and Energy Resources dated June 4
23, 2023, report (“June 2023 LEI Report”). Exhibit No. 4 is 5
Idaho Power’s 2026-2027 All Source Request for Proposals 6
(RFP) for Peak Capacity and Energy Resources issued on June 7
8, 2023 (“2026 RFP”). Confidential Exhibit No. 5 is LEI’s 8
Review of Eligibility and Initial Shortlist: 2026 All 9
Source Request for Proposals for Peak Capacity and Energy 10
Resources report (“August 2023 LEI Report”). Exhibit No. 6 11
details the AURORA modeling process utilized to help 12
identify the final shortlist projects. Confidential Exhibit 13
No. 7 presents the projects that make up the final 14
shortlist. Confidential Exhibit No. 8 is LEI’s Closing 15
Report: 2026 All Source Request for Proposals for Peak 16
Capacity and Energy Resources dated December 1, 2023 17
(“December 2023 LEI Report”). 18
I. BACKGROUND19
Q. Why did Idaho Power initiate a competitive20
request for proposals or RFP process to acquire the 2026 21
and 2027 peak capacity and energy resources? 22
A. As explained in the direct testimony of23
Company witness Mr. Jared Ellsworth, during preparation of 24
the 2021 Integrated Resource Plan (“IRP”), the Company 25
HACKETT, DI 5
Idaho Power Company
first identified a capacity deficit beginning in 2023. The 1
annual capacity positions identified in the 2021 IRP were 2
deficits of approximately 101 megawatts (“MW”) in 2023, 186 3
MW in 2024, 311 MW in 2025, 560 MW in 2026 and 665 MW in 4
2027. As a result, in order to meet its obligation to 5
reliably serve customer load in a least-cost, least-risk 6
manner, Idaho Power began the competitive solicitation for 7
the acquisition of resources, conducted through the 8
issuance of multiple RFPs, the 2021 All Source Request for 9
Proposals (RFP) for Peak Capacity and Energy Resources 10
issued on June 30, 2021 (“2021 RFP”),1 the 2022 All Source 11
Request for Proposals (RFP) for Peak Capacity and Energy 12
Resources issued on December 30, 2021 (“2022 RFP”),2 and the 13
2026 RFP. The competitive RFP process allows the Company to 14
access the broader peak capacity and energy market to 15
obtain the best resources for Idaho Power’s customers, 16
allowing for access to a spectrum of potential resources 17
and developers. Use of a formal RFP process provides 18
customers and regulatory agencies with the assurance that 19
the resource selection process was competitive, all 20
1 See Case No. IPC-E-22-13, In the Matter of Idaho Power Company’s Application
for a Certificate of Public Convenience and Necessity to Acquire Resources to
be Online by 2023 to Secure Adequate and Reliable Service to its Customers.
2 Case No. IPC-E-23-05, In the Matter of Idaho Power Company’s Application for a
Certificate of Public Convenience and Necessity to Acquire Resources to be
Online by 2024 and for Approval of a Power Purchase Agreement with Franklin
Solar LLC, and IPC-E-23-20, In the Matter of Idaho Power Company’s Application
for a Certificate of Public Convenience and Necessity to Acquire Resources to
be Online in both 2024 and 2025 and for Approval of an Energy Storage Agreement
with Kuna BESS LLC.
HACKETT, DI 6
Idaho Power Company
potential developers had an equal opportunity to 1
participate, and that the best resource alternative was 2
selected. My testimony will discuss the competitive bidding 3
process undertaken for issuance of the 2026 RFP and the 4
evaluation of the 2026 RFP bid submittals. 5
II. COMPETITIVE BIDDING RULES6
Q. Was Idaho Power in compliance with the7
competitive bidding rules adopted by the OPUC for which the 8
Commission directed the Company to follow as well?3 9
A. Yes. The OPUC’s competitive bidding10
requirements apply when an electric utility may acquire a 11
resource or contract for more than an aggregate of 80 MW 12
with a duration of five or more years.4 Further, they state 13
that when an electric utility is subject to competitive 14
bidding requirements, it must engage the services of an 15
Independent Evaluator (“IE”) to oversee the RFP process.5 16
Independent Evaluator Engagement 17
Q. Did the Company engage the services of an IE18
to oversee the RFP process? 19
A. Yes. On September 15, 2022, Idaho Power20
commenced the competitive bidding process, filing a request 21
with the OPUC to (1) open a docket for approval of the 2026 22
RFP, (2) appoint an IE to oversee the RFP process, and (3) 23
3 Case No. IPC-E-10-03.
4 Oregon Administrative Rule (“OAR”) 860-089-0100(1).
5 OAR 860-089-0200(1).
HACKETT, DI 7
Idaho Power Company
approve the proposed 2026 RFP scoring and modeling.6 Idaho 1
Power included, as part of the request, the RFP for an IE, 2
detailing the IE’s duties and scope of work regarding 3
preparation of the 2026 RFP, review of bids received in 4
response to the 2026 RFP, monitoring of the scoring and 5
modeling process, and participation in the OPUC proceeding. 6
The proposed 2026 RFP scoring and modeling included in the 7
Company’s request was required because the Company did not 8
include the request as part of the 2021 IRP when the 2026 9
capacity deficiency was identified. As such a draft RFP 10
reflecting any RFP elements, scoring methodology, and 11
associated modeling is required to be approved by the OPUC 12
in a separate proceeding.7 13
Q. When was the IE RFP issued?14
A. Following consideration of feedback from15
interested intervenors and OPUC Staff, Idaho Power issued 16
the IE RFP on November 1, 2022. The Company received five 17
responsive bids from interested IE candidates by the 18
November 15, 2022, deadline. Idaho Power subsequently held 19
a confidential workshop with interested stakeholders on 20
December 1, 2022, to review bids and exchange 21
recommendations on preferred IE candidates and incorporated 22
the feedback into the evaluation of the IE candidates. 23
6 Docket UM 2255, In the Matter of Idaho Power Company, Application for Approval
of 2026 All-Source Request for Proposals to Meet 2026 Capacity Resource Need.
7 OAR 860-089-0250(2).
HACKETT, DI 8
Idaho Power Company
Q. How did the Company evaluate the IE1
candidates? 2
A. All bids were evaluated based upon an3
assessment of each IE candidate’s RFP oversight experience, 4
understanding of an IE’s role and responsibilities under 5
the OPUC’s competitive bidding rules, and demonstrated 6
technical and topical experience. In addition, bids were 7
evaluated based on the overall cost of the project, the 8
overall elements of that cost, and the overall 9
appropriateness of the submitted costs in relation to the 10
submitted proposal. Finally, the bids were evaluated based 11
on the IE candidate’s adherence to the terms and conditions 12
of Idaho Power’s Professional Services Agreement. The not 13
to exceed bid of each proposal was considered to create a 14
composite score for each IE candidate. 15
Q.What were the results of the evaluation of the16
IE candidates? 17
A. The Company determined that all five IE18
candidates possessed the necessary experience to perform 19
the duties associated with oversight of the 2026 RFP, but 20
LEI received the highest cumulative weighted score. On 21
December 8, 2022, Idaho Power filed a request for OPUC 22
approval to engage the services of LEI, who also received 23
support from participating stakeholders. LEI demonstrated 24
experience as an IE in other jurisdictions and showed a 25
HACKETT, DI 9
Idaho Power Company
clear understanding of the IE’s duties as expressed in the 1
OPUC competitive bidding rules.8 Finally, LEI’s proposal 2
reflected the lowest cost to customers. 3
Q. Did the OPUC approve the Company’s request to4
engage LEI as the IE for the 2026 RFP? 5
A. Yes. On December 27, 2022, in a public6
meeting, the OPUC approved the selection of LEI as the IE 7
for Idaho Power’s 2026 RFP and evaluation of 2026 8
resources. The OPUC also approved the concurrent discussion 9
of both scoring and modeling methodologies and preparation 10
of the draft 2026 RFP.9 Over the next six weeks, the Company 11
worked with LEI to finalize the draft 2026 RFP and on 12
February 15, 2023, Idaho Power distributed the draft 2026 13
RFP to the participants in the OPUC docket. A workshop was 14
held on February 21, 2023, with stakeholders to solicit 15
feedback on the design of the 2026 RFP. 16
Draft Request for Proposals 17
Q. Was any feedback incorporated into the final18
draft 2026 RFP? 19
A. Yes. At the request of stakeholders, the20
Company made available to all bidders the transmission 21
rights defined in the proposed market purchase volumes 22
exhibit and requested that market purchase product bids 23
8 OAR 860-089-0450.
9 Order No. 22-495.
HACKETT, DI 10
Idaho Power Company
utilize these Idaho Power transmission rights. The Company 1
also clarified that bids that had not received or were not 2
seeking Network Resource Interconnection Service may 3
require additional cost adders in the event that 4
designation of the potential resource as a Network Resource 5
required additional transmission system investments. 6
Finally, Idaho Power clarified that bidder questions and 7
the Company’s responses to questions would be posted 8
publicly. In accordance with the OPUC competitive bidding 9
rules, the final draft 2026 RFP was filed with the OPUC on 10
February 22, 2023, with a request that the OPUC solicit 11
comments on and approve the scoring and modeling 12
methodologies as well as the final draft 2026 RFP. 13
Q. What resources did the final draft 2026 RFP14
target for procurement? 15
A. The final draft 2026 RFP targeted resource16
procurement consistent with the capacity deficiencies 17
identified in the 2021 IRP. Accordingly, the 2026 RFP 18
sought proposals for a combination of energy and capacity 19
resources with as much as 1,100 MW of variable energy 20
resources and a minimum of 350 MW of peak capacity. Idaho 21
Power accepted bids for energy or capacity incremental to 22
its system in the 2026 timeframe from market energy 23
purchases or new or existing resources. For new or existing 24
resources, bidders were encouraged to offer proposals under 25
HACKETT, DI 11
Idaho Power Company
any of three different structures: (1) power purchase 1
agreements (“PPA”) with exclusive ownership by Idaho Power 2
of any and all capacity and environmental attributes 3
associated with the energy generated, (2) build-transfer 4
transactions whereby the bidder develops the project, 5
assumes responsibility for construction, but ultimately 6
transfers the asset to Idaho Power pursuant to a build-7
transfer agreement (“BTA”), or (3) control of the output of 8
a standalone battery through a tolling agreement. 9
Q. Did the final draft 2026 RFP contemplate10
benchmark resources? 11
A. Yes. In fact, the OPUC competitive bidding12
rules require that, prior to the opening of bidding of an 13
approved RFP, the Company submit to the IE, for review and 14
comment, a detailed score for any benchmark resource with 15
supporting cost information, any transmission arrangements, 16
and all other necessary information to score the benchmark 17
resource. The rules require Idaho Power to apply the same 18
assumptions and bid scoring and evaluation criteria to the 19
benchmark bid that are used to score other bids. 20
In addition, as required by OAR 860-089-0300, the 21
Company identified a separate team of Idaho Power staff and 22
retained consultants (“Internal Bid Team”) to submit 23
resource-based product bids, or benchmark bids. As such, 24
the Company instituted a Separation of Functions protocol 25
HACKETT, DI 12
Idaho Power Company
where the evaluation of bids would be performed by a 1
separate team of Idaho Power staff and retained consultants 2
with relevant subject matter expertise (“Evaluation Team”) 3
to work directly with the IE. This Separation of Functions 4
protocol was developed with the purpose of defining 5
specific roles and responsibilities and outlined policies 6
and procedures to be maintained as a living document to 7
ensure the Evaluation Team and Internal Bid Team operate 8
separately, and no access to any non-public information is 9
shared. 10
So, when the final draft 2026 RFP was filed with the 11
OPUC, the Company indicated it would submit a detailed 12
score for the benchmark resources, with supporting cost 13
information, to the Commission and IE for review of 14
reasonableness, before opening market bids. Then, when the 15
2026 RFP was issued, Idaho Power would submit benchmark 16
resource proposals, providing a potential cost-based 17
alternative for customers. 18
Q. Was the bid scoring and evaluation criteria19
included in the final draft 2026 RFP submitted with the 20
OPUC? 21
A. Yes. However, the proposed scoring criteria22
and methodology was the same as that submitted with the 23
draft 2026 RFP filed with the OPUC on September 15, 2022, 24
and included as part of the IE RFP request. Idaho Power’s 25
HACKETT, DI 13
Idaho Power Company
proposed scoring and modeling methodology complied with the 1
requirements of the rules10 as it detailed a transparent 2
bid-scoring process using objective scoring criteria and 3
metrics, incorporating the following requirements: (1) the 4
initial shortlist bids must be based on both price and non-5
price factors, and non-price factors have been converted to 6
price factors where practicable, (2) the majority of scores 7
awarded to bids received will be based on price factors (75 8
percent attributed to price factors), (3) non-price factors 9
are based on resource characteristics identified in Idaho 10
Power’s 2021 IRP action plan and in conformance to the 11
standard form contracts attached to the 2026 RFP, and (4) 12
final shortlist bids are based on the bid resources’ 13
overall system costs and risks. 14
Q. What occurred after the filing of the final15
draft 2026 RFP with the OPUC on February 22, 2023? 16
A. Subsequent to filing of the final draft 202617
RFP, LEI submitted its March 2023 LEI Report, the first 18
deliverable under the engagement with the Company, included 19
as Exhibit No. 1. The March 2023 LEI Report provided 20
observations and recommendations to the draft 2026 RFP as 21
well as a summary of stakeholders’ comments discussed 22
during the workshop held on February 21, 2023, ultimately 23
recommending eight improvements to be incorporated into the 24
10 OAR 860-089-0400(1), (2) and (5).
HACKETT, DI 14
Idaho Power Company
final RFP that would make the solicitation process clearer 1
and more transparent to stakeholders. 2
Q. What were LEI’s eight recommended3
improvements? 4
A. The following are the eight adjustments to the5
draft 2026 RFP recommended by LEI: 6
add to the body of the RFP the Company’s target7
procurement mix based on the latest acknowledged8
IRP and disclose if the needs are expected to9
change during the 2026 RFP process,10
incorporate an additional exhibit disclosing11
prospective benchmark bids,12
extend the bid deadline to after the benchmark bids13
are evaluated by the IE,14
make self-scoring non-price questions less15
subjective and fine-tune the weighting calculation,16
provide information on Idaho Power’s approach to17
contract normalization,18
expand on the description of the price scoring19
model,20
incorporate an additional exhibit expanding on the21
bid evaluation process, and22
exclude the cost of imputed debt for the purpose of23
bid evaluation.24
HACKETT, DI 15
Idaho Power Company
Q. Did any stakeholders submit comments regarding1
Idaho Power’s draft 2026 RFP? 2
A. Yes. OPUC Staff and the Northwest and3
Intermountain Power Producers Coalition (“NIPPC”) also 4
filed comments regarding the Company’s draft 2026 RFP. OPUC 5
Staff expressed concerns regarding Idaho Power’s (1) 6
statement that it may prioritize the evaluation of bids 7
with relatively low prices to maximize the use of limited 8
time and resources, (2) inclusion of imputed debt in the 9
price scoring methodology, and (3) questions within the 10
non-price scoring matrix. In addition, OPUC Staff requested 11
an explanation of how capital costs are converted to a 12
levelized cost, the availability of tax credits for the 13
Company, and various IRP modeling components. 14
NIPPC also expressed concerns about the Company’s 15
inclusion of imputed debt and the questions within the non-16
price scoring matrix. Similar to OPUC Staff, NIPPC 17
requested clarity on a number of items. In addition, NIPPC 18
suggested change to the allocation of price to non-price 19
scoring, the timing of portfolio modeling, the length of 20
the cure period for bidders, the exclusivity of negotiation 21
rights of the shortlist projects, and various provisions of 22
draft contracts submitted as part of the draft 2026 RFP. 23
Q.Did the Company incorporate the feedback24
received from stakeholders into the 2026 RFP? 25
HACKETT, DI 16
Idaho Power Company
A. Yes. Because of the limited timeframe in the1
procedural schedule in Docket UM 2255 for Idaho Power to 2
file comments in response to the feedback from LEI, OPUC 3
Staff and NIPPC, the Company incorporated many of the 4
suggested changes and on March 24, 2023, submitted with 5
Reply Comments in the docket, a modified draft 2026 RFP. At 6
the time, the Company was still evaluating certain elements 7
of the feedback and committed to working collaboratively 8
with the IE and OPUC Staff to provide explanations of 9
various subjects and make additional modifications to the 10
RFP leading up to the next steps in the competitive bidding 11
process. On April 5, 2023, Idaho Power posted on its 12
website a revised draft 2026 RFP that incorporated further 13
feedback from stakeholders. 14
Q. What was the next step in the OPUC proceeding15
following the Company’s posting of the revised draft 2026 16
RFP? 17
A.Under the Docket UM 2255 procedural schedule,18
subsequent to Idaho Power’s Reply Comments, on May 2, 2023, 19
OPUC Staff submitted their report detailing their analysis 20
of whether or not the OPUC should approve the draft 2026 21
RFP and the associated scoring and modeling methodology, 22
recommending the Commission approve the draft 2026 RFP and 23
the associated scoring and modeling methodology with 24
certain conditions. In the report, OPUC Staff notes their 25
HACKETT, DI 17
Idaho Power Company
appreciation for the Company’s “willingness to address 1
concerns raised by the IE and stakeholders over multiple 2
iterations of the [d]raft RFP” and that “[w]hile some 3
issues remain open, the Company has resolved many of those 4
identified earlier in the review process.” OPUC Staff 5
thanked Idaho Power for its responsiveness and constant 6
communication throughout the process.11 Finally, OPUC Staff 7
found that the Company’s draft RFP complied with the OPUC 8
competitive bidding rules and that they believe the draft 9
2026 RFP, and the associated scoring and modeling 10
methodology, “can be employed in a generally fair and open 11
competitive procurement process.”12 12
Q. What were the OPUC Staff recommended13
conditions associated with the draft 2026 RFP and 14
associated scoring and modeling methodology? 15
A. Before I discuss OPUC Staff’s recommended16
changes to the draft 2026 RFP, it is worth noting that, due 17
to a scheduling oversight by OPUC Staff, their May 2, 2023, 18
report was filed prior to the May 2023 LEI Report, which 19
contained additional recommendations, including 20
endorsements of some stakeholder positions that had not 21
been adopted by OPUC Staff. The May 2023 LEI Report is 22
included as Exhibit No. 2 to my testimony. As a result, on 23
11 Docket UM 2255, Staff Report dated May 2, 2023, page 4.
12 Id. page 5.
HACKETT, DI 18
Idaho Power Company
June 1, 2023, OPUC Staff submitted supplemental 1
recommendations on both the draft 2026 RFP and the 2
associated scoring and modeling methodology, incorporating 3
the feedback from the May 2023 LEI Report and other issues 4
raised by stakeholders. I will discuss them as a whole. 5
OPUC Staff recommended three conditions associated 6
with the scoring and modeling methodology: (1) the specific 7
weighting for each question included in the Project 8
Readiness and Deliverability section of its Non-Price 9
Scoring Matrix is provided, (2) amend the Non-Price Scoring 10
Matrix to remove any scoring penalties applied to bidders 11
that provide redlines to form contracts or other elements 12
of the RFP and its exhibits, and (3) do not add or apply 13
any cost of imputed debt to the price scores of any bids, 14
specifically those using PPA, Battery Storage Agreement 15
(“BSA”), or similar contractual structures. In addition, 16
OPUC Staff made one supplemental recommendation associated 17
with the scoring and modeling methodology, suggesting Idaho 18
Power include an example of its term normalization 19
methodology within the RFP. 20
The seven initial RFP conditions recommended by OPUC 21
Staff indicated Idaho Power should: (1) provide a table 22
clearly delineating any and all modeling inputs and 23
assumptions that will be used, showing how those values 24
differ from the values provided in its 2021 IRP and 25
HACKETT, DI 19
Idaho Power Company
providing support for all changes, (2) clarify that no bids 1
will be excluded or otherwise penalized as long as all 2
materials and documentation have been completed and 3
submitted by the bid due date, (3) remove from the final 4
RFP the supplemental fee to bidders selected for the final 5
shortlist, (4) update item number two on the bid evaluation 6
checklist by adding the following language, “documentation 7
can include construction plans and schedules, evidence that 8
necessary permits have been or are being acquired, proof of 9
equipment procurement and delivery on site, and 10
interconnection studies and agreements that support the 11
commercial operation date”, (5) change the transmission 12
requirements in Exhibit C of the final 2026 RFP to make 13
them consistent with Exhibit D, (6) increase the cure 14
period in the final RFP for mistakes in the bid entry or 15
other forms to five calendar days from the date the bidder 16
is notified of the deficiency by Idaho Power, and (7) 17
remove the “Negotiation of Facility Purchase” section from 18
all draft Form Agreements in which it appears. 19
In their June 1, 2023, report, OPUC Staff 20
recommended 11 supplemental RFP conditions based on LEI’s 21
second report and stakeholder feedback. The further 22
recommendations requested that the Company (1) create a new 23
exhibit to the draft RFP that provides the size (in MW), 24
location, technology type, interconnection status, expected 25
HACKETT, DI 20
Idaho Power Company
life, expected efficiency, target commercial operation 1
date, status (new build vs. existing facility), and product 2
type (resource-based or market purchase) for each benchmark 3
bid, (2) provide its proposal regarding the availability, 4
or not, of benchmark bid assets to third parties as part of 5
the RFP, (3) state explicitly that bidders will be provided 6
with an opportunity to update their bid pricing upon 7
selection to the final shortlist, (4) amend the exclusivity 8
section to limit exclusivity to 60 days following 9
acknowledgement of the final shortlist, (5) reduce delay 10
damages in the form PPA to $200 per MW of nameplate 11
capacity per day, (6) amend the development security 12
section of all form contracts attached to the RFP to allow 13
cash as an acceptable form of security, (7) amend the 14
commercial operation date on both the form PPA and the form 15
BSA to include language stating that the scheduled 16
commercial operation date will be extended on a day-for-day 17
basis in the event that Idaho Commission approval of the 18
contract extends beyond six months, (8) amend the form PPA 19
by removing three specific provisions (Sections 1.145, 20
7.2.1, and 15.1), (9) remove any set numeric values for the 21
minimum experience in either years of operation or MW of 22
resources managed from all form contracts, (10) remove the 23
numeric value 87 percent from the definition of guaranteed 24
roundtrip efficiency in the form BSA, and (11) amend the 25
HACKETT, DI 21
Idaho Power Company
charging energy management section of the form BSA to 1
provide charge/discharge notification a minimum of one-2
hundred and twenty (120) minutes prior to the flow hour. 3
Q. Did Idaho Power have the opportunity to4
comment on the proposed recommendations to the draft RFP 5
and the associated scoring and modeling methodology? 6
A. Yes. The Company largely accepted all of OPUC7
Staff’s initial recommendations with the exception of the 8
exclusion of the impacts of imputed debt costs associated 9
with PPA’s and BSA’s and requested the OPUC allow Idaho 10
Power to consider the full range of costs associated with 11
PPA’s and BSA’s, including imputed debt. The Company 12
reiterated that imputed debt is a real cost that will 13
impact customers and must be reasonably considered in order 14
to determine whether a bid is the least-cost, least-risk 15
resource to meet the Company’s need. Ignoring imputed debt 16
tips the scales in favor of non-utility bids at the expense 17
of customers. Idaho Power did however suggest that, in the 18
alternative, if the OPUC rejects the inclusion of imputed 19
debt in the scoring and modeling methodology, the OPUC 20
leave open the option for Idaho Power to consider imputed 21
debt when selecting the final bids from the initial 22
shortlist. 23
With respect to OPUC Staff’s supplemental 24
recommendations in their June 1, 2023, report, the Company 25
HACKETT, DI 22
Idaho Power Company
largely agreed with all the recommended conditions except 1
for the second supplemental RFP condition that indicated 2
Idaho Power must make benchmark bid assets available to 3
third parties. Idaho Power submitted three benchmark bids, 4
whose scores were filed with the OPUC on June 13, 2023, in 5
compliance with the competitive bidding rules.13 In 6
addition, the benchmark bids were reviewed by LEI and 7
determined to meet the requirements outlined in the 2026 8
RFP, as outlined in the June 2023 LEI Report. The June 2023 9
LEI Report is provided as Confidential Exhibit No. 3 to my 10
testimony. Because two of the benchmark bids were Battery 11
Energy Storage Systems (“BESS”) and would be installed 12
within or incorporated into the boundary of existing 13
Company substations, the land rights could not be made 14
available to a third-party. The third benchmark bid was a 15
wind facility being developed with a third-party and also 16
could not unilaterally offer access of the wind facility’s 17
assets to third-party bidders. 18
Q. Did the OPUC issue a decision on the draft19
2026 RFP and associated scoring and modeling methodology? 20
A. Yes. By the time the Special Public Meeting21
was held on June 7, 2023, to discuss the draft 2026 RFP and 22
associated scoring and modeling methodology, the Company, 23
OPUC Staff and stakeholders had come to an agreement on 24
13 OAR 860-089-0350(1).
HACKETT, DI 23
Idaho Power Company
provisions that resolved all open issues with the exception 1
of the inclusion of imputed debt costs. Therefore, OPUC 2
Order No. 23-260, issued on July 17, 2023, approved Idaho 3
Power’s 2026 RFP and associated scoring and modeling 4
methodology with OPUC Staff’s recommendation conditions 5
detailed in their May 2, 2023, and June 1, 2023, reports, 6
and described earlier in my testimony, with one condition. 7
With respect to imputed debt, the OPUC agreed with OPUC 8
Staff’s condition that the cost of imputed debt be excluded 9
from the price scores of any bids, however the OPUC did not 10
object to Idaho Power providing additional informational 11
model runs that include the cost of imputed debt. As a 12
result, Idaho Power formally issued the 2026 RFP on June 8, 13
2023. The final 2026 RFP is included as Exhibit No. 4 to my 14
testimony. 15
Q. What is the Company’s view of the OPUC16
competitive bidding process? 17
A. Idaho Power acknowledges the OPUC competitive18
bidding process is thorough. However, the Company’s concern 19
is that the OPUC competitive bidding process is too 20
lengthy, especially during times of rapid changes in the 21
Company’s capacity deficiency often due to load growth 22
caused by large load customers. In the future, Idaho Power 23
may request modifications to the process to ensure the 24
Company can react in a timely manner to changing load 25
HACKETT, DI 24
Idaho Power Company
growth. 1
III. THE 2026 RFP2
Q. You indicated the 2026 RFP sought proposals3
for a combination of energy and capacity resources with as 4
much as 1,100 MW of variable energy resources and a minimum 5
of 350 MW of peak capacity. Please describe the intent of 6
the resources sought through the 2026 RFP. 7
A. Through the 2026 RFP, the Company’s intent was8
to solicit bids for (1) energy market purchases and (2) new 9
or existing resources. Energy market bids were required to 10
begin delivery across Idaho Power-controlled transmission 11
on or before June 2026. The eligible products included 12
asset purchases, PPA’s, and BSA’s with exclusive ownership 13
by the Company of any and all environmental attributes 14
associated with the energy generated. New resource bids 15
were required to have a target commercial operation date on 16
or before June 2026 as appropriate. 17
Q. Why were energy market purchases solicited as18
part of the 2026 RFP? 19
A. Market purchases were solicited as part of the20
2026 RFP because the Company holds, or anticipates holding, 21
firm transmission rights on various paths that can be used 22
for the delivery of energy market purchases. These 23
transmission rights will include future capacity from B2H. 24
As a cost-effective resource identified in the 2021 IRP 25
HACKETT, DI 25
Idaho Power Company
Preferred Portfolio, B2H will increase the Company’s 1
transmission capacity, enabling Idaho Power to purchase 2
energy to meet its resource capacity needs. 3
Q. How did the Company determine the available4
transmission capacity that market energy purchases could 5
utilize? 6
A. The 2026 RFP solicited market energy resources7
to associate with all available transmission, including 8
future capacity on B2H. The available transmission was 9
evaluated based on existing transmission rights Idaho Power 10
holds on third-party transmission systems (380 MW in summer 11
of 2026, 330 MW in summers thereafter) as well as capacity 12
on its own system. The transmission capacity available for 13
importing market purchases was listed in Exhibit E of the 14
2026 RFP. 15
Q.Did Idaho Power consider the impact on energy16
market purchases solicited through the 2026 RFP if there is 17
a delay in the in-service date of B2H? 18
A. Yes. Should the B2H in-service date slip,19
additional new resources will need to be acquired by 2026 20
that are not dependent on B2H transmission capacity, 21
therefore the Company’s 2026 RFP remained flexible. As 22
such, as detailed in Exhibit E to the 2026 RFP, Idaho Power 23
described various points, including but not limited to 24
points associated with B2H, to which the market purchase 25
HACKETT, DI 26
Idaho Power Company
bids could be delivered, including points from which Idaho 1
Power has firm transmission capacity rights available for 2
imports of energy to its system and various Idaho Power 3
system border points. 4
Q. In Case No. IPC-E-22-13, In the Matter of5
Idaho Power Company’s Application for a CPCN to Acquire 6
Resources to be Online by 2023 to Secure Adequate and 7
Reliable Service to its Customers, the Commission issued 8
Order No. 35643 detailing its concerns regarding the 9
robustness of the 2021 RFP process. Do you believe that the 10
2026 RFP process applied to acquire the resources at issue 11
in this case adequately addresses the Commission’s 12
concerns? 13
A. Yes. In Order No. 35643, the Commission14
expressed concern that the 2021 RFP process applied to 15
acquire resources for 2023 was overly restrictive.14 The 16
2026 RFP process did not restrict bids based on resource 17
type or ownership structure. That is, the 2026 RFP allowed 18
bids for all commercially viable resource types. 19
Q. When were responses to the 2026 RFP due?20
A. Responses to the 2026 RFP were due to Idaho21
Power via the Zycus portal on June 23, 2023. The 2026 RFP 22
was well received, with 192 bids from 31 different bidders 23
14 Pgs. 12-13.
HACKETT, DI 27
Idaho Power Company
across 47 resources sites, summing to more than 15 1
gigawatts (“GW”) of resources. Over 75 percent of the bids 2
incorporated solar photovoltaic (“PV”) resources within 3
their portfolios, and over 60 percent incorporated energy 4
storage. The following summarizes the bids by resource 5
type: 6
Table 1 – Bids by Resource Type 7
Resource Type Number of Bids
Wind 14
Wind + Solar PV 2
Wind + BESS 3
Wind + Long-Duration Energy
Storage (“LDES”) 1
Wind + Solar PV + BESS 3
Solar PV 51
Solar PV + BESS 78
Solar PV + LDES 13
BESS 21
Geothermal 1
G2H 1
Market Purchase 4
Total 192
8
Approximately 40 percent of the bids reflected a 9
commercial operation date by June 1, 2026, the remaining 60 10
percent of the bids reflected a projected commercial 11
operation date after June 1, 2026. The bids included a 12
variety of ownership structures, including many bids that 13
would result in bidder-owned resources (i.e., PPA’s, and 14
BSA’s). In addition, as I mentioned earlier in my 15
testimony, Idaho Power received three benchmark bids across 16
three sites from the Internal Bid Team. Consistent with the 17
HACKETT, DI 28
Idaho Power Company
OPUC competitive bidding rules,15 Idaho Power reviewed the 1
benchmark bids for conformity with minimum bid eligibility 2
requirements, which was completed prior to the Evaluation 3
Team opening the third-party bids on June 26, 2023. 4
Q. Did all 192 proposals meet the criteria of the5
2026 RFP? 6
A. No. Following scoring and submittal of the7
benchmark bids, third party bids were screened against the 8
specified minimum requirements as described in Section 4.1 9
of the 2026 RFP and further defined in Exhibit C to the 10
2026 RFP (Bid Eligibility Checklist). Accordingly, and with 11
IE oversight, requests for clarification and/or additional 12
information were solicited from the bidders (including the 13
Internal Bid Team). With review and input from the IE, the 14
Company identified certain bids were non-conforming and 15
failed to meet the 2026 RFP’s initial bidder eligibility 16
requirements. 17
Q. Did Idaho Power notify the bidders that their18
projects did not meet the initial bidder eligibility 19
requirements? 20
A. Yes. Idaho Power issued a notice dated July21
17, 2023, notifying bidders with non-conforming submittals, 22
providing the bidders the opportunity to correct their bid 23
within five business days. Bidders unable to resolve the 24
15 OAR 860-089-0350.
HACKETT, DI 29
Idaho Power Company
eligibility concerns were removed from further 1
consideration. Concluding the eligibility screen on July 2
27, 2023, the number of conforming bids, including the 3
three benchmark resources, totaled 146, across 28 eligible 4
bidders, 43 resources sites, and over 12 GW of resources. 5
The 146 projects moved forward to the bid evaluation 6
process. 7
Q. Please explain the first step in the bid8
evaluation process. 9
A. The bid evaluation process is designed to10
identify the combination and size of the proposed resources 11
that will maximize the customer benefits while ensuring the 12
Company meets its energy and capacity needs. As described 13
in the 2026 RFP, Section 7.2 Phase 1 – Initial Shortlist, 14
eligible bids were evaluated to identify a subset of bids 15
that would be advanced for further evaluation. Each bid was 16
ranked within the respective technology group based on its 17
pricing and non-pricing scores. 18
Q.Were the pricing and non-pricing scores19
determined in accordance with the scoring methodology you 20
described earlier in your testimony that was reviewed and 21
approved under the OPUC competitive bidding rules? 22
A. Yes. The scoring methodology was consistent23
and prescriptive as described in the 2026 RFP. Based on the 24
diversity of the technology of the bids, and to ensure fair 25
HACKETT, DI 30
Idaho Power Company
and equitable evaluation of the bids, the Company 1
identified the need to group bids by their specific 2
technology and developed an initial shortlist within each 3
disparate technology group. 4
Initial Shortlist 5
Q. What considerations were made to develop the6
initial shortlist by technology group? 7
A. All eligible bids were evaluated, and a8
combined price and non-price score was established for each 9
technology grouping. Idaho Power desired a reasonable and 10
diversified quantity of projects that represented each 11
technology category meeting the following principles: (1) 12
minimum of three bidders/projects where sufficient bids 13
were included, (2) sufficient capacity/energy quantity to 14
meet the stated needs of the 2026 RFP, (3) technology 15
categories that only had one bid were automatically moved 16
forward to the initial shortlist, and (4) step increases to 17
price and total score were utilized as a natural cutoff. 18
The highest ranking and relatively lowest cost bids within 19
each technology category moved forward to the initial 20
shortlist. During this process, the Company identified 21
pertinent information for 19 proposals from five different 22
bidders that removed them from further evaluation and 23
excluded them from the initial shortlist. 24
25
HACKETT, DI 31
Idaho Power Company
Q. What information did Idaho Power obtain that1
led to the exclusion of the 19 proposals from the 2
evaluation process? 3
A. Fifteen bids were formally withdrawn, three on4
July 26, 2023, and 12 on August 9, 2023. One bid did not 5
provide an all-inclusive asset purchase price as required. 6
Another bid was submitted as a surplus interconnection and 7
therefore limited to the existing point of interconnection. 8
Due to the limited incremental capacity, the bid would not 9
provide sufficient benefit. Finally, two bids assumed the 10
Company would procure the BESS and the cost proposed 11
included installation of the BESS system and was not 12
competitive. 13
Q.How many proposals made up the resulting14
initial shortlist? 15
A. Before the initial shortlist was finalized, on16
July 27, 2023, Idaho Power provided its updated bid 17
eligibility and confidential initial shortlist to LEI. The 18
IE documented their initial evaluation and scoring of 19
conforming bids, providing a confidential review of 20
eligibility and initial shortlist report just one week 21
later, on August 2, 2023. As outlined in the 2026 RFP, 22
Section 7.2, on August 3, 2023, the Company notified 10 23
bidders whose projects did not rank in the pool for further 24
consideration to make the initial shortlist. Those bidders 25
HACKETT, DI 32
Idaho Power Company
whose proposed bids had been ranked in the pool for further 1
consideration to make the initial shortlist were also 2
notified and requested (1) any and all significant changes 3
to overall projects (including schedule modifications, 4
interconnection study results, or any other material 5
changes), and (2) firm cost inputs (including any changes 6
or modifications to project pricing), in accordance with 7
the 2026 RFP, Section 7.3 Phase 2 - Final Shortlist. 8
Bidders receiving this notification of the best and final 9
offer opportunity were considered to comprise the initial 10
shortlist. 11
Q. How many projects were on the initial12
shortlist? 13
A. The initial shortlist, which included all14
projects found to be conforming by both Idaho Power and 15
LEI, included 51 projects, and 15 bidders across 11 16
technologies. 17
Q.Was the Company’s determination of the initial18
shortlist reviewed by the IE? 19
A. Yes. On August 2, 2023, the August 2023 LEI20
Report was issued, included as Confidential Exhibit No. 5, 21
detailing LEI’s extensive review of Idaho Power’s bid 22
evaluation and scoring process and determination of the 23
initial shortlist. The August 2023 LEI report provides 24
extensive detail of the bid submittals including bidder 25
HACKETT, DI 33
Idaho Power Company
names, number of eligible proposals by each bidder, pricing 1
score for each bid, and finally the total price/non-price 2
score of each bid, by resource type. In their report, LEI 3
stated they found that the Company’s “approach was 4
reasonable, and the process was conducted in a fair and 5
impartial manner.”16 Next, consistent with the bid 6
evaluation and selection process outlined in the 2026 RFP, 7
additional analyses and due diligence of the initial 8
shortlist was performed to identify and select projects on 9
the final shortlist. 10
Final Shortlist 11
Q. What additional analyses and due diligence was12
performed on the initial shortlist projects to create the 13
final shortlist? 14
A. First, in accordance with the OPUC competitive15
bidding rules,17 Idaho Power retained the services of 16
Hendrickson Renewables, LLC (“Hendrickson”) to provide an 17
independent third-party review of site-specific critical 18
performance factors for wind and solar resources, including 19
but not limited to: (1) an evaluation of the Variable 20
Energy Resource assessments submitted with each applicable 21
proposal, (2) quantification of any potential impact on 22
energy production, and (3) adjustment, if any, to the P50 23
16 August 2023 LEI Report, page 5.
17 OAR 860-089-0400(5)(a).
HACKETT, DI 34
Idaho Power Company
Net Capacity Factor (“NCF”) including the associated 1
confidence level where differences are identified. The 2
Company incorporated Hendrickson’s proposed adjusted NCF’s, 3
as applicable, into the models for the wind and solar 4
resource types, as part of the final shortlist selection 5
process. 6
Q. What modeling was performed of the initial7
shortlist projects? 8
A. Idaho Power utilized AURORA, which allows for9
the use of a consistent common evaluation tool with 10
consistent common assumptions in that tool, for reasonable 11
evaluation results, and the relative ranking of the initial 12
shortlist project submittals to better identify those 13
projects that best meet the Company’s resource needs. Idaho 14
Power created ten AURORA scenarios to help compile the 15
final shortlist. The ten scenarios were created to capture 16
a wide range of B2H online dates, inclusion or exclusion of 17
the Southwest Intertie Project-North transmission line 18
(“SWIP-N”), natural gas price futures, carbon price 19
futures, and large load demand futures. These scenarios 20
were discussed and developed with the IE and OPUC Staff 21
prior to their use in final shortlist modeling. Projects 22
selected across the ten AURORA scenarios were considered 23
for inclusion on the final shortlist. 24
25
HACKETT, DI 35
Idaho Power Company
Q. Please describe the assumptions utilized in1
the ten different AURORA scenarios. 2
A. I will summarize the assumptions below. For3
further information regarding the AURORA modeling process, 4
see Exhibit No. 6 to my testimony. 5
Scenario #1 – July 2026 B2H with SWIP-N: 2023 IRP6
general base assumptions with the addition of7
SWIP-N. A July 2026 online date is assumed for8
B2H and includes a January 2027 online date for9
SWIP-N. SWIP-N is modeled as providing a 500 MW10
resource equivalent capacity from the Desert11
Southwest, in the winter months beginning in12
January 2027. The Company assumed that SWIP-N13
could provide 50 MW of resource equivalent summer14
capacity in 2029, and 100 MW starting in 203015
through the remainder of the 2023 IRP, given the16
anticipated solar buildout in the southwest.17
Scenario #2 – November 2026 B2H with SWIP-N: 202318
IRP general base assumptions with the addition of19
SWIP-N. A November 2026 online date is assumed20
for B2H to assess how an alternate B2H online21
date would affect the Company’s resource needs22
and includes a January 2027 online date for SWIP-23
N.Uses the additional SWIP-N assumptions of24
Scenario #1. 25
HACKETT, DI 36
Idaho Power Company
Scenario #3 – June 2027 B2H with SWIP-N: 2023 IRP1
general base assumptions with the addition of the2
SWIP-N but assumes a June 2027 online date for3
B2H to assess how an alternate B2H online date4
would affect the Company’s resource needs and5
includes a January 2027 online date for SWIP-N.6
Uses the additional SWIP-N assumptions of7
Scenario #1.8
Scenario #4 – July 2026 B2H without SWIP-N: 20239
IRP general base assumptions. A July 2026 online10
date is assumed for B2H.11
Scenario #5 – November 2026 B2H without SWIP-N:12
2023 IRP general base assumptions. A November13
2026 online date is assumed for B2H to assess how14
an alternate B2H online date would affect the15
Company’s resource needs.16
Scenario #6 – June 2027 B2H without SWIP-N: 202317
IRP general base assumptions and a B2H online18
date of June 2027 to assess how an alternate B2H19
online date would affect the Company’s resource20
needs.21
Scenario #7 – High Gas High Carbon: High gas high22
carbon assumptions utilized in the 2023 IRP. A23
July 2026 online date is assumed for B2H, and24
SWIP-N is not included. The high gas high carbon25
HACKETT, DI 37
Idaho Power Company
scenario adjusts the natural gas price and carbon 1
adder price forecasts as detailed in Exhibit No. 2
6. 3
Scenario #8 – Low Gas Zero Carbon: Consistent4
with the low gas zero carbon assumptions utilized5
in the 2023 IRP. A July 2026 online date is6
assumed for B2H, and SWIP-N is not included. The7
low gas zero carbon scenario adjusts the natural8
gas price and carbon adder price forecasts as9
detailed in Exhibit No. 6.10
Scenario #9 – 100 MW Large Load: Based on the11
“100 MW large load” scenario utilized in the 202312
IRP. A November 2026 online date is assumed for13
B2H, and SWIP-N is not included. Additionally, a14
100 MW large load is added, with the load15
forecast increased above the base load forecast,16
ramping in 2026 and full 100 MW peak load ramp17
beginning in 2027.18
Scenario #10 – 200 MW Large Load: Based on the19
“200 MW large load” scenario utilized in the 202320
IRP. A November 2026 online date is assumed for21
B2H, and SWIP-N is not included. A 200 MW large22
load is added, with the load forecast increased23
above the base load forecast, ramping in 2026 and24
2027 and full 200 peak load ramp beginning in25
HACKETT, DI 38
Idaho Power Company
2028. 1
Q. What were the results of the modeling of the2
initial shortlist projects under the ten AURORA scenarios? 3
A. At this point, my testimony will focus on the4
projects with a commercial operation date by June 1, 2026 5
(“2026 projects”), as those are the projects for which 6
Idaho Power is requesting approval in this proceeding. 7
Table 2 below presents 2026 projects selected at least once 8
across the ten AURORA scenarios and considered for 9
inclusion on the final shortlist. 10
Table 2. 2026 Projects Selected in AURORA Modeling 11
Scenarios. 12
Rank Resource
1 Market Contract: 5 Years
2 200 MW Solar + 100 MW BESS
3 200 MW Solar
4 150 MW BESS
5 150 MW BESS
6 50 MW BESS
7 100 MW BESS
8 100 MW Solar + 100 MW BESS
9 200 MW Solar + 50 MW BESS
10 10 MW Geothermal
13
Q. Were all ten 2026 projects moved to the final14
shortlist? 15
A. No. After compiling the full list of 202616
projects selected from the ten AURORA scenarios for the 17
final shortlist, certain 2026 projects selected in the 18
AURORA scenarios were not included in the final shortlist 19
HACKETT, DI 39
Idaho Power Company
due to cost and timing uncertainty related to 1
interconnection. Pursuant to Order 2023, issued by the 2
Federal Energy Regulatory Commission on November 6, 2023, 3
four of the projects selected through the AURORA scenarios 4
will be included in the transition cluster study that Idaho 5
Power is required to implement for all early-stage 6
generation interconnection queued projects. The transition 7
cluster is a 360-day study that started on January 1, 2024. 8
Therefore, the Company does not anticipate having results, 9
including interconnection network upgrade costs, until the 10
end of the fourth quarter of 2024. Another project was not 11
advanced because it was not in the generation 12
interconnection queue at all, and thus presented 13
significant uncertainty regarding deliverability and 14
potential upgrade costs. 15
Q. What were the resulting 2026 projects that16
moved to the final shortlist? 17
A. Confidential Exhibit No. 7 presents the 202618
projects that were included in the final shortlist which 19
are summarized in Table 3 below. 20
Table 3. Final Shortlist – 2026 Projects. 21
Rank Resource
1 Market Contract: 5 Years
2 200 MW Solar + 100 MW BESS
3 200 MW Solar
4 150 MW BESS
5 100 MW Solar + 100 MW BESS
6 200 MW Solar + 50 MW BESS
HACKETT, DI 40
Idaho Power Company
1
Q. Were any additional analyses performed on the2
final shortlist projects? 3
A. Yes. After the final shortlist of projects was4
derived from the ten AURORA scenarios and after exclusion 5
of the projects presenting significant interconnection cost 6
or timing risk, Idaho Power performed a portfolio 7
sensitivity analysis on the final shortlisted projects. The 8
intention of the portfolio sensitivity process was to 9
assess the various mixes of final shortlisted projects and 10
how their portfolio costs compare to each other in 11
potential variable futures. This sensitivity analysis 12
informed the comparative ranking of final shortlist 13
projects to each other. The portfolio sensitivity analysis 14
employed a two-step approach. The initial step involved 15
conducting a portfolio analysis to generate the portfolios 16
that will serve as the input for the subsequent stochastic 17
risk analysis. The second step entailed performing the 18
stochastic risk analysis, which involves running 60 19
iterations using four stochastic variables: natural gas 20
prices, load, hydroelectric generation, and carbon prices. 21
The ‘November 2026 B2H without SWIP-N’ transmission 22
scenario assumptions were used as the basis for final 23
shortlist portfolio sensitivity modeling. The November 2026 24
B2H online date was selected because a late-2026 date 25
HACKETT, DI 41
Idaho Power Company
results in a greater need for a resource in 2026, and 1
therefore impacts the development of a 2026 final shortlist 2
projects. The Company intends to pursue 2026 resources 3
until it gains sufficient certainty around a likely B2H in-4
service date. Because discussions with the SWIP-N developer 5
are still in progress, the no SWIP-N scenario was chosen as 6
the base assumption for the AURORA shortlist runs, aligning 7
with the assumption utilized for the 2023 IRP analysis. 8
Q. What were the results of the portfolio9
sensitivity analysis on the final shortlisted projects? 10
A. For each portfolio, the Company calculated key11
statistics from the stochastic risk analysis, including 12
mean, P25, median, and P75 to assess the impact of various 13
uncertainties on each portfolio's net present value (“NPV”) 14
costs. These statistical measures provided valuable 15
insights into the distribution of NPV costs and the 16
potential range of outcomes under different sensitivities. 17
To effectively evaluate the portfolios, the mean NPV was 18
employed as the primary ranking criterion as it prioritizes 19
portfolios with consistently lower NPV costs, indicating 20
their overall cost-effectiveness. In simpler terms, a lower 21
mean NPV implies that the portfolio is less susceptible to 22
unfavorable cost fluctuations compared to its counterparts, 23
thereby minimizing the financial impact to customers. 24
25
HACKETT, DI 42
Idaho Power Company
Q. Were any projects removed from the final1
shortlist because of the portfolio sensitivity analysis? 2
A. No. There was one project that was initially3
considered for the final shortlist under prior evaluations 4
but ultimately did not clear the AURORA Long-Term Capacity 5
Expansion optimization analysis. In the December 2023 LEI 6
Report, the IE found “the use of a portfolio sensitivity 7
(stochastic) analysis to test the performance of resources 8
within portfolios subject to external shocks to be a 9
sensible way to test the robustness of resources within 10
uncertain and volatile market conditions.”18 The December 11
2023 LEI Report, included as Confidential Exhibit No. 8, 12
includes the detailed portfolio sensitivity analysis, the 13
stochastic sensitivity portfolio summary and the resulting 14
portfolio rankings based on mean NPV costs. 15
Q. Did the OPUC competitive bidding rules require16
Idaho Power to request acknowledgement of the final 17
shortlist? 18
A. Yes. OAR 860-089-0500 requires the Company19
request the OPUC acknowledge the final shortlist resulting 20
from the 2026 RFP. Therefore, on December 8, 2023, Idaho 21
Power filed its request, along with the December 2023 LEI 22
Report, which outlines the entire procurement process and 23
extensive bid evaluation, in Docket UM 2255. In the 24
18 December 2023 LEI Report, page 63.
HACKETT, DI 43
Idaho Power Company
December 2023 LEI Report, the IE attested to the 1
reasonableness of the Company’s approach in identifying 2
bids for the final shortlist, indicating “[t]he process was 3
conducted with the utmost fairness and impartiality, 4
upholding the integrity of the selection process.”19 5
Q. Did the OPUC approve Idaho Power’s 2026 RFP6
final shortlist? 7
A. Yes. On February 22, 2024, the OPUC issued8
Order No. 24-055 approving the Company’s final shortlist 9
with two conditions: (1) the OPUC acknowledged the final 10
shortlist volume up to 1,100 MW of variable energy 11
resources and 350 MW of peak capacity to meet the 2026 and 12
2027 capacity needs as identified in the 2021 IRP, but 13
ordered Idaho Power to file a report with an explanation 14
and justification for any procurement volume in excess of 15
those amounts, and (2) the Company must retain the IE to 16
monitor and report on all contract negotiations, with the 17
IE reporting to OPUC Staff at least monthly on contract 18
negotiations and any impacts to pricing or bid withdrawals. 19
IV. PROJECTS NECESSARY TO FILL 2026 CAPACITY DEFIENCY20
Q. Has Idaho Power executed any contracts21
associated with the final shortlist projects? 22
A. Yes. Once the most cost-effective 202623
projects were identified, the Company began negotiations 24
19 Id., page. 8.
HACKETT, DI 44
Idaho Power Company
with developers for procurement of the resources necessary 1
to meet Idaho Power’s 2026 capacity deficit of 236 MW: (1) 2
the market purchase product, (2) the 3
200 MW solar PV plus 100 MW BESS project, and (3) a 4
benchmark resource, the Idaho Power-owned battery storage 5
facility providing up to 150 MW of operating capacity. Once 6
executed, the Company immediately filed a request for 7
approval of the market purchase agreement in Case No. IPC-8
E-24-12 because of the contractual deadline within the9
agreement. Idaho Power’s request in this case is only 10
associated with the Company-owned battery storage facility. 11
Q. The final shortlist shows a 200 MW 12
solar project as more cost-effective than the 150 MW 13
battery storage benchmark resource. Why is the Company not 14
pursuing acquisition of the third-ranked project for 15
meeting the 2026 capacity deficit? 16
A.While two of projects made the final 17
shortlist, in their proposals, indicated that, while 18
multiples variations of a 19
project were submitted, only one alternative was available 20
for procurement. That is, the third ranked 200 MW solar 21
facility is the same solar facility reflected in the second 22
ranked project, not a separate, additional 200 MW 23
solar facility. 24
25
HACKETT, DI 45
Idaho Power Company
Market Purchase Agreement 1
Q. Please describe the agreement associated with2
the market purchase. 3
A. The Confirmation between Powerex Corp. and4
Idaho Power Company dated March 12, 2024 (“Powerex 5
Agreement”), for which the Company requested approval of in 6
Case No. IPC-E-24-12, memorializes the market purchase 7
agreement between Powerex and Idaho Power, describing the 8
sale and purchase of the capacity-based product and firm 9
energy. The Powerex Agreement is a transaction pursuant to 10
an industry-standard master agreement, the WSPP, Inc. 11
Agreement. Under the Powerex Agreement, the Company will 12
have 200 MW firm capacity during the months June through 13
September, hours-ending 0700 – 2200 Pacific Prevailing 14
Time, seven days a week. Idaho Power may call on energy up 15
to the 200 MW for the hours specified, on a day-ahead 16
basis. The details of the Powerex Agreement are presented 17
in testimony filed in Case No. IPC-E-24-12. 18
200 MW Solar PV Plus 100 MW BESS 19
Q. Has Idaho Power executed any agreements with20
for the 200 MW solar PV plus 100 MW BESS project? 21
A. No. However, the Company has been working22
diligently with on both the PPA associated with the 23
200 MW solar PV facility as well as the BSA associated with 24
the 100 MW BESS and is nearing completion of the 25
HACKETT, DI 46
Idaho Power Company
agreements. If the parties are unable to reach an 1
agreement, Idaho Power will work with the developers of the 2
next most cost-effective projects for the procurement of 3
additional necessary resources. The Company has engaged 4
with the two developers regarding selection of their 5
projects on the final shortlist and they stand ready for 6
contract negotiations. Once executed, which could occur as 7
early as May 2024, Idaho Power will bring any agreements to 8
the Commission for approval. 9
150 MW Battery Storage Facility 10
Q. What is the process Idaho Power will apply to11
initiate procurement of the Idaho Power-owned battery 12
storage facility providing 150 MW of operating capacity? 13
A. Because the battery storage facility that will14
provide 150 MW of operating capacity located at Boise Bench 15
is a benchmark resource, an agreement associated with the 16
purchase of the BESS that details the construction, 17
operation and maintenance (“O&M”) of the system, such as a 18
build-transfer agreement, is not necessary. Rather, the 19
Company will initiate a purchase order with a battery 20
supplier and enter into a contract specific to the delivery 21
and contract price of the BESS. Upon notification of 22
selection by the Evaluation Team following approval by the 23
OPUC of the final shortlist, the Company’s Power Supply 24
department began discussions with suppliers for procurement 25
HACKETT, DI 47
Idaho Power Company
of the BESS but has not yet executed a purchase order. 1
Q. Will there be any additional contracts2
required for the energy storage project? 3
A. Yes. Idaho Power will also enter into a Long-4
Term Services Agreement for O&M services performed for the 5
energy storage project following commercial operation of 6
the project, similar to the battery storage resources that 7
came online in 2023 and the Idaho Power-owned projects that 8
will be in service in 2024 and 2025. 9
Q.Does Idaho Power believe the competitive10
bidding process has determined the least-cost, least-risk 11
resources to meet the identified capacity deficiencies? 12
A. Yes. The approval of the final shortlist for13
procurement of resources under the competitive bidding 14
rules is an extensive process, spanning nearly 15 months, 15
that employs a fair and competitive 2026 RFP process. This 16
15-month timeline was solely related to the 2026 RFP17
process and diligence; it did not include contract 18
negotiation, contract execution, material procurement, and 19
construction, which can take another two to four years, 20
depending on the resource. The RFP process began with the 21
engagement of an IE, with participation from OPUC Staff and 22
stakeholders throughout, and involved a comprehensive 23
eligibility screening process, the meticulous assessment 24
and scoring of the resource bids, including benchmark 25
HACKETT, DI 48
Idaho Power Company
resources, and a rigorous scenario analysis followed by a 1
portfolio sensitivity analysis of the final shortlist. At 2
the end of the process, the Company’s IE attested to the 3
reasonableness of Idaho Power's approach in identifying 4
bids for the final shortlist and stated the process was 5
conducted with the utmost fairness and impartiality, 6
upholding the integrity of the selection process.20 7
To meet the 2026 capacity deficiency, the Company 8
used the results from the final shortlist, selecting the 9
three most cost-effective projects identified through the 10
extensive competitive bidding process. The resources 11
presented in my testimony are necessary and required to 12
timely meet the Company’s resource needs and continue to 13
provide reliable and adequate service to Idaho Power’s 14
customers starting in the summer of 2026 and into the 15
future. 16
V. CONCLUSION17
Q. Please summarize your testimony.18
A. Idaho Power initiated the 2026 RFP process on19
September 15, 2022, and in accordance with the OPUC 20
competitive bidding rules, in order to provide peak 21
capacity and energy resources to help meet the Company’s 22
peak electric energy needs in 2026. The resources selected 23
through the fair and competitive procurement process 24
20 December 2023 LEI Report.
HACKETT, DI 49
Idaho Power Company
include a 200 MW capacity-based product and firm energy 1
market purchase, an Idaho Power-owned battery storage at 2
Boise Bench providing 150 MW of operating capacity and a 3
200 MW solar PV plus 100 MW BESS. Idaho Power’s request in 4
this case is only associated with the Company-owned battery 5
storage facility. Idaho Power requested Commission approval 6
of the Powerex Agreement in Case No. IPC-E-24-12 and will 7
request Commission approval of an agreement associated with 8
the 200 MW solar PV plus 100 MW battery storage project in 9
a future proceeding. The combined projects provide for the 10
least-cost and least-risk resources necessary for meeting 11
the 2026 capacity deficiency. 12
Q. Does this conclude your testimony?13
A. Yes.14
HACKETT, DI 50
Idaho Power Company
DECLARATION OF ERIC HACKETT 1
I, Eric Hackett, declare under penalty of perjury 2
under the laws of the state of Idaho: 3
1. My name is Eric Hackett. I am employed by4
Idaho Power Company as the Projects and Design Senior 5
Manager. 6
2. On behalf of Idaho Power, I present this7
pre-filed direct testimony and Exhibit Nos. 1, 2, 4, and 6 8
and Confidential Exhibit Nos. 3, 5, 7 and 8 in this matter. 9
3.To the best of my knowledge, my pre-filed10
direct testimony and exhibits are true and accurate. 11
I hereby declare that the above statement is true to 12
the best of my knowledge and belief, and that I understand 13
it is made for use as evidence before the Idaho Public 14
Utilities Commission and is subject to penalty for perjury. 15
SIGNED this 3rd day of April 2024, at Boise, Idaho. 16
17
Signed: _______________________18
19

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

EXHIBIT NO. 1
Observations on Idaho Power Company’s Draft
2026 All Source Request for Proposal s for Peak
Capacity and Energy Resources : Independent
Evaluator Assessment Report
Marie Fagan
Ma. Cherrylin Trinidad
Sayad Moudachirou
Barbara Porto
Bat-Erdene Baatar
Hannah Braun
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
March 1, 2023
Exhibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
2
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
Table of contents
LIST OF ACRONYMS ....................................................................................................................................... 3
1 EXECUTIVE SUMMARY .......................................................................................................................... 4
2 INTRODUCTION ...................................................................................................................................... 6
3 LEI’S OBSERVATIONS ON THE DRAFT RFP ..................................................................................... 8
3.1 IE’S RECOMMENDED ADJUSTMENTS TO THE NEXT ITERATION OF THE DRAFT RFP ...................................... 8
3.1.1 Resource needs .................................................................................................................................. 9
3.1.2 Benchmark bids ................................................................................................................................. 9
3.1.3 RFP schedule .................................................................................................................................. 10
3.1.4 Bid evaluation process ..................................................................................................................... 11
3.1.5 Imputed debt impact of PPAs ........................................................................................................... 14
3.1.6 IE access to submitted bids .............................................................................................................. 15
3.2 SUMMARY OF PROPOSED IMPROVEMENTS EXPECTED IN THE FINAL RFP .................................................. 16
4 STAKEHOLDERS’ COMMENTS ON THE DRAFT RFP ................................................................... 17
4.1 Q&A PAGE ON THE RFP WEBSITE ......................................................................................................... 17
4.2 IMPUTED DEBT ..................................................................................................................................... 17
4.3 CONTRACT TERM NORMALIZATION ....................................................................................................... 17
4.4 MODELING METHODOLOGY .................................................................................................................. 17
4.5 ASSUMPTIONS USED IN ASSESSING UTILITY OWNERSHIP BIDS .................................................................. 18
4.6 NON-PRICE SCORING METHODOLOGY .................................................................................................... 18
4.7 INTERCONNECTION AGREEMENTS AND SITE CONTROL ............................................................................ 18
4.8 FINAL SHORTLIST FEE ........................................................................................................................... 18
4.9 BENCHMARK BIDS ................................................................................................................................ 19
Table of figures
FIGURE 1. LIST OF LEI’S OUTSTANDING RECOMMENDATIONS TO THE DRAFT RFP ................................................. 4
FIGURE 2. LIST OF STAKEHOLDER COMMENTS ON THE DRAFT RFP ......................................................................... 5
FIGURE 3. DUTIES OF THE IE .................................................................................................................................. 6
FIGURE 4. SUMMARY OF OUTSTANDING RECOMMENDATIONS TO BE INCORPORATED IN THE FINAL RFP ................ 8
Exhibit No. 
Case No. IPCE
E. Hackett IPC
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3
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
List of acronyms
AS All Source
BEF Bid Entry Form
BTA Build-Transfer Agreements
COD Commercial online date
IE Independent Evaluator
IPC Idaho Power Company
IRP Integrated Resource Plan
LEI London Economics International LLC
LTSA Long-Term Service Agreements
NIPPC Northwest & Intermountain Power Producers Coalition
OAR Oregon Administrative Rules
OPUC Oregon Public Utilities Commission
PPA Power purchase agreement
Q&A Question and Answer
RFP Request for Proposals
S&P Standard & Poor's
SMM Scoring and modeling methodology
Exhibit No. 1
Case No. IPC-E-24-16
E. Hackett, IPC
Page 3 of 19
4
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
1 Executive Summary
London Economics International LLC (“LEI”) was retained to serve as the independent evaluator
(“IE”) of Idaho Power Company’s (“IPC” or “the Company”) 2026 All Source (“AS”) Request for
Proposals (“RFP”) for Peak Capacity and Energy Resources (“2026 AS RFP”). This report is the
first deliverable of this engagement, in which LEI provides its observations and recommendations
to the draft 2026 AS RFP (“draft RFP”) filed by IPC on February 22, 2023. This report also includes
a summary of stakeholders’ comments discussed during the online Introductory Stakeholder
Workshop (“Workshop”), which was hosted by IPC on February 21, 2023.
Although IPC incorporated some of LEI’s recommendations in the first version of the RFP,1 LEI
finds that there are still some outstanding comments and recommendations that were not
reflected in the draft RFP filed. These outstanding comments and recommendations are
enumerated in Figure 1 and discussed in detail in Section 3.
Figure 1. List of LEI’s outstanding recommendations to the draft RFP
Stakeholders present at the Workshop also had several comments on the draft R FP that they
received via email communication on February 15, 2023. These main comments are listed in
Figure 2 below and discussed in detail in Section 4.
1 LEI had a meeting with IPC to discuss its comments on the first version of the draft RFP on February 9, 2023. LEI
submitted (via email) a redline version of the draft RFP with comments to IPC on February 13, 2023.
4321 5
State clearly in the
RFP its preferred
resources and/or
portfolio and note
that this is subject
to change based on
the upcoming 2023
IRP
Provide the list
of prospective
benchmark bids
and provide
more
information
such as fuel
type, size, and
location
Revise the
proposed RFP
schedule to
provide
sufficient time
for the IE to
carry out its
responsibilities
Provide more
explanation and
examples, if
possible, on the
bid evaluation
process,
including the
scoring model
methodology and
selection of the
final short list
6
Exclude
imputed debt
from the bid
evaluation
process
Provide
information on
IPC’s approach
to contract term
normalization
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 4 of 1
5
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
Figure 2. List of stakeholder comments on the draft RFP
4321 5
Create a Q&A
page readily
accessible to the
public with all
stakeholder
questions and IPC
answers posted
Clarify or
remove imputed
debt from the
evaluation of
bids
Provide greater
clarity on the
methodology
for contract
normalization
Provide detailed
information on
IPC’s modeling
methodology
Provide
stakeholders
with the
assumptions to
be used in
assessing
utility
ownership bids
6 7 8 9
Confirm
eligibility of
Market
Resource
Alternatives
given RFP
interconnectio
n requirements
Confirm
whether the
final shortlist
fee will be due
and payable by
bidders
included in the
final shortlist
Provide a
detailed
overview of
the benchmark
bid
assumptions
and process
Assure
stakeholders that
modeling
assumptions (to be
used in bid
evaluations) will
be conservative/
reasonable
Exhibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
6
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
2 Introduction
IPC is in the process of issuing an RFP through which it seeks to procure up to 1,100 MW of
variable energy resources and at least 350 MW of peak capacity. This RFP is a response to the
resource needs identified in IPC’s 2021 Integrated Resource Plan (“IRP”) and its 2026 and 2027
incremental needs, as identified in its application in Docket 2255.
The Company, through this RFP, is soliciting bids for two types of products, namely (i) energy
and capacity delivered from electric resources such as solar PV, wind, geothermal, battery energy
storage, long duration storage, and gas-fired convertible to hydrogen,2 and (ii) firm energy that
meets the eligibility requirements of the Western Resource Adequacy Program.3 Resources can
be existing or new; new resources must have a target commercial operation date on or before June
2026 or June 2027. In addition to the bids expected to be submitted by developers, the Company
will also submit one or more affiliate bids, which will be evaluated using the same bid scoring
criteria as the other bids.
This RFP will be conducted under the oversight of the IE, to ensure that the RFP process is
conducted in a fair and reasonable manner. LEI,4 through a competitive bidding process, was
selected to be the IE for this RFP process. Per the Oregon Administrative Rules (“OAR”) 860-089-
0450, the IE’s duties include the items enumerated in Figure 3.
Figure 3. Duties of the IE
2 Idaho Power Company. Draft 2026 All Resource Request for Proposals. February 22, 2023. Tables 3-1 and 3-2. p. 15-16.
3 Idaho Power Company. Draft 2026 All Resource Request for Proposal. February 22, 2023. p. 13.
4 “IE” and “LEI” are used interchangeably throughout this report.
1
2
3
45
6
7
Be available and responsive to the
Commission throughout the process
Check whether IPC’s scoring of the
bids and selection of the initial and
final shortlists are reasonable
Evaluate the unique risks and
advantages associated with any
Company -owned resources (including
but not limited to the Company’s
benchmark) and apply the same
evaluation to third -party bids
Independently score the affiliate bids
and bids with ownership
characteristics or options, if any, and
all or a sample of the remaining bids
Oversee the competitive bidding
process to ensure it is conducted
fairly, transparently, and properly
Review the reasonableness of any
score submitted by the Company for a
benchmark resource
Consult with the Company on
preparation of the draft RFP and
submit its assessment of the final
draft to the Commission
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 6 of 1
7
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
This report is one of several reports that the IE will be filing with the Oregon Public Utilities
Commission (“OPUC” or “the Commission”) as part of its responsibilities. This report focuses on
LEI’s observations and recommendations on the draft RFP that was filed on February 22, 2023,
and additional information received from the Company as of February 27, 2023.
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 7 of 1
8
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
3 LEI’s observations on the draft RFP
The IE reviewed the draft RFP document Idaho Power's Draft 2026 All-Source Request for Proposals
(RFP) prior to its initial filing on February 22, 2023 in Docket UM 2255. The IE had limited time
to review the filed draft RFP before drafting this document. Following its initial review of the
RFP documents, the IE formally provided feedback to the IPC team on February 13, 2023 (with
the submittal of a redline version of the RFP document and its corresponding appendices)
consisting of an initial set of comments and recommendations to improve the overall clarity of
the RFP. Additional feedback was provided to the Company during follow-up calls on February
15, February 21, and February 27, 2023.
3.1 IE’s recommended adjustments to the next iteration of the draft RFP
IPC incorporated some of LEI’s suggestions in the draft RFP. However, LEI finds that some key
comments remain outstanding and were not reflected in the draft RFP filed on February 22, 2023.
LEI, as the IE, recommends that IPC incorporate in the final RFP the improvements listed in
Figure 4. In the following subsections, LEI describes in more detail LEI’s areas of concern and
proposed improvements that should be reflected in the final RFP.
Figure 4. Summary of outstanding recommendations to be incorporated in the final RFP
Note: For item #3 (“RFP schedule”), LEI believes that an amended schedule would also provide IPC with additional
time to review and implement the recommendations submitted/filed by the IE.
1) Preferred resources
2)Benchmark bids
Disclose the number of prospective benchmark bids IPC intends to submit
in the 2026 AS RFP and provide more information about these bids,such as
fuel type,size,and substation they will be connected to
4) Bid evaluation process
Provide more in -depth explanation of the evaluation process, including the
scoring model methodology and selection of the ultimate shortlist
IPC should state clearly in the body of the RFP its preferred resources
and/or portfolio(s) and mention that this preference is subject to change
based on the upcoming 2023 IRP
5)Contract term
normalization
Provide information on approach to contract term normalization
3) RFP schedule
Amend the schedule to allocate sufficient time to the IE to carry out tasks
that are critical to the independent review of the process
6)Imputed debt Remove imputed debt from the bid evaluation process (i.e., from the
review of PPAs and PPA terms)
Exhibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
9
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
3.1.1 Resource needs
In the draft RFP, IPC states that it targets resource procurement consistent with the 2021 IRP
analysis and provides the identified volumes and product attributes in “EXHIBIT E – Proposed
Market Purchase Volumes.” However, LEI suggests that IPC add to the body of the RFP the
preferred portfolio based on the 2021 IRP – similar to the information provided in “Table 1.1
Preferred Portfolio additions and coal exits (MW)” of the 2021 IRP.
Additionally, IPC mentioned in several meetings with the IE that the RFP’s stated resource needs
might change based on the upcoming 2023 IRP. LEI recommends that IPC update its resource
needs in the final RFP based on the 2023 IRP. If the 2023 IRP is not finalized/acknowledged before
the submission of the final RFP, IPC should clearly state that resource needs are subject to change
based on the upcoming 2023 IRP and provide as much information as possible with respect to the
direction in which resource needs are likely to change.5
3.1.2 Benchmark bids
In the RFP, IPC indicates its intention to submit benchmark bids—i.e., bids by its own affiliate.
IPC is thorough in discussing the separation of functions between the IPC team preparing the
benchmark bids and the IPC team evaluating these bids. Nevertheless, the draft RFP does not
contain any explanation of the approach that the Company will take with respect to the
prospective benchmark bids analysis.
We recommend that IPC, consistent with requirements of OAR 860-089-0300, include in the final
RFP an additional exhibit listing IPC’s proposed benchmark resources including, but not limited
to, the following information:
•the number of prospective benchmark bids IPC intends to submit in the 2026 AS RFP;
•the size (in MW) of the bids;
•status (new build vs. existing facility);
•target commercial online date (“COD”);
•technology;
•expected life;
•expected efficiency;
•type of product (resource-based or market purchase);
•interconnection status; and
•location.
5 LEI understands that the portfolio selection are dependent on the inputs from the bids and will be different from the
preferred portfolio listed in the IRP. However, LEI believes it still represents what technology/resource IPC’s
system is lacking and it is most likely to be selected in the evaluation process to fulfill IPC’s system needs.
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page  of 1
10
London Economics International LLC
717 Atlantic Avenue, Suite 1A
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www.londoneconomics.com
This was done by PacifiCorp in its most recent RFP (PacifiCorp 2022 All-Source RFP); IPC’s RFP
should likewise provide the same level of information (see Section 4.9).
3.1.3 RFP schedule
LEI has some concerns with the proposed RFP schedule in the draft RFP. First, IPC requires that
bidders submit their bids two weeks before the Company will review these submissions. More
specifically, the proposed schedule requires that bidders submit their bids on May 31, 2023, while
IPC would open these bids on June 13, 2023. LEI suggests changing the bid due date from May
31, 2023 to June 13, 2023 to give bidders more time to put together their submissions. Moving the
RFP bid due date to right after the filing of the IE’s review of the benchmark bids will also ensure
that AS bids are only opened after the benchmark bids are fully evaluated, consistent with the
requirements of OAR 860-089-0350.6
Second, the IE believes that—especially in
light of the uncertainty as to the number of
benchmark bids that will be submitted—the
proposed timeline provided to evaluate the
benchmark bids and file the IE’s associated
report (the Benchmark Bids Report) is tight
and will be insufficient to allow the IE to
carry out its independent review
thoroughly and accurately. Based on the
proposed schedule in Section 2.8 of the draft
RFP, the benchmark bids are due on May 31,
2023 and LEI is required to submit the
Benchmark Bids Report by June 12, 2023.
During this period, the IE is required to
complete several effort-intensive tasks: (i)
review and comment on IPC’s filing on its
evaluation of the benchmark resource(s),
which includes reviewing supporting cost
information, any applicable transmission
arrangements, and all other information
necessary to score the benchmark resource
(OAR 860-089-035(1));7 (ii) independently
score the benchmark bids and compare IE’s
6 OAR 860-089-0350(1) states that “Prior to the opening of bidding on an approved RFP, the electric company must file
with the Commission and submit to the IE, for review and comment, a detailed score for any benchmark
resource with supporting cost information, any transmission arrangements, and all other information
necessary to score the benchmark resource. The electric company must apply the same assumptions and bid
scoring and evaluation criteria to the benchmark bid that are used to score other bids.”
7 See Footnote 6.
The IE is required to evaluate Company-owned
resources on the following elements:
a.construction cost overruns;
b.reasonableness of forced outage rates;
c.reasonableness of any proposal or absence
of a proposal to offer electric Company-
owned or benchmark resource elements
(e.g., site, transmission rights or fuel
arrangements) to third-party bidders as
part of the draft and final RFP;
d.end effect values;
e.environmental emission costs;
f.reasonableness of operations and
maintenance costs;
g.adequacy of capital additions costs;
h.reasonableness of performance
assumptions for output, heat rate, and
power curve; and
i.specificity of construction schedules or risk
of construction delays.
Source: OAR 860-089-0450(6)(a-i)
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 10 of 1
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scores with the Company’s (OAR 860-089-0450(7))8 (iii) evaluate the unique risks and advantages
of the Company-owned resource(s) based on the items listed in the textbox on the right (OAR
860-089-0450(6)); and (iv) draft the IE Benchmark Bids Report.
In the absence of more detail on the number of benchmark resources IPC expects to bring forward,
LEI recommends setting aside a minimum of 3 weeks for the benchmark bids analysis. LEI
informed IPC about this concern with the schedule during a meeting held on February 27, 2023.
During this meeting, IPC verbally acknowledged that it would likely be able to move the
benchmark bids due date up by one week (no specific date was mentioned); LEI will look for this
adjustment to the schedule in the next iteration of the draft RFP that IPC will share with LEI
and/or OPUC.
3.1.4 Bid evaluation process
The scoring and modeling methodology (“SMM”) was not approved/acknowledged prior to
opening of the 2026 AS RFP through docket UM 2255. Therefore, the SMM must be approved
through the RFP process.9
LEI reviewed the SMM information provided as part of Section 7 of the 2026 AS RFP document
(“7. Bid Evaluation, Negotiation and Approval”) and accompanying exhibits (“EXHIBIT C – Bid
Eligibility Checklist” and “EXHIBIT D – Non-Price Scoring Matrix”). LEI also attended the
Workshop held on February 21, 2023, where IPC presented its proposed SMM. In addition, LEI
had conference calls with IPC on February 21, 2023, and February 27, 2023 to discuss the SMM in
detail.
Although the Workshop and the follow-up discussions with the Company provided additional
information on the SMM that was not provided in the draft RFP, LEI still has the following
concerns and provides some suggestions to help improve clarity as to how the bids will be
evaluated:
•Non-price score: IPC made the minimum bid requirements a self-scoring element of the
submission. LEI is concerned that some of the minimum bid requirement questions were
too broad and, combined with the binary structure of the non-price score (“yes/no”
answers that correspond with scores of “1/0,” respectively) would entice bidders to score
themselves favorably. In an extreme scenario where all bids score the maximum 25 points,
the non-price score will become irrelevant. LEI suggests IPC be more specific in drafting
the questions or criteria. For example, in the Bid Entry Form (“BEF”), under item number
9 “Bidder has demonstrated ability to achieve commercial operations by proposed date,” IPC
should instead list all documents that will be accepted as proof of proposed commercial
8 OAR 860-089-0450(7) states that “the IE must review the reasonableness of any score submitted by the electric
company for a benchmark resource.”
9 The Commission granted a partial waiver of OAR 860-089-250(2)(a) to allow concurrent consideration of both scoring
and modeling methodologies and the draft RFP. [source: In re Idaho Power Company, Approval of
Independent Evaluator Selection for 2026 All-Source Request for Proposal and Request for Partial Waiver of
OAR 860-0890250(2)(a), Docket No. UM 2255, Order No. 22-495 (Dec. 29, 2022)].
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 11 of 1
12
London Economics International LLC
717 Atlantic Avenue, Suite 1A
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operations. This would serve as a better guarantee of timely commencement of
commercial operations, which is a core concern for IPC.
In response to feedback from LEI (and stakeholders, as discussed in Section 4.6), IPC
prepared a new iteration of the non-price scoring BEF and shared this document with LEI
on February 24, 2023.10 In this document, IPC made a clear effort to address the concerns
raised by both parties. For example, IPC provided scoring scales, where criteria important
to IPC are scored on a 0-5-10 point basis, while less important criteria are scored on a 0-1-
2 or 0-3-6 scale. Here, rather than maintain the binary structure of the non-price score, IPC
elaborated on what constitutes a “no” or “yes” response, and—for applicable criteria—
also provided the option of checking off an in-between box11 for which neither “yes” nor
“no” apply (i.e., a project has no site control (“no” response), is in the process of acquiring
site control (“in-between” response), or has full site control (“yes” response)). The
descriptions for both the criteria and the scales were also improved upon, as requested by
both LEI and stakeholders.
While this is welcome progress, LEI requested additional clarity and documentation on
the methodology during a discussion with IPC on February 27, 2023. As such, the non-
price scoring methodology is still a work in progress:
o LEI asked why the weighting calculations for each of the “no,” “yes,” and “in-
between” options were different; this was an error on IPC’s part.
o LEI also requested that IPC make clear in the Exhibit B, C, and D that bids can
receive scores of anywhere between 0 (if a bidder enters “no” for each criterium)
and 25 (if a bidder enters “yes” for each criterium).
o In terms of clarity, LEI had two specific recommendations. First, some descriptions
of criteria could benefit from additional fine-tuning. For example, “does not have
a defined site” under the “no” option of the “site control” criterium could be open
to interpretation. It may be clearer to directly refer to the lack of documentation to
prove progress towards achieving site control. Second, some criteria that were left
as binary scores could benefit from an “in-between” option; for instance, a bidder
may be in the process of negotiating debt and/or equity terms for its project, but
would not be able to make this known to IPC without such “in-between” choice.
The next iteration of the BEF and RFP that will be prepared by IPC should reflect some of
LEI’s comments on how to improve scoring.
10 Please note that this file has not yet been made publicly available (or available to bidders).
11 This language (“in-between”) is descriptive and is meant to explain the structure of the three new options provided
for each criterium of the BEF. This is not IPC’s language/terminology.
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 12 of 1
13
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
•Price scoring model: The description of the price scoring methodology in the draft RFP is
currently at a high level only. LEI recommends that, for the Final RFP, IPC expand on the
description of the model to at a minimum include:
o a brief description of the methodology of the scoring model;
o inputs used in the model and model outputs;
o clarity on how the energy and capacity components of bids will be
valued/calculated and compared across bids;
o clarity on how balancing flexibility is valued/calculated, if applicable; and
o an example of scores produced for five hypothetical bids of different product
types/technologies.
•Contract term normalization: LEI understands from our discussions with the Company
that the Company does not want to potentially exclude shorter-term PPAs and therefore
provided the option to the bidders to have a term up to 35 years. However, the draft RFP
does not provide any information on how PPAs with different terms will be evaluated.
IPC explained to LEI (on the February 27, 2023 conference call) that contract normalization
would be calculated for proposed utility owned assets and not for PPA bids; LEI does not
find this to be perfectly clear in the draft RFP. Furthermore, IPC explained to LEI that
contract normalization would be calculated as an annualized (levelized) cost, similar to
what IPC does in its IRP. This is neither sufficiently articulated in the draft RFP, nor has
IPC provided any step-by-step methodology or example of how this would work. To
fulfill its role as IE, LEI will need access to such information. To be transparent, IPC also
needs to make this information clear to stakeholders.
•Shortlist selection: Although the draft RFP mentions that the bids will be evaluated using
AURORA, LEI recommends that IPC include in the final RFP an additional exhibit
describing in detail how the AURORA model will evaluate and select bids. LEI expects,
at a minimum, to see the following information in the description of the price scoring
model:
o the ultimate cost metric input to the AURORA model (will it be the levelized cost
of capacity, levelized cost of energy, or a combination of both? If a combination,
how do they interact?);
o all inputs to the AURORA model, distinguishing the inputs that must be provided
by the bidder and the ones that will be calculated by IPC;
▪a description of the inputs calculated by IPC, including how they are
calculated and the internal assumptions by product type/technology;
▪a description of assumptions to be made by IPC for data inputs not
provided/available in the bid (e.g., cost of interconnection).
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14
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
o the ultimate output from the AURORA model;
o the inputs/outputs of the model provided in graphical form; and
o the expected stochastic iterations that will be performed as part of the final
shortlist selection (or refer to the latest acknowledged IRP, if it is already described
there).
LEI also notes that, as of writing of this report, LEI has not received the models and assumptions
relevant to the SMM and shortlist selection process. LEI will review the assumptions and model
and will provide a further review of the bid evaluation process in a subsequent IE report (s) once
the information is provided by IPC.
3.1.5 Imputed debt impact of PPAs
Debt rating agency Standard and Poor’s (“S&P”) notes that PPAs create “fixed, debt-like, financial
obligations that represent substitutes for debt-financed capital investments.“12 The IPC draft RFP
noted that “PPAs bring added costs beyond the direct contract costs in the form of imputed debt.
IPC will estimate the additional cost of imputed debt for each PPA, BSA or other third-party
owned asset and add this cost to the overall cost of a project.”13
LEI recommends not allowing IPC to add the cost of imputed debt to any of the bids for the
purposes of bid evaluation. There is precedent for not including an imputed debt analysis as part
of a bid evaluation process. In 2003, Portland General Electric issued an RFP noting that “it would
add the costs associated with the fixed obligations for purchased power into its bid price analysis
as debt equivalents.”14 The Commission ruled that “the leverage adjustment described [in] the
RFP will not take place. Instead, a leverage adjustment will be considered during the post -bid
process.”15
There are several reasons for excluding imputed debt from consideration:
•The impact of imputed debt is only one factor in comparing financial structures across
bids. A PPA or other third party-owned asset represents a different set of risks and returns
than a utility-built asset, and the impact on credit ratings (and thereby the cost of debt) is
only one of a variety of such risks and benefits. For example, under a PPA, the developer
12 Standard & Poor’s. Standard & Poor's Methodology for Imputing Debt for U.S. Utilities' Power Purchase Agreements. May
2007. p. 1.
13 Idaho Power Company. Draft 2026 All Resource Request for Proposal. February 22, 2023. p. 29.
14 Electric Power Supply Association. Electric Utility Resource Planning: The Role of Competitive Procurement and Debt
Equivalency. Prepared by GF Energy LLC. July 2005 [Citing direct testimony of Wayne Oliver on behalf of the
Utah Division of Public Utilities in Docket No. 04-035-30 before the Public Service Commission of Utah,
September 27, 2004].
15 Ibid. [Citing UM 1080, Order No. 03-387, as reported by Wayne Oliver testifying before the Public Service
Commission of Utah, September 27, 2004].
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 14 of 1
15
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
takes all risk of development, construction, and operating cost overruns, performance
shortfalls, and technology obsolescence. The value of this risk could offset, or potentially
more than offset, the impact of additional imputed debt. If IPC wants to account for
impacts of imputed debt on its credit rating, it should perform a holistic examination of
all the risk (and risk-mitigating) factors of PPAs versus those of utility-built and utility-
owned options. In addition, the impact on ratepayers as well as shareholders should be
part of the calculation; utility-owed assets earn a rate of return on equity, which increases
the cost to ratepayers, while PPAs do not. If a PPA’s bid price is increased based on its
impact on debt, then the equity portion of a utility-owned bid should be increased by the
utility’s cost of capital.
•Adoption of complex methodology would require expert scrutiny. LEI does not have
significant expertise in utility capital lease accounting. However, S&P’s published
materials indicate that the calculation of imputed debt includes only the capacity portion
of PPA costs and the impact of depreciation, both of which reduce the impact on imputed
debt.16 S&P also multiplies the financial results by a risk factor that is inversely related to
the strength and availability of regulatory mechanisms used for the recovery of PPA costs.
A utility that is allowed to pass the PPA cost to customers via rates already has a recovery
mechanism, which implies a lower risk factor and a smaller impact on the cost of debt.
S&P also notes that “PPAs that are treated as capital leases [by the utility] for accounting
purposes will not receive PPA treatment because capital lease treatment indicates that the
plant under contract economically ‘belongs" to the utility.’”17 This level of complexity
implies that expert scrutiny of IPC’s methodology by a utility accounting expert would be
required, to ensure fairness to bidders.
•The inclusion of imputed debt would result in an untransparent solicitation process. If
IPC were allowed to add this charge as part of its bid assessment, it would not be possible
for bidders to know prior to submission the magnitude of additional costs that IPC would
be adding to their respective bids. IPC must provide its proposed methodology to the IE
and OPUC Staff for review. If imputed debt is ultimately allowed by the OPUC, the model
and its results (for IPC’s own bids) must be made available to each bidder.
3.1.6 IE access to submitted bids
Lastly, to make this evaluation possible, the IE will require access to all bids submitted as part of
this solicitation. LEI had a discussion on this with IPC on February 27, 2023. Based on that
discussion, one option would be to grant LEI access to IPC’s Zycus pro curement software. This
would not only allow LEI to access all submitted bids and bid forms, but would also allow LEI to
ensure that no submitted bids were opened or reviewed prior to the Commission -approved bid
review date. Assuming that IPC follows through with its intent to move the bid submission date
to the bid review date, as discussed on February 27, 2023, then the latter is no longer a concern.
16 Standard & Poor’s. Standard & Poor's Methodology for Imputing Debt for U.S. Utilities' Power Purchase Agreements. May
2007. p. 3 and p. 5.
17 Ibid. p. 6.
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 15 of 1
16
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
For security reasons, also discussed on February 27, 2023, it may not be feasible or practical for
non-IPC staff to have access to Zycus, through which users can access more than just the
submissions of this RFP. Thus, IPC agreed to share all bid documents through an alternative data
room or data sharing platform. IPC also volunteered to share via this data room the audit reports
produced by Zycus, which detail what Zycus users accessed/opened what documents at specific
times.
3.2 Summary of proposed improvements expected in the final RFP
In summary, LEI recommends the following improvements to be incorporated in the final RFP.
These adjustments will make the solicitation process clearer and more transparent to all
stakeholders:
i.add to the body of the RFP the Company’s target procurement mix based on the latest
acknowledged IRP and disclose if the needs are expected to change during the 2026 AS
RFP process;
ii.incorporate an additional exhibit disclosing prospective benchmark bids;
iii.extend the AS bid deadline to after the benchmark bids are evaluated by the IE;
iv.make self-scoring non-price questions less subjective and fine-tune the weighting
calculation;
v.provide information on IPC’s approach to contract normalization;
vi.expand on the description of the price scoring model;
vii.incorporate an additional exhibit expanding on the bid evaluation process; and
viii.exclude the cost of imputed debt for the purpose of bid evaluation.
LEI also looks forward to receiving data room access, once that is set up and once bids are filed.
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 16 of 1
17
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
4 Stakeholders’ comments on the draft RFP
On February 23, 2023, IPC hosted the “Introductory Stakeholder Workshop on AS RFP and SMM”
virtually via Microsoft Teams, to introduce its all-source RFP to interested stakeholders. IPC
presented the Company’s target procurement mix—in terms of resource type, procurement type
(asset purchase or PPA), contract duration, transmission arrangements, and commencement of
commercial operations, among other eligibility criteria. Based on Microsoft Teams’ list of virtual
meeting participants, over 50 stakeholders joined this Workshop. These stakeholders represented
various organizations, including the Company, the Commission, consultants, and generators.
4.1 Q&A page on the RFP website
Stakeholders expressed their interest in having access to a Q&A page, or some portal where both
bidders and the general public can access any information posted pertaining to this RFP. Such
Q&A page has been helpful to stakeholders in past Oregon RFPs. IPC confirmed that it would be
making such portal available on its website. Non-bidders will likewise be able to access the
questions and answers posted.
4.2 Imputed debt
Stakeholders expressed concern about this provision of the RFP, and particularly the lack of detail
on this issue provided in the RFP. Northwest & Intermountain Power Producers Coalition
(“NIPPC”) in particular noted that this provision would likely be a point of contention, describing
it both as “very concerning” and “a black box”; the RFP does not make clear the magnitude to
which imputed debt will impact bid evaluations, and as such would not like to see imputed debt
be used as an adder to bids.
4.3 Contract term normalization
Stakeholders are of the view that IPC is likely to receive bids with contract terms of less than 35
years, and did not find that the proposed approach to term normalization has been made clear.
In response, the utility stated that it would use annualized payments for normalization and
would not use other methods such as "filling in” bids for the difference between 35 years and the
proposed contract term (i.e., IPC would not fill in 15 years’ worth of bids if a project were to
propose a 20-year contract term).
4.4 Modeling methodology
It was unclear to stakeholders what methodology IPC intends to use to assemble the initial
shortlist of approved bids. Namely, stakeholders sought clarity on whether the utility would be
performing portfolio modeling and how AURORA (IPC’s modeling tool) results would be used
once levelized prices are obtained.
In addition to the long-term capacity expansion model, the utility will also run a stochastic model.
Unlike the capacity expansion model, the purpose of the stochastic analysis is to ensure winning
projects provide the Company with the optimal mix of resources (supply) and risk.
Exhibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
18
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
4.5 Assumptions used in assessing utility ownership bids
According to stakeholders, IPC’s RFP also lacks detail on the assumptions that IPC will use in the
evaluation of utility ownership bids.
4.6 Non-price scoring methodology
Stakeholders had three main concerns with respect to non-price scoring:
•the 25 percentage points for non-price scoring provided in the RFP would benefit from a
more granular breakdown to help bidders understand (1) the mechanics of non-price
scoring and (2) IPC’s prioritized items/elements;
•some of the non-price scoring items were described as subjective. More objective criteria
would be preferrable; and
•it was also pointed out that not all non-price scored items will be applicable to all
resources for which bids are submitted into this RFP. This makes it unclear as to the
number of points those projects would receive.
While stakeholders agreed with the concept of self-scoring, greater insight into scoring would
still be appreciated. IPC stated that it will take this feedback back for consideration.
4.7 Interconnection agreements and site control
Based on the RFP, it seems that IPC is only accepting bids with network interconnections. It was
suggested that it would also be useful to allow Market Resource Alternatives (“MRAs”) to bid
here, as well. For example, there may be some initially developed projects interested in this RFP
that would have difficulty switching from MRA classification. The question, then, is if IPC would
be willing to accommodate such bids. IPC will have to think about this; to the Company, a
dispatchable resource tends to be a network resource. Perhaps energy side bids would be
applicable, but IPC will need to take this question back for consideration.
Furthermore, in response to a separate question, IPC confirmed that generation projects—which
are obligated to have binding and exclusive site control—must have ties that lead to IPC’s
transmission system. In other words, IPC expects that projects have both site control and are able
to deliver into the IPC system.
4.8 Final shortlist fee
Some stakeholders expressed concern over the inclusion of an additional fee to be paid by bidders
in order to be included in IPC’s final shortlist of projects. Though IPC has included this clause in
its previous RFPs, the Company has tended not to collect these fees. IPC will review this clause.
Exhibit No. 1
Case No. IPCE2416
E. Hackett, IPC
Page 18 of 1
19
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
4.9 Benchmark bids
One stakeholder commented that the RFP also lacks any detail on the benchmark bid process .
The analytical approach to the benchmark bid analysis should be discussed in the RFP; if the
utility chooses to forego inclusion of a benchmark bids process, then it should explain its rationale
for doing so in the RFP.
Exhibit No. 1
Case No. IPC-E-24-16
E. Hackett, IPC
Page 19 of 19

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

EXHIBIT NO. 2
Observations on Idaho Power Company’s Updated
Draft 2026 All Source Request for Proposal s for
Peak Capacity and Energy Resources : Second
Independent Evaluator Assessment Report
Marie Fagan
Ma. Cherrylin Trinidad
Sayad Moudachirou
Barbara Porto
Bat-Erdene Baatar
Hannah Braun
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
May 10, 2023
E[hibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
2
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
Table of contents
LIST OF ACRONYMS ....................................................................................................................................... 3
1 EXECUTIVE SUMMARY .......................................................................................................................... 4
2 INTRODUCTION ...................................................................................................................................... 5
3 LEI’S OBSERVATIONS ON THE UPDATED DRAFT RFP AND RECOMMENDATIONS ........... 7
3.1 IE’S RECOMMENDED ADJUSTMENTS TO THE FINAL RFP ............................................................................ 7
3.1.1 Resource needs .................................................................................................................................. 7
3.1.2 Benchmark bids ................................................................................................................................. 8
3.1.3 RFP schedule .................................................................................................................................... 9
3.1.4 Bid evaluation process ..................................................................................................................... 10
3.1.5 Imputed debt impact of PPAs ........................................................................................................... 11
3.1.6 Draft PPAs and BSAs ...................................................................................................................... 13
3.1.7 Draft solar PPA (Exhibit H)............................................................................................................. 16
3.1.8 Draft BSA (Exhibit H) ...................................................................................................................... 16
3.1.9 BTA (Exhibit H) ............................................................................................................................... 17
3.2 SUMMARY OF PROPOSED IMPROVEMENTS EXPECTED IN THE FINAL RFP .................................................. 18
4 COMMENTS ON AURORA ASSUMPTIONS AND MODELING................................................... 20
4.1 ASSUMPTIONS USED IN THE MODEL ....................................................................................................... 20
4.1.1 Load forecasts ................................................................................................................................. 20
4.1.2 Resources ........................................................................................................................................ 20
4.1.3 Fuel prices ...................................................................................................................................... 20
4.1.4 Calculation of the Effective Load Carrying Capability (“ELCC”) .................................................... 21
4.1.5 Scenarios......................................................................................................................................... 21
4.2 DRAFT FINANCIAL MODEL..................................................................................................................... 23
Table of figures
FIGURE 1. LIST OF LEI’S OUTSTANDING RECOMMENDATIONS TO THE UPDATED DRAFT RFP .................................. 4
FIGURE 2. DUTIES OF THE IE .................................................................................................................................. 5
FIGURE 3. IPC’S PROPOSED SENSITIVITIES ............................................................................................................. 22
FIGURE 4. LCOC FORMULA ................................................................................................................................. 23
FIGURE 5. IPC’S KEY FINANCIAL ASSUMPTIONS.................................................................................................... 23
FIGURE 6. IPC’S PROJECT LIFE ASSUMPTIONS ........................................................................................................ 24
E[hibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
3
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
List of acronyms
AEO Annual Energy Outlook
AS All Source
BEF Bid Entry Form
BSA Battery Storage Agreement
BTA Build-Transfer Agreement
COD Commercial Operations Date
EIA Energy Information Administration
ELCC Effective Load Carrying Capability
IE Independent Evaluator
IPC Idaho Power Company
IPUC Idaho Public Utilties Commission
IRP Integrated Resource Plan
ISL Initial Shortlist
LCOC Levelized Cost of Capacity
LCOE Levelized Cost of Energy
LEI London Economics International LLC
LTCE Long Term Capacity Expansion
NIPPC Northwest & Intermountain Power Producers Coalition
NREL National Renewable Energy Laboratory
OAR Oregon Administrative Rules
OPUC Oregon Public Utilities Commission
PPA Power Purchase Agreement
PVRR Present Value Revenue Requirement
RFP Request for Proposals
ROFO Right of First Offer
RTE Round-Trip Efficiency
SMM Scoring and Modeling Methodology
Exhibit No. 2
Case No. IPC-E-24-16
E. Hackett, IPC
Page 3 of 24
4
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
1 Executive Summary
London Economics International LLC (“LEI”) was retained to serve as the Independent Evaluator
(“IE”) of Idaho Power Company’s (“IPC” or “the Company” or “Idaho Power”) 2026 All Source
(“AS”) Request for Proposals (“RFP”) for Peak Capacity and Energy Resources (“2026 AS RFP”).
This report is the second deliverable of this engagement, in which LEI provides its observations
and recommendations to the updated draft 2026 AS RFP (“updated draft RFP”) filed by IPC with
the Oregon Public Utilities Commission (“OPUC” or “the Commission”) in Docket UM 2255 on
April 5, 2023.
Although IPC incorporated some of LEI’s recommendations from the first IE Assessment Report1
(“first IE Report”) in this updated version of the RFP, LEI finds that there are still a few
outstanding comments and recommendations that were not reflected in the filed updated draft
RFP. These outstanding comments and recommendations are enumerated in Figure 1 and
discussed in detail in Section 3.
Figure 1. List of LEI’s outstanding recommendations to the updated draft RFP
1 The first Independent Evaluator Assessment Report was issued on March 1, 2023.
1) Preferred resources
2)Benchmark bids
Disclose the number of prospective benchmark bids IPC intends to submit in the 2026 AS
RFP and provide more information about these bids,such as fuel type,size,and
substation they will be connected to
4) Bid evaluation process
Provide more information in the final RFP on the following: model that will be used to
evaluate the bids, and potential changes to the methodology (that is based on the 2021
IRP) as a result of the upcoming 2023 IRP
State clearly that resource needs are subject to change based on OPUC’s approval of the
upcoming 2023 Integrated Resource Plan (“IRP”)
5) Contract term
normalization
Provide more details on the approach to contract term normalization
3) RFP schedule
Amend the RFP schedule to provide the IE with sufficient time to perform the various
analyses and draft the remaining reports
6) Imputed debt
Remove imputed debt from the bid evaluation process and the financial model
8) Draft Build -Transfer
AJUHHPHQWV ´BTAVµ
Provide more clarity on the length and substantive requirements of the BTA’s duration
and essential prerequisites
Incorporate performance guarantees
7) Draft power purchase
DJUHHPHQWV ´PPAVµ
Modify several provisions in the draft PPAs, such as delay damages, right to terminate,
facility operations requirements, performance guarantee, and round -trip efficiency
requirement
Delete some provisions in the draft PPAs, such as the right of first offer clause, references
to OPUC approvals, solar forecasting costs, and references to special contract and Idaho
Power’s customer
9) Scenario analysis
Incorporate a sensitivity analysis wherein the Boardman to Hemmingway transmission
line (“B2H”) project experiences an extended delay
Exhibit No. 2
Case No. IPCE2416
E. Hackett, IPC
Page 4 of 24
5
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
2 Introduction
IPC issued its updated draft RFP on April 5, 2023, through which it seeks to procure up to 1,100
megawatts (“MW”) of variable energy resources and at least 350 MW of peak capacity. This RFP
is a response to the resource needs identified in IPC’s 2021 Integrated Resource Plan (“IRP”) and
its 2026 and 2027 incremental needs, as provided in its application in Docket UM 2255.
The Company, through this RFP, is soliciting bids for two types of products, namely (i) energy
and capacity delivered from electric resources such as solar PV, wind, geothermal, battery energy
storage, long duration storage, and gas-fired units convertible to hydrogen,2 and (ii) firm energy
that meets the eligibility requirements of the Western Resource Adequacy Program.3 Resources
can be existing or new; new resources must have a target commercial operation s date (“COD”)
on or before June 1, 2026 or June 1, 2027. In addition to the bids expected to be submitted by
developers, the Company will also submit one or more benchmark bids, which will be evaluated
using the same bid scoring criteria that apply to third-party bids.
Figure 2. Duties of the IE
Source: OAR 860-089-0450
2 Idaho Power Company. Draft 2026 All Resource Request for Proposals. February 22, 2023. Tables 3-1 and 3-2. p. 15-16.
3 Idaho Power Company. Draft 2026 All Resource Request for Proposal. February 22, 2023. p. 13.
1
2
3
45
6
7
Be available and responsive to the
Commission throughout the process
Check whether IPC’s scoring of the
bids and selection of the initial and
final shortlists are reasonable
Evaluate the unique risks and
advantages associated with any
Company -owned resources (including
but not limited to the Company’s
benchmark) and apply the same
evaluation to third -party bids
Independently score the affiliate bids
and bids with ownership
characteristics or options, if any, and
all or a sample of the remaining bids
Oversee the competitive bidding
process to ensure it is conducted
fairly, transparently, and properly
Review the reasonableness of any
score submitted by the Company for a
benchmark resource
Consult with the Company on
preparation of the draft RFP and
submit its assessment of the final
draft to the Commission
Exhibit No. 2
Case No. IPCE2416
E. Hackett, IPC
Page 5 of 24
6
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
This RFP process will be overseen by the IE to ensure that it is conducted in a fair and reasonable
manner. LEI,4 through a competitive bidding process, was selected to be the IE for this RFP
process. Per the Oregon Administrative Rules (“OAR”) 860-089-0450, the IE’s duties include the
items enumerated in Figure 2 above.
This report is the second IE report and one of several reports that the IE will be filing with the
OPUC as part of its responsibilities. This report focuses on LEI’s observations and
recommendations on the updated draft RFP that was posted on the Company’s RFP website5 on
April 5, 2023, and additional information received via email from the Company as of May 8, 2023.
4 “IE” and “LEI” are used interchangeably throughout this report.
5 See: zsn.zycus.com/zsp/guest/genericRegister/IDA822
Exhibit No. 2
Case No. IPCE2416
E. Hackett, IPC
Page 6 of 24
7
London Economics International LLC
717 Atlantic Avenue, Suite 1A
Boston, MA 02111
www.londoneconomics.com
3 LEI’s observations on the updated draft RFP and recommendations
The IE conducted a comprehensive review of the updated draft RFP for Idaho Power's Draft 2026
All-Source RFP, dated April 5, 2023, which was published on the IPC RFP 2026 website6 (a web
page on the Company’s website dedicated to this RFP) and on an RFP portal (the Company’s
solicitation platform called Zycus).7 Additional feedback and inquiries on the draft RFP were
conveyed by LEI to the Company through email correspondences dated April 5, 2023, April 12,
2023, and April 26, 2023. Idaho Power provided respons es to these comments and questions
posed by LEI on April 7, 2023, April 14, 2023, and May 8, 2023.
3.1 IE’s recommended adjustments to the final RFP
IPC incorporated into the draft RFP several of LEI’s suggestions from the first IE Report.
However, LEI finds that some major comments were not reflected in the updated draft RFP filed
on April 5, 2023. The IE recommends that IPC incorporate in the final RFP these improvements
to several areas of the document; these improvements are described in detail in the following
subsections.
3.1.1 Resource needs
In the first IE Report, LEI proposed two recommendations aimed at clarifying the Company's
resource needs: (i) adding the Company’s preferred portfolio of resources from its 2021 IRP into
the body of the RFP and (ii) updating the resource needs provided in "EXHIBIT E – Proposed
Market Purchase Volumes" of the final RFP based on available 2023 IRP data.
Regarding the first suggestion, IPC chose not to include a preferred portfolio in the RFP document
because the Company does not have any specific resource preferences. Instead, IPC is open to all
bidder proposals and prefers to evaluate each type of resource that is bid into the solicitation.8
LEI does not have any issue with this strategy.
Regarding the second suggestion, in line with its suggestion in the first IE Report, LEI still expects
IPC to update its resource needs in the final RFP based on the 2023 IRP. If the 2023 IRP is not
finalized or acknowledged before the submission of the final RFP, IPC should clearly state in the
RFP that resource needs are subject to change based on the upcoming 2023 IRP . The Company
should likewise provide as much information as possible regarding the anticipated changes.9
6 See: https://idahopower.com/about-us/doing-business-with-us/request-for-resources/
7 See: zsn.zycus.com/zsp/guest/genericRegister/IDA822
8 IPC’s responses to LEI’s comments dated April 5, 2023, shared via email communication on April 12, 2023.
9 LEI understands that IPC’s ultimate portfolio selection will be dependent on the makeup of the submitted bids and
will thus be different from the preferred portfolio listed in the Company’s IRP. However, LEI believes that
the preferred portfolio described in the Company’s 2021 IRP provides stakeholders with an understanding of
E[hibit No. 
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3.1.2 Benchmark bids
In the first IE Report, LEI noted that the draft RFP provides limited information about the
characteristics of the benchmark bid. Accordingly, LEI recommended that IPC include in the final
RFP an additional exhibit listing IPC’s proposed benchmark resources, including but not limited
to the following information, which has been provided in past RFPs held by other utilities under
the oversight of the OPUC:10
•the number of prospective benchmark bids IPC intends to submit in the 2026 AS RFP;
•the size (in MW) of the bids;
•status of the resource (newbuild vs. existing facility);
•target commercial operations date;
•technology type;
•expected facility life;
•expected facility efficiency;
•type of product (resource-based or market purchase);
•interconnection status; and
•location.
IPC, OPUC Staff, and the IE discussed this matter during a meeting held on March 22, 2023.
According to IPC, a separate and independent division within the Company will oversee the
preparation of the benchmark bids, and as a consequence, the IPC RFP team is not aware of the
specifics of these bids. IPC noted that the benchmark bid(s) will be evaluated in the same manner
as any other submitted bid.
However, the disclosure of benchmark bids in the RFP is required by the bidding rules stipulated
in OAR 860-089-0450 6c and also adheres to established precedents, such as the approach
employed by PacifiCorp in its 2022 All-Source RFP. Consequently, LEI strongly advises IPC to
incorporate the relevant information listed above.
Finally, should IPC choose not to make available the elements of the benchmark resource(s) such
as site transmission rights, among other factors, to all bidders, it is imperative for the Company
to present a comprehensive analysis justifying this decision, in compliance with the requirements
set forth in OAR 860-089-0300.
the technology/resource types that IPC’s system currently lacks. As a result, such portfolio is most likely to
be selected by IPC in the evaluation process to fulfill system needs.
10 LEI specifically has in mind the precedent set by PacifiCorp in its most recent RFP (“PacifiCorp 2022 All-Source
RFP”), in which it provided the level of information requested of IPC by LEI.
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3.1.3 RFP schedule
In the first IE Report, LEI identified two issues in the draft RFP schedule proposed by IPC. First,
LEI observed that IPC had set a deadline for bidders to submit their proposals two weeks prior
to the start of IPC's review process. The IE recommended extending the bid submission deadline
from May 31, 2023 to June 13, 2023 to allow bidders more time to prepare their submissions. The
IE noted that this scheduling change would also put the RFP bid due date right after the filing of
the IE's review of the benchmark bids, which aligns with OAR 860-089-035011 and helps to ensure
that submitted bids are only opened after the benchmark bids have been fully evaluated and filed.
In response, IPC revised the bid submission deadline to June 12, 2023, the same day that the IE is
due to submit its benchmark bids review. Although this is not exactly what was suggested, the
IE is satisfied with this compromise.
IPC, OPUC Staff, and the IE also discussed the docket schedule in the context of the submission
of the benchmark bids report. OPUC Staff noted that, according to Oregon bidding rules, it is
IPC—not the IE—that is tasked with submitting a benchmark bid report. As specified in the
bidding rules, the IE is responsible for reviewing the benchmark bid(s) filed by IPC and providing
feedback. LEI concurs with OPUC Staff on this matter.
Also relevant to the discussion of benchmark bids is LEI’s recommendation in the first IE Report
to allocate a minimum of three weeks for the benchmark bid analysis; this additional time in the
schedule would allow the IE to carry out its independent review thoroughly and accurately.
Though IPC previously stated that it would likely be able to move up the benchmark bids due
date by one week, ultimately the due date as provided in the updated draft RFP was only moved
up by two days, while the completion date for benchmark bid evaluation remains unchanged.
LEI remains of the view that the time allocated for the benchmark bids review process is
insufficient. As such, it has proposed to IPC that, if the benchmark bids report due date cannot
be adjusted, then the benchmark bids submission deadline and benchmark bids evaluation
should be rescheduled. LEI also noted that May 29, 2023, the proposed deadline for the
submission of the benchmark bids, is a federal holiday.
Finally, during several meetings with IPC and OPUC Staff, LEI voiced concerns regarding the
compressed schedule of the RFP. Especially in light of the number of bidders and bids expected
to participate in the RFP, the IE proposes that the RFP timeline be adjusted accordingly. For
example, LEI finds the current three-day window allotted for bid eligibility screening following
the opening of the solicitation to be inadequate. Similarly, the IE has only been allotted four
business days to review IPC’s initial shortlist (“ISL”) and prepare its analysis thereof. The IE
requires a minimum of seven business days to conduct and five business days to write up its
analysis. Additionally, only one day has been designated for the IE to complete its review of the
ISL and for IPC to notify selected bidders that their bids have made it into the ISL; this timing
11 OAR 860-089-0350(1) states: “Prior to the opening of bidding on an approved RFP, the electric company must file
with the Commission and submit to the IE, for review and comment, a detailed score for any benchmark
resource with supporting cost information, any transmission arrangements, and all other information
necessary to score the benchmark resource. The electric company must apply the same assumptions and bid
scoring and evaluation criteria to the benchmark bid that are used to score other bids.”
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assumes that there are no discrepancies between the ISL rankings prepared by the IE and IPC. To
ensure a thorough evaluation process, the IE recommends that IPC a dd at least 5 business days
between IE’s filing of the initial shortlist and IPC notification of shortlisted bidders. This would
give the IE and IPC time to consider and discuss ISL results as well as to address any
discrepancies in respective rankings.
Thus, the IE proposes that IPC reassesses the indicative RFP timeline and allocates additional
time for conducting in-depth analyses and preparing of reports. Additionally, the IE requests that
it be included in IPC’s deliberations around RFP schedule updates.
3.1.4 Bid evaluation process
The proposed scoring and modeling methodology (“SMM”) was neither approved nor
acknowledged through Docket UM 2255 prior to the opening of the 2026 AS RFP. Therefore, the
SMM must be approved through the RFP process itself.12
In the first IE Report, LEI recommended providing clarity on the following key sections of the
draft RFP:
i.non-price scoring model;
ii.price scoring model;
iii.contract term normalization; and
iv.ISL selection.
LEI’s main concern with the proposed non-price scoring model (item (i)) was its broad and binary
structure, which could entice bidders to score themselves favorably. As a solution, LEI suggested
providing greater specificity to the non-price scoring methodology through the drafting of
guiding questions or criteria. Subsequently, on April 14, 2023, IPC provided LEI with a new non-
price scoring file named “Exhibit B-C-D – Bid Entry Form 3.22.23_v2.xlsm.” This new file made
the following improvements: it provided greater specificity to the non-price scoring questions
and introduced three potential answers from which bidders could choose for each question
(previously, bidders would simply self-score with a “yes” or “no” to each more broadly phrased
question).
LEI appreciates IPC’s effort to improve the non-price scoring methodology and at this point only
recommends that IPC provide a numerical score for each potential answer to each question in the
non-price scoring file.
Regarding the price scoring model (item (ii)), LEI acknowledges the high-level description of the
price scoring methodology in the updated draft RFP. While it was recommended that Idaho
12 The Commission granted a partial waiver of OAR 860-089-250(2)(a) to allow concurrent consideration of both scoring
and modeling methodologies and the draft RFP. Source: In re Idaho Power Company, Approval of Independent
Evaluator Selection for 2026 All-Source Request for Proposal and Request for Partial Waiver of OAR 860-0890250(2)(a).
Docket No. UM 2255. Order No. 22-495. December 29, 2022.
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Power expand on the description of the model, no further explanations or commentary were
included in the latest version of the draft RFP. Nevertheless, IPC did furnish LEI with the models
and assumptions applicable to the SMM and ISL selection process. For the benefit of
stakeholders—who have not had the same level of access to verbal, written, or numerical
clarifications on the price scoring methodology that the IE was granted—LEI’s review and
observations of the financial model and its assumptions are provided in Section 4 of this report.
In relation to the normalization of contract terms (item (iii)), LEI suggested in its initial IE Report
that IPC incorporate additional details in the RFP outlining its methodology for evaluating power
purchase agreements (“PPAs”) with varying contract terms (i.e., number of years) on an equal
footing. In response to LEI’s suggestion and OPUC Staff’s information request dated April 14,
2023, IPC produced a detailed sample normalization calculation. LEI found the example to be
highly instructive and pertinent to the queries raised. Consequently, it is recommended that IPC
offer similar information to prospective bidders in the final RFP.
Finally, similar to the concern on the price scoring model, LEI finds the description of the shortlist
selection in the draft RFP (item (iv)) to be too general. LEI is of the opinion that bidders would
benefit from a more expanded description of how the AURORA modeling tool will be used to
evaluate and select bids during the final shortlist selection process.13 IPC clarified that “Idaho
Power will rely on the established and acknowledged IRP methodology to select economic
portfolios and points stakeholders to that information directly .”14 While LEI is satisfied with the
implementation of a methodology that is consistent with the acknowledged 2021 IRP, IPC
should—as soon as available—disclose in the final RFP any potential changes expected as a result
of the upcoming 2023 IRP.
3.1.5 Imputed debt impact of PPAs
In the first IE Report, LEI briefly discussed IPC’s intention to incorporate the cost of imputed debt
into the bid evaluation process, specifically as part of the price-score assessment of bids. IPC
would do this by estimating the cost of imputed debt for all submitted bids and adding this
estimated cost on top of each project’s respective total cost.15 IPC argues that this step is necessary
as imputed debt is a type of financial obligation that impacts the Company’s cost of debt and—
potentially—its credit rating. LEI's recommendation was to exclude imputed debt in the bid
evaluation process for three main reasons:
13 Following multiple conversations between IPC, OPUC Staff, and the IE, it was agreed that the initial shortlist will be
selected using only the results of the non-price and price scoring assessments. The levelized cost of capacity
(“LCOC”) output of the price scoring model, described in detail in Section 4 of this report, is a cost metric
input to the AURORA model, which will only be used in the final shortlist selection process.
14. Idaho Power Reply Comments. Oregon Docket No. UM2255. Filed March 24, 2023. p. 5.
<https://edocs.puc.state.or.us/efdocs/HAC/um2255hac145552.pdf>.
15 Idaho Power Company. Draft 2026 All Resource Request for Proposal. February 22, 2023. p. 29.
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1.there are other financial and risk factors that IPC will not be analyzing as part of the bid
evaluation process;16
2.the inclusion of imputed debt would require the involvement of a utility accounting
expert in this proceeding; and
3.the application of an imputed debt calculation methodology lacks transparency.17
Following several discussions with both IPC and OPUC Staff, LEI continues to maintain its
position on imputed debt. While IPC’s concerns are recognized, evidence suggests that the
imputed debt associated with newly acquired PPAs, battery storage agreements (“BSAs”), and
third-party assets does not definitively result in an increase in a company’s debt and debt-related
costs that would, in turn, lead to a downgrade by credit rating agencies. Furthermore, an all-
source solicitation may not be the appropriate venue to address the impact of imputed debt on
the Company’s finances. LEI’s primary concern with the inclusion of imputed debt into the bid
evaluation process is that—in addition to the aforementioned concerns—it may unintentionally
favor utility builds over submitted bids, or put submitted bids at a comparative disadvantage.
In recent years, US jurisdictions have taken different approaches to the treatment of imputed debt
in the context of the resource procurement process. Some of the relevant arguments made by
utilities, market stakeholders, and regulators can be summarized as follows:
•Utilities are concerned that the treatment of PPAs as debt obligations could increase the
cost of borrowing, impacting the utility’s credit rating and—ultimately—consumer rates.
As such, utilities have proposed solutions such as the implementation of cost recovery
mechanisms (where the utility would recover costs through adders or surcharges on
ratepayer bills) or even having the regulator or other state agency (as opposed to the
utility itself) act as the counterparty to the relevant PPA.
•Market stakeholders have questioned the extent to which PPAs do, in fact, impact a
utility’s debt equivalence.18 These stakeholders argue that utilities presume—without
providing any supporting evidence—the treatment of PPAs by credit rating agencies as
debt obligations. Moreover, utilities have been criticized for not providing any evidence
that imputed debt, if indeed taken into consideration, would have a real, material impact
on their balance sheets. 19
16 For example, IPC has not expressed its intent to assess the risk factors associated with utility-built options, or the
risks and benefits of utility-built options as compared to those of PPAs. By only including imputed debt as
part of the bid evaluation process, IPC would not be treating fairly all resources bid into the solicitation.
17 Fagan, Marie, Ma. Cherrylin Trinidad, Sayad Moudachirou, Barbara Porto, Bat-Erdene Baatar, and Hannah Braun.
Observations on Idaho Power Company’s Draft 2026 all Source Request for Proposals for Peak Capacity and Energy
Resources: Independent Evaluator Assessment Report. March 1, 2023. p. 14-15.
18 Debt equivalence is a term that describes the debt-like quality of long-term contracts. Source: Kahrl, Fredrich. All-
Source Competitive Solicitations: State and Electric Utility Practices . Grid Modernization Laboratory Consortium,
US Department of Energy. March 2021. p. 53.
19 For example, the regulator in Indiana did not allow Southern Indiana Gas and Electric Company’s request for the
inclusion of an adder to the solar PPA payment to offset the cost of imputed debt over the life of the contract.
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•Regulators and regulatory staff have expressed concern about the impact of imputed debt
on customer rates. Additionally, they have also expressed concern with the potential
misinterpretation by utilities of the imputed debt calculation methodologies applied by
credit rating agencies.
In a paper prepared by the Grid Modernization Laboratory Consortium of the US Department of
Energy, debt equivalence is described as one of “the most important comparability challenges”
for competitive procurements into which both utility and non-utility-owned assets are bid.20
Specifically, “Because debt equivalence and other utility financial impact metrics have the
potential to influence procurement decisions, their use in bid evaluation requires care to mitigate
their effect on the competitiveness of the solicitation.”21 To this end, some jurisdictions have
allowed the inclusion of debt equivalence in the bid evaluation process, but only under certain
conditions. For instance, California utilities cannot apply adders for imputed debt when self-
build options are bid into the solicitation process.22 In other states, utilities were asked to provide
justification for the inclusion of imputed debt in their respective procurement processes.
Finally, there are several examples of regulatory proceedings in which the regulator opted against
allowing for imputed debt considerations in the resource procurement process -- either because
the utility was unable to deliver the requested evidence or because the procurement process was
found to be an inappropriate venue for imputed debt discussions.23
3.1.6 Draft PPAs and BSAs
In its RFP, IPC included contract forms (Exhibit H) for solar-specific PPAs, a battery-specific grid-
charged tolling agreement (the BSA), and a battery -specific build transfer agreement (“BTA”).
IPC did not provide contract forms or summary term sheets applicable to other technology types
that may bid into the RFP. IPC should provide, at a minimum, term sheets relevant to other types
of technologies (e.g., wind, solar-plus-battery solutions, etc.).
An intervenor—the Northwest & Intermountain Power Producers Coalition (“NIPPC”)—
provided feedback on IPC’s contract terms.24 For the reader’s convenience, where applicable, LEI
The regulator stated, “We find it is not prudent to approve an adder when its necessity is in question and the
benefits were not demonstrated. We are also reluctant to approve the proposed adder based on speculation
upon the impact in the future to Petitioner’s credit metrics.” Order of the Commission, October 27, 2021.
(Cause No. 45501)
20 Ibid.
21 Ibid.
22 Ibid.
23 District of Columbia FC1017-2019-E952 and FC1017-2020-E-867; Indiana Case No. 45501; and Michigan Case No. U-
20165.
24 Oregon Public Utilities Commission. Northwest & Intermountain Power Producers Coalition’s Comments on Draft Request
for Proposals. Docket No. UM 2255. March 17, 2023.
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notes where its feedback aligns with that of NIPPC. Where necessary, LEI provides additional
observations. LEI is not a legal expert, therefore the comments in the subsections that follow
should not be taken as legal advice.
The following comments apply to provisions of Exhibit H, the PPA template, and the BSA
template.
3.1.6.1 Right of first offer (“ROFO”)
IPC’s ROFO clauses (PPA Sections 8.1-8.8 and 9.4) are not reasonable. The OPUC Staff report
concurs on this matter, specifying (as Condition 7) that IPC remove §8.5 “Negotiation of Facility
Purchase” from all Draft Form Agreements in which it appears.25 IPC is in the process of drafting
alternative language.
3.1.6.2 Delay damages
LEI agrees with NIPPC that delay damages, at $400/MWac (PPA Section 1.25), are unreasonably
high.26 LEI believes IPC’s damages should fall within the range of damages provided in other
RFPs cited by NIPPC, i.e., $150/MWac to $200/MWac. Also, LEI agrees that the PPA form should
reduce delay damages for cases in which an operating facility is partially completed, as is already
stipulated in the BSA form (Section 1.28).
3.1.6.3 Development security
LEI agrees with NIPPC that IPC should clearly state that development security may be
established with cash.27 LEI finds that the security amounts required by IPC ($90,000 per MW for
development security and $45,000 per MW for default security) are reasonable, as they are within
the broad ranges contained in a variety of other PPAs.
3.1.6.4 Idaho Public Utility Commission (“IPUC”) approval
LEI agrees with NIPPC that there should be a day-for-day extension to the Scheduled Commercial
Operation date if IPUC approval of the contract takes more than 6 months, as well as a right to
terminate without damages payable by the Seller for longer delays. The reference to OPUC
approvals should also be removed.28
25 Oregon Public Utility Commission. Public Utility Commission of Oregon Staff Report. Docket No. UM 2255. May 3, 2023.
p. 2. <https://edocs.puc.state.or.us/efdocs/HAH/um2255hah11921.pdf>.
26 Oregon Public Utility Commission. Northwest & Intermountain Power Producers Coalition’s Comments on Draft Request
for Proposals. Docket No. UM 2255. March 17, 2023. p. 28.
27 Ibid. p. 29.
28 Ibid.
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3.1.6.5 Limitation of Idaho Power Transmission liability
NIPPC argued that the provisions in PPA Sections 1.145, 7.2.1, and 15.1 could eliminate the
Seller’s ability to cite Idaho Power’s interconnection delays as justification for the inability to
perform under the PPA or BSA. As such, these provisions should be removed.29
LEI generally agrees with NIPPC and has the following recommendations:
•Section 1.145 (under Definitions, Rules of Interpretation) of IPC’s PPA provides that:
“Notwithstanding any other provision in this Agreement, nothing in the Generation
Interconnection Agreement, nor any other agreement between Seller on the one hand and
Transmission Provider or Interconnection Provider on the other hand, nor any alleged event of
default thereunder, shall alter or modify the Parties’ rights, duties, and obligation hereunder.” LEI
agrees with NIPPC that this is unfair to the Seller, as the actions taken by a Transmission
Provider are outside of the reasonable control of the Seller.
•Section 7.2.1 (under Standard of Facility Operation) provides that: “Seller acknowledges that
it shall have no claims hereunder against Idaho Power with respect to any requirements imposed
by or damages caused by (or allegedly caused by) the Transmission Provider. Seller will have no
claims against Idaho Power under this Agreement with respect to the provision of station service.”
Furthermore, “Seller acknowledges that Idaho Power, acting in its merchant capacity function as
purchaser hereunder, has no responsibility for or control over Interconnection Provider or
Transmission Provider, and is not liable for any breach of agreement or duty by Interconnection
Provider or Transmission Provider.” LEI finds these provisions to be acceptable only if other
provisions of the PPA make it clear that the Seller will not be held responsible for delays
that were caused by the Interconnection Provider and/or the Transmission Provider.
•Section 15.1 (under Force Majeure) includes the following provision in the description of
what Force Majeure is not: “(vii) any delay, alleged breach of contract, or failure by the
Transmission Provider, Network Service Provider or Interconnection Provider unless due to a
Force Majeure event.” LEI does not take issue with this language, as it is much like
provisions of other PPAs that LEI has encountered. However, as noted above, LEI finds
these provisions to be acceptable only if other provisions of the PPA make it clear that the
Seller will not be held responsible for delays that were caused by the Interconnection
Provider and/or the Transmission Provider.
3.1.6.6 Qualified operator
Lastly, LEI agrees with NIPPC that facility operations requirements (PPA Section 1.105 and BSA
Section 1.108) should be reduced to align with the maturity and size of the relevant industry.30
29 Ibid. p. 31.
30 Ibid.
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Whatever such requirements are, they should apply to utility-owned bids as well as to third-party
PPAs and BSAs.
3.1.7 Draft solar PPA (Exhibit H)
LEI agrees with NIPPC that the solar PPA (Section 7.7) should not include IPC’s portfolio-wide
near-term solar forecasting costs, i.e., the Idaho Power administered solar forecasting model
should not be applied to all solar projects that are under contract to provide energy to Idaho
Power.31 Other PPAs that LEI has reviewed in its previous work for other clients generally do not
require this type of payment; some Buyers accept the solar producer’s (Seller’s) forecast.
With regards to the performance guarantee, LEI agrees with NIPPC that the confusing language
in Section 12.1.2.8 should be clarified. As noted by NIPCC “The language contains a default and
termination provision designed for an annual delivery guarantee structured entirely differently from the
form’s monthly guarantee and liquidated damage structure. It states that a default for two consecutive
years of annual performance criteria, while monthly performance criteria are specified in the previous
failing to meet the performance guarantee will result i n termination. This is confusing and appears to be a
hold-over from a prior form using an annual delivery guarantee .” 32
Finally, multiple references to “special contract” and “Idaho Power’s customer” should be
deleted, as the RFP makes no other reference to a special contract customer.33
3.1.8 Draft BSA (Exhibit H)
Round-trip efficiency (“RTE”) is the ratio of useful energy output to useful energy input. NIPPC
argues that the contract’s 87% RTE requirement (BSA Sections 1.52, 4.5.3, and 12.1.2.8) is too
high.34
LEI notes that the proposed RTE is on the high end of current and recent technology. In 2019, the
utility-scale battery fleet in the United States operated with an average monthly round-trip
efficiency of 82%.35 In 2021, the National Energy Renewable Laboratory (“NREL”) adopted 86%
31 Ibid. p. 32.
32 Ibid.
33 Ibid. p. 33.
34 Ibid. p. 34.
35 Mey, Alex. “Utility-scale batteries and pumped storage return about 80% of the electricity they store.” US Energy
Information Administration. February 12, 2021.
<https://www.eia.gov/todayinenergy/detail.php?id=46756#:~:text=Round%2Dtrip%20efficiency%20is%2
0the,lost%20in%20the%20storage%20process>.
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as its Annual Technology Baseline.36 In addition, as noted by NIPPC, RTE can decline over the
life of the battery. For these reasons, LEI would prefer to see the RTE requirement be neg otiable.
Similar to NIPPC, LEI suggests that Section 7.7 should provide a reasonable deadline for
complying with charging/discharging instructions.37
3.1.9 BTA (Exhibit H)
3.1.9.1 Requirements of foundational contracts
Unlike a PPA, in which the developer retains ownership of the project and may expect to benefit
from any value remaining at the end of the PPA term, in a BTA, the developer gains no upside
beyond the sale price it charges when it transfers the project to the utility (the buyer). In addition,
it is standard industry practice for the BTA developer to price all cost contingencies into its bid,
which contributes to a higher price tag than if the utility were to engage an engineering,
procurement, and construction (“EPC”) contractor on its own.38 The contracts that provide the
foundation of a BTA (the EPC contract, operations and maintenance agreements, long-term
service agreements, and warranties) are therefore crucial to the balance of risk taken on by the
utility versus the developer. Therefore, LEI agrees with NIPPC that the BTA must provide more
clarity on the length and substantive requirements of such foundational contracts.39
3.1.9.2 Performance guarantees
LEI agrees with NIPPC that the BTA must contain ongoing performance guarantees equivalent
to those in the BSA, including:40
1.penalties and termination risk for non-performance;
2.a specified level of guaranteed RTE upon project completion before transfer of ownership;
and
3.ongoing contractual warranties with damages and termination rights (for the life of the
resource over which the levelized cost of energy (“LCOE”) is calculated for the price score)
or contingency cost risk adders.
36 “Utility-Scale Battery Storage.” National Renewable Energy Laboratory.
<https://atb.nrel.gov/electricity/2021/utility-scale_battery_storage>.
37 Oregon Public Utilities Commission. Northwest & Intermountain Power Producers Coalition’s Comments on Draft Request
for Proposals. Docket No. UM 2255. March 17, 20. p. 35.
38 Lazaroff, Mark A. and Neeraj Arora. “Key Considerations for Utility-Scale Energy Storage Procurements.” Morgan
Lewis. March 8, 2023. <https://www.morganlewis.com/pubs/2023/03/key-considerations-for-utility-scale-
energy-storage-procurements>.
39 Ibid. p. 35.
40 Ibid.
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3.2 Summary of proposed improvements expected in the final RFP
In summary, LEI recommends the following improvements to be incorporated in the final RFP
and its accompanying exhibits. These adjustments will make the solicitation process clearer and
more transparent to all stakeholders:
i.add to the body of the RFP the Company’s target procurement mix based on the latest
acknowledged IRP and disclose if resource needs are expected to change during the
course of the 2026 AS RFP process;
ii.incorporate a new exhibit disclosing the suggested additional information on the
prospective benchmark bids;
iii.adjust the RFP schedule and extend the time allocated for conducting in-depth analyses
and preparing of reports;
iv.include numerical scores for each answer to each question in the non-price score file;
v.provide more detailed information on as well as an example of IPC’s approach to contract
normalization;
vi.disclose any potential changes to the SMM and assumptions adopted from the
acknowledged 2021 IRP as a result of the upcoming 2023 IRP;
vii.exclude the cost of imputed debt in the evaluation of bids;
viii.provide summary term sheets for all technology types;
ix.adjust the following in the draft PPA and/or BSA:
a.delay damages should be reduced to $150-200/MWac in both the PPA and BSA;
b.add day-for-day extension to the Scheduled Commercial Operation date if IPUC
approval of the contract takes more than 6 months;
c.add right to terminate without damages by the Seller for longer delays;
d.add a provision in the PPA stating that the Seller will not be held responsible for
delays caused by the Interconnection Provider and/or the Transmission Provider;
e.adjust facility operations requirements to align with the maturity and size of the
relevant technology’s industry;
f.adjust confusing language on performance guarantees in the draft solar PPA
(Section 12.1.2.8); and
g.revise the RTE requirement in the draft BSA to be negotiable (not fixed).
x.remove the following from the draft PPA:
a.ROFO clause;
b.references to OPUC approvals;
c.IPC’s portfolio-wide near-term solar forecasting costs; and
d.references to “special contract” and “Idaho Power’s customer” in the solar PPA.
Exhibit No. 2
Case No. IPCE2416
E. Hackett, IPC
Page 18 of 24
19
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xi.provide more clarity on the length and substantive requirements of the BTAs as well as
ongoing performance guarantees equivalent to those in the BSA;
xii.enhance the transparency of the BTAs by providing further elaboration on their duration
and essential prerequisites; and
xiii.ensure that comparable ongoing performance guarantees featured in the BSA are also
incorporated in the BTA.
Exhibit No. 2
Case No. IPC-E-24-16
E. Hackett, IPC
Page 19 of 24
20
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4 Comments on AURORA assumptions and modeling
In response to an IE information request, on April 14, 2023 IPC provided its key assumptions to
its financial model. These include load forecast, supply (new entry and retirements), fuel prices,
and planned key scenarios. In addition, IPC also provided the IE with the draft financial model
that it will use to evaluate bids. The comments in this section of the report pertain to the updated
financial model provided to the IE; LEI expects that an updated financial model will be provided
by IPC before the actual evaluation of bids.
4.1 Assumptions used in the model
4.1.1 Load forecasts
As stated by IPC, the load forecast for the 2026 AS RFP will be derived from the load forecast
underlying the 2023 IRP, which is currently under revision.41 While LEI acknowledges the
importance of incorporating an up-to-date load forecast, potential issues arise from the fact that
the 2023 IRP has not yet been approved. LEI recommends that IPC should communicate
transparently with bidders about any potential issues or uncertainties related to the load forecast
utilized for the purpose of the 2026 AS RFP and provide regular updates on any changes or
revisions to the forecast as they become available.
4.1.2 Resources
According to IPC, power generating facilities that are currently operational and included in the
AURORA model align with the portfolio of resources provided in the acknowledged 2021 IRP.
The AURORA model only incorporates into the system existing and contracted resources, as well
as resources that align with announced and/or assumed customer clean energy goals. Any
further new entry additions are determined through so-called Long-Term Capacity Expansion
(“LTCE”) modeling. Similarly, retirements are modeled in accordance with the 2021 IRP:
retirement decisions are based on either the plant’s economic feasibility or end-of-life date. LEI
finds IPC’s approach to modeling new entries and retirements to be in line with established
industry practice and therefore deems it to be an appropriate and consistent approach.
4.1.3 Fuel prices
Fuel costs are a key driver in the selection and optimization of resources by the AURORA model.
Most fuel forecasts utilized by IPC are from well-known third-party vendors. Below is a list of
sources associated with each of IPC’s fuel assumptions to be applied in bid evaluation modeling
exercises:
•natural gas (base case): Platt’s long-term Henry Hub gas price forecast as of June 2023;
41 IPC. Response to LEI’s questions on AURORA assumptions. Shared via email communication on April 14, 2023.
Exhibit No. 2
Case No. IPCE2416
E. Hackett, IPC
Page 20 of 24
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•natural gas (low case): Henry Hub gas price from the US Energy Information
Administration’s (“EIA's”) 2023 Annual Energy Outlook (“AEO”) High Oil & Gas Supply
forecast;
•natural gas (high case): Henry Hub gas price from the EIA’s 2023 AEO Low Oil & Gas
Supply forecast;
•clean gas (hydrogen): NREL;42
•biomass: NREL 2022 Annual Technology Baseline;
•coal: IPC’s own forecast, as per its 2021 IRP; and
•uranium (small modular reactor): NREL’s 2022 Annual Technology Baseline.
LEI understands that the fuel forecasts used in this RFP process will be aligned with the upcoming
2023 IRP. IPC will also provide LEI with all fuel forecast assumptions once they are available and
prior to running AURORA.
4.1.4 Calculation of the Effective Load Carrying Capability (“ELCC”)
The ELCC is a reliability-based metric used to assess the ability of a resource to meet load when
it is most needed by the system. Technically, the ELCC measures the contribution of a resource
to system reliability. LEI understands that IPC will calculate the ELCC for each resource bid into
this solicitation based on the ELCC calculation methodology of the acknowledged 2021 IRP. This
methodology was further elaborated upon in IPC’s presentation to the Integrated Resource Plan
Advisory Council.43 According to these sources, IPC calculates the ELCC for variable and energy-
limited technology types, including run-of-river hydropower, demand resources, wind, solar,
and storage (standalone or in combination with a renewable resource).
In the 2021 IRP, IPC adopted the concept of “last-in ELCC,” in which individual future resources
are added to the system one at a time (as opposed to all at once). The ELCC of each resource is
calculated upon their addition to the system. This is essentially a marginal ELCC methodology,
which measures the incremental capacity value of a resource type (or a combination of resources),
evaluated relative to an existing portfolio of the same resource type. Marginal ELCC is useful for
comparing new resource options against one another at the margin. This is the methodology
chosen by IPC to estimate ELCC for future resources ; LEI does not have a critique of this choice.
4.1.5 Scenarios
As part of the final shortlist process, IPC stated its plan to conduct a series of sensitivity analyses
consistent with the upcoming 2023 IRP (see Figure 3 below).
42 Denholm, Paul et al. Examining Supply-Side Options to Achieve 100% Clean Electricity by 2035. National Renewable
Energy Laboratory. 2022. <https://www.nrel.gov/docs/fy22osti/81644.pdf>.
43 IPC. Reliability & Capacity Methodologies Overview, 2023 Integrated Resource Plan . March 9, 2023.
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London Economics International LLC
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www.londoneconomics.com
Figure 3. IPC’s proposed sensitivities
Note: “B2H” refers to the Boardman to Hemmingway transmission line, currently under construction.
Source: Idaho Power’s responses to LEI’s comments dated April 5, 2023
In addition, IPC will conduct a stochastic analysis to evaluate the impact on portfolio costs when
certain variables deviate from their established planning-case levels. As outlined in the RFP, the
stochastic analysis will consider variations in hydrologic conditions, load/demand, natural gas
prices, and carbon prices, all of which will be based on the forthcoming 2023 IRP. According to
IPC, the following is the expected range of values for the fuel variable in the stochastic analysis:
•natural gas: the stochastic spread will allow natural gas prices to swing within a range of
$1.35/MMBtu to $20.48/MMBtu; and
•carbon price: price adder will range between $0/ton and $412/ton.
Hydrology and electricity demand variables for the stochastic analysis will be provided to LEI
once the 2023 IRP is finalized.
It is LEI’s understanding that IPC will furnish LEI with the final 2023 IRP sensitivities and
stochastic inputs once they become available. Upon receiving these inputs, LEI will conduct a
thorough review of the data (and bid rankings) in compliance with the requirements stipulated
1) Base case
2) High gas and
high carbon
3) Low gas and
zero carbon
4) B2H delayed
until 2027
Gas: Platts Henry Hub natural gas price forecast as of June
2023
Includes a carbon price forecast and total emissions
constraints on some coal units as well as state-level carbon
policies and RPS standards
*as Based on EIA’s  Annual Energy Outlook Low Oil
and Gas Supply forecast
Carbon: 2023 IRP high carbon price forecast
*as EIA’s  high oilgas supply forecasts
Carbon: Assumes no federal or state legislation that would
require a tax or fee on carbon emissions and therefore zero
carbon costs
Base case with B2H starting operations in 2027, instead of
2026
B2H operations starting in 2026
E[hibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 
23
London Economics International LLC
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in OAR 860-089-0400. Subsequently, LEI will submit a comprehensive written evaluation to the
Commission before IPC seeks acknowledgment of the final shortlist.
In addition to the sensitivities proposed by IPC, LEI recommends incorporating a sensitivity
analysis wherein the Boardman to Hemmingway (“B2H”) project experiences an extended delay,
i.e., an operational start year of 2030. A one-year delay such as proposed by IPC may have little
impact on which projects comprise the optimal resource portfolio; a longer delay will provide a
more stringent test.
4.2 Draft financial model
IPC will use its proprietary Excel-based model to conduct a financial analysis and subsequently
prioritize bids to form the ISL. This model will serve as an initial screening tool that calculates the
levelized cost of capacity (“LCOC”) of each bid, whether for a single or bundled project (e.g., solar
plus storage). It computes the cost of a bid's resources over the project's lifetime in terms of
present value revenue requirement (“PVRR”) per megawatt hour (“MWh”). The LCOC is the
monthly cost per kilowatt that customers would incur for each project selected by IPC (Figure 4).
Figure 4. LCOC formula
𝐿𝐶𝑂𝐶=
𝑂𝑉𝑅𝑅𝑙𝑙𝑎𝑙𝑠 𝑠�ℎ𝑧𝑒× 1,000⁄
12 𝑙𝑙𝑙𝑠�𝑠
The LCOC calculation uses project-specific information provided in “EXHIBIT B – Bid Entry
Form,” as well as underlying internal assumptions developed by IPC.
IPC operational and financial input assumptions are the same across different technology types.
Assumptions are based on the latest information available for the upcoming 2023 IRP and are
similar to the assumptions found in the acknowledged 2021 IRP (see Figure 5 below). LEI will
review these assumptions again during the ISL process to check for any changes.
Figure 5. IPC’s key financial assumptions
Source: “2026 RFP Financial Models 04.13.23.xlsx” as of April 14, 2023
Table 9.1 Financial Assumptions 2023 IRP 2021 IRP 2019 IRP ѐ
Plant operating (book) life
Discount Rate weighted average cost of capital 7.12% 3HU %UXFH 0DF0DKRQ QR FKDQJH
Composite tax rate 25.74%25.74% 3HU *HQH 0DUFKLRUR QR FKDQJH
Deferred rate 21.30%21.30% 3HU *HQH 0DUFKLRUR QR FKDQJH
General O&M escalation Rate 2.20% %DVHG RQ D IRUHFDVW RI KHDGOLQH &3, IURP WKH 2FW  YLQWDJH IRUHFDVW UXQ
Annual property tax rate (% of Investment)0.49% ,GDKR 7D[ OHYLHV GHFOLQLQG GXH WR PDUNHW YDOXH VKLIW
Property tax escalation rate 3.00% ,GDKR WD[ EXGJHW JURZWK LV UHVWULFWHG WR 
Annual insurance premiums (% of Investment)0.308% $FWXDO  LQFUHDVH IRU UHQHZDO  -HII 3OHLPDQQ
Insurance escalation rate 2.00% 3URSHUW\ UHQHZDO ZH XVHG )DFWRU\ 0XWXDO ,QVXUDQFH &RPSDQ\ GHYHORSPHQW IDFWRU
AFUDC Rate (annual)7.65% (PDLO IURP 0LFKHDO :KLWH ZLWK $)8'& $OVR SXOOHG IURP  . %RQG UHILQDQFHV FRQWULEXWHG WR WKH LQFUHDVH
&XUUHQW <HDU 37& &UHGLW  3HU *HQH 0DUFKLRUR 37& LV  0:K IRU  DQG LQIODWLRQ DGMXVWHG HDFK \HDU WKHUHDIWHU
37& 7HUP 
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Expected Life of Asset
Exhibit No. 2
Case No. IPCE2416
E. Hackett, IPC
Page 23 of 24
24
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In addition to the key financial assumptions listed above, IPC has tax and economic (book) project
life assumptions for each technology type (see Figure 6 below), which are used to calculate
production tax credit amounts. Project life assumptions are also based on the upcoming 2023 IRP.
Figure 6. IPC’s project life assumptions
Source: “2026 RFP Financial Models 04.13.23.xlsx” as of April 14, 2023
LEI analyzed the methodology employed by IPC to determine the LCOC for each bid using the
Excel-based financial model entitled "2026 RFP Financial Models 04.13.23.xlsx" submitted via
email on April 14, 2023. The model differentiates between LCOC calculations for ownership
offers, such as BTA offers, and those for third-party-owned assets, such as PPA or BSA offers.
IPC included an estimated imputed debt cost in the LCOC computation for third-party-owned
asset bids. However, as outlined in Section 3.1.5, LEI recommends excluding imputed debt from
the bid evaluation process.
Aside from the matter of imputed debt, LEI considers the LCOC computation in IPC's draft
financial model to be a sound and justifiable approach for ranking bid proposals.
Project Lives Ta[Book
Solar 
:ind 
BESS 
SMR 
Biomass 
*eothermal 
Clean *as 
SCCT 
CCCT 
E[hibit No. 
Case No. IPCE
E. Hackett IPC
Page  of 

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

CONFIDENTIAL
EXHIBIT NO. 3

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

EXHIBIT NO. 4

2026-2027
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1 of 1056
Page i
Table of Contents
1. Disclaimer _______________________________________________________________ 1
2. Purpose _________________________________________________________________ 3
2.1. BACKGROUND ______________________________________________________________ 3
2.2. THE SOLICITATION ___________________________________________________________ 3
2.3. REGULATORY CONTEXT _______________________________________________________ 4
2.4. IPC SELF-BUILD RESOURCES AND BENCHMARK RESOURCES __________________________ 4
2.5. INDEPENDENT EVALUATOR ____________________________________________________ 5
2.6. CONFIDENTIALITY ____________________________________________________________ 6
2.7. SOLICITATION PORTAL AND RESTRICTION ON COMMUNICATIONS ____________________ 6
2.8. SCHEDULE __________________________________________________________________ 7
3. Product Specifications______________________________________________________ 8
3.1. ELIGIBLE PRODUCTS __________________________________________________________ 8
3.2. ALTERNATIVE PRODUCTS _____________________________________________________ 12
3.3. TRANSMISSION ALTERNATIVES ________________________________________________ 12
4. Resource Based Products: Additional Specifications and Instructions _______________ 12
4.1. MINIMUM REQUIREMENTS ___________________________________________________ 12
4.2. DELIVERY AND RESOURCE STATUS _____________________________________________ 12
4.3. OWNERSHIP AND AGREEMENT TYPES __________________________________________ 12
4.4. INTERCONNECTION STUDIES AND COST ESTIMATING ______________________________ 13
4.5. BID SUBMISSION PROCESS ____________________________________________________ 15
i Bid Definition Form ___________________________________________________________ 16
ii Bid Entry Form and Selectable Portfolio ___________________________________________ 16
iii Bid Submittal ________________________________________________________________ 16
4.6. BID FEES __________________________________________________________________ 16
4.7. EXCEPTIONS TO THE TECHNICAL SPECIFICATIONS _________________________________ 17
4.8. EXCEPTIONS TO THE DRAFT FORM LETTER OF CREDIT ______________________________ 18
5. Market Purchase Products: Additional Specifications and Instructions ______________ 18
5.1. MINIMUM REQUIREMENTS ___________________________________________________ 18
5.2. AGREEMENT TYPES _________________________________________________________ 18
5.3. PRODUCT ATTRIBUTES _______________________________________________________ 18
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 2 of 1056
Page ii
5.4. BID SUBMISSION PROCESS ____________________________________________________ 19
i Bid Definition Form ___________________________________________________________ 19
ii Bid Entry Form _______________________________________________________________ 19
iii Bid Submittal ________________________________________________________________ 19
6. Additional Requirements for All Products and Bids______________________________ 19
6.1. CONTENTS OF WRITTEN BID PROPOSAL _________________________________________ 19
6.2. BID NAMING _______________________________________________________________ 20
6.3. BID WRITTEN DOCUMENTS ___________________________________________________ 20
6.4. RFP EXHIBITS_______________________________________________________________ 20
6.5. FIRM BID __________________________________________________________________ 20
6.6. TAXES ____________________________________________________________________ 21
6.7. DATA AND CYBER SECURITY __________________________________________________ 21
6.8. PURCHASING RESTRICTIONS/PROHIBITED TECHNOLOGY ___________________________ 21
6.9. SMALL BUSINESS AND SMALL DISADVANTAGED BUSINESS PROGRAM ________________ 22
6.10. INSURANCE ______________________________________________________________ 22
6.11. FINANCIAL AND CREDIT INFORMATION _______________________________________ 22
6.12. EXCEPTIONS TO THE DRAFT FORM AGREEMENTS _______________________________ 22
6.13. CLARIFICATION OF BIDS ____________________________________________________ 23
6.14. ADDENDA TO RFP _________________________________________________________ 23
7. Bid Evaluation, Negotiation and Approval ____________________________________ 23
7.1. THE EVALUATION PROCESS ___________________________________________________ 23
7.2. PHASE 1 – INITIAL SHORTLIST _________________________________________________ 23
7.3. PHASE 2 – FINAL SHORTLIST __________________________________________________ 27
7.4. ADDITIONAL RIGHTS ________________________________________________________ 29
7.5. ACCEPTANCE AND REJECTION OF BIDS __________________________________________ 29
7.6. AGREEMENT NEGOTIATIONS __________________________________________________ 29
7.7. EXCLUSIVITY _______________________________________________________________ 30
7.8. PUBLICITY _________________________________________________________________ 30
7.9. COMMISSION APPROVAL_____________________________________________________ 30
8. ENTIRE RFP _____________________________________________________________ 30

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 3 of 1056
Page iii
EXHIBIT A – Bid Definition Form
EXHIBIT B – Bid Entry Form
EXHIBIT C – Bid Eligibility Checklist
EXHIBIT D – Non-Price Scoring Matrix
EXHIBIT E – Proposed Market Purchase Volumes
EXHIBIT F – Information on Preferred Locations for Resource Based Bids
EXHIBIT G – Information on Most Valuable Hours for Resource Based Bids
EXHIBIT H – Draft Form Agreements for Resource Based Bids
EXHIBIT I – BESS Technical Specifications
EXHIBIT J – Solar Technical Specifications
EXHIBIT K – Wind Technical Specifications
EXHIBIT L – Gas-Fired Convertible to Hydrogen Specifications
EXHIBIT M – Mutual Non-Disclosure Agreement
EXHIBIT N – Counterparty Financial Questionnaire
EXHIBIT O – Draft Form Letter of Credit
Exhibit P – Bid Format and Requirements
Exhibit Q – IRP Modeling Assumptions
Exhibit R – Levelized PVRR Scenarios
Exhibit S – Benchmark Bids
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 4 of 1056
Page 1
1. Disclaimer
The information contained in this Request for Proposals (RFP) is presented to assist interested parties in deciding
whether or not to submit a bid. Idaho Power Company (IPC), an operating company subsidiary of IDACORP, Inc.,
is issuing this RFP to solicit formal bids from qualified companies (each a Bidder) and does not represent this
information to be comprehensive or to contain all of the information that a Bidder may need to consider in
order to submit a bid. None of IPC, its affiliates, or their respective employees, directors, officers, customers,
agents and consultants makes, or will be deemed to have made, any current or future representation, promise
or warranty, express or implied, as to the accuracy, reliability or completeness of the information contained
herein, or in any document or information made available to a Bidder, whether or not the aforementioned
parties knew or should have known of any errors or omissions, or were responsible for their inclusion in, or
omission from, this RFP.
No part of this RFP and no part of any subsequent correspondence by IPC, its affiliates, or their respective
employees, directors, officers, customers, agents or consultants shall be taken as providing legal, financial or
other advice or as establishing a contract or contractual obligation. IPC reserves the right to request from
Bidders information that is not explicitly detailed in this document, obtain clarification from Bidders concerning
bids, conduct contract development discussions with selected Bidders, conduct discussions with members of the
Evaluation Team and other support resources as described in this RFP. The requirements specified in this RFP
reflect those presently known. IPC reservices the right to vary, in detail, the requirements and/or to issue
addenda to the RFP. In the event it becomes necessary to revise any part of the RFP, addenda will be provided to
Bidders included in the current and applicable stage of the RFP.
IPC will, in its sole discretion and without limitation, evaluate bids and proceed in the manner IPC deems
appropriate. IPC reserves the right to reject any and all, or portions of any bid submitted by Bidders for failure to
meet any criteria set forth in this RFP or otherwise, and to accept bids other than the lowest cost bid.
This RFP has been prepared solely to solicit bids and is not a contract offer. This RFP is not binding on IPC. The
only document that will be binding on IPC is an agreement duly executed by IPC and the successful Bidder (if
any) after the completion of the evaluation process and the award and negotiation of an agreement. IPC
reserves the right to reject any and all bids submitted by Bidders. The issuance of this RFP does not obligate IPC
to purchase any product or services offered by Bidder or any other entity. Furthermore, IPC may choose, at its
sole discretion, to abandon the RFP process in its entirety. Bidders agree that they submit bids without recourse
against IPC, IDACORP Inc., any of IDACORP Inc.’s affiliates, or any of their respective employees, agents, officers
or directors for failure to accept an offer for any reason. IPC also may decline to enter into any agreement with
any Bidder, terminate negotiations with any Bidder or abandon the RFP process in its entirety at any time, for
any reason and without notice thereof. Bidders that submit bids agree to do so without legal recourse against
IPC, its affiliates or their respective employees, directors, officers, customers, agents or consultants for rejection
of their bids or for failure to execute an agreement for any reason. IPC and its affiliates shall not be liable to any
Bidder or other party in law or equity for any reason whatsoever for any acts or omissions arising out of or in
connection with this RFP. Bidder shall conform in all material respects to all applicable laws, ordinances, rules
and regulations and nothing in this RFP shall be construed to require IPC or Bidder to act in a manner contrary to
law. Except as otherwise provided in the rules and orders of the Idaho Public Utilities Commission (IPUC) and the
Public Utility Commission of Oregon (the OPUC), (jointly the Commissions), by submitting its bid, a Bidder waives
any right to challenge any evaluation by IPC of its bid. Bidder whose bid may be selected in response to this RFP
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 5 of 1056
Page 2
acknowledges that it assumes full legal responsibility for the accuracy, validity and legality of the work provided
in conformance with this RFP. By submitting its bid, a Bidder waives any right to challenge any determination of
IPC to select or reject its bid. IPC reserves the right to accept the bid in whole or in part, and to award to more
than one Bidder. Furthermore, Bidder understands that any “award” by IPC does not obligate IPC in any way. IPC
will not be obligated to any part unless and until IPC executes a definitive agreement between the parties.
Bidder will absorb all costs incurred in responding to this RFP, including without limitation, costs related to the
preparation and presentation of its response. All materials submitted by the Bidder immediately become the
property of IPC. Any exception will require written agreement by both parties prior to the time of submission.
In responding to this RFP, Bidder shall adhere to best business and ethical practices. Bidder shall adhere to IPC’s
Supplier Code of Conduct, also available at idahopower.com.
Bidder is specifically notified that failure to comply with any part of this RFP may result in disqualification of the
bid, at IPC’s sole discretion.

This FINAL 2026 AS RFP, in its entirety is final and approved by the OPUC as of June 7, 2023.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 6 of 1056
Page 3
2. Purpose
2.1. BACKGROUND
IDACORP, Inc. is a holding company formed in 1998. Comprised of regulated and non-regulated businesses, its
origins lie with Idaho Power Company (IPC), a regulated electric utility that began operations in 1916. Today,
IPC is the largest regulated electric utility in the state of Idaho and IDACORP’s chief subsidiary. IPC serves over
610,000 residential, business, agricultural and industrial customers. The company’s service area covers
approximately 24,000 square miles, including portions of eastern Oregon. Learn more about IPC at
idahopower.com.
IPC currently serves its customers by supplying low-cost, reliable and clean energy. Affordable, clean
hydropower is the largest source of energy for customers. Power generation comes from a diverse set of
resources that continues to meet a growing demand. For a more detailed description of current generation
resources, please visit: idahopower.com/energy-environment/energy/energy-sources/.
IPC's service territory continues to experience customer growth and an increasing peak demand (load) for
electricity. IPC anticipates sustained load growth that will require the procurement of new resources to meet
peak summer demand and maintain system reliability as identified in the most recent 2021 Integrated Resource
Plan (IRP). The addition of new resources to meet peak demand is critical to ensure IPC can continue to reliably
meet the growing demands on its electrical system and serve its customers.
2.2. THE SOLICITATION
IPC is issuing this RFP to solicit formal bids from Bidders for two types of electric energy and capacity products
(Products). The first type is energy and capacity delivered from electric resources that employ certain
technologies (Resource Based Products: Products 1–17 in Table 3-1 and Table 3-2). The second type is firm
energy (WSPP Schedule C or equivalent preferred) that meets the eligibility requirements of the Western
Resource Adequacy Program (WRAP) in terms of resource specificity, transmission and other requirements
(Market Purchase Products: Products 18–19 in Table 3-3). The eligible types of Products are described further in
Section 3 of this RFP and include asset purchases, power purchase agreements and battery storage agreements
with exclusive ownership by IPC of any and all environmental attributes associated with all energy generated.
Details on the bid submission process and the bid evaluation process are also described further in this RFP.
This RFP targets resource procurement consistent with that identified in the 2021 IRP and the additional
incremental 2026 and 2027 needs identified by IPC in its application to open the RFP Docket UM 2255.
Accordingly, the RFP will seek bids for a combination of capacity and energy resources that provide a minimum
of approximately 350 megawatts (MW) of peak capacity and up to 1,100 MW of variable energy resources. IPC
will be accepting bids for energy or capacity incremental to its system beginning in the summer 2026 timeframe
and beyond from Resource Based Products and Market Purchase Products.
IPC holds (or expects to hold) transmission rights on various paths that could be used for delivery of Products.
These rights are listed in EXHIBIT E – Proposed Market Purchase Volumes and include capacity from the
planned Boardman to Hemingway (B2H) Transmission Line Project. IPC and other utilities in the region are
currently expecting the B2H project to be in-service prior to summer 2026. B2H is a proposed 500-kilovolt
transmission line that will run approximately 290 miles across eastern Oregon and southwestern Idaho. It will
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 7 of 1056
Page 4
connect the proposed Longhorn Substation four miles east of Boardman, Oregon, to Idaho Power’s existing
Hemingway Substation in Owyhee County, Idaho. IPC’s ownership share will be 45% representing
approximately 750 MW of west-to-east delivery capability. More information on B2H can be viewed on the IPC
website.1 As part of any bid submitted, a bidder must indicate whether or not the bid is contingent on delivery
of energy across B2H or any other transmission rights controlled by IPC.
Evaluation of bids will be performed by a team of IPC staff and retained consultants with relevant subject
matter expertise (Evaluation Team) and be reviewed by an independent evaluator as described in Section 2.5.
The process of issuing and responding to this RFP, evaluation and selection of bids, and the negotiation and
approval of the agreement(s), is known as the Solicitation. Bidders who are interested in participating in the
Solicitation and submitting a bid must first register via the third-party solicitation portal, Zycus, further
described in Section 2.7 of this RFP. This RFP sets forth the terms and conditions by which IPC will perform the
Solicitation. Bidder agrees to be bound by all the terms, conditions and other provisions of this RFP and any
addenda to it that may be issued by IPC. This RFP governs the Solicitation and supersedes any other written or
oral form of communication between Bidders and IPC concerning the Solicitation.
2.3. REGULATORY CONTEXT
Execution of any agreement will ultimately be subject to approval by the Commissions.
For the IPUC, this could include, but is not limited to, approval of a certificate of public convenience and
necessity (CPCN) application from IPC. IPC reserves the right to: 1) inform the IPUC that IPC could not reach
agreement with the Bidder of a selected resource; 2) request IPUC approval of any agreements it enters into
with successful Bidders (e.g., CPCN applications); and 3) terminate any agreement if IPC fails to receive IPUC
approval of submitted agreements or applications. Bidder shall provide any and all information and
documentation reasonably requested by IPC to support such applications and requests.
The OPUC has issued rules on competitive bidding for resource acquisitions, where a company seeks to acquire
resources or contracts with a duration greater than five years and a quantity greater than 80 MW. This RFP is
subject to those rules as further described in the Oregon Competitive Bidding Rules (Order 18-324).
2.4. IPC SELF-BUILD RESOURCES AND BENCHMARK RESOURCES
In addition to bids from Bidders, Resource Based Product bids may be submitted by a separate team of IPC staff
and retained consultants (Internal Bid Team). The Evaluation Team will treat the Internal Bid Team as a Bidder.
The Evaluation Team will subject any bid from the Internal Bid Team (an Internal Bid) to the same
requirements, evaluation methodology and other standards specified in this RFP for a bid from a Bidder.
Furthermore, the Evaluation Team and the Internal Bid Team must comply with an IPC Standards of Conduct
Protocol (Separation of Function) to ensure the Evaluation Team functions independently from the Internal Bid
team, does not provide access to any non-public information or undue preference to the Internal Bid Team and
provides the Internal Bid Team and Bidders equal access to non-public information related to the competitive
bidding process for new generation resource procurement.

1 https://www.idahopower.com/energy-environment/energy/planning-and-electrical-projects/current-projects/boardman-
to-hemingway/.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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An Internal Bid will include a self-build ownership proposal and will be required to submit the same
requirements described in this RFP. An Internal Bid may also include partnership arrangements or agreements
between the Internal Bid Team and third parties that may collaborate to submit a joint Internal Bid. Exhibit S –
Benchmark Bids describes the three bids anticipated to be submitted by the Internal Bid Team as well as the
availability of each to third-party bidders.
IPC’s Internal Bids will be submitted to the independent evaluator (IE) no later than seven (7) days prior to the
opening of market bids. Market bids shall not be opened until the IE and IPC’s Evaluation Team have reviewed,
evaluated, validated and scored any and all Internal Bids. The Internal Bid scores will be assigned using the
same bid scoring and evaluation criteria that will be used to score market bids.
IPC is also making available to all Bidders the transmission rights defined in EXHIBIT E – Proposed Market
Purchase Volumes and requests Market Purchase Product bids that utilize these IPC transmission rights.
2.5. INDEPENDENT EVALUATOR
The OPUC appointed London Economics International LLC as the independent, third-party IE for the Solicitation.
The IE will help ensure the Solicitation is conducted transparently in accordance with OPUC Competitive
Bidding Rules and that all bids are evaluated consistently and impartially. The IE will report to the OPUC. The
general role and responsibilities of the IE are outlined as follows:
The IE will review the initial draft RFP and Scoring and Modeling Methodology (SMM) developed by IPC
prior to filing of the draft RFP with the OPUC and consult with IPC on changes to the draft RFP and SMM.
After IPC files the draft RFP with the OPUC, the IE will participate in workshops concerning the filed draft
RFP and SMM, and review filings by OPUC Staff and others concerning the RFP.
The IE will also review stakeholder comments, provide feedback and suggest modifications to the draft
RFP prior to IPC’s filing of the final RFP with the OPUC.
Prior to receipt of benchmark bids and market bids, the IE will review the assumptions to be used by IPC
in its quantitative evaluation of the bids, including those for its AURORA capacity expansion and
production cost simulation.
The IE will prepare and submit to the OPUC an assessment of the draft RFP (IE Draft RFP Assessment
Report) and the final RFP (IE RFP Assessment Report) in conjunction with IPC’s filing of the RFP with the
OPUC for approval. The IE Draft RFP Assessment Report and IE RFP Assessment Report shall review the
adequacy, accuracy and completeness of all solicitation materials to ensure compliance with the OPUC
competitive bidding requirements and consistency with accepted industry standards and practices.
The IE shall independently score the competing bids and file the corresponding scores with the OPUC. As
described herein, IPC will submit Benchmark Bids, and the IE will independently score the Benchmark
Bids and file scores with the OPUC prior to opening and scoring the competing bids.
The IE shall review IPC’s sensitivity analysis for the final shortlist as completed per OAR 860-089-
0400(5)(b) and file a written assessment with the OPUC.
After IPC’s selection of its final shortlist, the IE shall prepare the Closing Report, which shall provide the
IE’s detailed assessment of IPC’s selection of the final shortlist of submitted bid, including but not limited
to, all aspects of the solicitation process and the IE’s involvement, observations, conclusions and
recommendations. Additionally, the IE shall wholly detail the reasons and basis for IPC’s evaluation and
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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selection process including: a) ranking benchmark and market bids; b) selecting and scoring benchmark
and market bids and c) rejecting benchmark and market bids.

2.6. CONFIDENTIALITY
Bidder acknowledges and agrees that all information obtained or produced in relation to this RFP is the sole
property of IPC and shall not be released or disclosed to any person or entity for any purpose other than
providing a bid to IPC, without the express written consent of IPC. Bidder agrees not to make any public
comments or disclosures, including statements made for advertising purposes, regarding this RFP to the media
or any other party without prior written consent of IPC. Bidder shall forward any media or other inquiries
regarding this RFP to IPC.
Bidders shall specifically designate and clearly label any bid material(s) or portions thereof, that the Bidder
deems to contain proprietary information as “CONFIDENTIAL.” IPC reserves the right to release all bid materials,
including those marked “CONFIDENTIAL,” to its affiliates and its affiliates’ agents, advisors and consultants, for
purposes of bid evaluation. IPC will, to the extent required by law, advise each agent, advisor or consultant that
receives such claimed confidential information of its obligations to protect such information. All information,
regardless of its confidential or proprietary nature, is subject to review by the Commissions and other
governmental entities and courts with jurisdiction, and may be subject to legal discovery. Bidder acknowledges
and agrees, IPC will provide a copy of Bidder’s materials to the Commissions and IE for review and compliance
with this solicitation. All Bidders whose bids are advanced to the Initial Short List will be required to execute a
Mutual Nondisclosure and Confidentiality Agreement (Confidentiality Agreement) in the form of EXHIBIT M –
Mutual Non-Disclosure Agreement with IPC prior to further discussion and evaluation of the bid by IPC.
2.7. SOLICITATION PORTAL AND RESTRICTION ON COMMUNICATIONS
IPC has opened a web-based portal hosted on the Zycus sourcing platform (the Portal). The web link to register
within the Portal is: zsn.zycus.com/zsp/guest/genericRegister/IDA822. Once registered, instructions will be
provided within the Portal to guide Bidder’s on how to upload documents. All information exchanged between
the Bidder and IPC concerning the Solicitation must only be via the Portal from the time the Portal is open until
it is closed by IPC. All information, including pre-bid materials, questions and IPC’s response to questions, will be
posted in the Portal or on the Idaho Power website (public information) at idahopower.com/about-us/doing-
business-with-us/request-for-resources/. The Portal allows a Bidder to see only its own information and not the
information of other Bidders.
IPC has the ability to communicate with Bidders through the Portal. Other than written communication through
the Portal, Bidders are prohibited from communicating with IPC employees, representatives, staff or board
members regarding the Solicitation during the period in which the Portal is open. Restricted communication
includes, but is not limited to, “thank you” letters, phone calls, emails and any contact that results in the direct
or indirect discussion of the Solicitation and/or submitted bids. Violation of this provision by Bidders or their
agents may lead to disqualification.
Bidder is responsible for ensuring it has registered for, and posts documents to, the correct portal hosted by
Zycus. The Bidder registering for access to the Portal must be a representative of the Bidder and counterparty
with which IPC will engage in any future negotiations, and not consultants or attorneys for the Bidder.
Exhibit No. 4
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To ensure a competitive bid process, Bidders must not disclose its participation in this Solicitation (other than by
attendance at any meeting held by IPC with respect to the Solicitation) or collaborate on or discuss with any
other Bidder or potential bidding strategies or the substance of any bid(s), including without limitation the price
or any other terms or conditions of any bid(s). This does not preclude parties from partnering in good faith to
submit a competitive proposal.
Questions or support needs regarding the Portal should be directed to: [e-mail]. Any
questions that are relevant to all Bidders will be provided in response through the Portal.
2.8. SCHEDULE
The key milestones for the Solicitation and their currently scheduled dates are provided in Table 2-1 below.
Table 2-1 – Key Milestones for the Solicitation
Milestone Date
RFP Distributed to Market 4/5/2023
Original Bid Definition Forms Due 4/13/2023
Original Bid Entry Forms Distributed to Bidders 4/21/2023
Approval of AS RFP 6/7/2023
Bid Definition Forms Due 6/8/2023
Last Day for AS RFP Questions 6/8/2023
Bid Entry Forms Distributed to Bidders 6/9/2023
Benchmark Bids Due 6/9/2023
IPC Files Benchmark Bid Evaluations Report 6/13/2023
AS RFP Bids Due 6/23/2023
IE Completes Reply Comments on Benchmark Bid 6/23/2023
Open AS RFP Bids 6/26/2023
Bid Eligibility Screening Completed 6/30/2023
IE Files Report on Bid Eligibility Screening 7/14/2023
Initial Bid Scoring/Ranking Complete 7/14/2023
Initial Shortlist 7/21/2023
IE Completes Review and Files Report of Initial Shortlist 7/28/2023
IPC Notifies Bidders Selected to Initial Shortlist 7/31/2023
Bidders Provide Initial Shortlist Price/Production Update 8/15/2023
Exhibit No. 4
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Milestone Date
IPC Notifies Bidders Selected to Final Shortlist 10/2/2023
IPC Begins Preliminary Contract Negotiations 10/11/2023
This schedule and documents associated with the Solicitation are subject to change. IPC will endeavor to notify
Bidders of any changes to the Solicitation but shall not be liable for any costs or liability incurred by Bidders or
any other party due to a change or for failing to provide notice or acceptable notice of any change. Bidders
should factor this schedule, and any changes thereto, into their project development timelines and bids.
Bidders should carefully review this RFP for questions, clarifications, defects and questionable or objectionable
materials. Comments and questions concerning clarifications, defects and questionable or objectionable
material must be submitted through the Portal and must be submitted on or before the date and time specified
in the above schedule. IPC may not respond to questions submitted after this date. All questions and their
applicable responses will be provided to Bidders via the Portal.
3. Product Specifications
A bid must demonstrate that the specifications stated in this section are satisfied.
3.1. ELIGIBLE PRODUCTS
The Products eligible to be proposed in response to the RFP are presented in Table 3-1, Table 3-2 and Table 3-3
below (Product Tables). The Products are distinctly aligned with two types of electric energy and capacity
products.
The first type is energy and capacity delivered from electric resources that employ certain technologies
(Resource Based Products: Products 1–17 in Table 3-1 and Table 3-2). All proposed Resource Based Products
must be located within the IPC Balancing Area (BA) or demonstrate transmission rights to the IPC BA. Additional
requirements for Resource Based Products are found in Section 4. Note that IPC does not require that Bidders
provide a 35-year term for Bidder owned assets compared to shorter term lengths (for example, 20-year power
purchase agreement [PPA] for Solar photovoltaic [PV]), but would be very interested in receiving term bids
equivalent to the life of the asset even if a bid is submitted for a shorter-term.
The second type is firm energy (preference for WSPP Schedule C or equivalent) that meets the eligibility
requirements of the Western Resource Adequacy Program (WRAP) in terms of resource or system specificity,
transmission and other requirements (Market Purchase Products: Products 18–19 in Table 3-3). Additional
requirements for Market Purchase Products are found in Section 5.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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Table 3-1 – Resource Based Products – Renewables
Resource Type Solar PV Wind Geothermal
Product #1 2 3 4 5 6 7 8 9
Product
Description
Solar Short-
Term PPA
Solar Long-
Term PPA
Solar Asset
Purchase
Wind Short-
Term PPA
Wind Long-
Term PPA
Wind Asset
Purchase
Geothermal
Short-Term
PPA
Geothermal
Long-Term
PPA
Geothermal
Asset
Purchase
Structure PPA PPA
Asset
Purchase PPA PPA Asset
Purchase PPA PPA Asset
Purchase
Ownership Bidder Bidder IPC Bidder Bidder IPC Bidder Bidder IPC
Term < 35 years 35 years n/a < 35 years 35 years n/a <35 years 35 years n/a
Design Life 35 years
First Delivery On or before 6/1/2026 OR 6/1/2027
Resource Status Existing (not currently delivering to IPC) or proposed new in late-stage development with pending or executed LGIA/SGIA
Peak Capacity See Table 2 in Exhibit E
Energy See Table 2 in Exhibit E
Interconnection IPC Transmission System, or Non-IPC Transmission Systems with all necessary transmission rights to the BA
Delivery Point Within the boundary of the IPC Balancing Authority Area (BA), or outside with all necessary transmission rights to the BA
Other
Products must include all environmental attributes, including Renewable Energy Certificates (REC). Bidders will be responsible for
ensuring RECs are bundled, and that they are established through Western Renewable Energy Generation Information System (WREGIS).
Proposed pricing for Asset Purchases shall include Operating and Maintenance (O&M), Long-Term Services Agreement (LTSA) and
warranty costs for the proposed term.
Exhibit No. 4
Case No. IPC-E-24-16
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Table 3-2 – Resource Based Products – Storage and Gas-fired
Resource Type Battery Energy Storage
(BESS)
Long Duration Storage (LDS)Gas-fired Convertible to Hydrogen (G2H)
Product #10 11 12 13 14 15 16 17
Product
Description
BESS
BSA
BESS Asset
Purchase
LDS Short-
Term BSA
LDS Long-
Term BSA
LDS Asset
Purchase
G2H Short-Term
PPA
G2H Long-Term
PPA
G2H Asset
Purchase
Structure BSA 1 Asset Purchase BSA BSA Asset
Purchase PPA PPA Asset Purchase
Ownership Bidder IPC Bidder Bidder IPC Bidder Bidder IPC
Term 20 years n/a <35 years 35 years n/a
<35 years 35 years n/a
Design Life 20 years 35 years
First Delivery On or before 6/1/2026 OR 6/1/2027
Resource Status Existing (not currently delivering to IPC) or proposed new in late-stage development with pending or executed LGIA/SGIA
Peak Capacity See Table 2 in Exhibit E
Energy To be dispatched by IPC 0-100% of capacity
Interconnection IPC Transmission System, or Non-IPC Transmission Systems with all necessary transmission rights to the BA
Delivery Point Within the boundary of the IPC Balancing Authority Area (BA), or outside with all necessary transmission rights to the BA
Storage
Duration 4+ hours 6+ hours n/a
Storage Cycles Minimum 1 cycle per day n/a
Other
Storage must be chargeable from the grid by IPC.
Proposed pricing for Asset Purchases shall include Operating and
Maintenance (O&M), Long-Term Services Agreement (LTSA) and warranty
costs for the proposed term.
Proposed pricing for Asset Purchases shall include
Operating and Maintenance (O&M), Long-Term Services
Agreement (LTSA) and warranty costs for the
proposed term.
1 Battery Storage Agreement (BSA)Exhibit No. 4
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Table 3-3 – Market Purchase Products
Resource Type Market Purchase, Transmission Contingent Market Purchase,Non-Transmission Contingent
(i.e., able to be delivered to IPC’s Border by Seller)
Product #18 19
Product
Description Firm Heavy Load and Light Load Hour Energy and Capacity
Structure Agreement for purchase of firm energy and capacity (prefer WSPP Agreement Schedule C or equivalent) meeting Western Resource
Adequacy Program (WRAP) eligibility requirements, including resource specificity, transmission and other requirements. Agreement may
take the form of a confirmation under a mutually agreeable master agreement (e.g., WSPP or other), or a mutually agreeable standalone
agreement. See Exhibit E.
Ownership Bidder
Term Prefer 3 years or more
First Delivery On or before 6/1/2026
Resource Status Any
Design Life Any
Pricing Index-based preferred, will consider other proposals. Pricing should not include costs of regulatory structures not applicable in Idaho or
Oregon, and should be based on product being sunk in Idaho or Oregon.
Peak Capacity See table 2 and 3 in Exhibit E
Energy See Exhibit E, Tables 2 and 3; and Exhibit E, Requested Attributes
Interconnection n/a
Delivery Point Delivery to an eligible Point of Delivery as listed in Exhibit E, Table 4
(Contingent on IPC-owned transmission rights as described in
Exhibit E Table 4)
Delivery to Idaho Power Border, as described in Exhibit E.
Other The volumes in Exhibit E Tables 2 and 3 reflect the minimum WRAP Qualified Capacity Contribution requested. Index or index plus
adder-based pricing is preferred but other pricing structures will be considered. Pricing should not include costs associated with
regulatory structures not applicable in Idaho or Oregon. See Exhibit E.

Exhibit No. 4
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3.2. ALTERNATIVE PRODUCTS
IPC may also accept other Products that meet the ownership and electrical functionality criteria
outlined in the Product Tables. Bidders who propose a product not specifically identified in the
Product Tables must fully describe how their product can meet the general desires and intent of the
Product Table. Products that are not eligible include, but are not limited to; energy or capacity that is
not electrical (e.g., thermal energy storage without conversion to electric energy), renewable energy
credits without the associated energy (Unbundled RECs), and financial instruments used to mitigate
variable cost exposure without associated energy or capacity (Financial Firming).
3.3. TRANSMISSION ALTERNATIVES
As part of IPC’s Integrated Resource Plan processes, in addition to supply- and demand-side resources,
IPC is directed to give equal and balanced treatment to transmission resources. Therefore, IPC will also
accept bids for transmission ownership, service or long-term rights that may meet energy and capacity
needs identified above.

4. Resource Based Products: Additional Specifications
and Instructions
4.1. MINIMUM REQUIREMENTS
IPC has specified minimum requirements for participating bids (the Minimum Requirements) for
Resource Based Products. These requirements are listed in EXHIBIT C – Bid Eligibility Checklist. After IE
review and consultation, non-conforming bids will be notified and given the opportunity to correct
their bid within five (5) business days; otherwise, the bid will be disqualified and removed from
consideration. Consistent with OAR 860-089-0400(2)(c), non-price score criteria that seek to identify
minimum thresholds for a successful bid have been converted into minimum bidder requirements.
4.2. DELIVERY AND RESOURCE STATUS
IPC prefers bids from resources with proof of generator interconnection status and ability to deliver
such as a pending or executed Generation Interconnection Agreement (LGIA or SGIA), progress or
status of the interconnection study, and/or understanding of contingent queue projects that may
hinder deliverability.
4.3. OWNERSHIP AND AGREEMENT TYPES
As reflected in the Product Tables (tables 3-1, 3-2, and 3-3), bidders are encouraged to offer bids under
any of three different structures: 1) a PPA with exclusive rights for IPC to any and all capacity and
environmental attributes associated with the energy generated; 2) an asset purchase, which may
include a Build-Transfer Agreement (BTA) whereby the bidder develops the project, assumes
responsibility for construction, but ultimately transfers ownership of the asset to IPC or an agreement
for the purchase of an existing asset; and 3) a Battery Storage Agreement (BSA) with exclusive rights
Exhibit No. 4
Case No. IPC-E-24-16
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for IPC to the capacity and charging/discharging of a standalone battery. For PPA bids, IPC prefers term
lengths that match the life of the asset which will help in cost comparisons between bidders. However,
the term of the PPA is not a weighted score and will not advantage or disadvantage the bid on a non-
price basis.
Bidders are encouraged to configure resources to maximize energy delivery during hours that are
most valuable to IPC. Information concerning the hours that are most valuable to IPC is provided in
EXHIBIT G – Information on Most Valuable Hours for Resource Based Bids attached hereto.
Bids for new resources (a Project) to be owned by IPC must assume the parties will execute a BTA.
Under a BTA, the Bidder is responsible for all aspects of the development and construction of the
Project, including but not limited to, permitting, design, development, engineering, procurement,
construction, interconnection and all related costs up to achieving the to-be-agreed upon milestone,
which will not be earlier than mechanical completion or later than the date the Project is placed into
service for tax purposes. After reaching the milestone, the Bidder will transfer ownership of the
Project assets to IPC in exchange for a purchase price. Bids that contemplate the transfer of 100%
equity interests in a single member LLC are acceptable. After purchase, the Bidder will remain
responsible for the completion of the Project pursuant to a Construction Completion Management
Agreement. Beginning at execution of the BTA and related agreements, the Bidder must post cash
collateral or a letter of credit in the amounts specified in the BTA to secure its performance
(Performance Security). The amount of Performance Security increases and decreases over the term of
the Project development, construction and operation phases. IPC may elect to enter other types of
agreements proposed by the Bidder, including an Engineering Procurement Construction (EPC)
agreement, operation and maintenance service agreements, or other arrangements that generally
achieve the desired results.
Bids for existing resources (a Plant) not currently delivering to IPC, to be owned by IPC, must assume
parties will execute an asset purchase agreement and an O&M agreement.
Bidders are directed to EXHIBIT H – Draft Form Agreements for Resource Based Bids for more detailed
information concerning the key terms and conditions of the agreements. Bidders are required to
submit a redline of the Draft Form Agreements with their bids. Bidders are also directed to EXHIBIT O –
Draft Form Letter of Credit for reference. In such cases that the Bidder is successful, Bidder shall be
responsible for furnishing a letter of credit in a format substantially similar to the forms included in
this RFP. These forms shall be subject to review and acceptance by IPC in its reasonable discretion.
Bidder shall deliver the required letter of credit no later than 30 days following any such notice of
award.
4.4. INTERCONNECTION STUDIES AND COST ESTIMATING
Bidder is responsible for understanding the generator interconnection processes of IPC or other
Transmission Providers, considering the durations and costs of those processes in its bids, and
successfully executing those processes to achieve coordination with IPC and delivery of the proposed
Products to IPC on or before the dates identified in its proposed schedule for the resource. A Bidder
proposing to interconnect a resource on to IPC’s system must demonstrate it has submitted a
Exhibit No. 4
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Generator Interconnection (GI) request and is meeting the requirements of the GI request process,
and that all known incremental costs to deliver energy from the resource to IPC’s load have been
included in the bid (including the interconnection facility types and cost estimates defined below). A
Bidder proposing to interconnect to another Transmission Provider’s system must demonstrate that it
has submitted a GI request and any required transmission service request(s) to the relevant
Transmission Providers and that it is meeting the requirements of those processes.
The Transmission Provider function within IPC, separate and apart from the Evaluation Team, performs
studies for GI application requests. The studies are performed to determine the feasibility, cost, time
to construct and injection capability for the interconnection of an electric generating resource.
Information concerning GIs can be found on IPC’s website at Generator Interconnection — Idaho
Power, including information on Public Utility Regulatory Policies Act of 1978 (PURPA) Qualifying
Facility (QF) interconnections, Non-PURPA GIs, and Facility Connection Requirements. IPC posts the
results of these studies on its Open Access Same-Time Information System (OASIS) website.
For purposes of aiding Bidders in determining points of interconnection and delivery on the IPC
transmission system, IPC has identified areas on the IPC system that are currently expected to have
relatively high injection capability and relatively low cost and time to construct if studied by the IPC
Transmission Provider. These areas are identified in EXHIBIT F – Information on Preferred Locations for
Resource Based Bids of this RFP.
If a Bidder has an active GI request, the Bidder must provide the GI request identifier(s) (the queue
position) associated with its resource in its bid. If the resource identified in the bid was in the queue
but has since withdrawn, the Bidder should provide that queue position even though it is no longer
active.
The interconnection facility types and cost estimating requirements are specified below.
Interconnection Customer’s Interconnection Facilities (ICIF) are all facilities and equipment
(including the generation tie line) located between the resource and the Point of Change of
Ownership. Bidder must submit resource-specific cost estimates of ICIF as part of its bid and
consider the cost of ICIF in its pricing.
Transmission Provider Interconnection Facilities (TPIF) connect the Interconnection
Customer’s Interconnection Facilities to the Transmission Provider transmission system and
facilitate the metering, relaying and communications, etc. TPIF are all facilities owned,
controlled or operated by the Transmission Provider from the Point of Change of Ownership
to the Point of Interconnection. These are facilities that the Transmission Provider will own,
and the Bidder will fund. Bidder must submit resource-specific cost estimates of TPIF as part
of its bid and consider the cost of TPIF in its pricing. In the absences of an estimate, IPC will
develop an estimate based on the information provided in Table 4-1 below. If an
interconnection study has been performed by the Transmission Provider that includes an
estimate of TPIF, then the costs from that study should be used in lieu of these estimates.
Exhibit No. 4
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Table 4-1 – Estimated Cost for TPIF
Voltage TPIF Estimated Cost (2023 $ 000s)
138 kV $2,000
230 kV $3,000
345 kV $4,000

Station Network Upgrades (SNU) are either new switchyards or additions to existing
switchyards or substations that are built to interconnect the generator to the IPC transmission
or distribution system. SNUs become a component of the integrated IPC transmission or
distribution system and are incorporated into IPC tariffs. Bidders are required to provide cost
estimates of SNUs.
Delivery Network Upgrades (DNU) are upgrades to IPC’s transmission or distribution network
that will be required for individual resources and groups of resources. These upgrades will be
incorporated into IPC’s transmission or distribution tariffs. Bidders are required to provide
cost estimates of DNUs.
Based on information available from the GI request (if any) and/or studies and estimates performed by
the Transmission Provider(s), separate and apart from the Evaluation Team (if available), the
Evaluation Team will determine bid-specific SNUs and DNUs and associated costs to include in the
evaluation of a bid. The Evaluation Team’s development of bid-specific SNUs/DNUs does not take the
place of the IPC Open Access Transmission Tariff (OATT) GI and transmission studies, and does not
remove the bidder’s obligation to submit GI or transmission requests to the Transmission Provider(s).
With respect to transmission service, for resources that will be owned in full or in part by IPC or for
which IPC will have an executed contract for the purchase of the generation, IPC anticipates that it will
designate the resource or executed contract as Network Resources of IPC under the OATT upon
commercial operation of the resource or first delivery date under the contract. Projects that are
seeking to interconnect to IPC’s system and have not requested Network Resource Interconnection
Service (NRIS) may need additional costs added to account for additional upgrades needed to ensure
delivery to load.
4.5. BID SUBMISSION PROCESS
A bid is considered the aggregate of the information uploaded by a Bidder to the Portal (Information).
The Information is in the form of data entered into forms on the Portal and subsequently uploaded to
the Portal by the Bidder and other written documents that are uploaded to the Portal. The Portal is
designed to accept the majority of the Information as data entered into the forms with data entry
restricted to only certain eligible types and values. The purpose is to ensure Information is entered
consistently across all Bidders and bids such that IPC can consistently, fairly and quickly organize the
information and evaluate the bids and minimize the amount of written (e.g., PDF, .docx) documents
that IPC must review and interpret.
Exhibit No. 4
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i Bid Definition Form
Any potential Bidder interested in participating in the RFP must first register in the
Portal. Once registered, the bid submission process begins with completion and
submission to IPC of an EXHIBIT A – Bid Definition Form (BDF) located in the Portal for
each bid that a bidder intends to submit. The BDF requests preliminary information
about the proposed Product(s) including a narrative description and basic Product
parameters.
ii Bid Entry Form and Selectable Portfolio
IPC will review the submitted BDF and subsequently respond to the Bidder with an
EXHIBIT B – Bid Entry Form (BEF) that is relevant to the proposed Product(s). The BEF
requests complete technical, commercial, financial and pricing information concerning
the proposed Product(s) for purposes of subsequent bid evaluation.
A Bidder may identify two or more of its bids, that if executed by IPC together, may
result in a lower total price or greater benefit to IPC than if the bids were not executed
together. An example of a Selectable Portfolio is a solar bid and wind bid and a storage
bid where the Bidder would not offer or contract any one of the individual
components, but rather all three are contingent. Another example is a 100 MW solar
PPA bid and a 100 MW solar asset purchase bid from a 200 MW solar project. If a
Bidder desires to combine, or make contingent, multiple Products of various structure,
ownership, term or resource type, then the Bidder will indicate within the BEF that
combination of Products that make a single portfolio (Selectable Portfolio). A
Selectable Portfolio will be evaluated as a complete proposal such that if it were
selected, the entire Selectable Portfolio would be reviewed for contract negotiation.
IPC will provide each Bidder with Bid Fee instructions to accompany the BEF when the
BEF is provided to the Bidder.
iii Bid Submittal
Bidders will submit the BEF and ancillary Information as defined in the RFP to the
Portal. The BEF requires certain cost data as inputs to the price score model.
Bidders are strongly advised to carefully review all exhibits relevant to their proposed Products prior to
uploading Information to the Portal. If and when a Bidder is selected for negotiation of an agreement,
IPC will utilize the Information submitted to populate the relevant portions of the agreements for that
Bidder. Bidders should upload Information with the understanding that it will ultimately result in
binding contract terms.
4.6. BID FEES
A Resource Based Product Bidder is required to submit to IPC a non-refundable fee with each bid
submitted (Evaluation Fee). The purpose of the Evaluation Fee is to encourage submission of well-
Exhibit No. 4
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developed and viable bids and to offset the cost to IPC for evaluation of bids. For each bid submitted,
the Bidder may submit a sub-bid at a reduced Evaluation Fee as described below. Bidders must use the
following guidance for the purpose of determining and submitting the Evaluation Fees, due with each
bid and sub-bid.
Bid Fee Example
A single project site and resource type
(can include multiple structures, terms,
and price)
$9,926 Site Alpha, 200 MW Solar PV, PPA, 35-yr
and
Site Alpha, 200 MW Solar PV, Asset Purchase
Same site and resource type but different
capacity or initial delivery year
+$4,963 Site Alpha, 400 MW Solar PV, Asset Purchase
Different site = different bid $9,926 Site Bravo, 150 MW BESS, 20-yr, BSA
Different resource = different bid
unless the different resource is part of,
and required, as part of the
Selectable Portfolio
$9,926 Site Alpha, 300 MW Wind, Asset Purchase
(different bid = $9,926)
or
Site Alpha, 300 MW Wind, Asset Purchase
contingent on Site Alpha, 200 MW Solar PV, PPA,
35-yr as a Selectable Resource only (not a
different bid)
IPC may deem a bid that does not satisfy the requirements for a single bid as multiple bids, each of
which would require a separate Evaluation Fee. If IPC deems a Bidder’s bid to be multiple bids, IPC will
notify the Bidder and allow the Bidder to elect to pay the incremental Evaluation Fee or to revise its
bid to comply with IPC’s requirements for a single bid.
4.7. EXCEPTIONS TO THE TECHNICAL SPECIFICATIONS
Bidders that propose a resource for IPC ownership must provide bids and pricing that are consistent
and compliant with the applicable Technical Specifications provided as exhibits to this RFP (namely
EXHIBIT I – BESS Technical Specifications; EXHIBIT J – Solar Technical Specifications; EXHIBIT K – Wind
Technical Specifications; and EXHIBIT L – Gas-Fired Convertible to Hydrogen Specifications). To the
extent that the validity of a Bidder’s bid and/or the Bidder’s ability to execute an agreement is
contingent upon material changes to the language in the Technical Specifications, the Bidder must
specifically identify the specifications it proposes to change in the form of a redline markup to the
Technical Specification and submit the redline with its bid. To the extent that a Bidder wishes to
propose changes to the Technical Specification that, if accepted by IPC, would reduce the Bidder’s
proposed pricing, the Bidder should specifically identify in the redline such changes and the associated
price reduction. To the extent practicable, Bidders should develop exhibits, schedules, attachments
and other supplemental documents required by the Technical Specification in the redline.
Exhibit No. 4
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The proposed changes must be specific and include a detailed explanation and supporting rationale for
each. General comments, drafting notes and footnotes such as “parties to discuss” will be disregarded
and not negotiated. Exceptions to the Technical Specifications requested by a Bidder will be reviewed
as part of IPC’s qualitative evaluation of the bid.
4.8. EXCEPTIONS TO THE DRAFT FORM LETTER OF CREDIT
Bidders that propose a resource for IPC ownership must provide bids and pricing that are consistent
and compliant with the EXHIBIT O – Draft Form Letter of Credit. To the extent that the validity of a
Bidder’s bid and/or the Bidder’s ability to execute an agreement is contingent upon material changes
to the language in the draft form letter of credit, the Bidder should specifically identify the terms they
propose to change in the form of a redline markup to EXHIBIT O – Draft Form Letter of Credit and
submit the redline with its bid. To the extent that a Bidder wishes to propose changes to the draft
form letter of credit that, if accepted by IPC, would reduce the Bidder’s proposed pricing for the bid,
should specifically identify in the redline such changes and the associated price reduction.
The proposed changes must be specific and include a detailed explanation and supporting rationale for
each. General comments, drafting notes and footnotes such as “parties to discuss,” will be disregarded
and not negotiated. Exceptions requested by a Bidder will be reviewed as part of IPC’s qualitative
evaluation of the bid.
5. Market Purchase Products: Additional Specifications
and Instructions
5.1. MINIMUM REQUIREMENTS
IPC has specified the Minimum Requirements for Market Purchase Products. These requirements are
listed in EXHIBIT C – Bid Eligibility Checklist. After IE review and consultation, non-conforming bids will
be notified and given the opportunity to correct their bid within two (2) business days; otherwise the
bid will be disqualified and removed from consideration. Consistent with OAR 860-089-0400(2)(c),
non-price score criteria that seek to identify minimum thresholds for a successful bid have been
converted into minimum bidder requirements.

5.2. AGREEMENT TYPES
IPC will consider proposals for agreements consisting of confirmations under mutually-agreeable
master agreements (i.e., WSPP or other), or mutually-agreeable standalone agreements.
5.3. PRODUCT ATTRIBUTES
Additional description of the volumes and product attributes Idaho Power is seeking are listed in
EXHIBIT E – Proposed Market Purchase Volumes. IPC anticipates that it will designate the resource or
executed contract as Network Resources of IPC under the OATT upon commercial operation of the
resource or first delivery date under the contract.
Exhibit No. 4
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5.4. BID SUBMISSION PROCESS
A bid is considered the aggregate of the Information uploaded by a Bidder to the Portal (Information).
The Information is in the form of data entered into forms on the Portal and subsequently uploaded to
the Portal by the Bidder and other written documents that are uploaded to the Portal. The Portal is
designed to accept the majority of the Information as data entered into the forms with data entry
restricted to only certain eligible types and values. The purpose is to ensure Information is entered
consistently across all Bidders and bids such that IPC can consistently, fairly and quickly organize the
Information and evaluate the bids and minimize the amount of written (e.g., PDF, .docx) documents
that IPC must review and interpret.
i Bid Definition Form
Any potential Bidder interested in participating in the RFP must first register in the
Portal. Once registered, the bid submission process begins with completion and
submission to IPC of an EXHIBIT A – Bid Definition Form (BDF) located in the Portal for
each bid that a bidder intends to submit. The BDF requests preliminary information
about the proposed Product(s) including a narrative description and basic Product
parameters.
ii Bid Entry Form
IPC will review the submitted BDF and subsequently respond to the Bidder with an
EXHIBIT B – Bid Entry Form (BEF) that is relevant to the proposed Product(s). The BEF
requests complete technical, commercial, financial, and pricing information
concerning the proposed Product(s) for purposes of subsequent bid evaluation.
iii Bid Submittal
Bidders will submit the BEF and ancillary Information as defined in the RFP to the
Portal. The BEF requires certain cost data as inputs to the price score model.
Bidders are strongly advised to carefully review all exhibits relevant to their proposed Products prior to
uploading Information to the Portal. If and when a Bidder is selected for negotiation of an agreement,
IPC will utilize the Information submitted to populate the relevant portions of the agreements for that
Bidder. Bidders should upload Information with the understanding that it will ultimately result in
binding contract terms.
6. Additional Requirements for All Products and Bids
6.1. CONTENTS OF WRITTEN BID PROPOSAL
A Bidder MUST prepare and submit as part of the bid a written narrative that fully describes the bid
and any details or nuances to fully explain the intent of the Bidder and the BEF. The narrative should
include a cover letter and introduction, company and project overview, a description of each
Exhibit No. 4
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product submitted in the BEF and project financing and contract terms according to Exhibit P – Bid
Format and Requirements.
6.2. BID NAMING
A unique name for each bid (Bid Code) will be developed by selecting and entering into the BEF where
indicated the Product Type, Bid Name, Delivery Level and whether the facility is new or existing. The
resulting Bid Code must thereafter be used by the Bidder when referring to the bid and must be
inserted into the file name of each document for the bid uploaded by the Bidder. The purpose of the
Bid Code is to allow IPC to more easily identify and differentiate among bids and documents.
6.3. BID WRITTEN DOCUMENTS
Written documents must be text-searchable PDF (portable document format, non-zipped) and must
contain documents reproduced directly from the native document (i.e., Word, Excel, MicroStation,
AutoCAD). Scanned images and documents will be considered irregular and may be rejected.
6.4. RFP EXHIBITS
Exhibits to this RFP summarize the information that must be uploaded by Bidders to the Portal.
Bidders are directed to the individual forms in the Portal to ensure review of all the current
information and the specific type and level of detail that must be provided is understood and are
summarized below. In Table 6-1 are the required exhibits that must be completed depending on the
type of contract offered.
Table 6-1 – Non-Price Factor
Exhibit Asset
Purchase
PPA/BSA Market Purchase
Products
Exhibit B – Bid Entry Form X X X
Redlines to Exhibit H – Draft Form Agreements for
Resource Based Products
X X
Redlines Exhibit I, J, K, and L (Technical Specifications) X
Exhibit N – Counterparty Financial Questionnaire X X X
6.5. FIRM BID
Each bid shall be firm, not subject to price escalation, and binding throughout the schedule of this RFP
from the date the bids are due under this RFP. Note, however, the bid evaluation process does have
an opportunity to update pricing.
Exhibit No. 4
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6.6. TAXES
Bidders are responsible for the payment of all sales, conveyance, transfer, excise, real estate transfer,
business and occupation and similar taxes assessed with respect to or imposed on either party in
connection with a proposed agreement.
6.7. DATA AND CYBER SECURITY
A bid must comply with the provisions of Presidential Executive Order 13920 (E.O. 13920) issued
May 1, 2020, titled Securing the United States Bulk-Power System (BPS), which (among other things)
prohibits any acquisition, importation, transfer or installation of BPS electric equipment by any person
or with respect to any property to which a foreign adversary or an associated national thereof has any
interest, that poses an undue risk to the BPS, the security or resiliency of United States (U.S.) critical
infrastructure or the U.S. economy, or U.S. national security.
All design and implementation details must follow electrical industry best practices for cyber security
as well as all applicable regulatory requirements pertaining to the security of electric system assets.
Any additional IPC-specific requirements will be addressed during the RFP review and contracting
process, pursuant to EXHIBIT M – Mutual Non-Disclosure Agreement. Bidder must state that any and
all equipment utilized in the proposed resource will not be procured through an Office of Foreign
Assets Control (OFAC) designated entity or otherwise be comprised of equipment prohibited for use
by electric utilities in the U.S.
6.8. PURCHASING RESTRICTIONS/PROHIBITED TECHNOLOGY
Pursuant to Section 889 of the John S. McCain National Defense Authorization Act for Fiscal Year 2019
and Federal Acquisition Regulation (FAR) 52.204-25 (Aug. 2020), Bidder agrees, represents and
warrants that Bidder shall not supply or deliver to IPC any “covered telecommunications equipment or
services” as a substantial or essential component of any system or critical technology of any system.
As defined in FAR 52.204-25(a), “covered telecommunications equipment or services” includes
equipment, systems, products or services made by any of the following companies, or any subsidiary
or affiliate thereof (including companies with the same principal word in the name, e.g., “Huawei” or
“Hytera”): Huawei Technologies Company; ZTE Corporation; Hytera Communications Corporation;
Hangzhou Hikvision Digital Technology Company; or Dahua Technology Company. “Covered
telecommunications equipment or services” may include, but are not limited to, video/monitoring
surveillance equipment/services, public switching and transmission equipment, private switches,
cables, local area networks, modems, mobile phones, wireless devices, landline telephones, laptops,
desktop computers, answering machines, teleprinters, fax machines and routers. “Covered
telecommunications equipment or services” do not include telecommunications equipment that
cannot route or redirect user data traffic or permit visibility into any user data or packets that the
equipment transmits or handles.
To the extent that the systems, products or services to be provided by Bidder under this Agreement
may be procured by IPC in support of or to satisfy IPC’s obligations under agreements with a federal
governmental entity, Bidder further agrees that FAR 52.204-25 (August 2020), except for paragraph
Exhibit No. 4
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(b)(2) thereof, shall be incorporated by reference into any future agreement and is binding on Bidder,
and that Bidder does not use any equipment, system or service that uses covered telecommunications
equipment or services and will not supply any covered telecommunications equipment or services to
IPC. Bidder further agrees that, if it identifies covered telecommunications equipment or services used
as a substantial or essential component of any system or as critical technology as part of any system
during contract performance, or Bidder is notified of such by a subcontractor at any tier or any other
source, Bidder shall immediately notify IPC and reasonably cooperate with IPC’s requests for
information.
6.9. SMALL BUSINESS AND SMALL DISADVANTAGED BUSINESS PROGRAM
IPC is committed to the implementation of a Small and Disadvantaged Business Program. It is the
intent of IPC that small business concerns and small businesses owned and controlled by socially and
economically disadvantaged individuals have the opportunity to participate in the performance of
contracts awarded by IPC. Consequently, IPC requests that Bidders indicate their eligibility as a small
business based upon the regulations in Title 13, Code of Federal Regulations, Part 121. If in doubt,
Bidders should consult the Small Business Administration Office in their area.
6.10. INSURANCE
Bidder is directed to the EXHIBIT H – Draft Form Agreements for Resource Based Bids for details
concerning the specific insurance requirements that must be met.
6.11. FINANCIAL AND CREDIT INFORMATION
Bidder must provide a written response and associated documents in response to the Counterparty
Financial Questionnaire. Details are further described in EXHIBIT N - Counterparty Financial
Questionnaire of this RFP.
6.12. EXCEPTIONS TO THE DRAFT FORM AGREEMENTS
Bidders must provide bids and pricing that are consistent and compliant with EXHIBIT H – Draft Form
Agreements for Resource Based Bids. To the extent that the validity of a Bidder’s bid and/or the
Bidder’s ability to execute an agreement is contingent upon material changes to the language in the
draft form agreements, the Bidder should specifically identify the terms they propose to change in the
form of a redline markup and submit the redline with its bid. To the extent that a Bidder wishes to
propose changes to the draft form agreements that, if accepted by IPC, would reduce the Bidder’s
proposed pricing the proposed changes should specifically identify in the redline such changes and the
associated price reduction. To the extent practicable, Bidders should develop exhibits, schedules,
attachments and other supplemental documents required by the draft form agreements in the
redline. Bidders proposing to sell existing generation facilities should propose in the redline changes to
the draft form agreements for the proposed resource type reflecting the terms and conditions on
which their bid is based. Note that not every technology and contract structure is presented in the
draft form agreements and thus proposed contracts and terms should be provided for contracts that
are substantively different to the provided draft form agreements. For a Wind PPA, Bidders should
Exhibit No. 4
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review and redline the substance of the EXHIBIT H – Power Purchase Agreement commercial terms
with the inclusion of the EXHIBIT H – Wind Performance Guarantees.
The proposed changes must be specific and include a detailed explanation and supporting rationale for
each. General comments, drafting notes and footnotes such as “parties to discuss” will be disregarded
and not negotiated. Exceptions to the draft form agreements requested by a Bidder will be reviewed
as part of IPC’s qualitative evaluation of the bid.
6.13. CLARIFICATION OF BIDS
While evaluating a bid, IPC may request clarification or additional information from the Bidder about
any item in its bid. Such requests will be sent via the Portal by IPC and the Bidder must provide a
response via the Portal back to IPC within five (5) business days, or IPC may deem the Bidder to be
non-responsive and either suspend or terminate further evaluation of its bid. Bidders are encouraged
to provide an alternate point of contact to ensure a timely response to clarification requests.
6.14. ADDENDA TO RFP
Any additional responses required from Bidders as a result of an Addendum to this RFP shall become
part of each bid. Bidders must acknowledge receipt of and list all addenda where indicated in the BEF.
7. Bid Evaluation, Negotiation and Approval
7.1. THE EVALUATION PROCESS
The bid evaluation and selection process are designed to identify the combination and size of
proposed resources (the Portfolio) that will maximize customer benefits and will satisfy projected
resource capacity and energy needs while maintaining reliability. The portfolio optimization models
used to identify the proposed resources are the same that IPC uses to evaluate proxy resources in the
2021 IRP (and subsequent IRPs). IRP portfolio optimization process details can be found in the
company’s most recently acknowledged 2021 IRP report in sections 9 and 10 and summarized in
EXHIBIT Q – IRP Modeling Assumptions.
IPC will separate and prioritize bids that can conform to meet a June 1, 2026, commercial operation
separately from those that confirm to meet a June 1, 2027, commercial operation. The bid evaluation
process is described below.
7.2. PHASE 1 – INITIAL SHORTLIST
Phase 1 of the bid evaluation process includes the screening, evaluation and ranking of the bids to
identify a subset that can be advanced to further evaluation (the Initial Shortlist). This includes: 1) bid
eligibility screening to ensure conformance with the Minimum Requirements; 2) price, and non-price
evaluation to score and rank bids; and 3) identification of the lowest cost bids for inclusion in the
Initial Shortlist.
Exhibit No. 4
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IPC will rely on the pricing and other data submitted by Bidders to screen, evaluate and rank bids.
During this phase of the bid evaluation process, IPC does not anticipate asking for, nor accepting,
updated pricing or updates to any other bid components. However, IPC will contact Bidders to confirm
and clarify information presented in each bid if necessary.
Additionally, if at any time during Phase 1, a Bidder determines its submitted bid is no longer valid, the
Bidder should notify IPC immediately and the bid will be withdrawn from further consideration.
Conformance to Minimum Requirements
Bids will initially be screened against the Minimum Requirements using EXHIBIT C – Bid Eligibility
Checklist and in consultation with the IE. After IE review and consultation, Bidders of non-conforming
bids will be notified and given the opportunity to correct their bid within two (2) business days;
otherwise, the bid will be removed from consideration.
Price and Non-Price Scoring, Ranking, and Initial Shortlist
After the eligibility screening has been completed, conforming bids will be evaluated and given price
and non-price scores. Each bid will be ranked based on the sum of their price and non-price bid score.
A maximum of 75 points are allocated to price scoring and a maximum of 25 points to non-price
scoring for a total maximum score of 100 points. Bids are then ranked within the respective
technology group, and the highest scoring bids within each technology group are chosen to be the
Initial Shortlist. Reasonable excess to, at a minimum, meet the identified capacity and energy needs
specified will be included.
Resource Based Product Price Score (up to 75 points)
IPC’s proprietary price scoring model will calculate the delivered revenue requirement per
kilowatt cost of each bid, inclusive of any applicable carrying cost and the impact of tax credit
benefits, as applicable. In developing the revenue requirement cost for each bid, IPC requires
certain cost data as inputs to the price score model. IPC will convert Bidder provided cost
inputs into a revenue requirement stream based on Generally Accepted Accounting Principles
(GAAP) and develop annual levelized costs as described in Exhibit R – Levelized PVRR
Scenarios. Any internal assumptions for key financial inputs (i.e., inflation rates, discount rates,
marginal tax rates, asset lives, allowance for funds used during construction [AFUDC] rates,
etc.) and IPC’s carrying costs (i.e., integration costs, owner’s costs, etc.) will be applied
consistently to all bids, as applicable.
As stated under Interconnection Studies above, Bidders must provide known costs for
interconnection costs and transmission network upgrade costs as provided in applicable
system impact study reports or LGIAs. If this information is not available, IPC will model the
bids with an anticipated cost based on the location of the interconnection point. IPC will
model bids with other uncertain terms and anticipated cost or price contingencies as
applicable.
Exhibit No. 4
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IPC’s proprietary price scoring model scores each bid relative to each other within the same
technology where feasible. Each bid’s per kilowatt price is ranked to determine the bid’s price
score. For each technology, a maximum score of 75 points is assigned to the bid with the
highest calculated relative score and a minimum of zero (0) points to the evaluated bid with
the lowest calculated relative score. The remaining bids using that same technology are scored
on a 0-to 75-point scale according to their relative relationship to those of the highest and
lowest performing bids.
Resource Based Products Non-Price Score (up to 25 points)
The non-price evaluation rubric for Resource Based Products is included in EXHIBIT D –
Non-Price Scoring Matrix. IPC’s non-price scoring model evaluates whether bids are thorough
and comprehensive, whether the proposed resource is viable and whether the bidder is likely
to achieve commercial operation by June 1, 2026, (or alternatively June 1, 2027) or the
proposed commercial operation date. Bidder must provide documentation, representation,
warranties and other information as necessary to sufficiently assure IPC that any proposed
project will complete construction and achieve full commercial operation by the defined
commercial operation date. The non-price rubric is designed to be objective, intuitive and self-
scoring. Bidders are required to score themselves by answering each of the non-price
questions and providing supporting documentation. The non-price questions seek to rank bids
based, among other factors, on the completeness of 2026 RFP bid requirements, the ability to
contract with the project, the maturity of the project and ability to deliver the project by the
commercial operation deadline. The questions and answers are defined in two categories and
weighted as described in Table 7-1.
Table 7-1 — Non-Price Factor Weighting
Non-Price Factor Maximum Points
Contracting Progress and Viability 5 points
Project Readiness and Deliverability 20 points
The first non-price factor section, “Contracting Progress and Viability,” scores Bidders based
on their ability to contract the bid. The single weighted question is worth up to five points and
will be given a score of zero or five. The intent of this question is to ensure Bidder’s have
submitted a bid that is generally consistent with the form agreements and technical
specifications, or appropriate revisions have been suggested.
The second section, “Project Readiness and Deliverability,” assesses each bid’s development
status and viability. Points are earned based on energy and capacity certainty, transmission
capacity availability, degree of site control, permits attained, status of generation
interconnection, completed equipment sourcing strategy and other operational characteristics
and having a reasonable construction schedule. If a Bidder is unable to demonstrate
commercial viability, and specifically the ability to meet the applicable in-service date, they
will be removed from further evaluation. Each question is weighted differently with a focus on
Exhibit No. 4
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current progress including site control and easements, state of generation interconnection
and network resource status, development schedule and safety. Additional considerations
include short-term permits, experience, financing and status of material and contractor
agreements. The maximum score possible for the 12 non-price questions is 100, which is then
divided by five to achieve a total score out of 20.
Market Purchase Products Price Evaluation
Market Purchase Products’ pricing will be evaluated and ranked based on the price structure
submitted with the bid. This initial scoring is for informational purposes. As noted below, the
Market Purchase Products that meet Minimum Qualifications will be submitted to the IRP
Planning Team for further analysis.

Market Purchase Products Non-Price Score (up to 25 points)
The non-price evaluation rubric for Market Purchase Products is included in EXHIBIT D –
Non-Price Scoring Matrix. IPC’s non-price scoring model evaluates whether bids are thorough
and comprehensive and meet the requested attributes as described in EXHIBIT E – Proposed
Market Purchase Volumes. Bidder must provide documentation, representation, warranties
and other information as necessary to sufficiently assure IPC that any proposed product will
meet the requirements. The non-price rubric is designed to be objective, intuitive and self-
scoring. Bidders are required to score themselves by answering each of the non-price
questions and providing supporting documentation. The non-price questions seek to rank bids
based, among other factors, on the completeness of 2026 RFP bid requirements and the bid’s
ability to meet the requested attributes described in EXHIBIT E – Proposed Market Purchase
Volumes.
Points are earned based on the bid’s ability to meet each of the product attributes requested
in EXHIBIT E – Proposed Market Purchase Volumes. If a bid offers attributes that could require
Idaho Power to incur additional costs (i.e., a bid of a WSPP Schedule B product could require
Idaho Power to incur additional Point-to-Point transmission costs), those costs will be
estimated and included in the pricing analysis. Each question is weighted differently with a
focus on product type, contribution to identified needs, shaping and flexibility options,
Western Resource Adequacy Program eligibility, point of delivery and pricing structure. The
maximum score possible for the 11 non-price questions is 100, which is then divided by four to
achieve a total score out of 25. This initial scoring is for informational purposes. As noted
below, the Market Purchase Products that meet Minimum Qualifications will be submitted to
the IRP Planning Team for further analysis.
Final Ranking (up to 100 points)
To determine the initial bid pool to be further evaluated, IPC will use the combined price and
non-price results to rank each bid. Based on these rankings, IPC will identify an initial pool of
highest-ranked bids by product and technology. This initial pool of bids will be made available
as alternatives for further modeling.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 30 of 1056
Page 27
Selection of the Initial Shortlist and Notification by IPC
The highest ranking and relatively lowest cost bids within each technology category will become the
Initial Shortlist. After the IE completes its review and files its report on the Initial Shortlist, IPC will
notify Bidders through the Portal that were selected for the Phase 1 – Initial Shortlist.
7.3. PHASE 2 – FINAL SHORTLIST
Phase 2 is the selection of the final shortlist. Bidders on the Initial Shortlist will be required to provide
IPC with any updates to their bids including relevant price or schedule modifications, interconnection
study results or any other material change that would impact the IRP production cost model or
Minimum Requirements of the RFP. IPC will then process updates for inclusion in the IRP production
cost models. AURORA will be run to help select the least-cost, least-risk portfolios based on bid cost,
performance data, and ELCC.
IPC will perform a reliability assessment to ensure that the selected portfolio of resources can meet all
hourly load and operating reserve requirements with sufficient cushion to account for other system
uncertainties such as non-normal weather events. This process is described in the company’s most
recently acknowledged 2021 IRP in the Technical Appendix C in the “Loss of Load Expectation” section.
IPC does not anticipate updating the non-price portion of the bid evaluation from Phase 1. However, if
at any time during Phase 2, a bidder determines its submitted bid is no longer valid, the bidder should
notify IPC immediately and the bid will be withdrawn from further consideration. Original non-price
scores combined with IRP modeling results will be considered in a cost and risk analysis. Any other
factors not expressly included in the formal evaluation process but required by applicable law, order
by the Commissions or other significant material industry or technology change may be used by IPC, in
consultation with the IE, to identify a subset of Bidders from Phase 1 that can be advanced to further
evaluation and negotiation (the Final Shortlist).
Processing of Bid Updates
Similar to the Phase 1 pricing evaluation, IPC uses its proprietary models to process bid updates. The
models are refreshed with updated bid information, including price. Consistent with the treatment of
capital revenue requirement in IPC’s IRP modeling, IPC will convert any calculated revenue
requirement associated with capital costs (i.e., return on investment, return of investment and taxes
and the impact of tax credits, as applicable) to first year real-levelized costs. Similarly, all other bid
costs are levelized and formatted for input into to the IRP models. Projected renewable resource
performance data (expected hourly capacity factor information) and ELCC are also processed for input
into the IRP models.
Bid Resource IRP Modeling, Sensitivity Analysis and Portfolio Development
The IRP team uses the AURORA model to help select the least-cost, least-risk resource types based on
bid cost, performance data and ELCC and select the Final Shortlist. IPC uses AURORA to develop and
evaluate the cost of multiple resource portfolios with various sensitivities and contingencies e.g.,
Boardman to Hemingway in-service dates).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 31 of 1056
Page 28
Following the Initial Shortlist and bid updates, IPC will submit the pool of bids (including Market
Purchase Products that have met the Minimum Qualifications) to its IRP Planning Team to evaluate
resources for the Final Shortlist. The IRP Planning Team will evaluate the pool of resources using
AURORA, the production cost model used in the IRP. Consistent with the treatment of capital revenue
requirement in IPC’s IRP modeling, IPC will convert any calculated revenue requirement associated
with capital costs (i.e., return on investment, return of investment, and taxes and the impact of tax
credits, as applicable) to first year-real-levelized costs. Similarly, all other bid costs are levelized and
formatted for input into to the IRP models. For a 25-year PPA for example, IPC calculates the present
value of the revenue requirement (contractual payment stream over the 25 years) for the project and
calculate the levelized payment based on the contract life as demonstrated in the example Exhibit R –
Levelized PVRR Scenarios. Projected renewable resource performance data (expected hourly capacity
factor information) will also be processed for input into the IRP models. Projected Effective Load
Carrying Capability (ELCC) for each bid will also be processed for input into the IRP models. The IRP
modeling tools will help select the least cost resource types based on bid cost, performance data, and
ELCC. IPC’s Final Shortlist may also include high-scoring bids in excess of the identified capacity limits if
those projects have economic benefit.

IPC will evaluate portfolios under a range of different environmental policy and market price scenarios
(policy-price scenarios). In this way, IPC uses AURORA to help optimize its selection of bid resources to
identify the lowest cost, reliable portfolio under multiple scenarios prior to undergoing additional risk
analysis and further consideration as part of the Final Shortlist process. The assumptions will be
established and reviewed with the IE before updated bids with best and final pricing are received and
opened.
Risk Analysis
IPC next uses AURORA to evaluate each portfolio and its ability to perform under dynamic market
conditions. In AURORA a stochastic analysis will be performed, which assesses the effect on portfolio
costs when select variables take on values different from their planning-case levels. AURORA measures
the risk of each portfolio through its production cost estimates. By holding a resource portfolio fixed
and using Latin Hypercube stochastic simulations of stochastic variables—including, for example, load,
natural gas prices, and hydro generation—AURORA can measure the expected cost of each portfolio in
an uncertain future. Stochastic variables are selected based on the degree to which there is
uncertainty regarding their forecasts and the degree to which they can affect the analysis results (i.e.,
portfolio costs). The Latin Hypercube design samples the distribution range with a relatively small
sample size, allowing a reduction in simulation run times. The Latin Hypercube method does this by
sampling at regular intervals across the distribution spectrum. The purpose of the stochastic analysis is
to understand the range of portfolio costs across the full extent of stochastic shocks (i.e., across the
full set of stochastic iterations) and how the ranges for portfolios differ.
Identification of Top-Performing Resource Portfolios
IPC will then summarize and analyze the portfolios to identify the specific bid resources that are most
consistently selected among the policy-price scenarios. Based on this data, as well as certain
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 32 of 1056
Page 29
qualitative and non-price criteria, and in consultation with the IE, IPC may select one or more resource
portfolios for further cost-risk analysis.
Other Factors – Applicable Law and Statutory Requirements
Before establishing a Final Shortlist, IPC may take into consideration, in consultation with the IE, other
factors that are not expressly or adequately factored into the evaluation process outlined above,
particularly any factor required by applicable law or order of either Commission to be considered.
Final Shortlist Selection
IPC will summarize and evaluate the results of its cost-risk analysis, considering present value revenue
requirement results, to identify the specific least-cost, least-risk bids. Based on these data and certain
other factors as described above, and in consultation with the IE, IPC will establish a Final Shortlist.
After the Final Shortlist is established and approved, IPC will re-engage in negotiations with the
selected bidder(s) to finalize their contract(s) and prepare the contract(s) for execution. Selection of a
bid to the Final Shortlist does not constitute a winning bid. Only execution of a definitive agreement
between IPC and the bidder, on terms acceptable to IPC, in its sole and absolute discretion, will
constitute a winning bid.
7.4. ADDITIONAL RIGHTS
IPC may, in coordination with OPUC and the IE, at any time during the Solicitation:
1. Appoint evaluation committees to review bids, seek the assistance of outside technical
experts and consultants in bid evaluation, and seek or obtain data from any source that
has the potential to improve the understanding and evaluation of the responses to this
RFP.
2. Revise and modify, at any time before the Deadline for Bid Submittal, the factors it will
consider in evaluating bids and to otherwise revise or expand its evaluation methodology.
3. Hold interviews and meetings to conduct discussions and exchange correspondence with
either all Bidders or only those with bids that IPC elects to select for detailed discussions
(Initial Shortlisted Bids) in order to seek an improved understanding and evaluation of an
individual Bidder’s bid.
4. Issue a new RFP.
5. Cancel or withdraw the entire RFP or any part thereof.
7.5. ACCEPTANCE AND REJECTION OF BIDS
IPC may or may not award an agreement after analysis and evaluation of the bids. IPC reserves the
right to reject any and all bids, to waive minor formalities and irregularities and to evaluate the bids to
determine which, in IPC’s sole judgment, represents the best value for the Products requested.
7.6. AGREEMENT NEGOTIATIONS
In anticipation of an award, there will be a period of negotiations to finalize the agreement(s) between
the parties. An agreement, including all terms, conditions, exhibits and attachments, must be executed
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 33 of 1056
Page 30
by both IPC and the successful Bidder in order to create a binding enforceable agreement between IPC
and the successful Bidder.
7.7. EXCLUSIVITY
If and when a bid is selected for the Final Shortlist, from that date, the Bidder and/or its affiliates
shall not execute an agreement with any other party for the sale of the proposed Product(s) such
that the Bidder would no longer be able to provide the Products proposed in the bid for a period of
sixty (60) days.
7.8. PUBLICITY
The parties intend to issue joint public announcements, in the form of press releases, case studies
and/or other materials, containing content mutually agreed to by the parties, upon execution of the
agreements. Neither party shall use the name, logo or any other indicia of the other party in any public
statement, press release other public relations or marketing materials, the identity of the other party
or any underlying information with respect to the agreement(s) at any time without the prior written
consent of the other party, which it may withhold in such other party’s sole discretion. Prior to making
any such permitted use, each party shall provide for the other party’s review and approval, any
publicity materials. Any and all goodwill from use of IPC’s name, logo or indicia will inure to IPC’s sole
and exclusive benefit.
7.9. COMMISSION APPROVAL
Execution of an agreement will ultimately be subject to approval by the Commissions.
8. ENTIRE RFP
This RFP and all exhibits, attachments, datasheets, forms, and addenda within the Portal event are
incorporated herein by this reference and represent the final expression of this RFP. Only information
supplied by IPC in writing through the parties listed herein or by this reference made in the submittal
of this RFP shall be used as the basis for the preparation of Bidders bids.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 34 of 1056
Idaho Power 202 All Source RFP
Exhibit A Bid Definition Form
Page 1 of 1 Exhibit No. 4
Case No. IPC-E-24-16
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Idaho Power 2026 All Source RFP
Exhibit B Bid Entry Form
Page 1 of 1

Bid Entry Form
(See Exhibit B_C_D Excel Workbook - Bid Entry Form to be sent through the Portal)

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 36 of 1056
Idaho Power 2026 All Source RFP
Exhibit C Bid Eligibility Checklist
Page 1 of 1

(See Exhibit B_C_D Excel Workbook to be sent through the Portal)

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 37 of 1056
Idaho Power 2026 All Source RFP
Exhibit D Non-Price Scoring Matrix
(See Exhibit B_C_D Excel Workbook to be sent through the Portal)

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 38 of 1056
Idaho Power 2026 All Source RFP
Exhibit D Non-Price Scoring Matrix

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 39 of 1056
Idaho Power 2026 All Source RFP
Exhibit D Non-Price Scoring Matrix

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 40 of 1056
Idaho Power 2026 All Source RFP
Exhibit E - Proposed Market Purchase Volumes

Page 1 of 5

Background
The Boardman to Hemingway 500-kV Transmission Line project (B2H) and associated market
purchases were identified as the least-cost, least-risk resource addition in Idaho Power
Company (Idaho Power or IPC or Company) 2021 Integrated Resource Plan (2021 IRP) to meet
projected future demand. This document summarizes the associated market purchase
procurement strategy and volumes coinciding with the increase in transmission capacity brought
on by B2H. Market purchases will be evaluated against other resource submittals to the 2026 All-
Source Request for Proposals (2026 RFP) as part of an overall resource procurement process and
scored and modeled as defined in the 2026 RFP; however, this Exhibit E focuses exclusively on
market purchases.
Proposed Market Purchase Volumes
Idaho Power is seeking energy purchases to serve load in varying monthly amounts for the years
2026 and beyond. Idaho Power is interested in offers with terms of up to 10 years, but the focus
is on the first three to five years (2026-2031).
In short, the identified needs have been determined based on the quantity of energy purchases
required to economically serve load according to analysis from the 2021 IRP, with the addition of
new incremental large load that Idaho Power is now forecasting since the completion of the 2021
IRP. The energy purchase needs identified in the 2026 RFP are described more fully below. The
transmission capacity that Idaho Power has available for importing energy is shown in Table 4
below.
In the 2026 RFP, Idaho Power is not seeking 100 percent of the identified need. Rather, the 2026
RFP seeks a portion of the total volumes that will be needed. This approach is intended to result
in the acquisition of a base volume of energy that is forecasted to be necessary to serve load.
Additional purchases will be necessary to supplement firm base volumes to serve load in many
hours throughout the years. These additional purchases will be made closer in time to the
operating season. This approach ensures that Idaho Power begins to acquire energy resources
that will be necessary to serve load in a timely and cost-effective manner, while not purchasing
more than will be necessary. This approach will also allow Idaho Power to make additional
procurement decisions as the Company moves forward in time, considering updated information
and the most recent IRP available at that time.
Because the 2021 IRP forecasts a significant volume of purchases to serve load, it is prudent to
begin acquiring a portion of that energy now. Phasing the purchase activity over multiple years
and procurement processes will ensure that Idaho Power is right-sizing its resource acquisition
volumes based on current information. Phasing the purchases will also ensure that Idaho Power
timely builds the purchase and resource portfolio needed to reliably serve its customers.
Requested Energy Volumes
Idaho Power is requesting proposals for energy volumes based on a percentage of the peak hour
purchases identified as economic by the model Idaho Power uses for long-term capacity
expansion planning, the AURORA model, for the preferred portfolio from the 2021 IRP. The
AURORA model provides a total hourly economic purchase volume. Those volumes reflect all the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 41 of 1056
Idaho Power 2026 All Source RFP
Exhibit E - Proposed Market Purchase Volumes

Page 2 of 5

purchases AURORA identified as economic. In determining needs for the 2026 RFP, those
volumes were reduced by application of a seasonal percentage intended to ensure that
purchases are right-sized and that additional purchases are made closer in time to the need. The
percentages vary by time of year (winter versus other months) and heavy load hours versus light
load hours.1 The percentages are higher in the winter season due to the higher winter Planning
Reserve Margin requirements expected in the Western Resource Adequacy Program (WRAP).
Table 1: Percentages applied to AURORA preferred portfolio peak hour economic purchases to
determine need.

These percentages reflect a minimum level of energy that will be needed to serve load across a
majority of hours.
The volumes that are calculated by these percentages are capped at reliability needs where
applicable (the need is the lesser of the percentage of the economic volume or the reliability
need). The reliability cap reflects the minimum level of purchases needed to serve load as
determined by the 2021
Finally, the quantities resulting from the calculation described here are adjusted to reflect the
new incremental large load that Idaho Power is now forecasting since the completion of the 2021
IRP. Specifically, the quantities have been increased by the amount of the anticipated load
addition that exceeds existing generation capacity in any given month.
The following tables provide the energy needs that Idaho Power is currently seeking:

Table 2: Heavy Load Hour Energy Need.

1 Heavy load hours (HLH or on-peak) means all hours in the peak period hour ending 0700 through 2200, Monday
through Saturday, excluding North American Electric Reliability Corporation (NERC) holidays. Light load hours (LLH
or off-peak) means all hours that are not on-peak hours generally all hours in the peak period hour ending 2200
through 0600, Monday through Saturday, and all day on Sundays and NERC holidays.

Heavy Load
Hours
Light Load
Hours
April-October 40% 30%
November-March 50% 40%
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 42 of 1056
Idaho Power 2026 All Source RFP
Exhibit E - Proposed Market Purchase Volumes

Page 3 of 5

Table 3: Light Load Hour Energy Need.

Requested Energy Attributes
Idaho Power is seeking these volumes as firm energy. Idaho Power prefers offers of WSPP
Agreement Schedule C or equivalent firm energy/capacity, but will consider offers of other
products such as WSPP Schedule B. The volumes in Tables 2 and 3 reflect the minimum Qualified
Capacity Contribution that Idaho Power is seeking, as that term is defined by the WRAP. Bid-in
energy or products must meet WRAP eligibility requirements. Idaho Power anticipates it will
designate purchased energy as a Network Resource under the Open Access Transmission Tariff
and will evaluate bids accordingly.
Idaho Power prefers bids with optionality to not take the energy if Idaho Power determines it is
not needed on particular days within the month. Idaho Power will consider various proposals for
the optionality including potential limits on the optionality to reach the most economical total
cost of the energy product.
Idaho Power will consider bids with different structures or different volumes than listed above,
including but not limited to multi-month or seasonal volume structures for Summer or Winter,2
if such structures facilitate more competitive bids. Multi-month or seasonal bids should include
optionality to not take the energy on days in the months when the bid volume exceeds the needs
shown in Tables 2 and 3. Idaho Power will consider proposals for standard heavy load or light

2 Summer: June September and Winter: November March.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 43 of 1056
Idaho Power 2026 All Source RFP
Exhibit E - Proposed Market Purchase Volumes

Page 4 of 5

load hour products or other proposals that include the ability to shape the energy into particular
hours of the day.
e years (2026-2031). Bidders
may submit proposals for any period of time greater than a month in the requested time period.
For example, bidders may bid on a month or multiple months, or for a season assuming the
optionality described above, and for one or more years.
With respect to pricing, Idaho Power prefers index or index plus adder-based pricing, but will
consider other pricing structures. Pricing should not include costs associated with regulatory
structures not applicable in Idaho or Oregon, and should be based on product being sunk in Idaho
or Oregon.
With respect to the form of agreement, Idaho Power prefers to use a confirmation under a
mutually-agreeable master agreement (such as the WSPP Agreement) but will consider proposals
for other agreement forms.
Eligible Delivery Points
Bids must provide for delivery to Idaho Power at its border or at one of the points listed in Table
4 below.
Bids may be delivered to the Idaho Power Border (Walla Walla, Lolo, SMLK, HURR, LaGrande,
M345, Jeff, Brady, Bora). The capacity available at the Idaho Power Border varies by point.3 Idaho
Power will consider the impact to and use of available transmission capacity in its evaluation.
Bids that deliver to the Idaho Power Border will be considered Product Number 19.
Bids may also be delivered to one of the points listed in Table 4 below. The table below indicates
firm transmission capacity rights Idaho Power has available for imports of energy to its system.
Idaho Power will consider the impact to and use of available transmission capacity in its
evaluation. Idaho Power will include the costs it incurs under the transm
Access Transmission Tariff for use of the capacity listed below in its evaluation of bids delivered
to these points and relying on such capacity. Bids that deliver to the Point(s) of Delivery identified
in Table 4 will be considered Product Number 18.
Delivery.
Point of Delivery Import Capability
MIDC Up to 100 MW4
MIDCREMOTE Up to 500 MW5

3
system for Idaho Power load service on an annual basis. Any resources or energy procured under the 2026 RFP
urce or energy.
4 Available through April 30, 2026, with the potential to extend beyond that date if renewed by Idaho Power Load

5 Contingent on B2H being in service.
Exhibit No. 4
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Idaho Power 2026 All Source RFP
Exhibit E - Proposed Market Purchase Volumes

Page 5 of 5

Point of Delivery Import Capability
AVA.BPAT Up to 100 MW6
McNary Up to 80 MW7
Slatt Up to 50 MW8
AVAT.NWMT Up to 50 MW, calendar year 2026 only
Mona/Four Corners Up to 200 MW available between the two points9
RedButte Up to 50 MW, June-October only10

6 Available through April 30, 2027, with the potential to extend beyond that date if renewed by Idaho Power Load
Serving Operations.
7 Available through December 31, 2027, with the potential to extend beyond that date if renewed by Idaho Power
Load Serving Operations.
8 Available through December 31, 2025, with the potential to extend beyond that date if renewed by Idaho Power
Load Serving Operations.
9 Contingent on PacifiCorp / Idaho Power asset swap associated with B2H. The Mona and Four Corners points of
delivery, in aggregate, may not exceed 200 MW.
10 Available through May 31, 2024, with the potential to extend beyond that date if renewed by Idaho Power Load
Serving Operations.
Exhibit No. 4
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Idaho Power 2026 All Source RFP
Exhibit F - Information on Preferred Locations for Resource Based Bids

Page 1 of 1

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 46 of 1056
Idaho Power 2026 All Source RFP
Exhibit G - Information on Most Valuable Hours for Resource Based Bids

Page 1 of 1
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 47 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements for Resource Based Bids

{00310207.DOCX; 1}
Respondent shall review and redline the following draft agreement into the submitted proposal for the
specific product type and ownership structure as defined in this RFP.
This draft Exhibit H is not comprehensive and does not constitute a binding offer, shall not form the bases
for an agreement by estoppel nor otherwise, and is not conditions upon each party’s receipt of all
requirement management approvals (including final credit and legal approval) and all regulatory
approvals. Any actions taken by a party in reliance on the terms set forth in this working draft or on
statements made during negotiations pursuant to this working draft shall be at that party’s own risk. Until
this agreement is negotiated, approved by management, executed, delivered, and approved by all required
regulatory bodies, no party shall have any other legal obligations, expressed or implied, or arising in any
other manner under this working draft or in the course of negotiations.
BATTERY STORAGE AGREEMENT
BETWEEN
____________________
AND

IDAHO POWER COMPANY

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 48 of 1056
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 49 of 1056
TABLE OF CONTENTS
Page
{00310207.DOCX; 1}-i-
SECTION 1 DEFINITIONS, RULES OF INTERPRETATION .................................................. 1
SECTION 2 REPRESENTATIONS AND WARRANTIES.......................................................16
2.1 Mutual Representations and Warranties..............................................................16
2.2 Seller’s Further Representations and Warranties.................................................17
2.3 No Other Representations or Warranties.............................................................19
2.4 Continuing Nature of Representations and Warranties; Notice ...........................19
SECTION 3 CONDITIONS PRECEDENT TO TERM..............................................................19
3.1 Conditions to be granted First Operation Date ....................................................19
3.2 Idaho Power’s Right to Monitor..........................................................................20
SECTION 4 TERM AND COMMERCIAL OPERATION DATE ............................................21
4.1 Term.....................................................................................................................21
4.2 Commercial Operation Date ................................................................................21
4.3 Condition Precedents to Commercial Operation .................................................23
4.4 Continuing Obligations........................................................................................24
4.5 Commercial Operation Date Delay, Delay Damages, Storage Capacity
Damages, Storage Availability Damages. ...........................................................24
4.6 Damages Calculation ...........................................................................................24
4.7 Damages Invoicing ..............................................................................................25
SECTION 5 DELIVERIES OF STORAGE PRODUCT............................................................ 25
5.1 Purchase and Sale ................................................................................................25
5.2 No Sales to Third Parties .....................................................................................25
5.3 Title and Risk of Loss of Storage Product ...........................................................25
5.4 Idaho Power as Merchant.....................................................................................26
5.5 Purchase and Sale of Capacity Rights .................................................................26
5.6 Representation Regarding Ownership of Capacity Rights ..................................26
5.7 Authority to Make Sales ......................................................................................26
5.8 Further Assurances...............................................................................................26
SECTION 6 CONTRACT PRICE; COSTS................................................................................26
6.1 Contract Price.......................................................................................................26
6.2 Costs and Charges ................................................................................................26
6.3 Station Service .....................................................................................................26
6.4 Taxes ....................................................................................................................27
Exhibit No. 4
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Page 50 of 1056
TABLE OF CONTENTS
(continued)
Page
{00310207.DOCX; 1}ii
6.5 Costs of Ownership and Operation ......................................................................27
6.6 Rates Not Subject to Review...............................................................................27
SECTION 7 OPERATION AND CONTROL ............................................................................27
7.1 As-Built Supplement............................................................................................27
7.2 Standard of Facility Operation .............................................................................28
7.3 Interconnection ....................................................................................................29
7.4 Coordination with System....................................................................................29
7.5 Outages ................................................................................................................29
7.6 Scheduling............................................................................................................30
7.7 Charging Energy Management. ...........................................................................31
7.8 Performance Tests; Guarantees............................................................................31
7.9 Electronic Communications.................................................................................32
7.10 Reports and Records ............................................................................................33
7.11 Financial and Accounting Information................................................................36
7.12 Access Rights .......................................................................................................36
7.13 Facility Images .....................................................................................................37
SECTION 8 RIGHT OF FIRST OFFER AND OWNERSHIP OR PURCHASE OPTION ....... 37
8.1 Buyer’s Affiliates .................................................................................................37
8.2 Right of First Offer ..............................................................................................37
8.3 Termination of Duty to Buy .................................................................................38
8.4 Right of First Offer on Ownership .......................................................................38
8.5 Negotiation of Facility Purchase..........................Error! Bookmark not defined.
8.6 Efforts Required to Transfer Facility and Offered Interests................................39
8.7 Due Diligence; Cooperation; Governmental Approvals; Notice of Rights.........39
8.8 Termination of Agreement...................................................................................40
SECTION 9 SECURITY AND CREDIT SUPPORT .................................................................40
9.1 Project Development Security.............................................................................40
9.2 Default Security ...................................................................................................41
9.3 Senior Lenders.....................................................................................................41
9.4 Change of Control ................................................................................................41
9.5 Security is Not a Limit on Seller’s Liability........................................................41
Exhibit No. 4
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Page 51 of 1056
TABLE OF CONTENTS
(continued)
Page
{00310207.DOCX; 1}- iii -
SECTION 10 METERING, METERING COMMUNICATIONS AND SCADA
TELEMETRY.............................................................................................................................. 42
10.1 Metering...............................................................................................................42
10.2 Metering Communications...................................................................................42
10.3 Supervisory Control and Data Acquisition (SCADA) Telemetry .......................42
10.4 Metering Costs .....................................................................................................43
10.5 Losses ...................................................................................................................43
SECTION 11 BILLINGS, COMPUTATIONS AND PAYMENTS...........................................43
11.1 Monthly Invoices.................................................................................................43
11.2 Offsets ..................................................................................................................43
11.3 Interest on Late Payments....................................................................................43
11.4 Disputed Amounts ...............................................................................................43
11.5 Audit Rights .........................................................................................................44
SECTION 12 DEFAULTS AND REMEDIES............................................................................44
12.1 Defaults ................................................................................................................44
12.2 Remedies for Failure to Deliver/Receive .............................................................47
12.3 Termination and Remedies ..................................................................................47
12.4 Termination Damages..........................................................................................48
12.5 Duty/Right to Mitigate.........................................................................................49
12.6 Security ................................................................................................................49
12.7 Cumulative Remedies ..........................................................................................49
SECTION 13 INDEMNIFICATION AND LIABILITY............................................................49
13.1 Indemnities...........................................................................................................49
SECTION 14 INSURANCE ........................................................................................................ 51
14.1 Required Policies and Coverages.........................................................................51
14.2 Certificates of insurance ......................................................................................51
SECTION 15 FORCE MAJEURE ..............................................................................................51
15.1 Definition of Force Majeure................................................................................51
15.2 Suspension of Performance..................................................................................52
15.3 Force Majeure Does Not Affect Other Obligations .............................................52
15.4 Strikes ..................................................................................................................52
15.5 Right to Terminate...............................................................................................52
Exhibit No. 4
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SECTION 16 SEVERAL OBLIGATIONS; THIRD PARTY BENEFICIARIES......................53
SECTION 17 CHOICE OF LAW ...............................................................................................53
SECTION 18 PARTIAL INVALIDITY .....................................................................................53
SECTION 19 NON-WAIVER.....................................................................................................53
SECTION 20 GOVERNMENTAL JURISDICTION AND AUTHORIZATIONS ...................53
SECTION 21 [INTENTIONALLY OMITTED].........................................................................53
SECTION 22 SUCCESSORS AND ASSIGNS.......................................................................... 53
22.1 Restriction on Assignments.................................................................................54
22.2 Permitted Assignments........................................................................................54
SECTION 23 ENTIRE AGREEMENT .......................................................................................54
SECTION 24 NOTICES ..............................................................................................................54
24.1 Addresses and Delivery Methods ........................................................................54
24.2 Changes of Address .............................................................................................55
SECTION 25 CONFIDENTIALITY...........................................................................................55
25.1 Confidential Business Information ......................................................................55
25.2 Duty to Maintain Confidentiality .........................................................................56
25.3 Idaho Power Regulatory Compliance..................................................................56
25.4 Irreparable Injury; Remedies ...............................................................................56
25.5 News Releases and Publicity ...............................................................................56
SECTION 26 DISAGREEMENTS ............................................................................................. 56
26.1 Negotiations.........................................................................................................56
26.2 Choice of Forum ..................................................................................................57
26.3 Settlement Discussions........................................................................................57
26.4 Waiver of Jury Trial .............................................................................................57
SECTION 27 COMPLIANCE.....................................................................................................58
27.1 Nondiscrimination................................................................................................58
27.2 Anti-Corruption.................................................................................................... 58
Exhibit No. 4
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EXHIBITS
Exhibit 1 Generation Scheduling and Reporting
Exhibit 2 Description of Facility
Exhibit 3 Point of Delivery/Interconnection Facilities
Exhibit 4 Storage Operating Restrictions
Exhibit 5 Contract Prices
Exhibit 6 NERC Event Types
Exhibit 7 Start-Up Testing
Exhibit 8 Form of Security – Credit Support Obligation
Exhibit 9 Required Facility Documents
Exhibit 10 Leases
Exhibit 11 Engineer’s Certification of O&M Policy, Engineer’s Certification
of Ongoing O&M, Engineer’s Certification of Design and
Construction Adequacy.
Exhibit 12 [Reserved]
Exhibit 13 Required Insurance
Exhibit 14 Seller Authorization to Release Generation Data to Idaho Power
Exhibit 15 Attachments
Exhibit 16 As-Built Supplement
Exhibit 17 Marketing Communications Agreement
Exhibit 18 Form of Construction Progress Report
Exhibit 19 Form of Operations Report
Exhibit 20 Idaho Power form of Qualified Reporting Entity Agreement
Exhibit 21 Form of Lender Consent
Exhibit 22 Form of Estoppel Certificate

Exhibit No. 4
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Exhibit No. 4
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THIS WORKING DRAFT DOES NOT CONSTITUTE A BINDING OFFER, SHALL NOT
FORM THE BASIS FOR AN AGREEMENT BY ESTOPPEL OR OTHERWISE, AND IS
CONDITIONED UPON EACH PARTY’S RECEIPT OF ALL REQUIRED
MANAGEMENT APPROVALS (INCLUDING FINAL CREDIT AND LEGAL
APPROVAL) AND ALL REGULATORY APPROVALS. ANY ACTIONS TAKEN BY A
PARTY IN RELIANCE ON THE TERMS SET FORTH IN THIS WORKING DRAFT OR
ON STATEMENTS MADE DURING NEGOTIATIONS PURSUANT TO THIS
WORKING DRAFT SHALL BE AT THAT PARTY’S OWN RISK. UNTIL THIS
AGREEMENT IS NEGOTIATED, APPROVED BY MANAGEMENT, EXECUTED,
DELIVERED AND APPROVED BY ALL REQUIRED REGULATORY BODIES, NO
PARTY SHALL HAVE ANY OTHER LEGAL OBLIGATIONS, EXPRESSED OR
IMPLIED, OR ARISING IN ANY OTHER MANNER UNDER THIS WORKING DRAFT
OR IN THE COURSE OF NEGOTIATIONS.
BATTERY STORAGE AGREEMENT
THIS BATTERY STORAGE AGREEMENT (this “Agreement”), dated as of
____________, 202_, (the “Effective Date”), is entered into between ____________ (the “Seller”)
and Idaho Power Company, an Idaho corporation (“Idaho Power” or “Buyer”). Seller and Idaho
Power are sometimes hereinafter referred to collectively as the “Parties” and individually as a
“Party.”
WHEREAS, Seller intends to construct, own, operate and maintain a battery energy
storage system (“BESS”) for the storage and discharge of electric energy located in [_______
____], [Idaho] with a Storage Capacity (as defined below) of ____ MWh (the “Facility”).
WHEREAS, Seller desires to sell, and Idaho Power desires to purchase, the Storage
Product (as defined below) delivered by the Facility in accordance with the terms and conditions
hereof.
NOW, THEREFORE, in consideration of the foregoing and the mutual promises
set forth below and for other good and valuable consideration, the receipt and sufficiency of which
are hereby acknowledged, the Parties mutually agree as follows:
SECTION 1
DEFINITIONS, RULES OF INTERPRETATION
Defined Terms. Unless otherwise required by the context in which any term appears, initially
capitalized terms used herein shall have the following meanings:
1.1 “Abandonment” means (a) the relinquishment of all possession and control of the Facility
by Seller, other than pursuant to a transfer permitted under this Agreement, or (b) if after
commencement of the construction, testing, and inspection of the Facility, and prior to the
Commercial Operation Date, there is a complete cessation of the construction, testing, and
inspection of the Facility for ninety (90) consecutive days by Seller and Seller’s
contractors, but only if such relinquishment or cessation is not caused by or attributable to
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an Event of Default by Idaho Power, a request by Idaho Power, or an event of Force
Majeure.
1.2 “AC” means alternating current.
1.3 “Affiliate” means, with respect to any entity, each entity that directly or indirectly controls,
is controlled by, or is under common control with, such designated entity, with “control”
meaning the possession, directly or indirectly, of the power to direct management and
policies, whether through the ownership of voting securities or by contract or otherwise.
1.4 “Agreement” is defined in the opening paragraph hereto.
1.5 “Ancillary Services” has the meaning set forth in Idaho Power’s Open Access
Transmission Tariff as approved by FERC.
1.6 “Anything of Value” includes, but is not limited to, cash or a cash equivalent (including
“grease”, “expediting” or facilitation payments), discounts, rebates, gifts, meals,
entertainment, hospitality, use of materials, facilities or equipment, transportation, lodging,
or promise of future employment.
1.7 “As-built Supplement” is a supplement to be added to Exhibit 16 that describes the Facility
as actually built, pursuant to Section 7.1 and includes an American Land Title Association
survey of the Premises.
1.8 “Auxiliary Load Test” has the meaning set forth in Exhibit 23.
1.9 “Book Value” means cost minus accumulated depreciation, and not deducting for debt or
other encumbrances, calculated in accordance with generally accepted accounting
principles consistently applied.
1.10 “Business Day” means any Monday through Friday except NERC recognized holidays
beginning at 6:00 a.m. and ending at 5:00 p.m. local time in Boise, Idaho.
1.11 “Capacity Rights” means any current or future defined characteristic, certificate, tag, credit,
reactive power, Ancillary Service or attribute thereof, or accounting construct, including
any of the same counted towards any current or future resource adequacy or reserve
requirements, associated with the energy storage and discharge of the Facility or the
Facility’s capability and ability to store and discharge energy. Capacity Rights are
measured in MW and do not include any Tax Credits, or any other tax incentives existing
now or in the future associated with the construction, ownership or operation of the
Facility.
1.12 “Change of Control” means, with respect to Seller, any transaction or series of transactions
following which Seller’s Parent Entity no longer directly or indirectly (i) remains the owner
of more than fifty percent (50%) of the direct or indirect equity or voting interests of Seller
which are not otherwise held by Seller’s Lenders (excluding any Tax Equity Investors), or
(ii) retains the power to control the management and policies of Seller; provided, however,
that a Seller Permitted Transfer shall not be a Change of Control.
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1.13 “Charge Rate Test” has the meaning set forth in Exhibit 23.
1.14 “Charging Energy” means the Energy provided to charge the Facility, which shall be
charged solely from energy provided by Buyer from the System.
1.15 “Charging Notice” means the operating instruction, and any subsequent updates, given by
Idaho Power to Seller, directing the Facility to charge at a specific MW rate to a specified
Stored Energy Level, including in connection with a Guaranteed Storage Capacity Test,
provided that any such operating instruction shall be in accordance with the Storage
Operating Restrictions.
1.16 “Commercial Operation” means that not less than the Storage Capacity of the Facility is
fully operational and reliable, the Guaranteed Roundtrip Efficiency has been met, all
Performance Tests have otherwise been completed with results submitted to Idaho Power
and the Facility is fully interconnected, fully integrated, and synchronized with the System,
all of which shall be Seller’s responsibility to receive or obtain, and without limiting
Seller’s other obligations under this Agreement, which occurs when all of the enumerated
events listed in Section 4.2 (a) have occurred, and (b) remain simultaneously true and
accurate as of the date and moment on which Seller gives Idaho Power written notice that
Commercial Operation has occurred.
1.17 “Commercial Operation Date” means the day commencing at 00:01 hours, Mountain Time,
following the day that all requirements of Section 4 have been completed and after the
Seller requested Operation Date.
1.18 “Confidential Business Information” is defined in Section 25.1.
1.19 “Construction Progress Report” is defined in Section 3.2.1.
1.20 “Contract Interest Rate” means the lesser of (a) the highest rate permitted under
Requirements of Law or (b) 200 basis points per annum plus the rate per annum equal to
the publicly announced prime rate or reference rate for commercial loans to large
businesses in effect from time to time quoted by Citibank, N.A. as its “prime rate.” If a
Citibank, N.A. prime rate is not available, the applicable prime rate shall be the announced
prime rate or reference rate for commercial loans in effect from time to time quoted by a
bank with $10 billion or more in assets in New York City, N.Y., selected by the Party to
whom interest is being paid.
1.21 “Contract Price” means the applicable price, expressed in dollars per kW-month for the
Storage Product, as set forth in Exhibit 5.
1.22 “Contract Year” means any consecutive 12-month period during the Term, commencing at
00:00 hours on the Commercial Operation Date or any of its anniversaries and ending at
24:00 hours on the last day of such 12-month period.
1.23 “Costs” means, with respect to the non-defaulting Party, (a) brokerage fees, commissions
and other similar third party transaction costs and expenses reasonably incurred by such
Party either in terminating any arrangement entered into pursuant to this Agreement or
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entering into new arrangements which replace this Agreement and (b) all reasonable
attorneys’ fees and expenses incurred by the non-defaulting Party in connection with the
termination of this Agreement.
1.24 “CPCN” means Certificate of Public Convenience and Necessity.
1.25 “Credit Requirements” means (a) three (3) years of audited financial statements, a view of
the financial position and financial performance, financial statement analysis and financial
trend analysis; (b) Debt Agency Ratings - a senior, unsecured long term debt rating (or
corporate rating if such debt rating is unavailable) of BBB+ or greater from S&P, or Baa1
or greater from Moody’s, and if such ratings are split, the lower of the two ratings must be
at least ‘BBB+’ or ‘Baa1’ from S&P or Moody’s, respectively. Idaho Power performs a
credit analysis, which considers both qualitative and quantitative factors, to determine
whether potential Counterparties have satisfied the Credit Requirements.
1.26 “Default” is defined in Section 12.1.
1.27 “Default Security” is defined in Section 9.2.1.
1.28 “Delay Damages” means for each day in which Commercial Operation is not achieved
after the Scheduled Commercial Operation Date, the amount equal to [XX] for each MWh,
prorated for fractional amounts thereof, of Storage Capacity below the Guaranteed Storage
Capacity.
1.29 “Discharging Energy” means ________MWh in the first, full Contract Year, reduced by
an annual degradation factor of ____ percent per Contract Year, measured at the Point of
Delivery. If at Final Completion the Facility’s Storage Capacity is less than the Guaranteed
Storage Capacity, Discharging Energy shall be reduced proportionally per year for each
MWh of Storage Capacity below the Guaranteed Storage Capacity. Seller acknowledges
that Idaho Power will include Discharging Energy in Idaho Power’s resource planning.
1.30 “Effective Date” is the date stated in the opening paragraph hereto which represents the
date upon which this Agreement was fully executed by both Parties.
1.31 “Electric System Authority” means each of NERC, WECC, WREGIS, an RTO, a regional
or sub-regional reliability council or authority, and any other similar council, corporation,
organization or body of recognized standing with respect to the operations of the electric
system in the WECC region, as such are applicable to the Seller or Idaho Power.
1.32 “Emissions Reduction Credit” means any credit, allowance or instrument issued or issuable
by a Governmental Authority under regulations of the Environmental Protection Agency
under the Clean Air Act.
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1.33 “Energy” means [single][three]
1-phase, sixty (60)-hertz alternating current electrical
energy (measured in MWh).
1.34 “Energy Imbalance Market” means the California Independent System Operator’s Western
Energy Imbalance Market.
1.35 “Environmental Contamination” means the introduction or presence of Hazardous
Materials at such levels, quantities or location, or of such form or character, as to constitute
a violation of federal, state or local laws or regulations, and present a material risk under
federal, state or local laws and regulations that the Premises will not be available or usable
for the purposes contemplated by this Agreement.
1.36 “Event of Default” is defined in Section 12.1.
1.37 “Facility” is defined in the Recitals and is more fully described in attached Exhibit 2 and
includes an AC-connected battery energy storage system, inverters, transformers, and
performance monitoring instruments, associated electrical components, and civil
infrastructure associated with the aforementioned components owned, controlled, operated
and managed by Seller in connection with, or to facilitate, the storage, discharge,
transmission, delivery, or furnishing of the Storage Product by Seller to Idaho Power and
required to interconnect with the System, as well as Seller’s interests in the Premises,
including Leases and any fee owned real property.
1.38 “FERC” means the Federal Energy Regulatory Commission.
1.39 “Final Completion” means the Facility is fully operational and reliable, at the Guaranteed
Storage Capacity, and fully interconnected, fully integrated, and synchronized with the
Transmission Provider’s System, modified if necessary to reflect the Storage Capacity and,
if applicable, through completion of all the items set forth on the Final Completion
Schedule.
1.40 “Final Completion Schedule” means the full list of all items to be completed in order to
achieve Final Completion in accordance with Section 4.2 (Commercial Operation Date).
1.41 “First Operation Date” means the day commencing at 00:01 hours, Mountain Time,
following the day that Seller has satisfied the requirements of Section 3 and after the Seller
requested First Operation Date.
1.42 “Force Majeure” and “event of Force Majeure” are defined in Section 15.1.
1.43 “Forced Outage” means NERC Event Types U1, U2 and U3, as set forth in attached Exhibit
6, and specifically excludes any Maintenance Outage or Planned Outage.
1.44 “Forward Settlement Amount” means, with respect to the non-defaulting Party, the net
Losses and Gains, and Costs, expressed in U.S. Dollars, which such Party incurs as a result

1 Note to Draft: Include as applicable based on the design of the Project.
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of the termination of this Agreement plus all amounts then owed to the non-defaulting Party
by the defaulting Party. If the non-defaulting Party’s aggregate Gains exceed its aggregate
Losses and Costs, if any, resulting from the termination of this Agreement, the Forward
Settlement Amount shall be zero.
1.45 “Full Cycle” means the Facility is charged, then discharged at a MWh quantity equal to the
energy capacity in MWh. For example, state of charge starts at one percent (1%), the
Facility is charged to one hundred percent (100%) and then discharged to one percent (1%).
1.46 “Full Cycle Equivalent” means Partial Cycles that aggregate to one Full Cycle. For
example, two fifty percent (50%) Partial Cycles or four twenty-five percent (25%) Partial
Cycles is one (1) Full Cycle Equivalent.
1.47 “Gains” means, with respect to any Party, an amount equal to the present value of the
economic benefit to it, if any (exclusive of Costs), resulting from the early termination of
this Agreement for the remainder of the Term that would have occurred but for the
occurrence of the Event of Default and early termination, determined in a commercially
reasonable manner.
1.48 “Generator Interconnection Agreement” or “GIA” means the large generator
interconnection agreement entered into separately between Seller and Interconnection
Provider concerning the Interconnection Facilities.
1.49 “Government Official” means any official or employee of any multinational, national,
regional, or local government in any country, including any official or employee of any
government department, agency, commission, or division; any official or employee of any
government-owned or -controlled enterprise; any official or employee of any public
educational, scientific, or research institution; any political party or official or employee of
a political party; any candidate for public office; any official or employee of a public
international organization; and any person acting on behalf of or any relatives, family, or
household members of any of those listed above.
1.50 “Governmental Authority” means any supranational, federal, state or other political
subdivision thereof, having jurisdiction over Seller, Idaho Power or this Agreement,
including any municipality, township or county, and any entity or body exercising
executive, legislative, judicial, regulatory or administrative functions of or pertaining to
government, including any corporation or other entity owned or controlled by any of the
foregoing.
1.51 “Guaranteed Commercial Operation Date” means June 1, 2024.
1.52 “Guaranteed Roundtrip Efficiency” means a Roundtrip Efficiency during the Term of no
less than [XX]2 %.

2 Note to Parties: To be discussed.
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1.53 “Guaranteed Roundtrip Efficiency Test” has the meaning set forth in Exhibit 23.
1.54 “Guaranteed Storage Availability” means, in each Contract Year, Storage Availability
equal to 98 % or greater.
1.55 “Guaranteed Storage Availability Test” has the meaning set forth in Exhibit 23.
1.56 “Guaranteed Storage Capacity” means the energy capacity of the Facility of [____] MWh
measured over [four] hours by AC monitoring equipment, as more particularly described
in Exhibit 2 and determined in accordance with the Guaranteed Storage Capacity Test.
1.57 “Guaranteed Storage Capacity Test” has the meaning set forth in Exhibit 23.
1.58 “Hazardous Materials” means any waste or other substance that is listed, defined,
designated or classified as or determined to be hazardous under or pursuant to any
environmental law or regulation.
1.59 “Idaho Power” and “Buyer” are defined in the opening paragraph, and explicitly excludes
Idaho Power Transmission.
1.60 “Idaho Power’s Cost to Cover” means the positive difference, if any, between (a) the time
weighted average of the Market Price Index for each day for which the determination is
being made, and (b) the Contract Price specified in Exhibit 5 in effect on such days, stated
as an amount of dollars per kW-month. If on a given day the difference between (a) minus
(b) referenced above is zero or negative, then Idaho Power’s Cost to Cover shall be zero
dollars ($0), and Seller shall have no obligation to pay any amount to Idaho Power on
account of Section 7.12.3 or Section 12.2.1 with respect to such day.
1.61 “Idaho Power Indemnitees” is defined in Section 13.1.1.
1.62 “Idaho Power Representatives” is defined in Section 7.13.
1.63 “Idaho Power Transmission” means Idaho Power Company, an Idaho corporation, acting
in its interconnection or transmission function capacity.
1.64 “Indemnified Party” is defined in Section 7.2.3.2.
1.65 “Indemnifying Party” is defined in Section 7.2.3.2.
1.66 “Interconnection Facilities” means all the facilities installed, or to be installed, for the
purpose of interconnecting the Facility to the System, including electrical transmission
lines, upgrades, transformers and associated equipment, substations, relay and switching
equipment, and safety equipment.
1.67 “Interconnection Provider” means Idaho Power Transmission.
1.68 “Inverter” means the equipment installed at the Facility to convert direct current to AC, as
described in Exhibit 2.
Exhibit No. 4
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1.69 “IPUC” means the Idaho Public Utilities Commission.
1.70 “IRP” means Idaho Power’s Integrated Resource Plan.
1.71 “ITC” means the investment tax credit established pursuant to Section 48 of the Internal
Revenue Code, as such law may be amended or superseded.
1.72 “kW-month” means kilowatts per month.
1.73 “Leases” means the memoranda of lease and redacted leases recorded in connection with
the development of the Facility, as the same may be supplemented, amended, extended,
restated, or replaced from time to time.
1.74 “Lender” means an entity lending money or extending credit (including any financing
lease, monetization of tax benefits, transaction with a tax equity investor, backleverage
financing or credit derivative arrangement) to Seller or Seller’s Affiliates (a) for the
construction, term or permanent financing or refinancing of the Facility; (b) for working
capital or other ordinary business requirements for the Facility (including for the
maintenance, repair, replacement or improvement of the Facility); (c) for any development
financing, bridge financing, credit support, and related credit enhancement in connection
with the development, construction or operation of the Facility; or (d) for the purchase of
the Facility and related rights from Seller.
1.75 “Letter of Credit” means an irrevocable standby letter of credit in a form reasonably
acceptable to Idaho Power, naming Idaho Power as the party entitled to demand payment
and present draw requests thereunder that:
1.75.1 is issued by a Qualifying Institution;
1.75.2 by its terms, permits Idaho Power to draw up to the face amount thereof for the
purpose of paying any and all amounts owing by Seller hereunder;
1.75.3 permits Idaho Power to draw the entire amount available thereunder if such letter
of credit is not renewed or replaced at least thirty (30) days prior to its stated
expiration date;
1.75.4 permits Idaho Power to draw the entire amount available thereunder if such letter
of credit is not increased or replaced as and when provided in Section 9;
1.75.5 is transferable by Idaho Power to any party to which Idaho Power may assign this
Agreement; and
1.75.6 shall remain in effect for at least ninety (90) days after the end of the Term.
1.76 “Liabilities” is defined in Section 13.1.1.
1.77 “Licensed Professional Engineer” means a person proposed by Seller and acceptable to
Idaho Power in its reasonable judgment who (a) to the extent mandated by Requirements
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of Law is licensed to practice engineering in the appropriate engineering discipline for the
required certification being made, in the state of Idaho, (b) has training and experience in
the engineering disciplines relevant to the matters with respect to which such person is
called upon to provide a certification, evaluation or opinion, (c) has no economic
relationship, association, or nexus with Seller and is not an employee of its members or
Affiliates, other than with the prior written consent of Idaho Power, for services previously
or currently being rendered to Seller or its members or Affiliates, and (d) is not a
representative of a consulting engineer, contractor, designer or other individual involved
in the development of the Facility, or a representative of a manufacturer or supplier of any
equipment installed in the Facility.
1.78 “Losses” means, with respect to any Party, an amount equal to the present value of the
economic loss to it, if any (exclusive of Costs), resulting from the termination of this
Agreement for the remainder of the Term that would have occurred but for the occurrence
of the Event of Default and early termination of this Agreement, determined in a
commercially reasonable manner. If Seller is the non-defaulting Party, “Losses” will
exclude the loss, repayment or recapture of any Tax Credits. If Idaho Power is the non-
defaulting Party, “Losses” will include Idaho Power’s cost of replacing this Agreement
with an agreement for new renewable capacity from a facility with similar technology that
has not yet been constructed.
1.79 “Maintenance Outage” means NERC Event Type MO, as set forth in attached Exhibit 6,
and includes any outage involving ten percent (10%) of the Facility’s Storage Capacity that
is not a Forced Outage or a Planned Outage.
1.80 “Market Operator” means the California Independent System Operator or any other entity
performing the market operator function for the Energy Imbalance Market.
1.81 “Market Price Index” means 82.4% of the monthly arithmetic average of each day’s
Intercontinental Exchange (“ICE”) daily firm Mid-C Peak Avg and Mid-C Off-Peak Avg
index prices in the month as follows:
The actual calculation being:

n
.824 * ( -C Peak Avgx * HLH hours for day) +
X=1

(ICE Mid-C Off-Peak Avgx * LLH hours for day)} / (n*24))

where n = number of days in the month
If the ICE Mid-C Index prices are not reported for a particular day or days, prices derived
from the respective averages of HLH and LLH prices for the immediately preceding and
following reporting periods or days shall be substituted into the formula stated in this
definition and shall therefore be multiplied by the appropriate respective numbers of HLH
and LLH Hours for such particular day or days with the result that each hour in such month
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shall have a related price in such formula. If the day for which prices are not reported has in
it only LLH Hours (for example a Sunday), the respective averages shall use only prices
reported for LLH hours in the immediately preceding and following reporting periods or
days. If the day for which prices are not reported is a Saturday or Monday or is adjacent on
the calendar to a holiday, the prices used for HLH Hours shall be those for HLH hours in the
nearest (forward or backward) reporting periods or days for which HLH prices are reported.
1.82 “Maximum Delivery Rate” means the maximum hourly rate of delivery of Discharging
Energy in MWh from the Facility to the Point of Delivery, calculated on the basis of the
Discharging Energy delivered in an hour accruing at an average rate equivalent to the actual
Storage Capacity.
1.83 “Moody’s” means Moody’s Investor Services, Inc.
1.84 “Mountain Prevailing Time” or “MPT” means Mountain Standard Time or Mountain
Daylight Time, as applicable in Idaho on the day in question.
1.85 “MW” means megawatt.
1.86 “MWh” means megawatt hour.
1.87 “NERC” means the North American Electric Reliability Corporation.
1.88 “Network Resource” is defined in the Tariff.
1.89 “Network Service Provider” means Idaho Power Transmission, as a provider of network
service to Idaho Power under the Tariff.
1.90 “Noise Test” has the meaning set forth in Exhibit 23.
1.91 “Offer Notice” is defined in Section 8.2.
1.92 “Offered Interests” is defined in Section 8.4.1.
1.93 “Off-Peak Hours” or “LLH” 3means the daily hours from hour ending 2300 – 0600 MPT,
(8 hours), plus all other hours on all Sundays and NERC designated holidays.
1.94 “On-Peak Hours” or “HLH”
4means the daily hours from hour ending 0700 - 2200 MPT,
(16 hours), Monday through Saturday, excluding all hours on all Sundays and NERC
designated holidays.
1.95 “Operations Report” is defined in Section 3.2.2.
1.96 “OPUC” means the Public Utility Commission of Oregon.

3Note to Parties: 1.93 “Off-Peak Hours” or “LLH” to be discussed.
4 Note to Parties: 1.94 “On-Peak Hours” or “HLH” to be discussed.
Exhibit No. 4
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1.97 “Partial Cycle” means the Facility is charged and discharged at a MWh quantity less than
one hundred percent (100%) of the Facility energy capacity. For example, State of Charge
starts at fifty percent (50%), the Storage Facility is discharged to zero percent (0%) and
then charged back to fifty percent (50%).
1.98 “Party” and “Parties” are defined in the opening paragraph hereto.
1.99 “Performance Tests” means the Guaranteed Storage Availability Test, the Guaranteed
Storage Capacity Test, the Guaranteed Roundtrip Efficiency Test, the Charge Rate Test,
the Ramp Rate Test, the Response Time Test, the Auxiliary Load Test, the Power Factor
Test, and the Noise Test.
1.100 “Permits” means the permits, licenses, approvals, certificates, entitlements and other
authorizations issued by Governmental Authorities required for the construction,
ownership or operation of the Facility or occupancy of the Premises, and all amendments,
modifications, supplements, general conditions and addenda thereto.
1.101 “Planned Outage” means NERC Event Type PO, as set forth in attached Exhibit 6, and
specifically excludes any Maintenance Outage or Forced Outage.
1.102 “Point of Delivery” means the point of interconnection between the Facility and the
System, as specified in the Generator Interconnection Agreement and as further described
in Exhibit 3.
1.103 “Power Factor Test” has the meaning set forth in Exhibit 23.
1.104 “Pre-COD Damages Payment” means liquidated damages in an amount equal to the
amount of Project Development Security required to be provided hereunder, plus the Delay
Damages Seller has paid to Buyer.
1.105 “Premises” means the real property on which the Facility is or will be located, as more
fully described on Exhibits 9, 10 and 15.
1.106 “Project Development Security” is defined in Section 9.1.1.
1.107 “Prudent Electrical Practices” means any of the practices, methods and acts engaged in or
approved by a significant portion of the independent electric power generation industry in
the United States for BESS facilities of similar size and characteristics or any of the
practices, methods or acts, which, in the exercise of reasonable judgment in the light of the
facts known at the time a decision is made, could have been expected to accomplish the
desired result at the lowest reasonable cost consistent with reliability, safety and
expedition.
1.108 “Qualified Operator” is (a) a partnership, corporation or limited liability company that
demonstrates acceptable experience with operating a BESS facility, or (b) any other Person
reasonably acceptable to Buyer.
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1.109 “Qualifying Institution” means a United States commercial bank or trust company
organized under the laws of the United States of America or a political subdivision thereof
having assets of at least $10,000,000,000 (net of reserves) and a credit rating on its long-
term senior unsecured debt of at least “A” from S&P and “A2” from Moody’s.
1.110 “Ramp Rate Test” has the meaning set forth in Exhibit 23.
1.111 “Reporting Month” is defined in Section 7.10.1.
1.112 “Required Facility Documents” means the Permits and other authorizations, rights and
agreements now or hereafter necessary for construction, ownership, operation, and
maintenance of the Facility, and to deliver the Storage Product to Idaho Power in
accordance with this Agreement and Requirements of Law, including those set forth in
Exhibit 9.
1.113 “Requirements of Law” means any applicable and mandatory (but not merely advisory)
federal, state and local law, statute, regulation, rule, action, order, code or ordinance
enacted, adopted, issued or promulgated by any federal, state, local or other Governmental
Authority or regulatory body (including those pertaining to electrical, building, zoning,
environmental and wildlife protection and occupational safety and health).
1.114 “Response Time Test” has the meaning set forth in Exhibit 23.
1.115 “Restricted Period” is defined in Section 8.2.
1.116 “Restricted Transaction” is defined in Section 8.4.1.
1.117 “ROFO” is defined in Section 8.2.
1.118 “ROFO Period” is defined in Section 8.4.1.
1.119 “ROFO Seller” is defined in Section 8.4.1.
1.120 “Roundtrip Efficiency” means the round trip DC-to-storage-to-DC energy efficiency of the
battery, or the fraction of energy put into the storage that can be retrieved, calculated in
accordance with Exhibit 23.
1.121 “RTO” means any entity (including an independent system operator) that becomes
responsible as system operator for, or directs the operation of, the System.
1.122 “S&P” means Standard & Poor’s Rating Group (a division of S&P Global, Inc.).
1.123 “Sanctioned Person” means any person (i) that is the target of Sanctions or owned or
controlled by any such person(s), or (ii) located, organized or resident in, or directly or
indirectly owned or controlled by the government of any Sanctioned Territory.
1.124 “Sanctioned Territory” means any country or territory now or hereafter subject to
comprehensive Sanctions.
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1.125 “Sanctions” means any economic or trade sanctions administered or enforced by any
Government Authorities of the United States, (including the Office of Foreign Assets
Control of the U.S. Department of the Treasury (“OFAC”) and the U.S. Department of
State), the United Nations, the European Community or, Her Majesty’s Treasury or any,
and each other sanctions authority which has jurisdiction in respect of any Party or the
Facility.
1.126 “SCADA” means supervisory control and data acquisition.
1.127 “Scheduled Commercial Operation Date” means means the date that is ninety (90) days
5prior to the Guaranteed Commercial Operation Date.
1.128 “Seller” is defined in the opening paragraph hereto.
1.129 “Seller Indemnitees” is defined in Section 13.1.2.
1.130 “Seller ROFO Notice” is defined in Section 8.4.1.
1.131 “Seller Uncontrollable Minutes” means, for the Facility in any month, the total number of
minutes during such month during which the Facility was unable to deliver Discharging
Energy to Idaho Power (or during which Idaho Power failed to accept such delivery) due
to one or more of the following events, each as recorded by SCADA and indicated by
electronic fault logs: (a) an emergency or Force Majeure event; (b) [reserved]; (c) the
System operating outside the voltage or frequency limits defined in the applicable
operating manual for the Inverters installed at the Facility; (d) Planned Outages, but in no
event exceeding thirty six (36) hours per Contract Year consistent with such operating
manual; (e) [reserved]; (f) a default by Idaho Power; provided, however, that if any of the
events described above in items (a) through (e) occur simultaneously, then the relevant
period of time shall only be counted once in order to prevent double counting. Seller
Uncontrollable Minutes shall not include minutes when (i) the Facility or any portion
thereof was unavailable solely due to Seller’s non-conformance with the Generation
Interconnection Agreement or (ii) the Facility or any portion thereof was paused or
withdrawn from use by Seller for reasons other than those covered in this definition.
1.132 “Seller’s Cost to Cover” means the positive difference, if any, between (a) the Contract
Price specified in Exhibit 5, and (b) the time weighted average of the Market Price Index
of Discharging Energy not purchased by Idaho Power as required hereunder. If on any
given day the difference between (a) minus (b) referenced above is zero or negative, then
Seller’s Cost to Cover shall be zero dollars with respect to such day, and Idaho Power shall
have no obligation to pay any amount to Seller on account of Section 12.2.2. For any days
prior to the Commercial Operation Date, the Contract Price applicable in the first Contract
Year shall be utilized for purposes of clause (a).
1.133 “Seller’s Parent Entity” means [_____].

5 Note to Parties: To be discussed.
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1.134 “Senior Lenders” means Lenders being granted senior security interests on the Facility or
its assets, or Seller or its equity, other than Affiliates of Seller.
1.135 “Storage Availability” shall be at least _____ percent (_____%), calculated in accordance
with the Guaranteed Storage Availability Test.
1.136 “Storage Availability Damages” means a payment equal to the difference between (i)
Storage Availability, calculated in accordance with Exhibit 23 and (ii) the Guaranteed
Storage Availability, multiplied by [$150,000].
1.137 “Storage Availability Damages Cap” means ___________ per year.
1.138 “Storage Capacity” means the maximum energy capacity of the completed Facility,
measured in MWh over a [four] hour period, when operated in compliance with the
Generator Interconnection Agreement and consistent with the recommended power factor
and operating parameters provided by the manufacturer of the BESS, as set forth in a
written notice from Seller to Idaho Power delivered prior to the Commercial Operation
Date and, if applicable, updated in a subsequent written notice from Seller to Idaho Power
as required for Final Completion.
1.139 “Storage Capacity Damages” means a payment equal to the difference between (i) the
Storage Capacity measured in accordance with Exhibit 23 and (ii) the Guaranteed Storage
Capacity, multiplied by [$100/MWh].
1.140 “Storage Capacity Damages Cap” means ___________.
1.141 “Storage Operating Restrictions” means those operating parameters and restrictions set
forth in Exhibit 4.
1.142 “Storage Product” means the Discharging Energy, Capacity Rights, Storage Capacity, and
Ancillary Services.
1.143 “Stored Energy Level” means, at a particular time, the amount of electric energy in the
Facility available to be discharged as Discharging Energy, expressed in MWh.
1.144 “System” means the electric transmission substation and transmission or distribution
facilities owned, operated or maintained by Transmission Provider, which shall include,
after construction and installation of the Facility, the circuit reinforcements, extensions,
and associated terminal facility reinforcements or additions required to interconnect the
Facility, all as set forth in the Generation Interconnection Agreement.
1.145 “Tariff” means the Idaho Power FERC Electric Tariff Volume No. 11 Open Access
Transmission Tariff, as revised from time to time.
1.146 “Tax Credits” means any state, local and/or federal production tax credit, tax deduction,
and/or investment tax credit (including the ITC) specific to the production of renewable
energy and/or investments in renewable energy facilities.
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1.147 “Term” is defined in Section 4.1.
1.148 “Transmission Provider” means Idaho Power Transmission.
1.149 “WECC” means the Western Electricity Coordinating Council.
1.150 “WREGIS” means the Western Renewable Energy Generation Information System.
1.151 Rules of Interpretation.
1.151.1General. Unless otherwise required by the context in which any term appears, (a)
the singular includes the plural and vice versa; (b) references to “Articles,”
“Sections,” “Schedules,” “Appendices” or “Exhibits” are to articles, sections,
schedules, appendices or exhibits hereof; (c) all references to a particular entity
or an electricity market price index include a reference to such entity’s or index’s
successors; (d) “herein,” “hereof” and “hereunder” refer to this Agreement as a
whole; (e) all accounting terms not specifically defined herein shall be construed
in accordance with generally accepted accounting principles, consistently
applied; (f) the masculine includes the feminine and neuter and vice versa; (g)
“including” means “including, without limitation” or “including, but not limited
to”; (h) all references to a particular law or statute mean that law or statute as
amended from time to time; (i) all references to electric energy or capacity are to
be interpreted as utilizing alternating current, unless expressly stated otherwise;
and (j) the word “or” is not necessarily exclusive. Reference to “days” shall be
calendar days, unless expressly stated otherwise herein.
1.151.2Terms Not to be Construed For or Against Either Party. Each term hereof shall be
construed according to its fair meaning and not strictly for or against either Party.
The Parties have jointly prepared this Agreement, and no term hereof shall be
construed against a Party on the ground that the Party is the author of that
provision.
1.151.3Headings. The headings used for the sections and articles hereof are for
convenience and reference purposes only and shall in no way affect the meaning
or interpretation of the provisions hereof.
1.151.4Examples. Example calculations and other examples set forth herein are for
purposes of illustration only and are not intended to constitute a representation,
warranty or covenant concerning the example itself or the matters assumed for
purposes of such example. If there is a conflict between an example and the text
hereof, the text shall control.
1.151.5Interpretation with FERC Orders. Each Party conducts and shall conduct its
operations in a manner intended to comply with FERC Order No. 717, Standards
of Conduct for Transmission Providers, and its companion orders, requiring the
separation of its transmission and merchant functions. Moreover, the Parties
acknowledge that Interconnection Provider’s transmission function offers
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transmission service on its system in a manner intended to comply with FERC
policies and requirements relating to the provision of open-access transmission
service. The Parties recognize that Seller will enter into the Generation
Interconnection Agreement with the Interconnection Provider. Nothing herein is
intended to make any statement about FERC jurisdiction in relation to the Seller.
1.152 Other Terms. The Parties acknowledge and agree that the Generator Interconnection
Agreement shall be a separate and free standing contract and that the terms hereof are not
binding upon the Interconnection Provider.
Notwithstanding any other provision in this Agreement, nothing in the Generation Interconnection
Agreement, nor any other agreement between Seller on the one hand and Transmission Provider
or Interconnection Provider on the other hand, nor any alleged event of default thereunder, shall
alter or modify the Parties’ rights, duties, and obligation hereunder. This Agreement shall not be
construed to create any rights between Seller and the Interconnection Provider or between Seller
and the Transmission Provider.
Seller expressly recognizes that, for purposes hereof, the Interconnection Provider and
Transmission Provider each shall be deemed to be a separate entity and separate contracting party
from Idaho Power whether or not the Generation Interconnection Agreement is entered into with
Interconnection Provider or an Affiliate thereof. Seller acknowledges that Idaho Power, acting in
its merchant capacity function as purchaser hereunder, has no responsibility for or control over
Interconnection Provider or Transmission Provider, and is not liable for any breach of agreement
or duty by Interconnection Provider or Transmission Provider.
SECTION 2
REPRESENTATIONS AND WARRANTIES
2.1 Mutual Representations and Warranties. Each Party represents, covenants, and warrants to
the other that:
2.1.1 Organization. It is duly organized and validly existing under the laws of the State
of its organization.
2.1.2 Authority. It has the requisite power and authority to enter this Agreement and to
perform according to the terms hereof.
2.1.3 Corporate Actions. It has taken all corporate or entity actions required to be taken
by it to authorize the execution, delivery and performance hereof and the
consummation of the transactions contemplated hereby.
2.1.4 No Contravention. The execution and delivery hereof does not contravene any
provision of, or constitute a default under, any indenture, mortgage, security
instrument or undertaking, or other material agreement to which it is a party or
by which it is bound, or any valid order of any court, or any regulatory agency or
other Governmental Authority having authority to which it is subject.
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2.1.5 Valid and Enforceable Agreement. This Agreement is a valid and legally binding
obligation of it, enforceable against it in accordance with its terms, except as the
enforceability hereof may be limited by general principles of equity or
bankruptcy, insolvency, bank moratorium or similar laws affecting creditors’
rights generally and laws restricting the availability of equitable remedies.
2.1.6 Litigation. No litigation, arbitration, investigation or other proceeding is pending
or, to the best of either Party’s knowledge, threatened in writing against either
Party or its members, with respect hereto and the transactions contemplated
hereunder. No other investigation or proceeding is pending or threatened in
writing against a Party, its members, or any Affiliate, the effect of which would
materially and adversely affect the Party’s performance of its obligations
hereunder.
2.1.7 Eligible Contract Participant. It, and any guarantor of its obligations under this
Agreement, is an “eligible contract participant” as that term is defined in the
United States Commodity Exchange Act.
2.1.8 Not a Sanctioned Person. It is not a Sanctioned Person.
2.2 Seller’s Further Representations and Warranties. Seller further represents, covenants, and
warrants to Idaho Power that:
2.2.1 Authority. Seller (a) has (or will have prior to the Commercial Operation Date) all
required regulatory authority to make wholesale sales from and purchases of
Charging Energy for the Facility; (b) has the power and authority to own and
operate the Facility and be present upon the Premises for the Term; and (c) is
duly qualified and in good standing under the laws of the state of Idaho and each
other jurisdiction where its ownership, lease or operation of property or the
conduct of its business requires such qualification.
2.2.2 No Contravention. The execution, delivery, performance and observance by Seller
of its obligations hereunder do not and will not:
2.2.2.1 contravene, conflict with or violate any provision of any material
Requirements of Law presently in effect having applicability to
either Seller or any of Seller’s members;
2.2.2.2 require the consent or approval of or material filing or registration with
any Governmental Authority or other person other than such
consents and approvals which are (i) set forth in Exhibit 9 or (ii)
required in connection with the construction, operation, or
maintenance of the Facility and expected to be obtained in due
course;
2.2.2.3 result in a breach of or constitute a default under any provision of any
security issued by any of Seller’s members or managers, the effect
of which would materially and adversely affect Seller’s performance
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of, or ability to perform, its obligations hereunder, or any material
agreement, instrument or undertaking to which either Seller’s
members or any Affiliates of Seller’s members is a party or by which
the property of any of Seller’s members or any Affiliates of Seller’s
members is bound, the effect of which would materially and
adversely affect Seller’s performance of, or ability to perform, its
obligations hereunder.
2.2.3 Required Facility Documents. All Required Facility Documents are listed on
Exhibit 9. Pursuant to the Required Facility Documents, Seller holds as of the
Effective Date, or will hold by the Commercial Operation Date (or such other
later date as may be specified under Requirements of Law), and will maintain for
the Term all Required Facility Documents. The anticipated use of the Facility
complies with all applicable restrictive covenants affecting the Premises.
Following the Commercial Operation Date, Seller shall promptly notify Idaho
Power of any additional Required Facility Documents.
2.2.4 Delivery of Storage Product. On or before the Commercial Operation Date, Seller
shall hold rights sufficient to enable Seller to deliver the Storage Product from
the Facility to the Point of Delivery pursuant to this Agreement throughout the
Term.
2.2.5 Control of Premises. Seller has all legal rights necessary for the Seller to enter upon
and occupy the Premises for the purpose of constructing, operating and
maintaining the Facility for the Term. All leases of real property required for the
operation of the Facility or the performance of any obligations of Seller
hereunder are set forth and accurately described in Exhibits 9 and 10. Seller shall
maintain all leases or other land grants necessary for the construction, operation
and maintenance of the Facility as valid for the Term. Upon request by Idaho
Power, Seller shall provide copies of the memoranda of lease recorded in
connection with the development of the Facility.
2.2.6 Undertaking of Agreement; Professionals and Experts. Seller has engaged those
professional or other experts it believes necessary to understand its rights and
obligations pursuant to this Agreement. All professionals or experts including
engineers, attorneys or accountants, that Seller may have consulted or relied on
in undertaking the transactions contemplated by this Agreement have been solely
those of Seller. In entering into this Agreement and the undertaking by Seller of
the obligations set forth herein, Seller has investigated and determined that it is
capable of performing hereunder and has not relied upon the advice, experience
or expertise of Idaho Power in connection with the transactions contemplated by
this Agreement.
2.2.7 Verification. All information relating to the Facility, its operation and output and
the Premises provided to Idaho Power and contained in this Agreement has been
verified by Seller and is true and accurate.
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2.3 No Other Representations or Warranties. Each Party acknowledges that it has entered into
this Agreement in reliance upon only the representations and warranties set forth in this
Agreement, and that no other representations or warranties have been made by the other
Party with respect to the subject matter hereof.
2.4 Continuing Nature of Representations and Warranties; Notice. The representations and
warranties set forth in this Section are made as of the Effective Date and deemed repeated
as of the Commercial Operation Date. If at any time during the Term, a Party obtains actual
knowledge of any event or information that would have caused any of the representations
and warranties in this Section 2 to be materially untrue or misleading at the time given,
such Party shall provide the other Party with written notice of the event or information, the
representations and warranties affected, and the action, if any, which such Party intends to
take to make the representations and warranties true and correct. If at any time a Party
obtains actual knowledge that the representations and warranties in this Section 2 are not
true, said Party shall provide written notice to the other Party. The notice required pursuant
to this section shall be given as soon as practicable after the occurrence of each such event.
SECTION 3
CONDITIONS PRECEDENT TO TERM
3.1 Conditions to be granted First Operation Date. As a condition of the Buyer’s acceptance of
deliveries of the Storage Product from the Seller, the following conditions shall be satisfied.
3.1.1 Commission/Regulatory Approval. This Agreement shall only become finally
effective upon the IPUC’s approval of all terms and provisions hereof without
change or condition, and declaration that all payment to be made to Seller
hereunder shall be allowed as prudently incurred expenses for ratemaking
purposes, and compliance of this Agreement with Idaho Power’s regulatory
requirements with the IPUC and OPUC (“IPUC Approval”);provided that,
notwithstanding anything to the contrary herein, if such IPUC Approval does not
occur on or prior to the date that is six (6) months after the filing of this
Agreement for IPUC Approval, the Parties agree to consult with each other for a
period of five (5) Business Days in the event of any such delay to evaluate
whether, notwithstanding such delay, the Facility will achieve Commercial
Operation by the Scheduled Commercial Operation Date; provided, further, that
if the Parties are unable to so agree, then the Scheduled Commercial Operation
Date and Commercial Operation Date shall each be extended on a day-for-day
basis for each day after the date that is six (6) months after the filing of this
Agreement for IPUC Approval, until such time as IPUC Approval is obtained. If
IPUC Approval does not occur by the date that is twelve (12) months after the
filing of this Agreement for IPUC Approval, then Seller will have a right to
terminate this Agreement and upon any such termination neither Party shall have
any obligation to the other under this Agreement, except with respect to the terms
and provisions hereof that expressly survive the termination of this Agreement .
3.1.2 The Parties recognize and acknowledge that regulatory proceedings at both the
IPUC and the OPUC may be required. This Agreement shall not become finally
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effective should the Agreement be disapproved by the IPUC and/or the OPUC.
Idaho Power will file a case seeking approval of this Agreement with the IPUC.
Additional and concurrent proceedings could include but may not be limited to:
the Facility’s successful selection in a possible Request for Proposals process that
complies with the OPUC’s procurement rules; cases before the IPUC and OPUC
regarding the waiver of process, timing, etc. related to compliance or lack thereof
with the OPUC procurement rules, and inclusion of the Facility in Idaho Power’s
Integrated Resource Planning process.
3.2 Idaho Power’s Right to Monitor. After the Effective Date, Seller shall, and shall permit
Idaho Power and its advisors and consultants to:
3.2.1 On and after the Execution Date through the Commercial Operation Date, by the
tenth (10th) Business Day of each month, Seller will provide Buyer a monthly
report for the prior month regarding development, financing and construction
updates in the form attached hereto as Exhibit 18, the form of which may be
reasonably revised by Buyer from time to time (the “Construction Progress
Report”).
3.2.2 Thirty (30) days prior to the expected Commercial Operation Date and thereafter
from the Commercial Operation Date and throughout the Settlement Term of this
Agreement, no later than the end of the month immediately following the month
for which information is being reported, Seller shall provide Buyer with a
monthly report for the prior month regarding material data pertaining to the
operation of the Facility in the form of Exhibit 19, the form of which may be
reasonably revised by Buyer from time to time (the “Operations Report”). Each
Operations Report shall include, at a minimum, the following information for the
Facility in such month: (i) A description of any Outages or other performance
issues in the prior month; (ii) the Storage Availability calculated in accordance
with Exhibit 23; and (iii) a description of any issues that could materially impact
(ii).
3.2.3 Review and discuss with Seller and its advisors and consultants monthly status
reports on the progress of the acquisition, design, financing, engineering,
construction and installation of the Facility.
3.2.4 Monitor the status of the acquisition, Premises, land leasing, design, financing,
engineering, construction and installation of the Facility and the performance of
the contractors constructing the Facility.
3.2.5 Witness initial performance tests and other tests and review the results thereof; with
Seller to make best efforts to provide Idaho Power five (5) Business Days’
advance written notice of each such major test. Seller shall provide Idaho Power
with at least two (2) Business Days prior written notice of each such test.
3.2.6 Perform such examinations, inspections, and quality surveillance as, in Idaho
Power’s reasonable judgment, are appropriate and advisable to determine that the
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Facility has been properly commissioned and Commercial Operation and Final
Completion have been achieved.
With respect to Idaho Power’s right to monitor under this Section 3.2, (i) Idaho Power is under no
obligation to exercise any of these monitoring rights, (ii) such monitoring shall occur subject to
reasonable rules developed by Seller regarding Facility construction, access, health, safety, and
environmental requirements, and (iii) Idaho Power shall have no liability to Seller for failing to
advise it of any condition, damages, circumstances, infraction, fact, act, omission or disclosure
discovered or not discovered by Idaho Power with respect to the Facility or any contractor. Any
review or monitoring of the Facility conducted by Idaho Power hereunder shall be performed in a
manner that does not impede, hinder, postpone, or delay Seller or its contractors in their
performance of the engineering, construction, design or testing of the Facility. Idaho Power shall
maintain one or more designated representatives for purposes of the monitoring activities
contemplated in this Section 3.2, which representatives shall have authority to act for Idaho Power
in all technical matters under this Section 3.2 as authorized by Idaho Power but not to amend or
modify any provision hereof. A Construction Progress Report and Operations Report delivered
pursuant to this Section 3.2 shall not constitute notice for any purpose under this Agreement,
including with respect to any fact, circumstance, request, issue, dispute or matter included in such
report. Seller does not herein grant Idaho Power the right to review, comment on or approve of
the terms or conditions of any contract or negotiation between Seller and a third party, the terms
and conditions of each such contract or negotiation being confidential and to be determined by
Seller in its sole discretion. Conversely, nothing in this Agreement shall be construed to require
Idaho Power to review, comment on, or approve of any contract between Seller and a third party
and any such review, comment or approval by Idaho Power shall not constitute a waiver by Idaho
Power or any of Seller’s obligations under this Agreement or create any obligation or liability for
Idaho Power.
SECTION 4
TERM AND COMMERCIAL OPERATION DATE
4.1 Term. This Agreement shall become effective on the Effective Date and, subject to earlier
termination as provided in this Agreement, shall continue in full force and effect for a
period of __________ Contract Years from the Commercial Operation Date (the “Term”).
4.2 Commercial Operation Date. Seller will in good faith using commercially reasonable
efforts seek to achieve the Commercial Operation Date by the Scheduled Commercial
Operation Date. The Commercial Operation Date shall occur after all the following
conditions have been satisfied.
4.2.1 Idaho Power has received the Default Security, as applicable.
4.2.2 Seller shall notify Buyer of the Seller’s proposed Commercial Operation Date, in
written form no later than five (5) Business Days prior to the proposed
Commercial Operation Date.
4.2.3 Seller shall provide to Idaho Power a certificate from a Licensed Professional
Engineer licensed in the state of Idaho addressed to Idaho Power stating that
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Seller has (a) the Required Facility Documents including the material permits,
consents and agreements necessary to operate and maintain the Facility and (b)
obtained or entered into all Permits and Required Facility Documents. Seller
must provide copies of any or all Required Facility Documents requested by
Idaho Power.
4.2.4 Seller shall provide Idaho Power with documentation showing that Seller has
obtained retail electric service for the Facility.
4.2.5 Idaho Power has received a certificate addressed to Idaho Power from a Licensed
Professional Engineer stating that, in conformance with the requirements of the
Generation Interconnection Agreement: (1) all required Interconnection
Facilities have been constructed; (2) all required interconnection tests have been
completed; and (3) the Facility is physically interconnected with the System in
conformance with the Generation Interconnection Agreement and able to deliver
electric energy consistent with the terms of this Agreement.
4.2.6 Idaho Power has received, addressed to Idaho Power from a Licensed Professional
Engineer, an executed Engineer’s Certification of Design & Construction
Adequacy and an Engineer’s Certification of Operations and Maintenance
(O&M) Policy. These certificates will be in the form specified in Exhibit 11 but
may be modified to the extent necessary to recognize the different engineering
disciplines providing the certificates.
4.2.7 Idaho Power has received an opinion from a law firm or attorney licensed in the
State of Idaho stating, after all appropriate and reasonable inquiry (1) Seller has
obtained or entered into all Required Facility Documents; and (2) neither Seller
nor the Facility are in violation of or subject to any liability under any
Requirements of Law.
4.2.8 Idaho Power has received a certificate addressed to Idaho Power from an authorized
officer of Seller (1) stating that Seller has completed all of its obligations under
the Generation Interconnection Agreement.
4.2.9 Seller has satisfied its obligation to pay for any required Network Upgrades as a
Network Resource pursuant to the Generation Interconnection Agreement (as
those terms are defined in the Generation Interconnection Agreement).
4.2.10 Seller shall submit written proof to the Buyer of all insurance required in Section
14.
4.2.11 Seller has completed all Start-Up Testing in accordance with Exhibit 7.
4.2.12 Seller has completed all Performance Tests, submitted the results thereof to Idaho
Power, and has achieved (i) the Guaranteed Storage Availability or paid all
Storage Availability Damages in accordance with Section 4.5.5, (ii) the
Guaranteed Storage Capacity or paid all Storage Capacity Damages in
accordance with Section 4.5.5, and (iii) Guaranteed Roundtrip Efficiency.
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4.2.13 Commercial Operation Date Notice. Seller shall provide written notice to Idaho
Power stating when Seller believes that the Facility has achieved Commercial
Operation accompanied by the certificates and opinions described above.
4.2.14 Idaho Power shall have ten (10) Business Days after receipt of such written notice
from Seller either to confirm to Seller that all of the conditions to Commercial
Operation have been satisfied or have occurred, or to state with specificity what
Idaho Power reasonably believes has not been satisfied. If, within such ten (10)
Business Day period, Idaho Power does not respond or notifies Seller confirming
that the Facility has achieved Commercial Operation, the original date of receipt
of Seller’s written notice shall be the Commercial Operation Date. If Idaho Power
notifies Seller within such ten (10) Business Day period that Idaho Power
reasonably believes the Facility has not achieved Commercial Operation, Seller
must address the concerns stated in Idaho Power’s notice to the satisfaction of
Idaho Power. In the event Idaho Power provides notice of deficiency with regards
to the information submitted to establish the Commercial Operation Date, then
the Commercial Operation Date will be the date upon which Seller has addressed
the concerns stated in Idaho Power’s notice to Idaho Power’s reasonable
satisfaction.
With respect to Sections 4.2.3 through 4.2.6 above, the certificate or opinion provided to Idaho
Power must come from a Licensed Professional Engineer or, in the case of Section 4.2.7 above,
an attorney that is not an employee of Seller (or any Affiliate) and has no financial interest in the
Facility.
Notwithstanding the foregoing in this Section 4.2, the date for achieving each of the foregoing
items shall be extended on a day for day basis for any delay due solely to Idaho Power’s delay in
taking, or failure to take, any action required of it hereunder in breach of this Agreement. These
Commercial Operation Date requirements are to be used solely for purposes of determining when
the Facility has achieved its Commercial Operation Date.
4.3 Condition Precedents to Commercial Operation. Seller covenants and agrees that before it
achieves the Commercial Operation Date, it shall ensure that it has done all of the
following, and Seller shall hold Idaho Power harmless from and against any failure of
Seller to have done so:
4.3.1 All Facility systems necessary for the stable, safe, reliable and consistent operation
of the installed Facility are substantially complete,
4.3.2 Any testing of the installed Facility required pursuant to the Interconnection
Agreement(s) and Interconnection Provider documents and equipment supplier
requirements have been successfully completed;
4.3.3 Seller has completed all of the Performance Tests and has achieved (i) the
Guaranteed Storage Availability or paid all Storage Availability Damages in
accordance with Section 4.5.5, (ii) the Guaranteed Storage Capacity or paid all
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Storage Capacity Damages in accordance with Section 4.5.5, and (iii) the
Guaranteed Roundtrip Efficiency; and
4.3.4 the Facility is available for operation in all material respects in accordance with the
Requirements of Law.
4.4 Continuing Obligations. Seller shall provide Buyer with the following during the Term of
this Agreement:
4.4.1 At Buyer’s request, Seller shall provide evidence that it is in compliance with the
insurance requirements set forth in Section 14.
4.4.2 Seller shall maintain compliance and remain in good standing in all requirements
of Sections 3 and 4 of this Agreement.
4.5 Commercial Operation Date Delay, Delay Damages, Storage Capacity Damages, Storage
Availability Damages.
4.5.1 If Commercial Operation is not achieved on or before the Scheduled Commercial
Operation Date, Seller shall pay to Idaho Power Delay Damages from and after
the Scheduled Commercial Operation Date up to, but not including, the date that
the Facility achieves Commercial Operation. Delay Damages cease to accrue in
the event of termination of this Agreement.
4.5.2 If the Facility does not achieve Commercial Operation by the Guaranteed
Commercial Operation Date, Idaho Power may terminate this Agreement
pursuant to Section 12.
4.5.3 If the Facility does not achieve the Guaranteed Roundtrip Efficiency, Idaho Power
may terminate this Agreement pursuant to Section 12.
4.5.4 If the Facility achieves Commercial Operation based on less than the Guaranteed
Storage Capacity, Seller shall pay to Idaho Power the Storage Capacity Damages,
provided, Seller shall not be required to pay Storage Capacity Damages in excess
of the Storage Capacity Damages Cap.
4.5.5 If the Facility achieves Commercial Operation based on less than the Guaranteed
Storage Availability, Seller shall pay to Idaho Power the Storage Availability
Damages, provided, Seller shall not be required to pay Storage Availability
Damages in excess of the Storage Availability Damages Cap.
4.6 Damages Calculation. Each Party agrees and acknowledges that (a) the damages that Idaho
Power would incur due to Seller’s delay in achieving Commercial Operation or failure to
achieve the Guaranteed Storage Capacity or Guaranteed Storage Availability would be
difficult or impossible to predict with certainty, and (b) it is impractical and difficult to
assess actual damages in the circumstances stated, and therefore the Delay Damages,
Storage Capacity Damages, and Storage Availability Damages as agreed to by the Parties
and set forth herein are a fair and reasonable calculation of such damages. The Parties agree
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that Delay Damages, Storage Capacity Damages, and Storage Availability Damages shall
be Idaho Power’s exclusive remedy for a delay in achieving Commercial Operation or
failure to achieve the Guaranteed Storage Availability and Guaranteed Storage Capacity
and believe that Delay Damages, Storage Capacity Damages, and Storage Availability
Damages fairly represent actual damages. Subject to the foregoing sentence, this Section
4.6 shall not limit Seller’s termination rights or the amount of damages payable to Idaho
Power if this Agreement is terminated as a result of Seller’s failure to achieve Commercial
Operation by the Guaranteed Commercial Operation Date. Any such termination damages
shall be determined in accordance with Section 12.4.
4.7 Damages Invoicing. By the tenth (10
th) day following the end of the calendar month in
which Delay Damages begin to accrue or Storage Capacity Damages or Storage
Availability Damages are incurred, as applicable, and continuing on the tenth (10 th) day of
each calendar month during the period in which Delay Damages accrue (and the following
months, if applicable), Idaho Power shall deliver to Seller an invoice showing Idaho
Power’s computation of such damages and any amount due Idaho Power in respect thereof
for the preceding calendar month. No later than ten (10) days after receiving such an
invoice and subject to Sections 11.2 and 11.3, Seller shall pay to Idaho Power, by wire
transfer of immediately available funds to an account specified in writing by Idaho Power
or by any other means agreed to by the Parties in writing from time to time, the amount set
forth as due in such invoice.
SECTION 5
DELIVERIES OF STORAGE PRODUCT
5.1 Purchase and Sale. Except as otherwise expressly provided herein, commencing on the
Commercial Operation Date and continuing through the Term, Seller shall sell and make
available to Idaho Power, and Idaho Power shall purchase and receive the Storage Product.
Idaho Power shall be under no obligation to make any purchase hereunder other than the
Storage Product, as described above. Idaho Power shall not be obligated to purchase,
receive or pay for Storage Product that is not delivered to Idaho Power at the Point of
Delivery or otherwise.
5.2 No Sales to Third Parties. During the Term, Seller shall not sell any Storage Product from
the Facility to any party other than Idaho Power; provided, however, that this restriction
shall not apply during periods when Idaho Power is in default hereof because it has failed
to accept the Storage Product delivered by Seller to Idaho Power as required hereunder.
5.3 Title and Risk of Loss of Storage Product. Seller shall deliver the Storage Product to Idaho
Power free and clear of all liens, claims and encumbrances. Title to and risk of loss of all
Storage Product shall transfer from Seller to Idaho Power upon its delivery to Idaho Power
at the Point of Delivery. Seller shall be deemed to be in exclusive control of, and
responsible for, any damage or injury caused by, all delivery of the Storage Product up to
and at the Point of Delivery, or failure to deliver the Storage Product to the Point of
Delivery. Idaho Power shall be deemed to be in exclusive control of Storage Product after
the Point of Delivery.
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5.4 Idaho Power as Merchant. Seller acknowledges that Idaho Power, acting in its merchant
capacity function as purchaser under this Agreement, has no responsibility for or control
over Idaho Power Transmission or any successor Transmission Provider.
5.5 Purchase and Sale of Capacity Rights. For and in consideration of Idaho Power’s
agreement to purchase from Seller the Storage Product on the terms and conditions set forth
herein, Seller transfers to Idaho Power, and Idaho Power accepts from Seller, all right, title,
and interest that Seller may have in and to Capacity Rights, if any, existing during the
Term.
5.6 Representation Regarding Ownership of Capacity Rights. Seller represents that it has not
sold, and covenants that during the Term it will not sell or attempt to sell to any other
person or entity the Capacity Rights, if any. During the Term, Seller shall not report to any
person or entity that the Capacity Rights, if any, belong to anyone other than Idaho Power.
Idaho Power may at its own risk and expense report to any person or entity that Capacity
Rights exclusively belong to it.
5.7 Authority to Make Sales. Seller covenants that during the Term it will maintain all required
regulatory authority to make wholesale sales from the Facility to Idaho Power.
5.8 Further Assurances. At Idaho Power’s request, the Parties shall execute such documents
and instruments as may be reasonably required to effect recognition and transfer of the
Storage Product to Idaho Power.
SECTION 6
CONTRACT PRICE; COSTS
6.1 Contract Price. Idaho Power shall pay Seller the Contract Price for the Storage Product.
Seller shall not be entitled to any compensation over and above the Contract Price for the
Storage Product.
6.2 Costs and Charges. Seller shall be responsible for paying or satisfying when due all costs
or charges imposed in connection with the scheduling and delivery of Storage Product up
to and at the Point of Delivery, including transmission costs, Transmission Service, and
transmission line losses, and any operation and maintenance charges imposed by
Interconnection Provider and Transmission Provider for the Interconnection Facilities.
Idaho Power shall be responsible for all costs or charges, if any, imposed in connection
with the delivery of Storage Product at and from the Point of Delivery, including
transmission costs and transmission line losses and imbalance charges or penalties.
Without limiting the generality of the foregoing, Seller, in accordance with the Generation
Interconnection Agreement, shall bear all costs associated with the modifications to
Interconnection Facilities or the System (including system upgrades) caused by or related
to (a) the interconnection of the Facility with the System and (b) any increase in generating
capacity of the Facility.
6.3 Station Service. Seller shall be responsible for arranging and obtaining, at its sole risk and
expense, any station service required by the Facility that is not provided by the Facility
itself.
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6.4 Taxes. Seller shall pay or cause to be paid when due, or reimburse Idaho Power for, all
existing and any new sales, use, excise, severance, ad valorem, and any other similar taxes,
imposed or levied by any Governmental Authority on the Storage Product up to and
including, but not beyond, the Point of Delivery, regardless of whether such taxes are
imposed on Idaho Power or Seller under Requirements of Law. Idaho Power shall pay or
cause to be paid when due all such taxes imposed or levied by any Governmental Authority
on the Storage Product beyond the Point of Delivery, regardless of whether such taxes are
imposed on Idaho Power or Seller under Requirements of Law. The Contract Price shall
not be adjusted on the basis of any action of any Governmental Authority with respect to
changes to or revocations of sales and use tax benefits, rebates, exception or give back. In
the event any taxes are imposed on a Party for which the other Party is responsible
hereunder, the Party on which the taxes are imposed shall promptly provide the other Party
written notice thereof and such other information as such Party may reasonably request
with respect to any such taxes. Seller shall be responsible for any and all sun and light
severance taxes.
6.5 Costs of Ownership and Operation. Without limiting the generality of any other provision
hereof and subject to Section 6.4, Seller shall be solely responsible for paying when due
(a) all costs of owning and operating the Facility in compliance with existing and future
Requirements of Law and the terms and conditions hereof, and (b) all taxes and charges
(however characterized) now existing or hereinafter imposed on or with respect to the
Facility, its operation, or on or with respect to emissions or other environmental impacts
of the Facility.
6.6 Rates Not Subject to Review. The rates for service specified herein shall remain in effect
until expiration of the Term and shall not be subject to change for any reason, including
regulatory review, absent agreement of the Parties. Neither Party shall petition FERC
pursuant to the provisions of Sections 205 or 206 of the Federal Power Act (16 U.S.C. §
792 et seq.) to amend such prices or terms or support a petition by any other person or
entity seeking to amend such prices or terms, absent the agreement in writing of the other
Party. Further, absent the agreement in writing by both Parties, the standard of review for
changes hereto proposed by a Party, a non-party or the FERC acting sua sponte shall be
the “public interest” application of the “just and reasonable” standard of review set forth
in United Gas Pipe Line Co. v. Mobile Gas Service Corp., 350 U.S. 332 (1956) and Federal
Power Commission v. Sierra Pacific Power Co., 350 U.S. 348 (1956) and clarified by
Morgan Stanley Capital Group. Inc. v. Public Util. Dist. No. 1 of Snohomish, 554 U.S.
527, 128 S. Ct. 2733 (2008).
SECTION 7
OPERATION AND CONTROL
7.1 As-Built Supplement. Within thirty (30) days of completion of construction of the Facility,
Seller shall provide Idaho Power the As-built Supplement. The As-built Supplement shall
be deemed effective and shall be added to Exhibit 16 when it has been reviewed and
approved by Idaho Power, which approval shall not be unreasonably withheld or delayed.
If the proposed As-built Supplement does not accurately describe the Facility as actually
built or is otherwise defective as to form in any material respect, Idaho Power may within
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fifteen (15) days after receiving the proposed As-built Supplement give Seller a notice
describing what Idaho Power wishes to correct. If Idaho Power does not give Seller such a
notice within the fifteen (15) day period, the As-built Supplement shall be deemed
approved. If Idaho Power provides a timely notice requiring corrections, Seller shall in
good faith cooperate with Idaho Power to revise the As-built Supplement to address Idaho
Power’s concerns. Notwithstanding the foregoing, Idaho Power shall have no right to
require Seller to relocate, modify or otherwise change in any respect any aspect of the
Facility as actually built.
7.2 Standard of Facility Operation.
7.2.1 General. At Seller’s sole cost and expense, Seller shall build, operate, maintain and
repair the Facility and the Interconnection Facilities in accordance with (a) the
applicable and mandatory standards, criteria and formal guidelines of FERC,
NERC, any RTO, and any other Electric System Authority and any successors to
the functions thereof; (b) the Permits and Required Facility Documents; (c) the
Generation Interconnection Agreement; (d) all Requirements of Law; (e) the
requirements hereof; and (f) Prudent Electrical Practice. Seller acknowledges that
it shall have no claims hereunder against Idaho Power with respect to any
requirements imposed by or damages caused by (or allegedly caused by) the
Transmission Provider. Sellerwill have no claims against Idaho Power under this
Agreement with respect to the provision of station service.
7.2.2 Qualified Operator. From and after the Commercial Operation Date, Seller will
cause the Project to be operated and maintained by a Qualified Operator. Seller
shall provide Idaho Power thirty (30) days prior written notice of any proposed
change in the Qualified Operator of the Facility.
7.2.3 Fines and Penalties.
7.2.3.1 Without limiting a Party’s rights under Section 7.2.3.2, each Party shall
pay all fines and penalties incurred by such Party on account of
noncompliance by such Party with Requirements of Law in respect
to this Agreement, except where such fines and penalties are being
contested in good faith through appropriate proceedings.
7.2.3.2 If fines, penalties, or legal costs are assessed against or incurred by either
Party (the “Indemnified Party”) on account of any action by any
Governmental Authority due to noncompliance by the other Party
(the “Indemnifying Party”) with any Requirements of Law or the
provisions hereof, or if the performance of the Indemnifying Party
is delayed or stopped by order of any Governmental Authority due
to the Indemnifying Party’s noncompliance with any Requirements
of Law, the Indemnifying Party shall indemnify and hold harmless
the Indemnified Party against any and all losses, liabilities, damages,
and claims suffered or incurred by the Indemnified Party as a result
thereof. Without limiting the generality of the foregoing, the
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Indemnifying Party shall reimburse the Indemnified Party for all
fees, damages, or penalties imposed on the Indemnified Party by any
Governmental Authority, other person or entity or to other utilities
for violations to the extent caused by a default by the Indemnifying
Party or a failure of performance by the Indemnifying Party
hereunder.
7.3 Interconnection. Seller shall be responsible for the costs and expenses associated with
obtaining from the Transmission Provider Network Resource interconnection service for
the Facility at its Nameplate Capacity Rating at the Point of Delivery. Seller shall have no
claims hereunder against Idaho Power, acting in its merchant function capacity, with
respect to any requirements imposed by or damages caused by (or allegedly caused by)
acts or omissions of the Transmission Provider or Interconnection Provider, in connection
with the Generation Interconnection Agreement or otherwise.
7.4 Coordination with System. Seller shall be responsible for the coordination and
synchronization of the Facility and the Interconnection Facilities with the System.
7.5 Outages.
7.5.1 Planned Outages. Except as otherwise provided herein, Seller shall not schedule a
Planned Outage during daylight hours (sun up to sunset) during any portion of
the months of November, December, January, February, June, July, and August,
except to the extent a Planned Outage is reasonably required to enable a vendor
to satisfy a guarantee requirement. Seller shall provide Idaho Power with an
annual forecast of Planned Outages for each Contract Year at least one (1) month,
but no more than three (3) months, before the first day of that Contract Year, and
shall promptly update such schedule, or otherwise change it, only to the extent
that Seller is reasonably required to change it in order to comply with Prudent
Electrical Practices. Seller shall not schedule any maintenance of Interconnection
Facilities during such months, without the prior written approval of Idaho Power,
which approval shall not be unreasonably withheld or delayed.
7.5.2 Maintenance Outages. If Seller reasonably determines that it is necessary to
schedule a Maintenance Outage, Seller shall notify Idaho Power in writing of the
proposed Maintenance Outage as soon as practicable but in any event at least five
(5) days before the outage begins. Upon such notice, the Parties shall plan the
Maintenance Outage to mutually accommodate the reasonable requirements of
Seller and the service obligations of Idaho Power; provided, however, that Seller
shall take all reasonable measures consistent with Prudent Electrical Practices to
not schedule any Maintenance Outage during the daylight hours of the following
periods: November, December, January, February, June 15 through June 30, July,
August, and September 1 through September 15. Notice of a proposed
Maintenance Outage shall include the expected start date and time of the outage,
the amount of generation capacity of the Facility that will not be available, and
the expected completion date and time of the outage. Seller shall give Idaho
Power notice of the Maintenance Outage as soon as practicable after Seller
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determines that the Maintenance Outage is necessary. Idaho Power shall
promptly respond to such notice and may request reasonable modifications in the
schedule for the outage. Seller shall use all reasonable efforts to comply with any
request to modify the schedule for a Maintenance Outage provided that such
change has no substantial impact on Seller. Seller shall notify Idaho Power of
any subsequent changes in generation capacity available to Idaho Power as a
result of such Maintenance Outage or any changes in the Maintenance Outage
completion date and time. As soon as practicable, any notifications given orally
shall be confirmed in writing. Seller shall take all reasonable measures consistent
with Prudent Electrical Practices to minimize the frequency and duration of
Maintenance Outages.
7.5.3 Forced Outages. Seller shall promptly provide to Idaho Power an oral report, via
telephone to a number specified by Idaho Power (or other method approved by
Idaho Power), of any Forced Outage resulting in more than ten percent (10%) of
the Storage Capacity of the Facility being unavailable. This report shall include
the amount of the generation capacity of the Facility that will not be available
because of the Forced Outage and the expected return date of such generation
capacity. Seller shall promptly update the report as necessary to advise Idaho
Power of changed circumstances. As soon as practicable, the oral report shall be
confirmed in writing by notice to Idaho Power. Seller shall take all reasonable
measures consistent with Prudent Electrical Practices to avoid Forced Outages
and to minimize their duration.
7.5.4 Notice of Deratings and Outages. Without limiting the foregoing, Seller will inform
Idaho Power, via telephone to a number specified by Idaho Power (or other
method approved by Idaho Power), of any major limitations, restrictions,
deratings or outages known to Seller affecting the Facility for the following day
and will promptly update Seller’s notice to the extent of any material changes in
this information, with “major” defined as affecting more than five percent (5%)
of the Storage Capacity.
7.6 Scheduling.
7.6.1 Cooperation and Standards. With respect to any and all scheduling requirements
hereunder, (a) Seller shall cooperate with Idaho Power with respect to scheduling
Discharging Energy and Ancillary Services, and (b) each Party shall designate
authorized representatives to communicate with regard to scheduling and related
matters arising hereunder. Each Party shall comply with the applicable variable
resource standards and criteria of any applicable Electric System Authority.
Idaho Power shall have all right, title, and interest in and to any gross revenues
received by Seller for any Ancillary Services provided by the Facility. Seller
shall operate the Facility in accordance with the Storage Operating Restrictions.
7.6.2 Schedule Coordination. If, as a result hereof, Idaho Power is deemed by an RTO to
be financially responsible for Seller’s performance under the Generation
Interconnection Agreement, due to Seller’s lack of standing as a “scheduling
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coordinator” or other RTO recognized designation, qualification or otherwise,
then Seller shall acquire such RTO recognized standing (or shall contract with a
third party who has such RTO recognized standing) such that Idaho Power is no
longer responsible for Seller’s performance under the Generation Interconnection
Agreement or RTO requirement.
7.7 Charging Energy Management.
7.7.1 Upon receipt of a valid Charging Notice, but subject to Section 7.7.2, Seller shall
take any and all action necessary to accept the Charging Energy from the Idaho
Power generating facilities to the Facility in order to deliver the Storage Product
in accordance with the terms and conditions of this Agreement. Idaho Power shall
have the right to direct Seller to charge the Facility seven (7) days per week and
twenty-four (24) hours per day (including holidays), by providing Charging
Notices to Seller electronically; provided, that Idaho Power’s right to issue
Charging Notices is subject to the requirements and limitations set forth in this
Agreement, including the Storage Operating Restrictions set forth in Exhibit 4.
Each Charging Notice issued in accordance with this Agreement will be effective
unless and until Idaho Power modifies such Charging Notice by providing Seller
with an updated Charging Notice. Seller shall not charge the Facility other than
pursuant to a valid Charging Notice or in connection with a Guaranteed Storage
Capacity Test. If Seller (a) charges the Facility to a Stored Energy Level greater
than the Stored Energy Level provided for in the Charging Notice or (b) charges
the Facility in violation of the first sentence of this Section 7.7.1, then (x) Seller
shall be responsible for all Energy costs associated with such charging of the
Facility, (y) Idaho Power shall not be required to pay for the charging of such
Energy (i.e., Charging Energy), and (z) Idaho Power shall be entitled to discharge
such Energy and entitled to all of the benefits (including Storage Product)
associated with such discharge. Idaho Power shall have the right to direct Seller
to discharge the Facility seven (7) days per week and twenty-four (24) hours per
day (including holidays), by providing Discharging Notices to Seller
electronically, and subject to the requirements and limitations set forth in this
Agreement, including the Storage Operating Restrictions. Each Discharging
Notice issued in accordance with this Agreement will be effective unless and
until Idaho Power modifies such Discharging Notice by providing Seller with an
updated Discharging Notice.
7.7.2 Notwithstanding anything in this Agreement to the contrary, any curtailment order
issued by the RTO or any other Governmental Authority, as applicable, regarding
the reduced or increased generation of the Facility, whether in response to an
Emergency or otherwise, shall have priority over any Charging Notices and
Discharging Notices for the applicable period, and Seller shall have no liability
for violation of this Section 7.1 or any Charging Notice or Discharging Notice if
and to the extent such violation is caused by Seller’s compliance with any such
notice of curtailment.
7.8 Performance Tests; Guarantees.
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7.8.1 Guaranteed Storage Capacity. Seller shall perform the Storage Capacity Test as
provided in Exhibit 23, provided in the event that Seller fails to demonstrate
compliance with the Guaranteed Storage Capacity. Seller shall pay as liquidated
damages for such failure and not as a penalty, the Storage Capacity Damages in
the event that Seller fails to demonstrate compliance with the Guaranteed Storage
Capacity.
7.8.2 Guaranteed Storage Availability. Seller shall perform the Storage Availability Test
as provided in Exhibit 23; provided, if Seller does not achieve the Guaranteed
Storage Availability for the previous Contract Year as determined in accordance
with the terms of Exhibit 23, then, Seller shall pay as liquidated damages for such
failure and not as a penalty, the Storage Availability Damages for each Day
during the previous Contract Year in which Seller fails to demonstrate
compliance with the Guaranteed Storage Availability.
7.8.3 Guaranteed Roundtrip Efficiency. Seller shall perform the Roundtrip Efficiency
Test as provided in Exhibit 23.
7.8.4 Ramp Rate Test. Seller shall perform the Ramp Rate Test as provided in Exhibit
23.
7.8.5 Response Time Test. Seller shall perform the Response Time Test as provided in
Exhibit 23.
7.8.6 Auxiliary Load Test. Seller shall perform the Auxiliary Load Test as provided in
Exhibit 23.
7.8.7 Power Factor Test. Seller shall perform the Power Factor Test as provided in
Exhibit 23.
7.8.8 Noise Test. Seller shall perform the Noise Test as provided in Exhibit 23.
7.9 Electronic Communications.
7.9.1 GOLC. Beginning on the Commercial Operation Date, Idaho Power will dispatch
Facility through its GOLC system installed by Seller. The GOLC Set-Point is
calculated by the Transmission Provider and communicated electronically
through the SCADA system. Seller shall ensure that, throughout the Term, the
SCADA signal is capable of functioning on all GOLC Set-Points within the
margin of error specified in the Facility control system manufacturer’s set point
margin of error. Unless otherwise directed by Idaho Power, Seller shall ensure
that the Facility GOLC is in “Remote” set-point control during normal
operations.
7.9.2 Telemetering. Seller shall during the Term provide telemetering equipment and
facilities capable of transmitting the following information concerning the
Facility pursuant to the Generation Interconnection Agreement and to Idaho
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Power on a real-time basis, and will operate such equipment when requested by
Idaho Power to indicate instantaneous MW output at the Point of Delivery.
Commencing on the Commercial Operation Date, Seller shall also transmit or
cause to be transmitted to or make accessible to Idaho Power any other data from
the Facility that Seller receives on a real time basis, including meteorological
data, Charging Energy, Discharging Energy, Storage Capacity, Storage
Availability and any Ancillary Services provided by the Facility. Such real time
data shall be provided to or be made accessible to Idaho Power on the same basis
on which Seller receives the data (e.g., if Seller receives the data in four second
intervals, Idaho Power shall also receive the data in four second intervals). Seller
must provide Idaho Power access to Seller’s web-based performance monitoring
system.
7.9.3 Transmission Provider Consent. Seller shall execute a consent, in the form required
by Transmission Provider, to provide that Idaho Power can read the meter and
receive any and all data from the Transmission Provider relating to the Charging
Energy or Storage Product, or other matters relating to the Facility without the
need for further consent from Seller.
7.9.4 Dedicated Communication Circuit. Seller shall install a dedicated direct
communication circuit (which may be by common carrier telephone) between
Idaho Power and the control center in the Facility’s control room or such other
communication equipment as the Parties may agree.
7.10 Reports and Records.
7.10.1 Monthly Reports. Commencing on the Commercial Operation Date, within thirty
(30) days after the end of each calendar month during the Term (each, a
“Reporting Month”), Seller shall provide to Idaho Power a report in electronic
format, which report shall include (a) summaries of the Facility’s Charging
Energy, Discharge Energy, and Ancillary Services provided, including
information from the Facility’s computer monitoring system; (b) summaries of
any other significant events related to the construction or operation of the Facility
for the Reporting Month; and (c) any supporting information that Idaho Power
may from time to time reasonably request.
7.10.2 Electronic Fault Log. Seller shall maintain an electronic fault log of operations of
the Facility during each hour of the Term commencing on the Commercial
Operation Date. Seller shall provide Idaho Power with a copy of the electronic
fault log within thirty (30) days after the end of the calendar month to which the
fault log applies.
7.10.3 Other Information to be Provided to Idaho Power. Seller shall provide to Idaho
Power the following information concerning the Facility:
7.10.3.1 Upon the request of Idaho Power, the manufacturers’ guidelines and
recommendations for maintenance of the Facility equipment;
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7.10.3.2 A report summarizing the results of maintenance performed during
each Maintenance Outage, Planned Outage, and any Forced Outage,
and upon request of Idaho Power any of the technical data obtained
in connection with such maintenance;
7.10.3.3 Before Final Completion, a monthly progress report stating the
percentage completion of the Facility and a brief summary of
construction activity during the prior month;
7.10.3.4 Before Final Completion, a monthly report containing a brief
summary of construction activity contemplated for the next calendar
month;
7.10.3.5 From and after the Commercial Operation Date, a monthly report
detailing the availability of the Facility; and
7.10.3.6 At any time from the Effective Date, one year’s advance notice of
the termination or expiration of any material agreement, including
Leases, pursuant to which the Facility or any material equipment
relating thereto is upon the Premises; provided that the foregoing
does not authorize any early termination of any land lease. In the
event Seller has less than one year’s advance notice of such
termination or expiration, Seller shall provide the notice
contemplated by this Section to Idaho Power within fifteen (15)
Business Days of Seller obtaining knowledge of the termination or
expiration.
7.10.4 Information to Governmental Authorities. Seller shall, promptly upon written
request from Idaho Power, provide Idaho Power with all data collected by Seller
related to the construction, operation or maintenance of the Facility reasonably
required by Idaho Power or an Affiliate thereof for reports to, and information
requests from, any Governmental Authority or Electric System Authority. Along
with this information, Seller shall provide to Idaho Power copies of all submittals
to Governmental Authorities or Electric System Authorities directed by Idaho
Power and related to the operation of the Facility with a certificate that the
contents of the submittals are true and accurate to the best of Seller’s knowledge.
Seller shall use best efforts to provide this information to Idaho Power with
sufficient advance written notice to enable Idaho Power to review such
information and meet any submission deadlines imposed by the requesting
organization or entity.
7.10.5 Data Request. Seller shall, promptly upon written request from Idaho Power,
provide Idaho Power with data collected by Seller related to the construction,
operation or maintenance of the Facility reasonably required for information
requests from any Governmental Authorities, state or federal agency intervener
or any other party achieving intervenor status in any Idaho Power rate proceeding
or other proceeding before any Governmental Authority. Seller shall use best
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efforts to provide this information to Idaho Power sufficiently in advance to
enable Idaho Power to review it and meet any submission deadlines. Idaho Power
shall reimburse Seller for all of Seller’s reasonable actual costs and expenses in
excess of $10,000 per year, if any, incurred in connection with Idaho Power’s
requests for information under this Section 7.10.5.
7.10.6 Documents to Governmental Authorities. After sending or filing any statement,
application, and report or any document with any Governmental Authority or
Electric System Authority relating to operation and maintenance of the Facility,
Seller shall, within five (5) Business Days of such submission or filing, provide
to Idaho Power a copy of the same.
7.10.7 Environmental Information. Seller shall, promptly upon written request from Idaho
Power, provide Idaho Power with all data reasonably requested by Idaho Power
relating to environmental information under the Required Facility Documents.
Seller shall further provide Idaho Power with information relating to
environmental impact mitigation measures it is taking in connection with the
Facility’s construction or operation that are required by any Governmental
Authority. As soon as it is known to Seller, Seller shall disclose to Idaho Power,
the extent of any material violation of any environmental laws or regulations
arising out of the construction, operation, or maintenance of the Facility, or the
presence of Environmental Contamination at the Facility or on the Premises,
alleged to exist by any Governmental Authority having jurisdiction over the
Premises, or the present existence of, or the occurrence during Seller’s occupancy
of the Premises of, any enforcement, legal, or regulatory action or proceeding
relating to such alleged violation or alleged presence of Environmental
Contamination presently occurring or having occurred during the period of time
that Seller has occupied the Premises.
7.10.8 Operational Reports. Seller shall provide Idaho Power monthly operational reports
in a form and substance reasonably acceptable to Idaho Power, and Seller shall,
promptly upon written request from Idaho Power, provide Idaho Power with all
operational data requested by Idaho Power with respect to the performance of the
Facility and delivery of the Storage Product.
7.10.9 Notice of Material Adverse Events. Seller shall promptly notify Idaho Power of
receipt of written notice or actual knowledge by Seller or its Affiliates of the
occurrence of any event of default under any material agreement to which Seller
is a party and of any other development, financial or otherwise, which would
have a material adverse effect on Seller, the Facility or Seller’s ability to develop,
construct, operate, maintain or own the Facility as provided herein. Seller shall
promptly disclose to Buyer (but in no case later than two (2) Business Days after
Seller obtains actual knowledge) any violation of any Applicable Laws arising
out of the construction or operation of the Facility by Seller, its Affiliates or any
contractor of any of them, including any Qualified Operator, or the existence of
any past or present enforcement, legal, or regulatory action or proceeding relating
to the Facility, if such violation, action or proceeding adversely affects or could
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reasonably be expected to adversely affect the construction or operation of the
Facility or the commercial reputation of Buyer or its Affiliates.
7.10.10Notice of Litigation. Following its receipt of written notice or actual knowledge of
the commencement of any action, suit, or proceeding before any court or
Governmental Authority against Seller or its members with respect to this
Agreement or the transactions contemplated hereunder, Seller shall, within ten
(10) days of such notice or knowledge, give written notice to Idaho Power of the
same. Following its receipt of written notice or actual knowledge of the
commencement of any action, suit or proceeding before any court or
Governmental Authority against Seller, its members or any Affiliate, the effect
of which would materially and adversely affect Seller’s performance of its
obligations hereunder, Seller shall, within ten (10) days of such notice or
knowledge, give notice to Idaho Power of the same.
7.10.11Additional Information. Seller shall provide to Idaho Power such other information
respecting the condition or operations of Seller, as such pertains to Seller’s
performance of its obligations hereunder, or the Facility as Idaho Power may,
from time to time, reasonably request.
7.10.12Confidential Treatment. The monthly reports and other information provided to
Idaho Power under this Section 7.10 shall be treated as Confidential Business
Information if such treatment is requested in writing by Seller at the time the
information is provided to Idaho Power, subject to Idaho Power’s rights to
disclose such information pursuant to Sections 7.10.4, 7.10.5, 7.10.7, 11.5, 25.2
and 25.3, and pursuant to any applicable Requirements of Law. Seller shall have
the right to seek confidential treatment of any such information from the
Governmental Authority entitled to receive such information.
7.11 Financial and Accounting Information. If Idaho Power or one of its Affiliates determines
that, under (i) the Accounting Standards Codification (ASC) 810, Consolidation of
Variable Interest Entities, and (ii) Requirements of Law that it may hold a variable interest
in Seller, but it lacks the information necessary to make a definitive conclusion, Seller
hereby agrees to provide, upon Idaho Power’s written request, sufficient financial and
ownership information so that Idaho Power or its Affiliate may confirm whether a variable
interest does exist under ASC 810 and Requirements of Law. If Idaho Power or its Affiliate
determines that, under ASC 810, it holds a variable interest in Seller, Seller hereby agrees
to provide, upon Idaho Power’s written request, sufficient financial and other information
to Idaho Power or its Affiliate so that Idaho Power may properly consolidate the entity in
which it holds the variable interest or present the disclosures required by ASC 810 and
Requirements of Law. Idaho Power shall reimburse Seller for Seller’s reasonable costs and
expenses, if any, incurred in connection with Idaho Power’s requests for information under
this Section 7.11.
7.12 Access Rights. Upon reasonable prior notice and subject to the prudent safety requirements
of Seller, and Requirements of Law relating to workplace health and safety, Seller shall
provide Idaho Power and its authorized agents, employees and inspectors (“Idaho Power
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Representatives”) with reasonable access to the Facility: (a) for the purpose of reading or
testing metering equipment, (b) as necessary to witness any acceptance tests, (c) to provide
tours of the Facility to customers and other guests of Idaho Power (not more than twelve
(12) times per year), (d) for purposes of implementing Sections 2.7 or 10.5, and (e) for
other reasonable purposes at the reasonable request of Idaho Power. Idaho Power shall
release Seller from any and all Liabilities resulting from actions or omissions by any of the
Idaho Power Representatives in connection with their access to the Facility, except to the
extent that such Liabilities are caused by the intentional or negligent act or omission of
Seller or its agents or Affiliates.
7.13 Facility Images. Idaho Power shall be free to use any and all images from or of the Facility
for promotional purposes, subject to Seller’s consent (not to be unreasonably withheld or
delayed, and which consent may consider Requirements of Law relating to Premises
security, obligations to outside vendors (including any confidentiality obligations), and the
corporate policies of Seller’s Affiliates). Upon Idaho Power’s request and at Idaho Power’s
expense, Seller shall install imaging equipment at the Facility as Idaho Power may request,
including video and or web-based imaging equipment subject to the prudent safety
requirements of Seller, and Requirements of Law relating to workplace health and safety.
Idaho Power shall retain full discretion on how such images are presented including
associating images of the Facility with a Idaho Power-designated corporate logo.
SECTION 8
RIGHT OF FIRST OFFER AND OWNERSHIP OR PURCHASE OPTION
8.1 Buyer’s Affiliates. For purposes of this Section 8, any reference to “Buyer” or “Idaho
Power” shall also mean Buyer’s or Idaho Power’s “Affiliate” as that term is defined in this
Agreement.
8.2 Right of First Offer. If this Agreement is terminated for any reason prior to the Commercial
Operation Date, then during the Restricted Period, neither Seller nor any of Seller’s
Affiliates may enter into any agreement to sell, or hedge the quantity of, Storage Product
to any party other than Buyer, without first offering the same material price and terms of
such agreement to Buyer by written notice (“Offer Notice”). “Restricted Period” means a
period that ends eighteen (18) months after the effective date of a termination. If Buyer
rejects or fails to respond to the Offer Notice within thirty (30) Business Days, or the Parties
negotiate to enter into an agreement but are unable to execute a definitive agreement within
sixty (60) days after Buyer accepts such offer from Seller, then Seller shall have the right
to enter into an agreement with a third party on terms and conditions in the aggregate not
more favorable than the terms and conditions contained in the Offer Notice. If either Seller
or any of its Affiliates wish to enter into an agreement with a third party on terms in the
aggregate more favorable to such third party than those offered to Buyer in the Offer
Notice, or if Seller or such Affiliate fails to close the transaction (which gave rise to Seller’s
obligation to provide an Offer Notice) within nine (9) months following the issuance of the
Offer Notice, then any subsequent agreement during the Restricted Period shall again be
subject to this Section 8.2. This Section 8.2 shall be specifically enforceable by Buyer
without bond and without the need to prove irreparable harm. Neither Seller nor Seller’s
Affiliates may sell or transfer the Facility, or any part thereof, or land rights or interests in
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the Site (including the Interconnection Agreement) during the Restricted Period, except by
a transfer permitted by Section 8.2. Upon termination of this Agreement prior to the
Commercial Operation Date, Seller shall deliver a notice of Buyer’s rights in respect of the
Site, in an executed, recordable form reasonably acceptable to Buyer, that Buyer may
record in the real estate records giving notice of Buyer’s rights under this Section 8.2.
Seller enters into this Section 8.2 as authorized agent for all of its present and future
Affiliates. This Section 8.2 shall apply until the earlier of the expiration of the Restricted
Period and the consummation of the first bona fide transfer in accordance with its terms.
8.3 Termination of Duty to Buy. If this Agreement is terminated because of a default by Seller,
neither Seller, nor any successor to Seller with respect to the ownership of the Facility (for
whom Seller acts herein as agent), may thereafter require or seek to require Buyer to
purchase Output from the Facility under Public Utility Regulatory policy Act on account
of its status as a Qualifying Facility, or any other Requirements of Law, for any periods
that would have been within the Term had this Agreement remained in effect. Seller, on
behalf of itself and on behalf of any other entity on whose behalf it may act, hereby waives
its rights to require Buyer to do so.
8.4 Right of First Offer on Ownership.
8.4.1 At any time subsequent to the Effective Date of this Agreement, except in
accordance with this Section 8.4.1, Seller: (a) shall not sell, transfer or offer to
sell or transfer, the Facility; and (b) shall cause its immediately upstream
owner(s) (together with Seller, each a “ROFO Seller”) not to sell, transfer or offer
to sell or transfer, any ownership interest in Seller (the Facility and ownership
interests in Seller, as applicable, each the “Offered Interests”) other than to an
Affiliate in accordance with the provisions of Section 22.2 (each a “Restricted
Transaction”). If a ROFO Seller intends to enter into a Restricted Transaction,
Seller shall provide Buyer with written notice of same (a “Seller ROFO Notice”),
and Buyer shall have a right of first offer with respect to the purchase of such
Offered Interests. Within thirty (30) days after receipt of the Seller ROFO Notice,
Buyer shall notify Seller in writing of its decision whether or not to negotiate
with ROFO Seller for the purchase of the Offered Interests (the “Buyer ROFO
Notice”). If Buyer elects to negotiate with ROFO Seller for the purchase of the
Offered Interests, Seller shall cause ROFO Seller to negotiate in good faith and
exclusively with Buyer, for a period of not less than ninety (90) days following
ROFO Seller’s receipt of the Buyer ROFO Notice. (“ROFO Period”).
8.4.2 In the event that Buyer does not elect to negotiate with ROFO Seller for the
purchase of the Offered Interests pursuant to Section 8.4.1, ROFO Seller shall be
free to sell, transfer or offer or negotiate to sell or transfer the Offered Interests
in ROFO Seller’s sole discretion. In the event that Buyer elects to negotiate with
ROFO Seller for the purchase of the Offered Interests pursuant to Section 8.4.1,
and if definitive transaction documents between ROFO Seller and Buyer or its
designee have not been executed with respect to the Offered Interests within the
ROFO Period, ROFO Seller may negotiate a Restricted Transaction with any
other Person, subject, in all cases, to the terms and conditions of this Agreement,
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including Section 8.4.1 and the provisions of Section 22. In no event may ROFO
Seller enter into a Restricted Transaction with any other Person on economic
terms (such as purchase price, payment terms and overall revenue streams
associated with such transaction) or other material terms less favorable to ROFO
Seller than such economic terms, if any, as were negotiated by Buyer and ROFO
Seller. As used in this Section 8.4.2, “other material terms” means any terms
identified by the Parties acting in good faith within five (5) Business Days
following expiration of the ROFO Period that the Parties have not agreed to
during their negotiation.
8.4.3 If ROFO Seller and such other Person do not agree upon the terms, conditions and
pricing for the Offered Interests within one hundred eighty (180) days following
the expiration of the ROFO Period, ROFO Seller and any Offered Interests shall
again be subject to this Section 8.2 with respect to any Restricted Transaction.
8.5 [Reserved]
8.6 Efforts Required to Transfer Facility and Offered Interests. If Buyer exercises any right to
purchase or agrees to purchase the Facility (or Offered Interests) pursuant to any of the
means specified in this Section 8, then such purchase shall occur pursuant to a form of
purchase and sale agreement prepared by Buyer which shall contain customary
representations, warranties and covenants and otherwise be in form reasonably acceptable
to Buyer. It shall be a condition of any such purchase that Buyer obtains all necessary
Governmental Approvals, and notwithstanding any language to the contrary in this
Agreement, Buyer shall be given sufficient time to obtain such approvals in accordance
with applicable statutes and regulations. Pursuant to the purchase and sale agreement,
Seller will take all actions necessary to transfer by deed, bill of sale, or both, the Facility
or Offered Interests to Buyer, as well as all other improvements placed on the Premises by
Seller that are required for the continued and uninterrupted use, maintenance and operation
of the Facility, free and clear from any lien or monetary encumbrance created by or on
behalf of Seller or its Affiliates. In addition, Seller will assign to Buyer all transferrable
Governmental Approvals applicable to the Facility and Required Facility Documents, and
all transferrable warranties for the Facility. Seller shall cooperate with Buyer to assign and
enforce any and all warranties that apply to the Facility or any of its component parts,
which obligation shall survive the termination of this Agreement.
8.7 Due Diligence; Cooperation; Governmental Approvals; Notice of Rights. Seller will
provide, in a timely manner, information regarding the Facility and Offered Interests which
is reasonably requested by Buyer to allow Buyer to perform due diligence for the purchase
of the Facility and Offered Interests pursuant to this Section 8. Seller shall further provide
commercially reasonable cooperation and assistance to Buyer, without further
compensation, throughout Buyer’s efforts to properly account for and obtain any necessary
Governmental Approvals with respect to the purchase of the Facility and Offered Interests
pursuant to this Section 8. Notwithstanding anything in this Agreement or any definitive
transaction documentation, Buyer shall not be obligated to proceed with the purchase of
the Facility or any Offered Interests pursuant to this Section 8 if Buyer does not receive all
necessary Governmental Approvals in connection with such transaction. Seller shall put
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any Person with which it enters into discussions or negotiations regarding a Restricted
Transaction on notice of the rights of Buyer set forth in this Section 8. Buyer shall be
permitted to file a notice of the rights contained in this Section 8 with respect to the
Premises.
8.8 Termination of Agreement. Upon the acquisition of the Facility or Offered Interests by
Buyer pursuant to this Section 8, this Agreement shall terminate and neither Party shall
have any obligation to the other under this Agreement, except with respect to the terms and
provisions hereof that expressly survive the termination of this Agreement.
SECTION 9
SECURITY AND CREDIT SUPPORT
9.1 Project Development Security. Seller shall provide within five (5) Business Days from
receipt of a written request from Idaho Power all reasonable financial records necessary
for Idaho Power to confirm Seller satisfies the Credit Requirements.
9.1.1 Form and Amount of Project Development Security. On or before thirty (30) days
of the date of the Effective Date, Seller shall post and maintain in favor of Idaho
Power (a) a guaranty from a party that satisfies the Credit Requirements, in
substantially the form attached hereto as Exhibit 8, (b) a Letter of Credit in favor
of Idaho Power, in a form acceptable to Idaho Power in its reasonable discretion,
or (c) cash collateral equal in each case to [$40,000] per MWh of Guaranteed
Storage Capacity (the “Project Development Security”). Seller and any person or
entity providing a guaranty shall provide within five (5) Business Days from
receipt of a written request from Idaho Power all reasonable financial records
necessary for Idaho Power to confirm the guarantor satisfies the Credit
Requirements.
9.1.2 Use of Project Development Security to Pay Delay Damages. If the Commercial
Operation Date occurs after the Scheduled Commercial Operation Date and
Seller has failed to pay any Delay Damages when due under Section 4.5, Idaho
Power shall be entitled to and shall draw upon the Project Development Security
an amount equal to the Delay Damages. Idaho Power shall also be entitled to
draw upon the Project Development Security for other damages if this Agreement
is terminated under Section 12 because of Seller’s default.
9.1.3 Termination of Project Development Security. Seller shall no longer be required to
maintain the Project Development Security after the Commercial Operation Date,
if at such time no damages are owed to Idaho Power under this Agreement.
However, as of the Commercial Operation Date, Seller may elect to apply the
Project Development Security toward the Default Security required by Section
9.2, including by the automatic continuation (as opposed to the replacement)
thereof.
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9.2 Default Security.
9.2.1 Duty to Post Default Security. On the date specified in Section 4.2.1, Seller shall
post and maintain in favor of Idaho Power (a) a guaranty from an entity that
satisfies the Credit Requirements, in substantially the form attached hereto as
Exhibit 8, or (b) a Letter of Credit, each in the amount specified in Section 9.2.2
(the “Default Security”), as provided in this Section 9.2. Seller and any person or
entity providing a guaranty shall provide within five (5) Business Days from
receipt of a written request from Idaho Power all reasonable financial records
necessary for Idaho Power to confirm the guarantor satisfies the Credit
Requirements.
9.2.2 Amount of Default Security. The amount of the Default Security required by
Section 9.2.1 shall be [$20,0000] per MWh of Guaranteed Storage Capacity and
will be held until this Agreement expires.
9.2.3 Use of Default Security to Pay Deficit Damages. If the Seller has failed to pay any
Storage Capacity Damages or Storage Availability Damages when due under
Section 4.5, Idaho Power shall be entitled to and shall draw upon the Default
Security an amount equal to the amount of such damages owed until such time
as the Default Security is exhausted. Idaho Power shall also be entitled to draw
upon the Default Security for other damages if this Agreement is terminated
under Section 12 because of Seller’s default.
9.3 Senior Lenders. If Seller collaterally assigns this Agreement to Seller’s Lenders in a
manner permitted under this Agreement, Buyer, at Seller’s sole cost and expense, if
requested shall enter into a Lender Consent with Seller’s Lenders substantially in the form
of Exhibit 21. If Seller enters into a Tax Equity Financing, Buyer, at Seller’s sole cost and
expense, if requested shall provide an Estoppel Certificate to Seller’s Tax Equity Investors
substantially in the form of Exhibit 22. Seller will within five (5) Business Days of written
demand reimburse Buyer all Buyer’s costs and expenses, including legal fees and costs of
due diligence, incurred in connection with any action or exercise of rights or remedies by
any of Seller’s Lenders against Seller, including any proceeding or foreclosure against
Seller or this Agreement.
9.4 Change of Control. Seller may not suffer any Change of Control, whether voluntary or by
operation of law, without Buyer’s prior written consent, granted or withheld in Buyer’s
reasonable discretion. Seller may not suffer a Change of Control or any other change of
ownership or control, whether direct or indirect, voluntary or by operation of law, such that
Seller becomes a Sanctioned Person. Seller shall give Buyer notice of any Change of
Control within ten (10) Business Days following the effectiveness thereof
9.5 Security is Not a Limit on Seller’s Liability. The security contemplated by this Section 9
(a) constitutes security for, but is not a limitation of, Seller’s obligations hereunder and (b)
shall not be Idaho Power’s exclusive remedy for Seller’s failure to perform in accordance
with this Agreement. Seller shall maintain security as required by Sections 9.1 and 9.2, as
applicable per this Agreement. To the extent that Idaho Power draws on any security, Seller
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shall, within five (5) Business Days following such draw, replenish or reinstate the security
to the full amount then required under this Section 9. If at any time the Seller or Seller’s
credit support provider(s) fails to meet the Credit Requirements, then Seller shall provide
replacement security meeting the requirements set forth in Section 9 within ten (10)
Business Days after the earlier of (x) Seller’s receipt of notice from any source that Seller
or the credit support provider(s), as applicable, no longer meets the Credit Requirements
or (y) Seller’s receipt of written notice from Idaho Power requesting the posting of alternate
security.
SECTION 10
METERING, METERING COMMUNICATIONS AND SCADA TELEMETRY
10.1 Metering. Idaho Power shall, provide, install, and maintain metering equipment needed for
metering the electrical energy storage and discharge from the Facility. The metering
equipment will be capable of measuring, recording, retrieving and reporting the Facility’s
hourly gross electrical energy storage, production, station use, maximum energy deliveries
(MW) and any other energy measurements at the Point of Delivery that Idaho Power needs
to administer this Agreement and integrate this Facility’s energy production into the Idaho
Power electrical system. Specific equipment, installation details and requirements for this
metering equipment will be established in the GIA process and documented in the
GIA. Seller shall be responsible for all initial and ongoing costs of this equipment as
specified in Schedule 72 of the Tariff and the GIA. Seller shall cause the Facility to
implement all necessary generation information communications in WREGIS, and report
generation information to WREGIS pursuant to a WREGIS-approved meter that is
dedicated to the Facility and only the Facility.
10.2 Metering Communications. Seller shall, at the Seller’s sole initial and ongoing expense,
arrange for, provide, install, and maintain dedicated metering communications equipment
capable of transmitting the metering data specified in Section10.1 to Idaho Power in a
frequency, manner and form acceptable to Idaho Power. Seller shall grant Idaho Power
sole control and use of this dedicated metering communications equipment. Specific details
and requirements for this metering communications equipment will be established in the
GIA process and documented in the GIA.
10.3 Supervisory Control and Data Acquisition (SCADA) Telemetry. If the Facility’s
Nameplate Capacity exceeds 3 MW, in addition to the requirements of Section 10.1 and
10.2, Idaho Power may require telemetry equipment and telecommunications which will
be capable of providing Idaho Power with continuous instantaneous SCADA telemetry of
the Seller’s Charging Energy and Discharging Energy in a form acceptable to Idaho
Power. Seller shall grant Idaho Power sole control and use of this dedicated SCADA and
telecommunications equipment. Specific details and requirements for this SCADA
Telemetry and telecommunications equipment will be established in the GIA process and
documented in the GIA. Seller shall be responsible for all initial and ongoing costs of this
equipment as specified in Schedule 72 of the Tariff and the GIA.
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10.4 Metering Costs. To the extent not otherwise provided in the Generation Interconnection
Agreement, Seller shall bear all costs (including Idaho Power’s costs) relating to all
metering equipment installed to accommodate the Facility.
10.5 Losses. If the Idaho Power Metering equipment is capable of measuring the exact energy
deliveries by the Seller to the Idaho Power electrical system at the Point of Delivery, no
Losses will be calculated for this Facility. If the Idaho Power Metering Equipment is unable
to measure the exact electric energy deliveries by the Seller to the Idaho Power electrical
system at the Point of Delivery, a Losses calculation will be established to measure the
energy losses (MWh) between the Seller’s Facility and the Idaho Power Point of
Delivery. This loss calculation will be initially set at two percent (2%) of the MWh energy
discharge recorded on the Facility generation metering equipment. At such time as Seller
provides Idaho Power with the electrical equipment specifications (transformer loss
specifications, conductor sizes, etc.) of all of the electrical equipment between the Facility
and the Idaho Power electrical system, Idaho Power will configure a revised loss
calculation formula to be agreed to by both parties and used to calculate the MWh Losses
for the remaining term of the Agreement. If at any time during the term of this Agreement,
Idaho Power determines that the loss calculation does not correctly reflect the actual MWh
losses attributed to the electrical equipment between the Facility and the Idaho Power
electrical system, Idaho Power may adjust the calculation and retroactively adjust the
previous month’s MWh loss calculations.
SECTION 11
BILLINGS, COMPUTATIONS AND PAYMENTS
11.1 Monthly Invoices. On or before the tenth (10
th) day following the end of each calendar
month, Seller shall deliver to Idaho Power a proper invoice showing Seller’s computation
of Discharging Energy delivered to the Point of Delivery during such month in the form of
Exhibit 1. When calculating the invoice, Seller shall provide computations showing the
portion of Discharging Energy that was delivered during On-Peak Hours and the portion
of Discharging Energy that was delivered during Off-Peak Hours. If such invoice is
delivered by Seller to Idaho Power, then Idaho Power shall make payment to Seller within
thirty (30) days of receipt of an accurate and undisputed invoice; provided, however, that
IPC’s payment is not due unless Seller is in compliance with all provisions of this
Agreement.
11.2 Offsets. Either Party may offset any payment due hereunder against amounts owed by the
other Party pursuant to the terms of this Agreement. Either Party’s exercise of recoupment
and set off rights shall not limit the other remedies available to such Party hereunder.
11.3 Interest on Late Payments. Any amounts that are not paid when due hereunder shall bear
interest at the Contract Interest Rate from the date due until paid.
11.4 Disputed Amounts. If either Party, in good faith, disputes any amount due pursuant to an
invoice rendered hereunder, such Party shall notify the other Party of the specific basis for
the dispute and, if the invoice shows an amount due, shall pay that portion of the statement
that is undisputed, on or before the due date. Except with respect to invoices provided under
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Section 11.1, any such notice shall be provided within two (2) years of the date of the
invoice in which the error first occurred. If any amount disputed by such Party is
determined to be due the other Party, or if the Parties resolve the payment dispute, the
amount due shall be paid within thirty (30) Business Days after such determination or
resolution, along with interest at the Contract Interest Rate from the date due until the date
paid.
11.5 Audit Rights. Each Party, through its authorized representatives, shall have the right, at its
sole expense upon reasonable written notice and during normal business hours, to examine
and copy the records of the other Party to the extent reasonably necessary to verify the
accuracy of any statement, charge or computation made hereunder or to verify the other
Party’s performance of its obligations hereunder. Upon request, each Party shall provide
to the other Party statements evidencing the quantities of Discharging Energy delivered at
the Point of Delivery or Ancillary Services, if any, provided under this Agreement. If any
statement is found to be inaccurate, a corrected statement shall be issued and any amount
due thereunder will be promptly paid and shall bear interest at the Contract Interest Rate
from the date of the overpayment or underpayment to the date of receipt of the reconciling
payment. Notwithstanding the foregoing, no adjustment shall be made with respect to any
statement or payment hereunder unless a Party questions the accuracy of such payment or
statement within two (2) years after the date of such statement or payment.
SECTION 12
DEFAULTS AND REMEDIES
12.1 Defaults. The following events are defaults (each a “default” before the passing of
applicable notice and cure periods, and an “Event of Default” thereafter) hereunder:
12.1.1 Defaults by Either Party:
12.1.1.1 A Party fails to make a payment when due hereunder if the failure
is not cured within ten (10) Business Days after the non-defaulting
Party gives the defaulting Party a notice of the default.
12.1.1.2 A Party (i) makes a general assignment for the benefit of its
creditors; (ii) files a petition or otherwise commences, authorizes or
acquiesces in the commencement of a proceeding or cause of action
under any bankruptcy or similar law for the protection of creditors,
or has such a petition filed against it and such petition is not
withdrawn or dismissed within sixty (60) days after such filing; (iii)
becomes insolvent; or (iv) is unable to pay its debts when due.
12.1.1.3 A Party breaches a representation or warranty made by it herein if
the breach is not cured within thirty (30) days after the non-
defaulting Party gives the defaulting Party a written notice of the
default; provided that if such default is not reasonably capable of
being cured within the thirty (30) day cure period but is reasonably
capable of being cured within a ninety (90) day cure period, the
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defaulting Party will have such additional time (not exceeding an
additional sixty (60) days) as is reasonably necessary to cure, if,
prior to the end of the thirty (30) day cure period the defaulting Party
provides the non-defaulting Party a remediation plan, the non-
defaulting Party approves such remediation plan, and the defaulting
Party promptly commences and diligently pursues the remediation
plan.
12.1.1.4 A Party otherwise fails to perform any material obligation hereunder
for which an exclusive remedy is not provided hereunder and which
is not addressed in any other default described in Section 12.1, if the
failure is not cured within thirty (30) days after the non-defaulting
Party gives the defaulting Party written notice of the default;
provided that if such default is not reasonably capable of being cured
within the thirty (30) day cure period but is reasonably capable of
being cured within a ninety (90) day cure period, the defaulting
Party will have such additional time (not exceeding an additional
sixty (60) days) as is reasonably necessary to cure, if, prior to the
end of the thirty (30) day cure period the defaulting Party provides
the non-defaulting Party a remediation plan, the non-defaulting
Party approves such remediation plan, and the defaulting Party
promptly commences and diligently pursues the remediation plan.
12.1.2 Defaults by Seller.
12.1.2.1 Seller fails to post, increase, or maintain the Project Development
Security or Default Security as required under, and by the applicable
dates set forth in, Section 9.1 and Section 9.2 and such failure is not
cured within ten (10) Business Days after Idaho Power gives Seller
notice of default.
12.1.2.2 Seller fails to (i) cause the Facility to achieve Commercial Operation
on or before the Guaranteed Commercial Operation Date, or (ii)
complete all items included on the Final Completion Schedule
within ninety (90) days after the Commercial Operation Date.
12.1.2.3 Seller sells Storage Product from the Facility to a party other than
Idaho Power in breach of Section 5.2.
12.1.2.4 Idaho Power receives notice of foreclosure of the Facility or any part
thereof by a Lender, mechanic or materialman, or any other holder,
of an unpaid lien or other charge or encumbrance, if the same has
not been stayed, paid, or bonded around within ten (10) days of the
date of the notice received by Idaho Power.
12.1.2.5 After the Commercial Operation Date, Seller fails to maintain any
Required Facility Documents or Permits necessary to own, operate,
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or maintain the Facility and such failure continues for thirty (30)
days after Seller’s receipt of written notice thereof from Idaho
Power; provided, however, that, upon written notice from Seller, the
thirty (30) day period shall be extended by an additional sixty (60)
days if (i) the failure cannot reasonably be cured within the thirty
(30) day period despite diligent efforts, (ii) the default is capable of
being cured within the additional sixty (60) day period, and (iii)
Seller commences the cure within the original thirty (30) day period
and is at all times thereafter diligently and continuously proceeding
to cure the failure.
12.1.2.6 Seller’s Abandonment of construction or operation of the Facility
and such failure continues for thirty (30) days after Seller’s receipt
of written notice thereof from Idaho Power.
12.1.2.7 Seller fails to maintain insurance as required by the Agreement and
such failure continues for fifteen (15) days after Seller’s receipt of
written notice thereof from Idaho Power.
12.1.2.8 Seller fails to meet the Guaranteed Storage Availability for two (2)
consecutive Contract Years.
12.1.2.9 Seller accrues Storage Availability Damages in excess of the
Storage Availability Damages Cap in any Contract Year.
12.1.2.10 Seller accrues Storage Capacity Damages in excess of the Storage
Capacity Damages Cap.
12.1.2.11 Every three (3) years after the Commercial Operation Date, Seller
will supply Idaho Power with a Certification of Ongoing Operations
and Maintenance (O&M) from a Registered Professional Engineer
licensed in the State of Idaho, which Certification of Ongoing O&M
shall be in the form specified in Exhibit 11. Seller’s failure to supply
the required certificate will be an event of default. Such a default
may only be cured by Seller providing the required certificate; and
12.1.2.12 During the full Term of this Agreement, Seller shall maintain
compliance with all Required Facility Documents and
determinations described in Exhibit 9 of this Agreement. In
addition, Seller will supply Idaho Power with copies of any new or
additional Required Facility Documents or determinations. At least
every fifth (5th) Contract Year, Seller will update the documentation
described in Exhibit 9. If at any time Seller fails to maintain
compliance with the Required Facility Documents and
determinations described in Section 2.2.3 or to provide the
documentation required by this paragraph, such failure will be a
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default of Seller and may only be cured by Seller submitting to Idaho
Power evidence of compliance from the permitting agency.
12.1.2.13 Seller is or becomes a Sanctioned Person.
12.1.2.14 Seller breaches any obligation in Section 27.2, or any representation
or warranty made by Seller in Section 27.2 is or becomes false or
misleading in any material respect (provided that if the falsity or
misleading nature of the representation or breach of the obligation
is capable of being cured, an Event of Default will be deemed to
occur only if the falsity or misleading nature of the representation or
breach of obligation is not remedied within five (5) days after
notice);
12.2 Remedies for Failure to Deliver/Receive.
12.2.1 Remedy for Seller’s Failure to Deliver. Upon the occurrence and during the
continuation of a default of Seller under Section 12.1.2, Seller shall pay Idaho
Power within five (5) Business Days after invoice receipt, an amount equal to the
sum of (a) Idaho Power’s Cost to Cover multiplied by the Discharging Energy
delivered to a party other than Idaho Power, (b) additional transmission charges,
if any, reasonably incurred by Idaho Power in moving replacement energy to the
Point of Delivery or if not there, to such points in Idaho Power’s control area as
are determined by Idaho Power, and (c) any additional cost or expense incurred
as a result of Seller’s default under Section 12.1.3, as determined by Idaho Power
in a commercially reasonable manner, including the loss of value of Ancillary
Services. The invoice for such amount shall include a written statement
explaining in reasonable detail the calculation of such amount.
12.2.2 Remedy for Idaho Power’s Failure to Purchase. If Idaho Power fails to receive or
purchase all or part of the Storage Product required to be purchased pursuant
hereto and such failure is not excused under the terms hereof or by Seller’s failure
to perform, then Seller shall first satisfy its obligations under Section 12.7 and
then Idaho Power shall pay Seller, on the earlier of the date payment would
otherwise be due in respect of the month in which the failure occurred or within
five (5) Business Days after invoice receipt, an amount equal to Seller’s Cost to
Cover multiplied by the amount of Storage Product so not purchased, less
amounts received by Seller pursuant to Section 12.7. The invoice for such amount
shall include a written statement explaining in reasonable detail the calculation
thereof.
12.2.3 Remedy for Seller’s Failure to Sell/Deliver Capacity Rights. Seller shall be liable
for Idaho Power’s actual damages in the event Seller fails to sell or deliver all or
any portion of the Capacity Rights of the Facility to Idaho Power.
12.3 Termination and Remedies. From and during the continuance of an Event of Default, the
non-defaulting Party shall be entitled to all remedies available at law or in equity, and may
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terminate this Agreement by written notice to the other Party designating the date of
termination and delivered to the defaulting Party no less than one (1) Business Day before
such termination date. The notice required by this Section 12.3 may be provided in the
notice of default (and does not have to be a separate notice) so long as it complies with all
other terms of this Section 12.3. As a precondition to Seller’s exercise of this termination
right, Seller must also provide copies of such notice to the notice addresses of the then-
current President and General Counsel of Idaho Power. Such copies shall be sent by
registered overnight delivery service or by certified or registered mail, return receipt
requested. In addition, Seller’s termination notice shall state prominently therein in type
font no smaller than 14-point all-capital letters that “THIS IS A TERMINATION NOTICE
UNDER A BSA. YOU MUST CURE A DEFAULT, OR THE BSA WILL BE
TERMINATED,” and shall state therein any amount purported to be owed and wiring
instructions. Notwithstanding any other provision of this Agreement to the contrary, Seller
will not have any right to terminate this Agreement if the default that gave rise to the
termination right is cured within fifteen (15) Business Days of Idaho Power’s receipt of
such notice. Further, from and after the date upon which Seller fails to remedy a default
within the time periods provided in Section 12.1, and until Idaho Power has recovered all
damages incurred on account of such default by Seller, without exercising its termination
right, Idaho Power may offset its damages against any payment due Seller. Except in
circumstances in which a remedy provided for in this Agreement is described as a Party’s
sole or exclusive remedy, upon termination, the non-defaulting Party may pursue any and
all legal or equitable remedies provided by law, equity or this Agreement. The rights
contemplated by this Section 12 are cumulative such that the exercise of one or more rights
shall not constitute a waiver of any other rights. In the event of a termination hereof:
12.3.1 Each Party shall pay to the other all amounts due the other hereunder for all periods
prior to termination, subject to offset by the non-defaulting Party against damages
incurred by such Party.
12.3.2 The amounts due pursuant to Section 12.3.1 shall be calculated and paid within
thirty (30) days after the billing date for such charges and shall bear interest
thereon at the Contract Interest Rate from the date of termination until the date
paid. The foregoing does not extend the due date of, or provide an interest holiday
for any payments otherwise due hereunder.
12.3.3 Before and after the effective date of termination, the non-defaulting Party may
pursue, to the extent permitted by this Agreement, any and all legal or equitable
remedies provided by law, equity or this Agreement.
12.3.4 Without limiting the generality of the foregoing, the provisions of Sections 6.4, 6.5,
7.10.4, 7.10.5, 7.10.7, 11.3, 11.4, 11.5, and Section 12, Section 13, Section 14.1,
Section 17, Section 23, Section 24, Section 25, and Section 26 shall survive the
termination hereof.
12.4 Termination Damages. If this Agreement is terminated as a result of an Event of Default
by one of the Parties, termination damages shall be determined. The amount of termination
damages shall be calculated by the non-defaulting Party within a reasonable period after
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termination of the Agreement. In the event of a default by Seller before the Commercial
Operation Date, the termination payment shall be the Pre-COD Damages Payment. In the
event of default by Seller on or after the Commercial Operation Date, or any default by
Buyer, the termination payment shall be the Forward Settlement Amount. Amounts owed
pursuant to this section shall be due within five (5) Business Days after the non-defaulting
Party gives the defaulting Party written notice of the amount due. The non-defaulting Party
shall under no circumstances be required to account for or otherwise credit or pay the
defaulting Party for economic benefits accruing to the non-defaulting Party as a result of
the defaulting Party’s default.
12.5 Duty/Right to Mitigate. Each Party agrees that it has a duty to mitigate damages and
covenants that it will use commercially reasonable efforts to minimize any damages it may
incur as a result of the other Party’s performance or non-performance hereof; provided,
however, that this duty to mitigate shall not limit the amounts payable by the defaulting
Party to the non-defaulting Party pursuant to Section 12.4. “Commercially reasonable
efforts” (a) by Seller shall include requiring Seller to use commercially reasonable efforts
to maximize the price for Storage Product received by Seller from third parties, including
entering into an enabling agreement with, or being affiliated with, one or more power
marketers of nationally recognized standing to market such Storage Product not purchased
or accepted by Idaho Power (only during a period Idaho Power is in default), in each case
only to the extent any of the foregoing actions are permitted under Requirements of Law
and the Interconnection Agreement; and (b) by Idaho Power shall include requiring Idaho
Power to use commercially reasonable efforts to minimize the price paid to third parties
for Storage Product purchased to replace Storage Product not delivered by Seller as
required hereunder.
12.6 Security. If this Agreement is terminated because of Seller’s default, Idaho Power may, in
addition to pursuing any and all other remedies available at law or in equity, proceed
against any Seller security held by Idaho Power in whatever form to reduce any amounts
that Seller owes Idaho Power arising from such default.
12.7 Cumulative Remedies. Except in circumstances in which a remedy provided for in this
Agreement is described as a sole or exclusive remedy, the rights and remedies provided to
Idaho Power hereunder are cumulative and not exclusive of any rights or remedies of Idaho
Power.
INDEMNIFICATION AND LIABILITY
13.1 Indemnities.
13.1.1 Indemnity by Seller. To the extent permitted by Requirements of Law and subject
to Section 13.1.5, Seller shall release, indemnify and hold harmless Idaho Power,
its Affiliates, and each of its and their respective directors, officers, employees,
agents, and representatives (collectively, the “Idaho Power Indemnitees”) against
and from any and all losses, fines, penalties, claims, demands, damages,
liabilities, actions or suits of any nature whatsoever (including legal costs and
attorneys’ fees, both at trial and on appeal, whether or not suit is brought)
(collectively, “Liabilities”) actually or allegedly resulting from, or arising out of,
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or in any way connected with, the performance by Seller of its obligations
hereunder, or relating to the Facility or Premises, for or on account of injury,
bodily or otherwise, to, or death of, or damage to or destruction of property of,
any person or entity, or for or on account of violation of environmental or
criminal law, excepting only to the extent such Liabilities as may be caused by
the gross negligence or willful misconduct of any person or entity within the
Idaho Power Indemnitees. Seller shall be solely responsible for (and shall defend
and hold Idaho Power harmless against) any damage that may occur as a direct
result of Seller’s breach of the Generation Interconnection Agreement.
13.1.2 Indemnity by Idaho Power. To the extent permitted by Requirements of Law and
subject to Section 13.1.5, Idaho Power shall release, indemnify and hold harmless
Seller, its Affiliates, and each of its and their respective directors, officers,
employees, agents, and representatives (collectively, the “Seller Indemnitees”)
against and from any and all Liabilities actually or allegedly resulting from, or
arising out of, or in any way connected with, the performance by Idaho Power of
its obligations hereunder for or on account of (a) injury, bodily or otherwise, to,
or death of, or (b) for damage to, or destruction of property of, any person or
entity within the Seller Indemnitees, excepting only to the extent such Liabilities
as may be caused by the negligence or willful misconduct of any person or entity
within the Seller Indemnitees.
13.1.3 Additional Cross Indemnity. Without limiting Sections 13.1.1 and 13.1.2, Seller
shall release, indemnify and hold harmless the Idaho Power Indemnitees from
and against all Liabilities related to Storage Product prior to its delivery by Seller
at the Point of Delivery, and Idaho Power shall release, indemnify and hold
harmless the Seller Indemnitees from and against all Liabilities related to Storage
Product once delivered to Idaho Power at the Point of Delivery as provided
herein, except in each case to the extent such Liabilities are attributable to the
gross negligence or willful misconduct or a breach of this Agreement by any
member of the Idaho Power Indemnitees or the Seller Indemnitees, respectively,
seeking indemnification hereunder.
13.1.4 No Dedication. Nothing herein shall be construed to create any duty to, any
standard of care with reference to, or any liability to any person not a Party. No
undertaking by one Party to the other under any provision hereof shall constitute
the dedication of Idaho Power’s facilities or any portion thereof to Seller or to
the public, nor affect the status of Idaho Power as an independent public utility
corporation or Seller as an independent individual or entity.
13.1.5 Consequential Damages. NEITHER PARTY SHALL BE LIABLE TO THE
OTHER PARTY FOR SPECIAL, PUNITIVE, INDIRECT, EXEMPLARY
OR CONSEQUENTIAL DAMAGES, WHETHER SUCH DAMAGES ARE
ALLOWED OR PROVIDED BY CONTRACT, TORT (INCLUDING
NEGLIGENCE), STRICT LIABILITY, STATUTE OR OTHERWISE.
THE PARTIES AGREE THAT ANY LIQUIDATED DAMAGES,
SECURITY, INDEMNIFIED CLAIMS OR DAMAGES, DELAY
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DAMAGES, IDAHO POWER AND SELLER COST TO COVER
DAMAGES, SECTION 12.2.3 CAPACITY RIGHTS LOSS DAMAGES,
OR OTHER SPECIFIED MEASURE OF DAMAGES EXPRESSLY
PROVIDED FOR HEREIN, ARE NOT INTENDED BY THEM TO
REPRESENT AND WILL NOT BE DEEMED SPECIAL, PUNITIVE,
INDIRECT, EXEMPLARY OR CONSEQUENTIAL DAMAGES AND
SHALL NOT BE LIMITED IN AMOUNT BY THIS SECTION 13.1.5.
SECTION 14
INSURANCE
14.1 Required Policies and Coverages. Without limiting any liabilities or any other obligations
of Seller hereunder, Seller shall secure and continuously carry the insurance coverage
specified on Exhibit 13 during the Term or longer period if specified in Exhibit 13.
14.2 Certificates of insurance. Seller shall provide Idaho Power with certificates of insurance
within ten (10) days after the date by which such policies are required to be obtained (as
set forth in Exhibit 13). Seller shall provide a certificate of insurance (in ACORD or similar
industry form) to Idaho Power within ten (10) days of the effective date of any insurance
policy required under this Agreement.
SECTION 15
FORCE MAJEURE
15.1 Definition of Force Majeure. “Force Majeure” or “an event of Force Majeure” means an
event that (a) is not reasonably anticipated as of the Effective Date hereof, (b) is not within
the reasonable control of the Party affected by the event, (c) is not the result of such Party’s
negligence or failure to act, and (d) could not be overcome by the affected Party’s use of
due diligence in the circumstances. Force Majeure includes, but is not restricted to, events
of the following types (but only to the extent that such an event, in consideration of the
circumstances, satisfies the tests set forth in the preceding sentence): acts of God; civil
disturbance; sabotage; strikes; lock-outs; work stoppages; and action or restraint by court
order or public or Governmental Authority (as long as the affected Party has not applied
for or assisted in the application for, and has opposed to the extent reasonable, such court
or government action). Notwithstanding the foregoing, none of the following constitute
Force Majeure: (i) Seller’s ability to sell, or Idaho Power’s ability to purchase the Storage
Product at a more advantageous price than is provided hereunder; (ii) the cost or
availability of Charging Energy for the Facility; (iii) economic hardship, including lack of
money; (iv) any breakdown or malfunction of the Facility’s equipment (including any
serial equipment defect) that is not caused by an independent event of Force Majeure, (v)
the imposition upon a Party of costs or taxes allocated to such Party under Section 6.4, (vi)
delay or failure of Seller to obtain or perform any Required Facility Document unless due
to a Force Majeure event, (vii) any delay, alleged breach of contract, or failure by the
Transmission Provider, Network Service Provider or Interconnection Provider unless due
to a Force Majeure event, (viii) maintenance upgrade or repair of any facilities or right of
way corridors constituting part of or involving the Interconnection Facilities, whether
performed by or for Seller, or other third parties (except for repairs made necessary as a
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result of an event of Force Majeure); (ix) Seller’s failure to obtain, or perform under, the
Generation Interconnection Agreement, or its other contracts and obligations to
transmission owner, Transmission Provider or Interconnection Provider, unless due to a
Force Majeure event; (x) Seller’s inability to obtain any supply of any good or service,
unless due to an independent event of Force Majeure; or (xi) any event attributable to the
use of Interconnection Facilities for deliveries of Storage Product to any party other than
Idaho Power. Notwithstanding anything to the contrary herein, in no event will the
increased cost of electricity, steel, labor, or transportation constitute an event of Force
Majeure.
15.2 Suspension of Performance. Neither Party shall be liable for any delay or failure in its
performance under this Agreement, nor shall any delay, failure, or other occurrence or
event become a default, to the extent such delay, failure, occurrence or event is
substantially caused by conditions or events of Force Majeure during the continuation of
the event of Force Majeure, for the same number of days that the event of Force Majeure
has prevailed, provided that:
15.2.1 the Party affected by the Force Majeure, shall, within five (5) days after the
occurrence of the event of Force Majeure, give the other Party written notice
describing the particulars of the event; and
15.2.2 the suspension of performance shall be of no greater scope and of no longer
duration than is required to remedy the effect of the Force Majeure; and
15.2.3 the affected Party shall use diligent efforts to remedy its inability to perform and
shall provide prompt notice to the other Party of the cessation of the event or
condition giving rise to its excuse from performance.
15.3 Force Majeure Does Not Affect Other Obligations. No obligations of either Party that arose
before the Force Majeure causing the suspension of performance or that arise after the
cessation of the Force Majeure shall be excused by the Force Majeure. No obligation of
Seller arising before the Commercial Operation Date may be excused by Force Majeure.
15.4 Strikes. Notwithstanding any other provision hereof, neither Party shall be required to settle
any strike, walkout, lockout or other labor dispute on terms which, in the sole judgment of
the Party involved in the dispute, are contrary to the Party’s best interests.
15.5 Right to Terminate. If a Force Majeure event prevents a Party from substantially
performing its obligations hereunder for a period exceeding one hundred and eighty (180)
consecutive days (despite the affected Party’s effort to take all reasonable steps to remedy
the effects of the Force Majeure with all reasonable dispatch), then the Party not affected
by the Force Majeure event, with respect to its obligations hereunder, may terminate this
Agreement by giving ten (10) days prior written notice to the other Party. Upon such
termination, neither Party will have any liability to the other with respect to the period
following the effective date of such termination; provided, however, that this Agreement
will remain in effect to the extent necessary to facilitate the settlement of all liabilities and
obligations arising hereunder before the effective date of such termination.
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SECTION 16
SEVERAL OBLIGATIONS; THIRD PARTY BENEFICIARIES
Nothing contained herein shall be construed to create an association, trust, partnership or joint
venture or to impose a trust, partnership or fiduciary duty, obligation or liability on or between the
Parties. Nothing in this Agreement shall be construed to create any duty, obligation or liability of
Seller or Buyer to any Person not a Party to this Agreement.
SECTION 17
CHOICE OF LAW
This Agreement shall be interpreted and enforced in accordance with the laws of the State of Idaho
notwithstanding its choice of law provisions.
SECTION 18
PARTIAL INVALIDITY
The Parties do not intend to violate any laws governing the subject matter hereof. If any of the
terms hereof are finally held or determined to be invalid, illegal or void as being contrary to any
Requirements of Law or public policy, all other terms hereof shall remain in effect. The Parties
shall use best efforts to amend this Agreement to reform or replace any terms determined to be
invalid, illegal or void, such that the amended terms (a) comply with and are enforceable under
Requirements of Law, (b) give effect to the intent of the Parties under this Agreement, and (c)
preserve the balance of the economics and equities contemplated by this Agreement in all material
respects.
SECTION 19
NON-WAIVER
No waiver of any provision hereof shall be effective unless the waiver is set forth in a writing that
(a) expressly identifies the provision being waived, and (b) is executed by the Party waiving the
provision. A Party’s waiver of one or more failures by the other Party in the performance of any
of the provisions hereof shall not be construed as a waiver of any other failure or failures, whether
of a like kind or different nature.
SECTION 20
GOVERNMENTAL JURISDICTION
AND AUTHORIZATIONS
This Agreement is subject to the jurisdiction of those Governmental Authorities having control
over either Party, the Facility, or this Agreement. During the Term, Seller shall maintain all Permits
required, as applicable, for the construction, operation, or ownership of the Facility.
SECTION 21
[INTENTIONALLY OMITTED]
SECTION 22
SUCCESSORS AND ASSIGNS
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22.1 Restriction on Assignments. Except as expressly provided in this Section 20, neither Party
may assign this Agreement or any of its rights or obligations hereunder without the prior
written consent of the other Party, which consent shall not be unreasonably withheld.
22.2 Permitted Assignments. Notwithstanding Section 22.1, either Party may, without the need
for consent from the other Party (but with written notice to the other Party, including the
names of the assignees): (a) transfer, sell, pledge, encumber or assign this Agreement or
the accounts, revenues or proceeds therefrom in connection with project financing for the
Facility; or (b) transfer or assign this Agreement to an Affiliate meeting the requirements
of this Agreement; provided, however, that Seller shall not transfer, sell, encumber or
assign this Agreement or any interest herein to any Affiliate of Idaho Power without the
prior written consent of Idaho Power. Except with respect to collateral assignments for
financing purposes in every assignment permitted under this Section 22.2, the assignee
must not be a Sanctioned Person, must agree in writing to be bound by the terms and
conditions hereof and must possess the same or similar experience, and possess the same
or better creditworthiness, as the assignor. Idaho Power may assign this Agreement in
whole or in part without the consent of Seller to any person or entity in the event that Idaho
Power ceases to be a load-serving entity, in which event Idaho Power shall be released
from liability hereunder upon approval of Idaho Power ceasing to be a load-serving entity
by the IPUC and OPUC. The Party seeking to assign or transfer this Agreement shall be
solely responsible for paying all costs of assignment.
SECTION 23
ENTIRE AGREEMENT
This Agreement supersedes all prior agreements, proposals, representations, negotiations,
discussions or letters, whether oral or in writing, regarding the subject matter hereof. No
modification hereof shall be effective unless it is in writing and executed by both Parties.
SECTION 24
NOTICES
24.1 Addresses and Delivery Methods. All notices, requests, statements or payments shall be
made to the addresses set out below. In addition, copies of a notice of termination of this
Agreement under Section 12.3 shall contain the information required by Section 12.3 and
shall be sent to the then-current President and General Counsel of Idaho Power. Notices
required to be in writing shall be delivered by letter, facsimile or other tangible
documentary form. Notice by overnight mail or courier shall be deemed to have been given
on the date and time evidenced by the delivery receipt. Notice by hand delivery shall be
deemed to have been given when received or hand delivered. Notice by facsimile is
effective as of transmission to each and all of the telefacsimile numbers provided below
for a Party, but must be followed up by notice by registered mail or overnight carrier to be
effective. Notice by overnight mail shall be deemed to have been given the Business Day
after it is sent, if sent for next day delivery to a domestic address by a recognized overnight
delivery service (e.g., Federal Express or UPS). Notice by certified or registered mail,
return receipt requested, shall be deemed to have been given upon receipt.
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To Seller:
To Idaho Power: Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Vice President, Power Supply
Email: [e-mail]
with a copy to: Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Energy Contracts
Email: [e-mail]
and termination notices copied to: Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Vice President and General Counsel
Email: [e-mail]
24.2 Changes of Address. The Parties may change any of the persons to whom notices are
addressed, or their addresses, by providing written notice in accordance with this section.
SECTION 25
CONFIDENTIALITY
25.1 Confidential Business Information. The following constitutes “Confidential Business
Information,” whether oral or written: (a) the Parties’ proposals and negotiations
concerning this Agreement, made or conducted prior to the Effective Date, (b) the actual
charges billed to Idaho Power hereunder, and (c) any information delivered by Idaho Power
to Seller prior to the Effective Date relating to the market prices of Storage Product and
methodologies for their determination or estimation. Seller and Idaho Power each agree to
hold such Confidential Business Information wholly confidential, except as otherwise
expressly provided in this Agreement. “Confidential Business Information” shall not
include information that (x) is in or enters the public domain through no fault of the Party
receiving such information, or (y) was in the possession of a Party prior to the Effective
Date, other than through delivery thereof as specified in subsections (a) and (c) above. A
Party providing any written Confidential Business Information under this Agreement shall
clearly mark all pages of all documents and materials to be treated as Confidential Business
information with the term “Confidential” on the front of each page, document or material.
If the Confidential Business Information is transmitted by electronic means the title or
subject line shall indicate the information is Confidential Business Information. All
Confidential Business Information shall be maintained as confidential, pursuant to the
terms of this Section 25.1, for a period of two (2) years from the date it is received by the
receiving Party unless otherwise agreed to in writing by the Parties.
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25.2 Duty to Maintain Confidentiality. Each Party agrees not to disclose Confidential Business
Information to any other person (other than its Affiliates, accountants, auditors, counsel,
consultants, lenders, prospective lenders, employees, officers and directors), without the
prior written consent of the other Party, provided that: (a) either Party may disclose
Confidential Business Information, if and to the extent such disclosure is required (i) by
Requirements of Law, (ii) in order for Idaho Power to receive regulatory approval and
recovery of expenses related to this Agreement, (iii) pursuant to an order of a court or
regulatory agency, or (iv) in order to enforce this Agreement or to seek approval hereof,
and (b) notwithstanding any other provision hereof, Idaho Power may in its sole discretion
disclose or otherwise use for any purpose in its sole discretion the Confidential Business
Information described in Sections 25.1(b) or 25.1(c). In the event a Party is required by
Requirements of Law to disclose Confidential Business Information, such Party shall to
the extent possible promptly notify the other Party of the obligation to disclose such
information.
25.3 Idaho Power Regulatory Compliance. The Parties acknowledge that Idaho Power is
required by Requirements of Law to report certain information that is or could otherwise
embody Confidential Business Information from time to time. Such reports include
models, filings, reports of Idaho Power’s net power costs, general rate case filings, power
cost adjustment mechanisms, FERC-required reporting such as those made on FERC Form
1 or Form 714, market power and market monitoring reports, annual state reports that
include resources and loads, integrated resource planning reports, reports to entities such
as NERC, WECC, Pacific Northwest Utility Coordinating Committee, WREGIS, or similar
or successor organizations, forms, filings, or reports, the specific names of which may vary
by jurisdiction, along with supporting documentation. Additionally, in regulatory
proceedings in all state and federal jurisdictions in which it does business, Idaho Power
will from time to time be required to produce Confidential Business Information. Idaho
Power may use its business judgment in its compliance with all of the foregoing and the
appropriate level of confidentiality it seeks for such disclosures. Idaho Power may submit
Confidential Business Information in regulatory proceedings without notice to Seller.
25.4 Irreparable Injury; Remedies. Each Party agrees that violation of the terms of this Section
25 constitutes irreparable harm to the other, and that the harmed Party may seek any and
all remedies available to it at law or in equity, including injunctive relief.
25.5 News Releases and Publicity. Except as otherwise provided in Section 7.14, before either
Party issues any news release or publicly distributed promotional material regarding the
Facility that mentions the Facility, such Party shall first provide a copy thereof to the other
Party for its review and approval. Any use of either Party’s name in such news release or
promotional material must adhere to such Party’s publicity guidelines then in effect; any
use of Idaho Power’s name requires Idaho Power’s prior written consent.
SECTION 26
DISAGREEMENTS
26.1 Negotiations. Prior to proceeding with formal dispute resolution procedures as provided
below in this Section 26, the Parties must first attempt in good faith to resolve all disputes
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arising out of, related to or in connection with this Agreement promptly by negotiation, as
follows. Any Party may give the other Party written notice of any dispute not resolved in
the normal course of business. Executives of both Parties at levels one level above those
employees who have previously been involved in the dispute must meet at a mutually
acceptable time and place within ten (10) days after delivery of such notice, and thereafter
as often as they reasonably deem necessary, to exchange relevant information and to
attempt to resolve the dispute. If the matter has not been resolved within thirty (30) days
after the referral of the dispute to such senior executives, or if no meeting of such senior
executives has taken place within fifteen (15) days after such referral, either Party may
initiate any legal remedies available to the Party. All negotiations pursuant to this clause
are confidential.
26.2 Choice of Forum. Each Party irrevocably consents and agrees that any legal action or
proceeding arising out of this Agreement or the actions of the Parties leading up to this
Agreement shall be brought exclusively in the United States District Court for the District
of Idaho in Boise, Idaho, or if such court does not have jurisdiction, in the 4 th Judicial
District (Ada County) Court of the State of Idaho. By execution and delivery hereof, each
Party (a) accepts the exclusive jurisdiction of such court and waives any objection that it
may now or hereafter have to the exercise of personal jurisdiction by such court over each
Party for the purpose of any proceeding related to this Agreement, (b) irrevocably agrees
to be bound by any final judgment (after any and all appeals) of any such court arising out
of such documents or actions, (c) irrevocably waives, to the fullest extent permitted by law,
any objection that it may now or hereafter have to the laying of venue of any suit, action
or proceedings arising out of such documents brought in such court (including any claim
that any such suit, action or proceeding has been brought in an inconvenient forum) in
connection herewith, (d) agrees that service of process in any such action may be effected
by mailing a copy thereof by registered or certified mail, postage prepaid, to such Party at
its address as set forth herein, and (e) agrees that nothing herein shall affect the right to
effect service of process in any other manner permitted by law.
26.3 Settlement Discussions. No statements of position or offers of settlement made in the
course of the dispute process described in this Section 26 will be offered into evidence for
any purpose in any litigation between the Parties, nor will any such statements or offers of
settlement be used in any manner against either Party in any such litigation. Further, no
such statements or offers of settlement shall constitute an admission or waiver of rights by
either Party in connection with any such litigation. At the request of either Party, any such
statements and offers of settlement, and all copies thereof, shall be promptly returned to
the Party providing the same.
26.4 Waiver of Jury Trial. EACH PARTY KNOWINGLY, VOLUNTARILY,
INTENTIONALLY AND IRREVOCABLY WAIVES THE RIGHT TO A TRIAL BY
JURY IN RESPECT OF ANY LITIGATION BASED ON THIS AGREEMENT, OR
ARISING OUT OF, UNDER OR IN CONNECTION WITH THIS AGREEMENT AND
ANY AGREEMENT EXECUTED OR CONTEMPLATED TO BE EXECUTED IN
CONJUNCTION WITH THIS AGREEMENT, OR ANY COURSE OF CONDUCT,
COURSE OF DEALING, STATEMENTS (WHETHER VERBAL OR WRITTEN) OR
ACTIONS OF ANY PARTY HERETO. THIS PROVISION IS A MATERIAL
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INDUCEMENT TO EACH OF THE PARTIES FOR ENTERING HEREINTO. EACH
PARTY HEREBY WAIVES ANY RIGHT TO CONSOLIDATE ANY ACTION,
PROCEEDING OR COUNTERCLAIM ARISING OUT OF OR IN CONNECTION
WITH THIS AGREEMENT OR ANY OTHER AGREEMENT EXECUTED OR
CONTEMPLATED TO BE EXECUTED IN CONJUNCTION WITH THIS
AGREEMENT, OR ANY MATTER ARISING HEREUNDER OR THEREUNDER,
WITH ANY PROCEEDING IN WHICH A JURY TRIAL HAS NOT OR CANNOT BE
WAIVED. THIS SECTION WILL SURVIVE THE EXPIRATION OR TERMINATION
OF THIS AGREEMENT.
SECTION 27
COMPLIANCE
27.1 Nondiscrimination. Buyer is a federal contractor and maintains an equal
opportunity/affirmative action program in accordance with Applicable Law. As a result,
Seller must, to the extent required by Applicable Law, afford equal employment
opportunity to all of its applicants and employees, regardless of their race, color, national
origin, sex, age, religion, marital status, sexual orientation, gender identity and gender
expression, protected veteran status, disability, or other basis protected by law. Also as a
result, but only if required by Applicable Law, Seller shall abide by the requirements of 41
CFR 60-1.4(a), 60-300.5(a) and 60-741.5(a). These regulations prohibit discrimination
against qualified individuals based on their status as protected veterans or individuals with
disabilities and prohibit discrimination against all individuals based on their race, color,
religion, sex, sexual orientation, gender identity, or national origin. Moreover, these
regulations require that covered prime contractors and subcontractors take affirmative
action to employ and advance in employment individuals without regard to race, color,
religion, sex, sexual orientation, gender identity, national origin, disability, or veteran
status. In connection with this Agreement and the Facility, Seller will comply with, and
cause all of its direct and indirect contractors and subcontractors to expressly agree to
comply with, all laws and regulations relating to forced, bonded (including debt bondage)
or indentured labor, involuntary or exploitative prison labor, slavery or trafficking of
persons.
27.2 Anti-Corruption. In connection with the negotiation and performance of this Agreement
and the development, construction, and operation of the Facility or the Premises, Seller, on
behalf of itself, Seller’s Parent Entity and any other direct or indirect upstream equity
owners that, notwithstanding percentage of equity ownership interest, have the voting
power or otherwise have the power to control the day-to-day management, operations and
policies of Seller, and such Affiliates that Seller contractually or otherwise controls or
directs in the management or operation of the Facility, and in each case, including the
officers, directors, employees and agents of such entities, represents and warrants that it
has not engaged in, and that it shall refrain from, offering, promising, paying, giving,
authorizing the paying or giving of, soliciting, or accepting money or Anything of Value,
directly or indirectly, to or from (a) any Government Official to (i) influence any act or
decision of a Government Official in his or her official capacity, (ii) induce a Government
Official to act in violation of his or her lawful duty, (iii) induce a Government Official to
use his or her influence with a government or instrumentality thereof, or (iv) otherwise
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secure any improper advantage, in each case to the extent prohibited by applicable anti-
corruption laws; or (b) any person in any manner that would constitute bribery or an illegal
kickback, or would otherwise violate applicable anti-corruption laws. If Seller fails to
comply with this Section 27.2 then Buyer may terminate this Agreement in accordance
with Section 12.1.2.12. In connection with the performance of this Agreement and all fees
charged Buyer, Seller shall maintain books and records practices and internal controls to
ensure (a) that receipts and expenses are accurately recorded with reasonable detail and are
based on accurate and sufficient supporting documentation and (b) that no “off the books”
accounts are created or maintained. Unless otherwise required by law, such books and
records will be maintained for five (5) years after termination or expiration of this
Agreement. Seller will immediately report to Buyer any breach of this Section 27.2 by
Seller or its representatives. Seller will ensure that the contractors and subcontractors it
retains in connection with this Agreement expressly agree to anti-corruption undertakings,
representations, and warranties substantially similar to the provisions herein. If Buyer has
reason to believe that a breach of this Section 27.2 has occurred or will occur, Buyer shall
have the right to audit Seller’s books and records insofar as they relate to performance of
this Agreement and to withhold further payments without any liability to Seller until
reasonably satisfied that no breach has occurred. If the Agreement is terminated pursuant
to an Event of Default under Section 12.1.2.12, Buyer shall have no obligation to make
further payments hereunder. Buyer’s rights and Seller’s obligations under this Section 27.2
shall survive the termination or expiration of the Agreement.
27.3 Prohibited Technology. Pursuant to Section 889 of the John S. McCain National Defense
Authorization Act for Fiscal Year 2019 and Federal Acquisition Regulation (FAR) 52.204-
25 (Aug. 2020), Seller agrees, represents, and warrants that Seller shall not supply or
deliver to IPC any “covered telecommunications equipment or services” as a substantial or
essential component of any system or critical technology of any system. As defined in
FAR 52.204-25(a), “covered telecommunications equipment or services” includes
equipment, systems, products, or services made by any of the following companies, or any
subsidiary or affiliate thereof (including companies with the same principal word in the
name, e.g., “Huawei” or “Hytera”): Huawei Technologies Company; ZTE Corporation;
Hytera Communications Corporation; Hangzhou Hikvision Digital Technology Company;
or Dahua Technology Company. “Covered telecommunications equipment or services”
may include, but are not limited to, video/monitoring surveillance equipment/services,
public switching and transmission equipment, private switches, cables, local area networks,
modems, mobile phones, wireless devices, landline telephones, laptops, desktop
computers, answering machines, teleprinters, fax machines, and routers. “Covered
telecommunications equipment or services” do not include telecommunications equipment
that cannot route or redirect user data traffic or permit visibility into any user data or
packets that the equipment transmits or handles.
To the extent that the systems, products, or services to be provided by Seller under this
Agreement may be procured by IPC in support of or to satisfy IPC’s obligations under
agreements with a federal governmental entity, Seller further agrees that FAR 52.204-25
(Aug. 2020), except for paragraph (b)(2) thereof, shall be incorporated by reference into
this Agreement and is binding on Seller, and that Seller does not use any equipment,
system, or service that uses covered telecommunications equipment or services and will
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not supply any covered telecommunications equipment or services to IPC. Seller further
agrees that, if it identifies covered telecommunications equipment or services used as a
substantial or essential component of any system or as critical technology as part of any
system during contract performance, or Seller is notified of such by a subcontractor at any
tier or any other source, Seller shall immediately notify IPC and reasonably cooperate with
IPC’s requests for information.

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed
in their respective names as of the date last written below.

By:
Name:
Title:
Date: ______________________________
By:
Name:
Title: ______________________________
Date: _______________________________
Exhibit No. 4
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EXHIBIT 1
MONTHLY POWER PRODUCTION AND SWITCHING REPORT
Month Year
Project Project
Address Phone
City State Zip State
Facility Station Metered
Output Usage Maximum
Meter Number:
End of Month MWh Meter
Reading: MW
Beginning of Month MWh
Difference:
Times Meter Constant: Net Generation
MWh for the Month:- =
Metered Demand:
Breaker Opening Record Breaker Closing Record
Date Time Meter * Reason Date Time Meter

* Breaker Opening Reason Codes
1 Lack of Adequate Prime Mover I hereby certify that the above meter
readings are true and correct as of Midnight
on the last day of the above month and that the
switching record is accurate and complete as
required by the Energy Sales Agreement to
2 Forced Outage of Facility
3 Disturbance of IPCo System
4 Scheduled Maintenance
5 Testing of Protection Systems
6 Cause Unknown
7 Other (Explain)

Signature Date
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A-2 AUTOMATED METER READING COLLECTION PROCESS
Monthly, Idaho Power will use the provided Metering and Telemetry equipment and processes to
collect the meter reading information from the Idaho Power provided Metering Equipment that
measures the Net Energy and energy delivered to supply Station Use for the Facility recorded at
12:00 AM (Midnight) of the last day of the month.
The meter information collected will include but not be limited to energy production, Station Use,
the maximum generated power (MW) and any other required energy measurements to adequately
administer this Agreement.
A-3 SELLER CONTACT INFORMATION

Seller’s Contact Information
Name:
Telephone Number:
Cell Phone:
E-Mail:

24-Hour Project Operational Contact

Name:
Telephone Number:
Cell Phone:
E-Mail:

Project On-site Contact information

Name:
Telephone Number:
Cell Phone:
E-Mail:

Exhibit No. 4
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EXHIBIT 2
DESCRIPTION OF FACILITY
Project Name: ______________
Project Number: ______________
B-1 DESCRIPTION OF FACILITY
(Must include the Nameplate Capacity rating and VAR capability (both leading and
lagging) of all Generation Units to be included in the Facility.)

______________________________________________________________________________
______________________________________________________________________________
______________________________________________________________________________
______________________________________________________________________________
______________________________________________________________________________
Var Capability (Both leading and lagging) Leading is _______Lagging is ________.
B-2 LOCATION OF FACILITY
Near: ______________
Actual or nearest physical street address: ______________
GPS Coordinates: Latitude Decimal Degrees: ______________
Longitude Decimal Degrees: ____________
State: ______________ County: ______________

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EXHIBIT 3
POINT OF DELIVERY/INTERCONNECTION FACILITIES
Instructions to Seller:
1. Include description of point of metering, and Point of Interconnection
2. Include description of Point of Delivery
3. Provide interconnection single line drawing of Facility including any transmission
facilities on Seller’s side of the Point of Interconnection.
4. Describe Seller’s arrangements for station service to the Facility and show on one-
line diagram how station service will be provided and metered.
5. Specify the maximum hourly rate (MW) at which Seller is permitted to deliver energy
to the Point of Delivery and in compliance with Seller’s transmission rights between the Point of
Interconnection and the Point of Delivery (“Maximum Transmission Rate”):
__________MW.

Seller to provide to Buyer with a copy of the final Generator Interconnection Agreement

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EXHIBIT 4
STORAGE OPERATING RESTRICTIONS
Maximum Storage Level: [____] MWh
Minimum Storage Level:[____] MWh
Maximum Charging Capacity: [____] MW
Minimum Charging Capacity:[____] MW
Maximum Discharging Capacity:[____] MWh
Minimum Discharging Capacity:[____] MWh
Maximum State of Charge during
Charging:
[____]%
Minimum State of Charge during
Discharging:
[____]%
Ramp Rate:[___] MW/minute
Annual Cycles:Maximum of [___] Full Cycle Equivalents per
Contract Year with no monthly cap.
Daily Dispatch Limits: Charging: [___] per day
Discharging: [___] per day
Partial Charging/Discharging: [___]
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Maximum Time at Minimum Storage
Level:
N/A
Other Operating Limits:1. Storage Facility to be charged only from
the Generating Facility.
2. All manual dispatch commands by Idaho
Power must use the supplied energy
management system.
3. The average resting State of Charge per
Contract Year must be below [___]%.
4. Up to [___] hours of idle time is required
following a continuous discharge of
greater than [___]% of the Storage
Capacity (as measured in MWh).

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EXHIBIT 5
CONTRACT PRICE
Contract Price
Contract Year $/kW-Month
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
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EXHIBIT 6
NERC EVENT TYPES
Event
Type
Description of Outages
U1
Unplanned (Forced) Outage—Immediate – An outage that requires immediate
removal of a unit from service, another outage state or a Reserve Shutdown state.
This type of outage results from immediate mechanical/electrical/hydraulic
control systems trips and operator-initiated trips in response to unit alarms.
U2
Unplanned (Forced) Outage—Delayed – An outage that does not require
immediate removal of a unit from the in-service state but requires removal within
six (6) hours. This type of outage can only occur while the unit is in service.
U3
Unplanned (Forced) Outage—Postponed – An outage that can be postponed
beyond six hours but requires that a unit be removed from the in-service state
before the end of the next weekend. This type of outage can only occur while the
unit is in service.
SF
Startup Failure – An outage that results from the inability to synchronize a unit
within a specified startup time period following an outage or Reserve Shutdown.
A startup period begins with the command to start and ends when the unit is
synchronized. An SF begins when the problem preventing the unit from
synchronizing occurs. The SF ends when the unit is synchronized or another SF
occurs.
MO
Maintenance Outage – An outage that can be deferred beyond the end of the next
weekend, but requires that the unit be removed from service before the next
planned outage. (Characteristically, a MO can occur any time during the year, has
a flexible start date, may or may not have a predetermined duration and is usually
much shorter than a PO.)
ME
Maintenance Outage Extension – An extension of a maintenance outage (MO)
beyond its estimated completion date. This is typically used where the original
scope of work requires more time to complete than originally scheduled. Do not
use this where unexpected problems or delays render the unit out of service
beyond the estimated end date of the MO.
PO
Planned Outage – An outage that is scheduled well in advance and is of a
predetermined duration, lasts for several weeks and occurs only once or twice a
year. (Boiler overhauls, turbine replacement or inspections are typical planned
outages.)
PE
Planned Outage Extension – An extension of a planned outage (PO) beyond its
estimated completion date. This is typically used where the original scope of work
requires more time to complete than originally scheduled. Do not use this where
unexpected problems or delays render the unit out of service beyond the estimated
end date of the PO.
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EXHIBIT 7
START-UP TESTING
(Seller to provide to Buyer before the First Operation Date)

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EXHIBIT 8
FORM OF GUARANTY — CREDIT SUPPORT OBLIGATION
FORMS OF LIQUID SECURITY
The Seller shall provide Idaho Power with commercially reasonable security instruments
such as Cash, Cash Escrow Security, Guarantee or Letter of Credit as those terms are
defined below or other forms of liquid financial security that would provide readily
available cash to Idaho Power to satisfy the security requirements within this Agreement.

For the purpose of this Appendix D, the term “Credit Requirements” shall mean acceptable
financial creditworthiness of the entity providing the security instrument in relation to the
term of the obligation in the reasonable judgment of Idaho Power, provided that any
guarantee and/or Letter of Credit issued by any other entity with a short-term or long-term
investment grade credit rating by Standard & Poor’s Corporation or Moody’s Investor
Services, Inc. or any successors shall be deemed to have acceptable financial
creditworthiness.
1. Cash – Seller shall deposit cash in the amount of the required security with Idaho
Power. Idaho Power will not be responsible to calculate or pay any interest on these funds
deposited with Idaho Power.

2. Cash Escrow Security – Seller shall deposit funds in an escrow account established
by the Seller in a banking institution acceptable to both Parties equal to the required security.
The Seller shall be responsible for all costs, and receive any interest earned associated with
establishing and maintaining the escrow account(s).
3. Guarantee or Letter of Credit Security – Seller shall post and maintain in an amount
equal to the required security: (a) a guaranty from a party that satisfies the Credit Requirements,
in a form acceptable to Idaho Power at its discretion, or (b) an irrevocable Letter of Credit in a
form acceptable to Idaho Power, in favor of Idaho Power. The Letter of Credit will be issued by
a financial institution acceptable to both parties. The Seller shall be responsible for all costs
associated with establishing and maintaining the Guarantee(s) or Letter(s) of Credit.
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EXHIBIT 9
REQUIRED FACILITY DOCUMENTS
1.Obtained Required Facility Documents:
Permits:
Conditional Use Permits from Twin Falls County for the construction and
operation of the Facility
Land Rights:
Lease Agreement for the land, access, and interconnection of the Facility.
2.To Be Obtained (Prior to Commercial Operation) Required Facility Documents:
Licenses, Permits and Authorizations:
Evidence of market-based rate authority under Section 205 of the Federal Power Act or evidence
of qualifying facility certification under the Public Utility Regulatory Policies Act
Access road easement
Electrical Permit
Building Permit
Interconnection approval
Utility easement
Crossing Agreement
Construction and Operations and Maintenance:
Contract for the Sale of Power Generation Equipment and Related Services between vendors and
engineering, procurement, and construction contractor and Seller
Generator Interconnection Agreement
Retail Electric Service Agreement
Proof of Insurance
Construction Agreements:
Balance of Plant/Construction Services Agreement
Operations and Maintenance Agreements:
Warranty, Service and Maintenance Agreement
Exhibit No. 4
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SUCH LIST MAY BE UPDATED PURSUANT TO SECTION 2.2.3
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EXHIBIT 10
LEASES

(Seller to provide to Buyer before the Commercial Operation Date)

Memorandum of Lease Agreement 1
Memorandum of Lease Agreement 2

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EXHIBIT 11
ENGINEER’S CERTIFICATIONS
ENGINEER’S CERTIFICATION
OF
OPERATIONS & MAINTENANCE POLICY
The undersigned _____________________________________, on behalf of himself/herself and
___________ , hereinafter collectively referred to as “Engineer,” hereby states and certifies to the
Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of
Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter referred to as
the “Agreement,” between Idaho Power as Buyer, and ________________as Seller, dated
_________________________.
3. That the cogeneration or small power production project which is the subject of the
Agreement and this Statement is identified as Idaho Power Company Facility
No. ________________ and is hereinafter referred to as the “Project.”
4. That the Project, which is commonly known as the ____________________Project,
is located in Section _____ Township ________ Range ________, Boise Meridian, __________
County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish
electrical energy to Idaho Power for a ________ year period.
6. That Engineer has substantial experience in the design, construction and operation of
electric power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
8. That Engineer has reviewed and/or supervised the review of the Policy for Operation
and Maintenance (“O&M”) for this Project and it is his professional opinion that, said Project
has been designed and built to appropriate standards, and adherence to said O&M Policy will
result in the Project’s producing at or near the design electrical output, efficiency and plant factor
for the full Contact Term of _____________ years.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the
Agreement, is relying on Engineer’s representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to
the best of his/her knowledge and therefore sets his/her hand and seal below.
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By ______________________________
(P.E. Stamp)
Date ______________________________

Exhibit No. 4
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ENGINEER’S CERTIFICATION
OF
ONGOING OPERATIONS AND MAINTENANCE

The undersigned ____________________________________, on behalf of
himself/herself and _______________________ hereinafter collectively referred to as “Engineer,”
hereby states and certifies to the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of
Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter referred to as
the “Agreement,” between Idaho Power as Buyer, and ___________________ as Seller, dated
_________________________.
3. That the cogeneration or small power production project which is the subject of the
Agreement and this Statement is identified as Idaho Power Company Facility No.
_____________ and hereinafter referred to as the “Project”.
4. That the Project, which is commonly known as the ____________________Project,
is located in Section _____ Township ________ Range ________, Boise Meridian, __________
County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish
electrical energy to Idaho Power for a _________ year period.
6. That Engineer has substantial experience in the design, construction and operation of
electric power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
8. That Engineer has made a physical inspection of said Project, its operations and
maintenance records since the last previous certified inspection. The Engineer certifies, based on
the Project’s appearance and the information provided by the Project, that the Project’s ongoing
O&M has been completed in accordance with said O&M Policy; that it is in reasonably good
operating condition; and it is in the Engineer’s professional opinion that if adherence to said
O&M Policy continues, the Project will continue producing at or near its design electrical output,
efficiency and plant factor for the remaining ______ years of the Agreement.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the
Agreement, is relying on Engineer’s representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to
the best of his/her knowledge and therefore sets his/her hand and seal below.
Exhibit No. 4
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By ____________________________

(P.E. Stamp)

Date ______________________________

Exhibit No. 4
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ENGINEER’S CERTIFICATION
OF

DESIGN & CONSTRUCTION ADEQUACY
The undersigned _____________________________________, on behalf of himself/herself and
_________________________ hereinafter collectively referred to as “Engineer”, hereby states
and certifies to Idaho Power as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of
Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter referred to as
the “Agreement”, between Idaho Power as Buyer, and _____________________________as
Seller, dated __________, _____________________________.
3. That the cogeneration or small power production project, which is the subject of the
Agreement and this Statement, is identified as Idaho Power Company Facility
No ________________ and is hereinafter referred to as the “Project”.
4. That the Project, which is commonly known as the ____________________Project is
located in Section _____ Township ________ Range ________, Boise Meridian, __________
County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish
electrical energy to Idaho Power for a _____________ year period.
6. That Engineer has substantial experience in the design, construction and operation of
electric power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project
and has made the analysis of the plans and specifications independently.
8. That Engineer has reviewed the engineering design and construction of the Project,
including the civil work, electrical work, generating equipment, prime mover conveyance
system, Seller furnished Interconnection Facilities and other Project facilities and equipment.
9. That the Project has been constructed in accordance with said plans and
specifications, all applicable codes and consistent with Prudent Electrical Practices as that term is
described in the Agreement.
10. That the design and construction of the Project is such that with reasonable and
prudent operation and maintenance practices by Seller, the Project is capable of performing in
accordance with the terms of the Agreement and with Prudent Electrical Practices for a
________ year period.
11. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the
Agreement, in interconnecting the Project with its system, is relying on Engineer’s
representations and opinions contained in this Statement.
12. That Engineer certifies that the above statements are complete, true and accurate to
the best of his/her knowledge and therefore sets his/her hand and seal below.
Exhibit No. 4
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By ____________________________

(P.E. Stamp)

Date ______________________________
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EXHIBIT 12
[RESERVED]

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EXHIBIT 13
REQUIRED INSURANCE
The Seller shall secure and continuously carry insurance as specified within this Appendix for the
term of the Agreement.

Insurance Requirements:

1. All insurance required by this Agreement shall be placed with an insurance company
with an A.M. Best Company rating of A- or better.

2. If the insurance coverage required in this Appendix is cancelled, materially changed
or lapses for any reason, the Seller will immediately notify Idaho Power in writing. This notice
will advise Idaho Power of the specific reason for cancellation, material change or lapse and the
steps being taken to comply with these Insurance Requirements. Failure to provide this notice
and to comply with these Insurance Requirements within 5 days of the cancellation, material
change or lapse will constitute a material breach and Idaho Power may terminate this Agreement.

3. Prior to the First Energy date and subsequently within 10 days of the annual
anniversary of the Operation Date, the Seller shall provide a Certificate of Insurance in the name
of Idaho Power Company and list Idaho Power Company as an Additional Insured Endorsement
and Waiver of Subrogation Endorsement.

4. The Certificate of Insurance shall evidence the appropriate insurance coverage of
Comprehensive General Liability Insurance for both bodily injury and property damage with
limits equal to [$1,000,000], each occurrence, combined single limit. The deductible for such
insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
Seller shall be entitled to self-insure these coverages with approval of Idaho Power, which shall
not be unreasonable withheld, delayed or conditioned.
4.1 Periodic Review. Idaho Power may review this schedule of insurance as often as once every
two (2) years. Idaho Power may in its discretion require Seller to make reasonable changes to
the policies and coverages described in this Exhibit to the extent reasonably necessary to cause
such policies and coverages to conform to the insurance policies and coverages typically
obtained or required for power generation facilities comparable to the Facility at the time Idaho
Power’s review takes place.
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EXHIBIT 14
SELLER AUTHORIZATION TO RELEASE GENERATION DATA TO IDAHO
POWER
[DATE]
Idaho Power
1221 W Idaho St
Boise, ID 83702
Email: [e-mail]
To Whom it May Concern:
_______________________ (“Seller”) hereby voluntarily authorizes Idaho Power’s
Transmission business unit to share Seller’s interconnection information with marketing function
employees of Idaho Power, including but not limited to those in Power Supply. Seller
acknowledges that Idaho Power did not provide it any preferences, either operational or rate-
related, in exchange for this voluntary consent.
_______________________

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EXHIBIT 15
ATTACHMENTS
(Seller to provide to Buyer before the First Generation Date)

1. Site Map
2. As-Builts
3. Manufacturer’s performance warranties
4. [Other]
EXHIBIT 16
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AS-BUILT SUPPLEMENT

Exhibit No. 4
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EXHIBIT 17
[NOT USED]
EXHIBIT 18
FORM OF CONSTRUCTION PROGRESS REPORT

Construction Progress Report
of
_________________________
(“Seller”)
provided to
[BUYER ENTITY]
(“Buyer”)
[Date]

Instructions.
Any capitalized terms used in this report which are not defined herein are defined in the Power
Purchase Agreement by and between , (“Seller”) and [BUYER ENTITY] dated
____________, (the “Agreement”).
Seller shall review the status of each milestone of the construction schedule for the Facility and
Seller shall identify such matters referenced in clauses (i)-(v) below as known to Seller and
which in Seller’s reasonable judgment are expected to adversely affect the schedule, and with
respect to any such matters, shall state the actions which Seller intends to take to ensure that the
milestones will be attained by their required dates. Such matters may include:
(i) Any material matter or issue arising in connection with a Permit, or compliance
therewith, with respect to which there is an actual or threatened dispute over the interpretation of
an Applicable Law, actual or threatened opposition to the granting of a necessary Permit, any
organized public opposition, any action or expenditure required for compliance or obtaining
approval that Seller is unwilling to take or make, or in each case which could reasonably be
expected to materially threaten or prevent financing of the Facility, attaining any milestone, or
obtaining any contemplated agreements with other parties which are necessary for attaining any
milestone or which otherwise reasonably could be expected to materially threaten Seller’s ability
to attain any milestone.

(ii) Any development or event in the financial markets or the independent power industry,
any change in taxation or accounting standards or practices or in Seller’s business or prospects
which reasonably could be expected to materially threaten financing of the Facility, attainment of
any milestone or materially threaten any contemplated agreements with other parties which are
necessary for attaining any Milestone or could otherwise reasonably be expected to materially
threaten Seller’s ability to attain any milestone;
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(iii) A change in, or discovery by Seller of, any legal or regulatory requirement which would
reasonably be expected to materially threaten Seller’s ability to attain any milestone;
(iv) Any material change in Seller’s schedule for initiating or completing any material aspect
of Facility;
(v) The status of any matter or issue identified as outstanding in any prior Construction
Progress Report and any material change in Seller’s proposed actions to remedy or overcome
such matter or issue.
For guidance, each “overview” subsection shall include a summary of the status and progress of
major activities associated with that section, whether planned, in progress, or completed,
including relevant dates. Each “recent activities” subsection shall include details of activities
during the previous month. Each “expected activities” subsection shall include a brief list of
major activities planned for the current month.
Seller shall complete, certify, and deliver this form of Construction Progress Report to
[____________], together with all attachments and exhibits, with copies of this report delivered
to [____________].
1. Executive Summary
Please provide an overview of the Facility, including technology, size, location, and ownership.
Please provide a brief chronological cumulative summary of the major activities completed for
each of the following aspects of the Facility. Include the date each item was added to the
summary:
1.1 Milestones

1.2 Permits

1.3 Financing

1.4 Property Acquisition

1.5 Design and Engineering

1.6 Major Equipment procurement

1.7 Construction

1.8 Interconnection

1.9 Startup

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2. Milestones
In this section, please include information on each significant milestone related to the Facility.
2.1 Milestone schedule
Please state the status and progress of each milestone. Provide the date of completion of
completed milestone(s) and the expected date of completion of uncompleted milestone(s). The
expected date is the current best estimate, and may change from time to time as better
information becomes available.
2.2 Remedial Action Plan (applicable if Seller fails to achieve a milestone by the anticipated
milestone date)

Please describe in detail any delays (actual or anticipated) beyond the scheduled milestone dates.
Describe the cause of the delay (e.g., governmental approvals, financing, property acquisition,
design activities, equipment procurement, Facility construction, interconnection, or any other
factor). Describe Seller’s remedial action plan which shall include detailed plans to achieve the
missed milestone and subsequent milestones.
3. Permits
In this section, please include information on each of the Permits required for the construction of
the Facility and the status thereof. List the applicable government agency, the type of
application/approval requested, and the dates (expected or actual) of significant activity.
Significant activity includes application submission, notice of complete application, notice of
preparation, public hearing or comment period, draft documents or approvals, final documents or
approvals, notice of determination, or issuance of permit. If the government agency maintains a
website with information on the approval process for the Facility, please provide a link.
3.1 Environmental Impact Report/Statement (EIR/EIS) of Conditional Use Permit (CUP)

Please describe the environmental review process and each of the Permit(s) to be obtained for the
Facility. Provide the status and completion date (expected or actual) of each significant activity
in the process.

3.2 Other Permits

Please describe each of the other Permits to be obtained for the Facility. Provide the status and
completion date (expected or actual) of each significant activity.

3.3 Recent Permit activities

Please describe in detail the Permit activities that occurred during the previous calendar month.

3.4 Expected Permit activities
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Please list all Permit activities that are expected to be performed during the current calendar
month.
4. Financing Activities
In this section, please include information on each separate phase of financing for the Facility.
Include information on debt, equity, or federal or state loans or grants.

4.1 Overview of financing activities

Please provide a summary of the status and progress of each major financing activity, including
the date of execution of significant documents, and information on the expected timing of future
significant activities.

4.2 Recent financing activities

Please describe in detail the financing activities that occurred during the previous calendar
month.

4.3 Expected financing activities

Please list the financing activities that are expected to be performed during the current calendar
month.

5. Property Acquisition Activities

In this section, please include information on property acquisition or site control activities for the
Facility.

5.1 Overview of property acquisition activities

Please provide a summary of the status and progress of each major property acquisition activity,
including the date of execution of significant documents, and information on the expected timing
of future significant activities.

5.2 Recent property acquisition activities

Please describe in detail the property acquisition activities that occurred during the previous
calendar month.

5.3 Expected property acquisition activities
Please list the property acquisition activities that are expected to be performed during the current
calendar month.
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6. Design and Engineering Activities
In this section, please include information on the status of design and engineering for the
Facility.
6.1 Overview of design activities

Please provide a summary of the status and progress of each major design or engineering
activity, including dates of completion of significant activities and expected timing of future
activities.

6.2 Recent design activities

Please describe in detail the design activities that occurred during the previous calendar month.

6.3 Expected design activities

Please list the design activities that are expected to be performed during the current calendar
month.

7. Major Equipment Procurement

In this section, please include information on all major equipment to be procured for all portions
of the Facility to be completed by Seller, including switchyards, substations and any other
interconnection equipment, in addition to generating and auxiliary equipment.

7.1 Overview of major equipment procurement activities

For each type of equipment, list the number of each major item to be procured, the manufacturer,
model number (if applicable), and rating. List the delivery schedule (expected or actual as
applicable), breaking out the number of each item (to be) procured or delivered in each month.

7.2 Recent major equipment procurement activities

Please describe in detail the major equipment procurement activities that occurred during the
previous calendar month.

7.3 Expected major equipment procurement activities

Please list the major equipment procurement activities that are expected to be performed during
the current calendar month.

8. Construction Activities

In this section, please include information on the status of any construction-related factors that
may affect the ability of the Facility to deliver the Storage Product. Include information on the
Facility infrastructure, generating equipment, and major auxiliary equipment. Also include
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information on the substations, switchyards, gen-ties, telecommunications equipment or other
interconnection facilities that are the direct responsibility of the Facility.
8.1 Overview of major construction activities

Please provide a summary of the status and progress of each major construction activity for all
portions of the Facility, including a schedule showing expected or actual dates as applicable.
Provide the name of the EPC Contractor, the date of execution of the EPC Contract, and the date
of issuance of a Notice to Proceed (or equivalent). For each major type of equipment, break out
the number of each item (to be) installed or commissioned in each month.

8.2 Recent construction activities

Please describe in detail the construction activities that occurred during the previous calendar
month.

8.3 Expected construction activities

Please list the interconnection activities that are expected to be performed during the current
calendar month.

8.4 EPC Contractor Progress Report

Please attach a copy of the progress reports received during the previous calendar month from
the EPC Contractor pursuant to the construction contract between Seller and EPC Contractor,
certified by the EPC Contractor as being true and correct as of the date issued.

8.5 Look-ahead construction schedule

Please provide a look-ahead construction schedule covering at least three months.

8.6 OSHA Recordables

Please list all OSHA recordables from the previous calendar month.

8.7 Work stoppages

Please describe any work stoppage from the previous calendar month and its effect on the
construction schedule.

9. Interconnection Activities

In this section, please include information on interconnection-related factors that may affect the
ability of the Facility to deliver Facility Energy. Include information on the status of
interconnection studies, Interconnection Agreements, design and construction of interconnection
facilities (e.g., substations, switchyards, gen-ties, system protection schemes,
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telecommunications equipment to the extent not already covered in the Facility construction
information in Section 8), network upgrades, and grid outage or interconnection schedules.
9.1 Overview of interconnection activities
Please provide a summary of the status and progress of each major interconnection activity
including dates of completion of significant activities and expected timing of future activities.
9.2 Recent interconnection activities

Please describe in detail the interconnection activities that occurred during the previous calendar
month.

9.3 Expected interconnection activities
Please list the interconnection activities that are expected to be performed during the current
calendar month.
10. Startup

In this section, please include information on the status of activities related to preparation for
Commercial Operation, including equipment testing, commissioning, release to operations,
requirements of the grid operator, and any other activities that must be conducted before the
Facility may deliver Energy to the grid or declare Commercial Operation.
10.1 Overview of startup activities

Please provide a summary of the status and progress of each major startup activity including
dates of completion of significant activities and expected timing of future activities.
10.2 Recent startup activities

Please describe in detail the startup activities that occurred during the previous calendar month.

10.3 Expected startup activities
Please list the startup activities that are expected to be performed during the current calendar
month.
11. Other Information Reasonably Requested by Buyer
11.1 Litigation
Please list any communication received directly or indirectly from any third party that is in the
nature of a threat of litigation, a litigation hold notice, a summons and complaint, or a
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commencement of a judicial, regulatory, or arbitration proceeding or investigation against Seller
or concerning the Facility
11.2 [_________________]
I, ________________, on behalf of and as an authorized representative of ________________,
do hereby certify that any and all information contained in this Seller’s Construction Progress
Report is true and accurate, and reflects, to the best of my knowledge, the current status of the
construction of the Facility as of the date specified below.

By:_______________________________
Name:_____________________________
Title:______________________________
Date:______________________________

Exhibit No. 4
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EXHIBIT 19
FORM OF OPERATIONS REPORT

Exhibit No. 4
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EXHBIT 20
[IDAHO POWER FORM OF WREGIS QRE AGREEMENT]

Exhibit No. 4
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EXHIBIT 21
FORM OF LENDER CONSENT
CONSENT AND AGREEMENT

This Consent and Agreement (this “Consent”) is made and entered into as of ___ _, 20__, by and
between Idaho Power Corporation (“Buyer”), and _______ (“Lender”).

RECITALS

A. ________ (“Seller”), has entered into that certain Loan Agreement, dated as of ___ __,
20__ (as amended, restated, supplemented, or otherwise modified from time to time, the “Loan
Agreement”), with Lender in order to finance construction of a battery energy storage system
owned by Seller and located at ____ (the “Project”).

B. Seller and Buyer have entered into that certain Battery Storage Agreement, dated as of
____ (as amended, restated, supplemented or otherwise modified from time to time, the “BSA”),
relating to the energy stored and discharged by the Project to supply the needs of Buyer’s
customers.

C. As part of the transactions contemplated by the Loan Agreement, Lender has received a
pledge of all the limited liability company interests in Seller (the “Pledged Equity”), and Seller
has collaterally assigned all of its rights, title and interests in, to and under the BSA (the
“Pledged SA”, collectively with the Pledged Equity, the “Assigned Interest”) to Lender.

AGREEMENTS

NOW, THEREFORE, for and in consideration of the premises and the mutual covenants
contained herein, and for other good and valuable consideration, the receipt, adequacy and legal
sufficiency of which are hereby acknowledged, and intending to be legally bound hereby, the
parties hereby agree as follows:

1. Consent to Assignment. Buyer hereby consents to the collateral assignment by Seller
to Lender of the Pledged BSA and the pledge to Lender of the Pledged Equity and acknowledges
the right of Lender to exercise Lender’s rights and remedies as a secured creditor with respect to
the Assigned Interest.

2. Pledged BSA Step-In. “Subsequent Seller Requirements” means an entity that (a) is
acceptable to Buyer; (b) is not involved, and has no Affiliate involved, in any state or federal
litigation or regulatory proceeding adverse to Buyer or any Affiliate of Buyer; (c) has, or has
retained, a reputable entity acceptable to Buyer that has, at least five (5) years’ experience in the
operation and maintenance of battery energy storage facilities of comparable size to the Facility
and the ability perform all aspects of the BSA; (d) has agreed in writing to be bound by the BSA
and to assume all of Seller’s obligations under the BSA; and (e) is not a Sanctioned Person.
Buyer agrees that, if Lender has elected to exercise its rights and remedies to proceed against the
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Pledged BSA, and has so notified Buyer, then, if and only if (i) the hereinafter-defined
Subsequent Seller meets all of the Subsequent Seller Requirements, (ii) Buyer is holding, and
will be holding as of and after the date of assignment, the Project Development Security or
Default Security, as applicable, and (iii) Buyer has not terminated this BSA pursuant to the terms
thereof and of this Consent, then Lender or any assignee or designee of Lender, including Lender
or any purchaser in a foreclosure sale or in lieu of foreclosure of the Pledged BSA (a
“Subsequent Seller”), may be substituted for Seller under the BSA and Buyer shall recognize
such Subsequent Seller as its counterparty under the BSA and, subject to all rights and remedies
of Buyer under the BSA, continue to perform its obligations under the BSA in favor of such
Subsequent Seller. Lender shall have no liability or obligation under the BSA as a result of this
Consent except if Lender becomes a Subsequent Seller. Any Subsequent Seller succeeds to the
interests and obligations of Seller and must comply with the BSA. The transfer of the BSA from
Seller to a Subsequent Seller does not relieve or discharge Seller of its obligations and liabilities
to Buyer which accrued prior to the date of such transfer.
3. Change of Control. Buyer hereby consents to both (i) the pledge of the Pledged
Equity to Lender as part of the transactions contemplated by the Loan Agreement, and (ii) the
transfer of such Pledged Equity, in connection with such an exercise of Lender’s remedies
against the Pledged Equity, to a Subsequent Seller that meets the Subsequent Seller
Requirements, provided that Lender provides written notice to Buyer in advance of any such
transfer.

4. Notice of Default. If Seller defaults in the performance of any of its obligations under
the BSA, Lender may cure such default by the deadline provided therefor in the BSA. Buyer will
not terminate the BSA before providing notice to Lender and giving Lender the opportunity to
cure such default as follows: (a) with respect to payment defaults, or a default under Section
11.1(l) of the BSA, before the later of (i) ten (10) business days after Buyer’s delivery of notice
to Lender of such default or (ii) five (5) business days plus the number of days in the applicable
cure period provided Seller in the BSA, and (b) with respect to other defaults (except those set
forth in Section 11.1(e)-(j) of the BSA, for which no notice or extension is promised by Buyer
herein), within the greater of (i) ninety (90) days or (ii) thirty (30) days plus the number of days
in the applicable cure period provided Seller in the BSA following delivery of such notice from
Buyer to Lender; provided, however, that such cure period in clause (b) may be extended by a
reasonable period of time, not to exceed an additional ninety (90) days (or, with respect to an
Event of Default under Section 11.1(c) of the BSA, to a date that is no greater than ninety (90)
days after Buyer’s delivery of notice to Lender of such default), if Lender has commenced and is
diligently pursuing appropriate action to cure such non-monetary default; provided further, that
to the extent that such default permits Lender to foreclose on its security interests in the Assigned
Interest and Lender needs to gain possession of the Project in order to perform such cure, Buyer
will allow an additional reasonable amount of time, not to exceed sixty (60) days, to permit
Lender to do so.
5. BSA Termination. Buyer agrees that it shall not, without Lender’s prior written
consent, mutually agree with Seller to a voluntary termination of the BSA; provided that
notwithstanding the foregoing, Buyer may terminate the BSA without Lender consent due to an
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uncured Event of Default under the BSA after the expiration of Lender’s rights to cure under
Section 4 hereof.
6. No Setoff. Notwithstanding any provision to the contrary set forth in this Consent,
Lender may not use the Consent or any other setoff or other right set forth in the BSA as a basis
for any action under, or nonperformance of, its obligations under any letter of credit naming
Buyer or any affiliate as beneficiary, with respect to which the terms of such letter of credit shall
control.
7. Certifications of Buyer. Buyer hereby certifies to Lender, as of the date hereof, that
(i) the execution, delivery and performance by Buyer of this Consent and the BSA have been
duly authorized by all necessary corporate action on the part of Buyer, (ii) each of this Consent
and the BSA is in full force and effect and constitutes the legal, valid and binding obligation of
Buyer, enforceable against Buyer in accordance with its terms, except as the enforceability
thereof may be limited by bankruptcy, insolvency, reorganization or other similar laws affecting
the enforcement of creditors’ rights generally and general equitable principles, (iii) the BSA and
the Acknowledgment of Consent and Agreement (attached hereto) with respect to this Consent
are the only agreements between Seller and Buyer, (iv) a true and correct copy of the BSA is
attached hereto as Exhibit A and the BSA has not been further amended, (v) Buyer is not in
default of any of its obligations under the BSA, (vi) solely to the best of the actual knowledge of
its employees with responsibility for administering the BSA, Seller is not in default of any of its
obligations under the BSA, (vii) solely to the best of the actual knowledge of its employees with
responsibility for administering the BSA, there are no material disputes between Buyer and
Seller under the BSA, (viii) Buyer has not assigned any interest it has in the BSA, and Buyer has
no notice of, and has not consented to, any previous assignment by Seller of all or any part of its
rights under the BSA, (ix) there are no actions pending against Buyer as a debtor under any
federal or state bankruptcy or insolvency laws, (x) there are no proceedings pending or, to
Buyer’s knowledge, threatened against or affecting Buyer before any court, governmental
authority, or arbitration board or tribunal which could reasonably be expected to have a material
adverse effect on the ability of Buyer to perform its obligations under the BSA, (xi) solely to the
best of the actual knowledge of its employees with responsibility for administering the BSA, no
event of Force Majeure has occurred, and (xii) subject to Seller’s obligation to declare the
Commercial Operation Date on or before the Guaranteed Commercial Operation date, solely to
the best of the actual knowledge of Buyer’s employees with responsibility for administering the
BSA, no event or condition exists that would either immediately or with the passage of any
applicable grace period or giving of notice, or both, enable either Buyer or Seller to terminate or
suspend its obligations under the BSA.

8. Replacement Agreement. If the BSA is rejected or terminated as a result of any
bankruptcy, insolvency, reorganization or similar proceeding affecting Seller, Buyer will, at the
option of Lender exercised by providing written notice thereof to Buyer within forty-five (45)
days after such rejection or termination, enter into a new agreement with Lender (or its designee
or assignee) having identical terms as the BSA (subject to any conforming changes (none of
which may include limitation of Buyer’s remedies) necessitated by the substitution of the seller
entity); provided that the following conditions shall apply: (i) the seller under the new agreement
must meet the Subsequent Seller Requirements; (ii) the term under such new agreement shall be
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equal to the remaining balance of the term specified in the BSA and (iii) Lender (or its designee
or assignee) shall have cured any then-existing payment or performance defaults by Seller under
the BSA (other than the bankruptcy of Seller or a transfer of the Facility to Lender, or of Seller to
Lender, that was in connection with Lender’s foreclosure thereupon and in compliance with this
Consent but that was not in compliance with Section 9.2 of the BSA).

9. Notices. All notices given under this Consent shall be in writing and shall be deemed
effectively given: (a) upon personal delivery to the party to be notified; (b) one business day
after deposit with a reputable overnight courier, prepaid for overnight delivery and addressed as
set forth below, with a copy of the notice simultaneously emailed to each applicable recipient at
the email address shown below; provided that the sending party receives a confirmation of
delivery from the overnight courier service; or (c) three (3) business days after deposit with the
U.S. Post Office, postage prepaid, certified with return receipt requested and addressed to the
party to be notified at the address indicated for such party below with a copy of the notice
simultaneously emailed to each applicable recipient at the email address shown below. The
parties may designate alternative notice addresses upon ten (10) days’ advance written notice to
the other parties:
If to Seller:
With a copy to:
If to Buyer:

With copies to all of:

If to Lender:
With a copy to:
10. Successors and Assigns. This Consent shall be binding upon Buyer and Seller and
their permitted successors and assigns.
11. Termination. Upon the satisfaction in full of Seller’s obligations under the Loan
Agreement (other than contingent indemnification and reimbursement obligations that survive
repayment of the loans and advances, interest fees and other amounts owed under the Loan
Documents): (a) Lender shall notify Buyer of such fact and (b) this Consent shall terminate
without further action of the parties hereto. Additionally, upon Lender’s consummation of all of
its remedies available under this Consent, this Consent shall terminate without further action of
the parties hereto.
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12. Waiver of Right to Jury Trial. TO THE FULLEST EXTENT PERMITTED BY
LAW, EACH OF THE PARTIES HERETO WAIVES ANY RIGHT IT MAY HAVE TO A
TRIAL BY JURY IN RESPECT OF LITIGATION DIRECTLY OR INDIRECTLY ARISING
OUT OF, UNDER OR IN CONNECTION WITH THIS CONSENT. EACH PARTY
FURTHER WAIVES ANY RIGHT TO CONSOLIDATE ANY ACTION IN WHICH A JURY
TRIAL HAS BEEN WAIVED WITH ANY OTHER ACTION IN WHICH A JURY TRIAL
CANNOT BE OR HAS NOT BEEN WAIVED.
13. Governing Law. This Consent will be governed by and construed in accordance with
the laws of the State of New York, without giving effect to principles of conflicts of law.
14. Severability. If any provision of this Consent or the application thereof is determined
by a court of competent jurisdiction to be invalid, void or unenforceable, the remaining
provisions hereof, or the application of such provision to the parties hereto or circumstances
other than those as to which it has been held invalid or unenforceable, shall remain in full force
and effect and shall in no way be affected, impaired or invalidated thereby, so long as the
economic or legal substance of the transactions contemplated hereby is not affected in any
manner materially adverse to any party by the invalidity, unenforceability or nullification of the
offensive provisions.
15. Amendment. This Consent may not be amended, modified, or changed in any respect
except by an agreement in writing signed by Lender and Buyer. Nothing in this Consent amends
or modifies the BSA.
16. Counterparts; Rules of Construction; Definitions. This Consent may be executed in
one or more counterparts, each of which will be an original and all of which, when taken
together, will constitute one and the same original agreement. All references made (a) in the
neuter, masculine, or feminine gender are made in all such genders, and (b) in the singular or
plural includes the plural or singular number as well. Any capitalized term used but not defined
herein is defined in the BSA.
17. Third Party Rights. Nothing in this Consent, expressed or implied, is intended or
shall be construed to confer upon, or give to any Person, other than Buyer and Lender,
respectively, rights, remedies or claims, legal or equitable, under or by reason hereof, or any
covenant or condition hereof; and this Consent and the covenants and agreements, here contained
are and shall be held for the sole and exclusive benefit of Buyer and Lender.
18. Seller Acknowledgement of Consent and Agreement. Buyer’s obligations under this
Consent are conditioned upon the execution and delivery by Seller to Buyer of the
Acknowledgment of Consent and Agreement attached hereto.
[REMAINDER OF PAGE LEFT INTENTIONALLY BLANK]

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IN WITNESS WHEREOF, the parties hereto have caused this Consent to be duly executed and
delivered by their duly authorized signatories as of the date first above written.
IDAHO POWER COPRPORATION
By: ______________________________________
Name:_________________________________
Title:__________________________________
[LENDER]
By _______________________
Its _______________________

Exhibit No. 4
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ACKNOWLEDGEMENT OF CONSENT AND AGREEMENT
Reference is made to the Consent and Agreement dated as of ______ (the “Consent and
Agreement”) between Idaho Power Corporation (as “Buyer”), and ______ (as “Lender”). _____
as “Seller” under the BSA (as defined in the Consent and Agreement) hereby directs Buyer to
pay any amounts payable by Buyer under the BSA, as and when required under the BSA,
pursuant to the payment instructions delivered and effective as of or proximate to the date hereof,
from Seller to Buyer, or as may otherwise be specified from time to time by Lender or Seller to
Buyer in writing. Any payment made to Seller or as Buyer in good faith believes to have been
directed by Seller or Lender shall discharge any obligation of Buyer to Seller with respect to the
making of such payment. Seller, by its execution of this Acknowledgment of Consent and
Agreement, acknowledges and agrees that, notwithstanding any term to the contrary in the BSA,
Buyer and Lender may perform all acts or obligations as set forth in the Consent and Agreement,
and Buyer may perform as set forth herein or as otherwise purportedly instructed by Lender,
including, without limitation, the manner and place of any payments to be made by Buyer that
would otherwise be required pursuant to the BSA, and further agrees and consents to the various
agreements made by Buyer in the Consent and Agreement, issues or confirms the instructions
contained in the Consent and Agreement or herein or as hereafter issued by Seller or Lender,
agrees to indemnify Buyer for any damages or liabilities suffered in the performance of the
Consent and Agreement or such instruction; and further agrees that none of the execution of the
Consent and Agreement, the performance by Buyer or Lender of any of their respective
obligations thereunder, the exercise of any of the rights of Buyer or Lender thereunder, or the
acceptance by Buyer of performance of the BSA by any party acting at the direction of Seller,
Lender, or a Subsequent Seller shall subject Buyer to liability to Seller or release Seller from any
obligation of Seller under the BSA. Seller acknowledges that Buyer need not enter into any
agreement in the nature of the Consent and Agreement with any of Seller’s other lenders prior to
the termination of the Consent and Agreement. Nothing in this Acknowledgment of Consent and
Agreement or in the Consent and Agreement amends or modifies the BSA. Seller shall have no
rights against Buyer, under the BSA or otherwise, arising out of or on account of the Consent
and Agreement or Buyer’s performance (or nonperformance) thereunder or of the instruction.

Agreed to and Accepted:

By:
Its:
Date:

Exhibit No. 4
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EXHIBIT 22
FORM OF ESTOPPEL CERTIFICATE
ESTOPPEL CERTIFICATE
This Estoppel Certificate (“Estoppel”) is dated _____ __, 20__. Reference is made to that
certain Battery Storage Agreement, dated as of ______ (the “BSA”), by and between Idaho
Power Corporation (“Buyer”), and _________ (“Seller”) concerning the storage and discharge of
electrical energy and other services provided the battery energy storage system owned by Seller
and located in ____ (the “Project”). This certificate is delivered by Buyer to __________
(“Investor”) and _______ as Administrative Agent (as defined in the Consent defined below)
(“Administrative Agent”). Capitalized terms used but not defined herein are defined in the
BSA.
Buyer certifies that, as of the date hereof, that (i) the execution, delivery and performance by
Buyer of this Estoppel and the BSA have been duly authorized by all necessary action on the part
of Buyer, (ii) each of this Estoppel and the BSA is in full force and effect and constitutes the
legal, valid and binding obligation of Buyer, enforceable against Buyer in accordance with its
terms, except as the enforceability thereof may be limited by bankruptcy, insolvency,
reorganization or other similar laws affecting the enforcement of creditors’ rights generally and
general equitable principles, (iii) the BSA and the Acknowledgment of Consent and Agreement
dated _____ are the only agreements between Seller and Buyer, (iv) a true and correct copy of
the BSA is attached hereto as Exhibit A and the BSA has not been further amended, (v) solely to
the best of the actual knowledge of its employees responsible for administering the BSA, Buyer
is not in default of any of its obligations under the BSA, (vi) solely to the best of the actual
knowledge of its employees with responsibility for administering the BSA, Seller is not in
default of any of its obligations under the BSA, (vii) solely to the best of the actual knowledge of
its employees with responsibility for administering the BSA, there are no material disputes
between Buyer and Seller under the BSA, (viii) Buyer has not assigned any interest it has in the
BSA, and Buyer has no notice of, and has not consented to, any previous assignment by Seller of
all or any part of its rights under the BSA, (ix) there are no actions pending against Buyer as a
debtor under any federal or state bankruptcy or any other similar laws, (x) there are no
proceedings pending or, to Buyer’s knowledge, threatened against or affecting Buyer before any
court, governmental authority, or arbitration board or tribunal which could reasonably be
expected to have a material adverse effect on the ability of Buyer to perform its obligations under
the BSA, (xi) solely to the best of the actual knowledge of its employees with responsibility for
administering the BSA, no event of Force Majeure has occurred, and [(xii) subject to Seller’s
obligation to declare the Commercial Operation Date on or before the Guaranteed Commercial
Operation Date, solely to the best of the actual knowledge of Buyer’s employees with
responsibility for administering the BSA][omit if estoppel delivered after COD], no event or
condition exists that would either immediately or with the passage of any applicable grace period
or giving of notice, or both, enable either Buyer or Seller to terminate or suspend its obligations
under the BSA. Buyer disclaims any obligation to advise Investor or Administrative Agent of
any changes to the foregoing.
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IN WITNESS WHEREOF, the undersigned has caused this Estoppel to be signed by its
authorized signatory as of the date first set forth above.
IDAHO POWER CORPORATION
By: ______________________________________
Name:_________________________________
Title:__________________________________

Exhibit No. 4
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EXHIBIT 23
PERFORMANCE TESTS
Test Records: Seller shall record the results of each Performance Test, provide all raw data, records
and results associated with each Performance Test, and submit a testing report detailing all results
and findings of each Performance Test to Buyer within four (4) Business Days following
completion of such Performance Test. During the performance of each Performance Test, the
Facility shall be functioning in a manner to permit Buyer to remotely monitor, observe and
independently verify the performance of the Facility through the Facility’s remote monitoring and
control systems.
Guaranteed Storage Availability Test
No later than forty-five (45) days prior to the Scheduled Commercial Operation Date, and no later
than thirty (30) days following the conclusion of each Contract Year thereafter for the Settlement
Term, the Storage Availability shall be at least __________ percent (_____%), calculated in
accordance with the following procedure (“Guaranteed Storage Availability Test”):6

“Storage Availability” shall be calculated based upon the following formula:
PH = period hours
PMH = period planned maintenance hours
GPC = Guaranteed Power Capacity
PC = Available power capacity (MW) defined as battery power capability
on-line and available for operation in either charge or discharge
GEC = Guaranteed Rated Energy Capacity
AC = Available energy capacity (MWh) defined as the battery energy
storage capacity online and available for operation in either charge or
discharge
PAC = Period unavailable average capability, calculated as the normalized
average of the maximum either energy storage capacity or power available
during the period. A sample is not valid if during planned maintenance or a
no-fault outage.
=1 ,
PFO = Period at-fault outage hours, defined as hours during which all or a
portion of the available energy or power capacity is unavailable

6 Note: The Facility will need to be operational in order to conduct the Storage Availability Test, and thereafter
calculated annually in accordance with a procedure to be agreed upon by the Parties.
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PNFO = Period of not at fault (excused) outage hours, defined as hours
during which all or a portion of the available energy or power capacity is
unavailable due to no fault of Seller provided equipment
Therefore, Availability is calculated as the following:

= 100
([])
()
Guaranteed Storage Capacity Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, and no later than
thirty (30) days following the conclusion of each Contract Year thereafter for the Settlement Term,
the Facility shall be capable of the Guaranteed Storage Capacity. The Storage Capacity shall be
calculated in accordance with the following procedure (“Guaranteed Storage Capacity Test”):
The “Guaranteed Storage Capacity” shall mean the guaranteed energy capacity (MWhAC)
delivered over a full continuous discharge of the Facility at the Guaranteed Power Capacity
(MW).
The “Energy Capacity” shall be defined as:

Energy Capacity =

Where the following terms are defined as:

MVD = Medium Voltage Main Meter reading during discharge cycle
(“Gross Metering” in the metering configuration)
AXD = Auxiliary Meter reading during the discharge cycle (“Aux
Metering” in the metering configuration)
MVC = Medium Voltage Main Meter reading during charge cycle (“Gross
Metering” in the metering configuration)
AXC = Auxiliary Meter reading during the charge cycle (“Aux Metering”
in the metering configuration)

AXM = Maximum auxiliary energy consumed based on nameplate rating
of the auxiliary power transformer(s)

The “Guaranteed Storage Capacity” shall mean the guaranteed Power Capacity set
forth in the Agreement. The “Power Capacity” is defined as the Energy Capacity
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divided by the measured time required for discharge of the Guaranteed Storage
Capacity. The metered instantaneous power shall be within +/- 2% of the guaranteed
power for the duration of the guaranteed power capacity test, with infrequent
momentary excursions from this band being acceptable.

Energy Capacity and Power Capacity shall be calculated by the following testing
procedure:
i. Rest 2 hours with cell temperatures at 25-35 °C.
ii. Charge the batteries with 0.25 cp to its cut-off voltage, then charge via
constant current – constant voltage method to full charge. Record the AC
energy for both the Gross Metering (MVC) and the Aux Metering (AXC)
iii. Allow batteries to rest for up to 30 minutes
iv. Discharge the batteries with 0.25 cp to its cut-off voltage to starting SOC
using constant current method. Record the AC energy for both the Gross
Metering (MVD) and the Aux Metering (AXD)
v. Allow batteries to rest for up to 30 minutes
vi. Repeat steps (ii) through (iv) two (2) times in total

The “Energy Capacity” is calculated as

={+,+,+}
Guaranteed Roundtrip Efficiency Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, and no later
than thirty (30) days following the conclusion of each Contract Year thereafter for the Settlement
Term, the Facility shall be capable of the Guaranteed Roundtrip Efficiency. The Roundtrip
Efficiency shall be conducted in accordance with the following procedure (“Guaranteed
Roundtrip Efficiency Test”):
Roundtrip Efficiency Test shall be conducted in conjunction with the Guaranteed Storage
Capacity Test.
The “Roundtrip Efficiency” is calculated as
=+,+,+
Where the following terms are defined as:

MVD = Medium Voltage Main Meter reading during discharge cycle

MVC = Medium Voltage Main Meter reading during charge cycle

AXC = Auxiliary Meter reading during charge cycle
Exhibit No. 4
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AXD = Auxiliary Meter reading during discharge cycle
Charge Rate Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, the Charge
Rate Test shall be performed in accordance with the following procedure (“Charge Rate Test”):
The Facility, not including auxiliary power, must be designed and capable of charging at 100%
of the proposed AC power and energy capacity at the POI.
The charge rate shall be determined as part of the Roundtrip Efficiency Test.
The charge rate shall be defined as the energy capacity divided by the time required to charge
the Guaranteed Storage Capacity.
Charge Rate Guarantee = ()/

Where the following terms are defined as:

MVC = Medium Voltage Main Meter (“Gross Metering”) reading during
charge cycle

TCH = Total Time to Charge
AXC = Auxiliary Meter (“Aux Metering”) reading during charge cycle
Ramp Rate Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, the Ramp Rate
Test shall be performed in accordance with the following procedure (“Ramp Rate Test”):
The Facility shall be capable of responding to input signals and reaching 98% of full power
charging and discharging within 200 ms. The Response Time Test is conducted concurrent
with the Ramp Rate Test.
Response Time Test
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No later than thirty (30) days prior to the Scheduled Commercial Operation Date, the Response
Time Test shall be performed in accordance with the following procedure (“Response Time
Test”):
The Facility shall be capable of responding to input signals and responding within 200 ms for
the Term.

The response shall be defined as the time required for the Facility output to transition from no
discharge to full rated discharge and from no charge to full rated charge when the breakers are
closed and the system is on-line.
The start time shall be when the signal is received at the Facility boundary, and the end time
shall be when the measured discharge power reaches 100% ±2% of the rated power when the
breakers are closed and the system is on-line.
Auxiliary Load Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, the Auxiliary
Load Test shall be performed in accordance with the following procedure (“Auxiliary Load
Test”):
The maximum instantaneous auxiliary power consumption of the Facility will be lower than
the rating of the auxiliary power transformer. Seller shall guarantee the maximum amount of
auxiliary load to be consumed by the Facility, expressed in kW, measured at the auxiliary load
meter.
The auxiliary load test condition, including but not limited to ambient temperature, duty cycle
will be agreed upon by Buyer and Seller. Correction curves will be allowed with the
concurrence of both Parties.
Auxiliary Load Guarantee = ({,,})

Where the following terms are defined:

AXC = Auxiliary Meter maximum power reading during charge cycle

AXD = Auxiliary Meter maximum power reading during discharge cycle

AXS = Auxiliary Meter maximum power reading during standby
Power Factor Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, the Power
Factor Test shall be performed in accordance with the following procedure (“Power Factor
Test”):
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In accordance with Exhibit A, the power factor during charge and discharge operation shall be
controlled to ± 0.95 at the POI, except as may be provided in a Subsequent Purchase Order.
The sizing and design requirements to meet Buyer power factor requirements.
Details of the testing will depend on Facility Site reactive power constraints and will be
determined as a part of Facility Site design. Testing shall meet MRO MOD-025-02 including:
At the real power rating equal to the real power rating of the Facility Site
(i.e. ±0.95 PF at 25 MW for a 25 MW rated site)
Testing of active power under charge and discharge conditions
Testing shall be done with approval of and in coordination with WECC and Buyer.
Noise Test
No later than thirty (30) days prior to the Scheduled Commercial Operation Date, the Noise Test
shall be performed in accordance with the following procedure (“Noise Test”):

The noise shall be less than 85 decibels on the A weighted scale at a distance of 1 meter along
the perimeter of the Facility. Sound shall be measured at 1.5 meters above the grade elevation.

Exhibit No. 4
Case No. IPC-E-24-16
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Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements for Resources Based Bids
dated as of
[___2022]
by and between
and
[DEVELOPER]
Respondent shall review and redline the following draft agreement into the submitted proposal for the specific
product type and ownership structure as defined in this RFP.
This draft Exhibit H is not comprehensive and does not constitute a binding offer, shall not form the bases for an
agreement by estoppel nor otherwise, and is not conditions upon each party’s receipt of all requirement
management approvals (including final credit and legal approval) and all regulatory approvals. Any actions
taken by a party in reliance on the terms set forth in this working draft or on statements made during negotiations
pursuant to this working draft shall be at that party’s own risk. Until this agreement is negotiated, approved by
management, executed, delivered, and approved by all required regulatory bodies, no party shall have any other
legal obligations, expressed or implied, or arising in any other manner under this working draft or in the course
of negotiations.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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Build Transfer Agreement – Page i
Page

1.1 Defined Terms...........................................................................................................................1
1.2 Interpretation. .........................................................................................................................20

2.1 IPUC Approval..........................................................................................................................22
2.2 Sale and Transfer of Membership Interests. ................................................................22
2.3 Firm Date...................................................................................................................................22
2.4 Full Notice to Proceed...........................................................................................................23
2.5 Closing Deliverables..............................................................................................................23
2.6 Purchase Price.........................................................................................................................25
2.7 Closing and Payment Structure. ........................................................................................26
2.8 Further Assurances................................................................................................................27
2.9 Conditions Precedent to Buyer’s Obligation to Complete the
Closing.........................................................................................................................................27
2.10 Conditions Precedent to Developer’s Obligation to Complete the
Closing.........................................................................................................................................28
2.11 Early Termination. .................................................................................................................29

3.1 Organization, Standing, and Power.................................................................................31
3.2 Authority; Execution and Delivery..................................................................................32
3.3 Binding Agreement. ...............................................................................................................32
3.4 No Conflicts. ..............................................................................................................................32
3.5 No Proceedings. .......................................................................................................................33
3.6 Compliance with Laws..........................................................................................................33
3.7 Membership Interests...........................................................................................................33
3.8 Financial Resources...............................................................................................................33
3.9 Reports. ......................................................................................................................................33
3.10 Due Diligence. ..........................................................................................................................34
3.11 No Material Adverse Change..............................................................................................34
3.12 Affiliate Transactions............................................................................................................34
3.13 Brokers.......................................................................................................................................34
Exhibit No. 4
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Build Transfer Agreement – Page ii
3.14 Absence of Certain Business Practices...........................................................................34
3.15 Solvency.....................................................................................................................................35
COM
4.1 Organization, Standing, and Power. ................................................................................35
4.2 No Conflicts...............................................................................................................................35
4.3 No Proceedings........................................................................................................................36
4.4 Compliance with Laws..........................................................................................................36
4.5 No Prior Business...................................................................................................................36
4.6 Employees.................................................................................................................................37
4.7 Subsidiaries and Joint Ventures. .......................................................................................37
4.8 Managers and Bank Accounts............................................................................................37
4.9 No Undisclosed Liabilities...................................................................................................37
4.10 Project Assets...........................................................................................................................37
4.11 Project Company Contracts................................................................................................37
4.12 Project Company Permits; Project Company Regulatory Approvals. ................38
4.13 Real Estate. ................................................................................................................................39
4.14 Environmental Matters........................................................................................................40
4.15 Sufficiency of Assets. .............................................................................................................41
4.16 Construction of the Project; Expertise...........................................................................42
4.17 Tax Benefits..............................................................................................................................42
4.18 Taxes. ...........................................................................................................................................43
4.19 FERC............................................................................................................................................45
4.20 Insurance...................................................................................................................................45
4.21 Books and Records.................................................................................................................45
4.22 Intellectual Property.............................................................................................................45
4.23 No Data Breaches. ..................................................................................................................45
4.24 No Other Representations...................................................................................................46

5.1 Organization, Standing, and Power. ................................................................................46
5.2 Authority; Execution and Delivery..................................................................................46
5.3 Binding Agreement. ...............................................................................................................46
5.4 No Conflicts...............................................................................................................................46
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 168 of 1056
Build Transfer Agreement – Page iii
5.5 No Proceedings........................................................................................................................47
5.6 Buyer Permits; Buyer Regulatory Approvals. .............................................................47
5.7 Brokers.......................................................................................................................................47
5.8 Solvency.....................................................................................................................................47
5.9 Sufficiency of Funds...............................................................................................................48

6.1 Credit Support.........................................................................................................................48
6.2 Utilization of Credit Support..............................................................................................48
6.3 Release of Credit Support....................................................................................................48
6.4 Contractor Credit Support..................................................................................................49

7.1 General Covenants of the Parties. ....................................................................................49
7.2 Developer Covenants............................................................................................................49
7.3 Buyer Covenants .....................................................................................................................52
7.4 Updating of the Disclosure Schedules............................................................................52

8.1 Developer’s General Obligations......................................................................................53
8.2 Contractor and Subcontractors.........................................................................................54
8.3 Compliance with Law. ...........................................................................................................55
8.4 Permits.......................................................................................................................................55
8.5 Interconnection.......................................................................................................................55
8.6 Opportunities for Other Contractors. .............................................................................56
8.7 Labor and Employment........................................................................................................56
8.8 Authority for Access for Inspection. ................................................................................57
8.9 Contractor Drawings and Manuals. .................................................................................57
8.10 Training......................................................................................................................................58
8.11 Safety. ..........................................................................................................................................58
8.12 Intellectual Property Rights...............................................................................................59
8.13 Developer’s Representatives.............................................................................................59
8.14 Developer’s Personnel/Drugs, Alcohol and Firearms. .............................................60
8.15 Spare Parts Inventory. ..........................................................................................................60
8.16 Further Assurances................................................................................................................60
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 169 of 1056
Build Transfer Agreement – Page iv
8.17 Other Liens................................................................................................................................61
8.18 Restriction on Fundamental Changes. ............................................................................61
8.19 Records and Accounts. .........................................................................................................61
8.20 Data Breaches..........................................................................................................................61

9.1 Buyer’s General Obligations...............................................................................................61
9.2 Buyer’s Representative........................................................................................................62
9.3 Standard of Conduct..............................................................................................................62
9.4 Buyer Response. ......................................................................................................................62

10.1 Site Security..............................................................................................................................62
10.2 Preservation of Public and Private Access. ..................................................................63
10.3 Avoidance of Noise and Disturbance..............................................................................63
10.4 Fencing, Protection, Lighting.............................................................................................63
10.5 Site Services..............................................................................................................................63
10.6 Cleanup.......................................................................................................................................63
10.7 Regulated Materials. ..............................................................................................................63
10.8 Wildlife and Cultural Concerns. ........................................................................................63

11.1 Project Schedule. .....................................................................................................................64
11.2 Form of Project Schedule....................................................................................................64
11.3 Rejection of Project Schedule............................................................................................64
11.4 Alterations and Updates to Project Schedule..............................................................65
11.5 Recovery of Project Schedule. ...........................................................................................65
11.6 Progress Reports. ...................................................................................................................65
11.7 Progress Meetings. .................................................................................................................66
11.8 Schedule Relief. .......................................................................................................................66

12.1 Changes......................................................................................................................................66
12.2 Procedure for Changes. ........................................................................................................67
12.3 Continued Performance Pending Resolution of Disputes.......................................69
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 170 of 1056
Build Transfer Agreement – Page v
12.4 Preservation of Schedule and Contract Price..............................................................69
WORKMANSHI
13.1 Manner of Execution.............................................................................................................69
13.2 Condition of Materials..........................................................................................................69
13.3 Inspection..................................................................................................................................69
DRAWINGS
14.1 Drawings....................................................................................................................................70
14.2 Buyer Design Review............................................................................................................70
14.3 Documents not in accordance with Agreement. .........................................................71
14.4 Drawings Submitted..............................................................................................................71
14.5 Inspection of Drawings........................................................................................................71
14.6 Operating and Maintenance Instructions.....................................................................71
14.7 Buyer’s Use of Drawings. .....................................................................................................71
14.8 Errors in Drawings Supplied by Developer..................................................................72

15.1 Performance Guarantees.....................................................................................................72
15.2 Cost and Direction..................................................................................................................72
15.3 Buyer’s Right to Validate.....................................................................................................73
15.4 Timing.........................................................................................................................................73
15.5 Test Reports.............................................................................................................................73
15.6 Failure on Tests or Inspection...........................................................................................74
15.7 Duty to Advise of Defects, Errors, and Omissions......................................................74

16.1 EPC Milestones in the EPC Contract................................................................................74
16.2 Notice of Mechanical Completion.....................................................................................74
16.3 Notice of Substantial Completion.....................................................................................75
16.4 Notice of Final Completion. ................................................................................................75
16.5 Risk of Loss; Care, Custody and Control; Punch List Items. ...................................76
16.6 Dispatch Coordination. .........................................................................................................77
16.7 Removal of Equipment.........................................................................................................77
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 171 of 1056
Build Transfer Agreement – Page vi

17.1 Tax Indemnification. .............................................................................................................77
17.2 Transfer Tax.............................................................................................................................77
17.3 Purchase Price Allocation....................................................................................................77
17.4 Tax Benefits. .............................................................................................................................78
17.5 Tax Returns. ..............................................................................................................................78
17.6 Tax Contests.............................................................................................................................79
17.7 Duties and Excises..................................................................................................................80
17.8 Cooperation..............................................................................................................................80
17.9 Coordination with General Indemnification................................................................80

18.1 General Obligations. ..............................................................................................................80
18.2 Release On-Site. .......................................................................................................................81
18.3 Release Off-Site........................................................................................................................81
18.4 Liability. ......................................................................................................................................81
18.5 Pre-existing Regulated Materials.....................................................................................81
18.6 Notice..........................................................................................................................................82

19.1 Warranties. ...............................................................................................................................82
19.2 Warranty Period. ....................................................................................................................83
19.3 Repair of Defects.....................................................................................................................84
19.4 Warranty Period Extension................................................................................................84
19.5 Subcontractor Warranties. .................................................................................................84
19.6 Delay in Remedying Defects. ..............................................................................................84
19.7 Serial Defects. ...........................................................................................................................84
19.8 Assignment of Warranties..................................................................................................85

20.1 General. .......................................................................................................................................85
20.2 Delay Liquidated Damages.................................................................................................85
20.3 Performance Liquidated Damages. ..................................................................................86
20.4 Offset of EPC Contract Liquidated Damages................................................................86
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 172 of 1056
Build Transfer Agreement – Page vii
20.5 Calculations and Payments of Liquidated Damages.................................................87

21.1 Duty to Mitigate.......................................................................................................................87
21.2 Limitation of Liability...........................................................................................................87
21.3 Enforceability of Liquidated Damages. ..........................................................................87
INDEMNIFICATION
22.1 Indemnification.......................................................................................................................88
22.2 Title Indemnity and Liens. ..................................................................................................90
22.3 Intellectual Property.............................................................................................................91
22.4 Indemnity Period....................................................................................................................91
22.5 Tax Treatment of Indemnity Payments.........................................................................91
INSURANCE
23.1 Contractor’s and Subcontractors’ Insurance Coverage...........................................92
23.2 Buyer’s Insurance...................................................................................................................92
23.3 Developer’s Cooperation with Buyer..............................................................................92

24.1 Effect of Force Majeure........................................................................................................92
24.2 Notice of Occurrence.............................................................................................................92
24.3 Performance to Continue. ...................................................................................................93
24.4 Termination in Consequence of Force Majeure..........................................................93
24.5 Risk of Loss. ..............................................................................................................................93
DEFAULT
25.1 Developer Default...................................................................................................................93
25.2 Buyer Default. ..........................................................................................................................94
25.3 Cure Rights................................................................................................................................95
TERMINATION
26.1 Termination by Buyer...........................................................................................................95
26.2 Termination by Developer. .................................................................................................96
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 173 of 1056
Build Transfer Agreement – Page viii

ASSIGNMENT
28.1 Assignment of Developer’s Interests..............................................................................97
28.2 Assignment of Buyer’s Interests. ......................................................................................97
CONFIDENTIALITY
29.1 Confidentiality.........................................................................................................................97

30.1 Notices, Consents, and Approvals....................................................................................99
30.2 Entire Agreement................................................................................................................ 100
30.3 Amendment; Waiver.......................................................................................................... 100
30.4 Successors and Assigns. .................................................................................................... 100
30.5 Third Party Beneficiaries..................................................................................................100
30.6 Severability............................................................................................................................ 100
30.7 Further Assurances............................................................................................................. 100
30.8 Publicity..................................................................................................................................100
30.9 Independent Contractor. .................................................................................................. 101
30.10 Separation of Functions.................................................................................................... 101
30.11 Survival.................................................................................................................................... 101
30.12 Governing Law; Waiver of Jury Trial........................................................................... 101
30.13 Counterparts.........................................................................................................................102
30.14 Captions. .................................................................................................................................. 102
30.15 Offset. .......................................................................................................................................102
30.16 Time of the Essence............................................................................................................ 102
30.17 Non-Exclusive Remedy...................................................................................................... 102
30.18 Recitals.................................................................................................................................... 102
30.19 Developer Code of Conduct. ............................................................................................ 102
30.20 Prohibited Technology...................................................................................................... 102
30.21 Performance Security. ....................................................................................................... 103

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 174 of 1056
Build Transfer Agreement – Page ix
Appendix A Technical Specification and Scope of Work
Appendix B Project Schedule
Appendix C Major Subcontractors
Appendix D-1 Form of Certificate of Mechanical Completion
Appendix D-2 Form of Certificate of Substantial Completion
Appendix D-3 Form of Certificate of Final Completion
Appendix E Major Equipment Warranties
Appendix F Manuals
Appendix G Engineering Documents, Drawings, and Other Deliverables
Appendix H Key Personnel
Appendix I Release and Waiver of Liens and Claims
Appendix J Critical Milestones
Appendix K Form of Progress Report
Appendix L-1 Developer Insurance
Appendix L-2 Buyer Insurance
Appendix M Contractor’s Safety Assurance Program
Appendix N-1 Form of Change Order
Appendix N-2 Form of Change Order Request
Appendix N-3 Form of Change Order Notice
Appendix O Performance Tests
Appendix P Completion Criteria
Appendix Q List of Independent Engineers

Exhibit A Project Description
Exhibit B Reserved
Exhibit C Form of Assignment and Assumption Agreement
Exhibit D Form of Beginning of Construction Certificate
Exhibit E Form of Letter of Credit
Exhibit F Form of EPC Contract
Exhibit G Forms of Major Supply Agreements
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 175 of 1056
Build Transfer Agreement – Page x
Exhibit H Form of Consent
Schedule 2.3(a)(i)(D) Firm Date Reports
Schedule 2.6(c) Pro-ratable Items
Schedule 3.4(b) Developer Consents
Schedule 3.5 No Proceedings (Developer)
Schedule 3.12 Affiliate Transactions
Schedule 4.2(b) Project Company Consents
Schedule 4.3(a) No Proceedings (Project Company)
Schedule 4.3(b) Force Majeure Notices
Schedule 4.9 Liabilities and Permitted Indebtedness
Schedule 4.10 Project Assets
Schedule 4.11 Project Company Contracts
Schedule 4.12(a) Project Company Permits
Schedule 4.12(b) Deferred Permits
Schedule 4.12(c) Permit Proceedings
Schedule 4.13(a) Real Property Contracts
Schedule 4.13(b) Easements
Schedule 4.13(e) Zoning, Land Use, Condemnation
Schedule 4.14(a) Environmental Reports
Schedule 4.14(c) Environmental Consents and Liens
Schedule 4.20 Insurance
Schedule 4.22 Intellectual Property
Schedule 5.4(b) Buyer Consents
Schedule 5.5 No Proceedings (Buyer)
Schedule 5.6(a) Buyer Permits
Schedule 5.6(b) Buyer Regulatory Approvals
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 176 of 1056
THIS WORKING DRAFT DOES NOT CONSTITUTE A BINDING OFFER, SHALL NOT
FORM THE BASIS FOR AN AGREEMENT BY ESTOPPEL OR OTHERWISE, AND IS
CONDITIONED UPON EACH PARTY’S RECEIPT OF ALL REQUIRED
MANAGEMENT APPROVALS (INCLUDING FINAL CREDIT AND LEGAL
APPROVAL) AND ALL REGULATORY APPROVALS. ANY ACTIONS TAKEN BY A
PARTY IN RELIANCE ON THE TERMS SET FORTH IN THIS WORKING DRAFT OR
ON STATEMENTS MADE DURING NEGOTIATIONS PURSUANT TO THIS
WORKING DRAFT SHALL BE AT THAT PARTY’S OWN RISK. UNTIL THIS
AGREEMENT IS NEGOTIATED, APPROVED BY MANAGEMENT, EXECUTED,
DELIVERED AND APPROVED BY ALL REQUIRED REGULATORY BODIES, NO
PARTY SHALL HAVE ANY OTHER LEGAL OBLIGATIONS, EXPRESSED OR
IMPLIED, OR ARISING IN ANY OTHER MANNER UNDER THIS WORKING DRAFT
OR IN THE COURSE OF NEGOTIATIONS.
THIS BUILD TRANSFER AGREEMENT (this “Agreement”) is entered into as of [_____], 2022
(the “Execution Date”), by and between Idaho Power Company, an Idaho Corporation (“Buyer”), and
[______], a [____] (“Developer”). Buyer and Developer are referred to individually as “Party” and,
collectively, as the “Parties.”
RECITALS
WHEREAS, Developer owns one hundred percent (100%) of the outstanding membership
interests (the “Membership Interests”) in [_____], a special purpose entity (the “Project Company”);
WHEREAS, the Project Company is developing the [_______] facility (the “Project”) as further
described in Exhibit A, a true and correct copy is attached hereto and incorporated into this
agreement as if set forth in full at this point; and
WHEREAS, upon Mechanical Completion of the Project, Buyer desires to purchase all of the
Membership Interests in the Project Company from Developer, subject to the terms and conditions
set forth herein.
NOW THEREFORE, in consideration of the premises and mutual representations, warranties,
covenants and agreements set forth herein, and for other good and valuable consideration, the
receipt and sufficiency of which are hereby acknowledged, the Parties agree as follows.
AGREEMENT
1.1
Capitalized terms used in this Agreement have the meanings set forth below:
“1933 Act” means the Securities Act of 1933, as amended, and the rules and regulations promulgated
thereunder.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 177 of 1056
“[__%] ITC” means an ITC with respect to which the “energy percentage” (as defined in Section
48(a)(2) of the Code) is [___]percent ([__]%).]1
“After-Tax Basis” means, with respect to any payment to be actually or constructively received by
any Person, the amount of such payment (the “base payment”) supplemented by a further payment
(the “additional payment”) to that Person so that the sum of the base payment plus the additional
payment shall, after deduction of the amount of all federal income taxes required to be paid by such
Person in respect of the receipt or accrual of the base payment and the additional payment, using an
assumed rate equal to the then-highest marginal U.S. federal income tax rate in effect applicable to
corporations subject to tax under subchapter C of the Code (currently 21%, and ignoring state and
local taxes), taking into account any federal income tax savings realized by the recipient as a result of
the payment or the event giving rise to the payment, using an assumed rate equal to such marginal
tax rate (and assuming the recipient has sufficient taxable income to fully utilize on a current basis
any tax benefits resulting from the payment or the event giving rise to the payment), equals the
amount required to be received.
“Accepted Update” shall have the meaning set forth in 7.4(b).
“Affiliate” means with respect to any Person, any other Person who, directly or indirectly, Controls
such first Person or is Controlled by such first Person or is under common Control with such first
Person.
“Agreement” shall have the meaning set forth in the preamble of this Agreement.
“Assignment and Assumption Agreement” shall have the meaning set forth in 2.5(a)(i).
“Authorized Signatory” means, for each of Developer and Project Company, any of [____].
“Auxiliary Load Guarantee” means the auxiliary load guarantee set forth in Appendix O.
“Auxiliary Load Test” means the test performed in accordance with the requirements of Appendix O,
Section 7, and Appendix A and related Design Documents to determine whether the Auxiliary Load
Guarantee has been achieved.
“Availability” shall have the meaning set forth in Appendix O.
“Availability Guarantee” means the availability guarantee set forth in Appendix O.
“Availability Test” means the test performed in accordance with the requirements of Appendix O, and
Appendix A and related Design Documents to determine whether the Availability Guarantee has been
achieved.
“Bankruptcy Code” means the United States Bankruptcy Code, as in effect from time to time.
“Bankruptcy Laws” shall have the meaning set forth in 25.1(h).
“Base Purchase Price” shall have the meaning set forth in 2.6(a).
“Benefit Plan” means any employee benefit plan, as that term is defined in Section 3(3) of ERISA, or
other material pension, bonus, profit sharing, stock option or other agreement or arrangement
providing for employee remuneration or benefits, including a multiemployer plan, as that term is
defined in Section 4001(a)(3) of ERISA.

1 Note to Bidders: For storage projects co-located with solar.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 178 of 1056
“Business Day” means any day other than a Saturday, Sunday or other day on which banks are
authorized or required to be closed in Boise, Idaho.
“Buydown Amount” shall have the meaning set forth in 20.3(b).
“Buydown Right” shall have the meaning set forth in 20.3(b).
“Buyer” shall have the meaning set forth in the preamble to the Agreement.
“Buyer Consents” shall have the meaning set forth in 5.4(b).
“Buyer Default” shall have the meaning set forth in 25.2.
“Buyer Design Review Parties” shall have the meaning set forth in 14.2(a).
“Buyer Indemnified Parties” means Buyer and its Affiliates (including, after the Closing, Project
Company) and their respective directors, officers, employees, and agents.
“Buyer Material Adverse Change” means any change in condition after the Execution Date that
actually has, or is reasonably likely to have, a significant adverse effect on: (a) the validity or
enforceability of this Agreement or any of the other Transaction Documents as against Buyer; or (b)
the performance of or the ability of Buyer to perform its obligations under the Transaction
Documents to which it is a party.
“Buyer Obligation” shall have the meaning set forth in 11.2.
“Buyer Permits” shall have the meaning set forth in 5.6(a).
“Buyer’s Knowledge” means, as of the date on which any representation and warranty or other matter
qualified by Buyer’s Knowledge is required to be made by Buyer, the actual knowledge, after
reasonable inquiry of the employees of the Buyer or any of its Affiliates who are responsible for, or
have direct involvement, in the subject matter of the representation and warranty or other matter
involved, of any of one or more of the following persons (and any successor person holding the same
title or the functional equivalent and having responsibility for the transaction contemplated by this
Agreement): [______].
“Buyer’s Representative” means the natural Person designated as such by Buyer pursuant to Section
9.2(a), which shall initially be [_______].
“Buyer-Caused Delay” shall mean an actual delay to the critical path of any portion of the Work that
in turn delays the completion of such Work past any applicable deadline established by this
Agreement or the EPC Agreement (as applicable) caused solely by Buyer’s failure to respond in
accordance with Section 9.4. For the avoidance of doubt, where this Agreement or the EPC Contract
sets forth a period of time for review, approval or inspection by Buyer or “Owner,” as such term is
defined under the EPC Contract, Buyer shall not be deemed to have delayed the critical path of the
Work until the date that occurs after the date by which Buyer or “Owner,” as the case may be, was
required to act.
“Buyer-Caused Delay Costs” shall have the meaning set forth in 2.6(d).
“Buyer-Initiated Change” shall have the meaning set forth in 12.2(b).
“Buyer-Initiated Change Order Costs” shall have the meaning set forth in 2.6(e).
“Capacity Guarantee” means the capacity guarantee set forth in Appendix O.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 179 of 1056
“Capacity Test” means the test performed in accordance with the requirements of Appendix O, and
Appendix A and related Design Documents to determine whether the Capacity Guarantee has been
achieved.
“CEII” means Critical Energy/Electric Infrastructure Information, as defined by the Code of Federal
Regulations, Title 18, Section 388. CEII includes both Critical Energy Infrastructure Information and
Critical Electric Infrastructure Information. As used in this Agreement, Critical Energy Infrastructure
Information means specific engineering, vulnerability, or detailed design information about
proposed or existing critical infrastructure that: (i) Contains detail about the production, generation,
transportation, transmission, or distribution of energy; (ii) Could be useful to a person planning an
attack on critical infrastructure; (iii) Is exempt from mandatory disclosure under the Freedom of
Information Act, 5 U.S.C. 552; (iv) Does not simply give the general location of the critical
infrastructure.
“Certificate of Final Completion” shall have the meaning set forth in 16.4(a).
“Certificate of Substantial Completion” shall have the meaning set forth in 16.3(a).
“Change” means any alteration of the Work whether by way of addition, deletion, modification,
substitution or omission as authorized in accordance with Section 12.1, but shall not include any
instruction to the extent that such instruction is issued as a result of any breach by Developer of this
Agreement or otherwise to require Developer to fulfill its obligations under this Agreement. Changes
shall include changes to Scope of Work, Project Schedule, and Purchase Price. Re-performance of any
Work required to rectify or recover Work that is necessary due to Developer’s (or its Contractor’s or
any Subcontractor’s) negligence or breach of this Agreement shall not constitute a Change.
“Change in Law” means (i) the enactment, adoption, promulgation, modification, replacement,
successor or repeal or any change in application, after the Execution Date of any applicable Law; (ii)
the imposition of any material conditions on the issuance or renewal of any applicable Permit after
the Execution Date (notwithstanding the general requirements contained in any applicable permit
at the time of application or issue to comply with future laws, ordinances, codes, rules, regulations
or similar legislation); (iii) a change in any utility rate schedule or tariff approved by any
Governmental Authority; or (iv) revocation of any tax credit, which establishes requirements or
revokes beneficial laws or rules affecting the value or availability of tax credits, owning, supplying,
constructing, installing, operating, or maintaining the Project, or other performance of the Parties’
obligations hereunder or which has a material adverse effect on the cost to either Party of
performing such obligations..
“Change of Control” shall mean:
(a) with respect to any Person, the occurrence of any one of the following with respect to
such Person: (i) the consolidation with or merger into any other Person by such Person or by
any other Person, or (ii) a direct or indirect assignment, conveyance, transfer, lease,
exchange, conversion or other disposition of the equity interests in such Person or any other
Person, or in either case the voting rights with respect thereto; in either case, as a result of
which the Person or Persons that Control, directly or indirectly, such Person shall cease to,
directly or indirectly, Control such Person; and
(b) with respect to Developer, Developer Parent ceases to be an Affiliate of Developer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 180 of 1056
“Change Order” means any order identified as a “Change Order” and issued by Buyer to Developer
that affects the Work, and may affect the Project Schedule, and in accordance with the terms of this
Agreement.
“Change Order Notice” means the written notice of Change Order issued to Developer by Buyer
pursuant to ARTICLE 12, substantially in the form set forth in Appendix N-3.
“Change Order Request” means the written request for a Change Order issued to Buyer by Developer
pursuant to ARTICLE 12, substantially in the form set forth in Appendix N-2.
“Charge Rate Guarantee” means the charge rate guarantee set forth in Appendix O.
“Charge Rate Test” means the test performed in accordance with the requirements of Appendix O,
and Appendix A and related Design Documents to determine whether the Charge Rate Guarantee has
been achieved.
“Claim” or “Claims” means any indemnity, demand, demand letter, claim, litigation, cause of action,
notice of noncompliance or violation, or other proceeding.
“Closing” shall have the meaning set forth in 2.7(a).
“Closing Date” shall have the meaning set forth in 2.7(a).
“Code” means the Internal Revenue Code of 1986, as the same may be amended from time to time,
including any amendments or any substitute or successor provisions thereto.
“Confidential Information” shall have the meaning set forth in 29.1(a).
“Confidentiality Affiliates” shall have the meaning set forth in 29.1(a).
“Construction Period Credit Support” shall have the meaning set forth in 6.1(b).
“Contract” means any agreement, lease, license (other than a Permit), note, bond, evidence of
Indebtedness, mortgage, indenture, security agreement, purchase order, binding bid or other
instrument or contract, whether written or oral.
“Contractor” shall mean the primary contractor, as approved by Buyer, engaged by Project Company
pursuant to the EPC Contract.
“Contractor Drawings and Manuals” means all drawings and information developed by Contractor
and Subcontractors and provided to Developer in connection with Contractor’s and any
Subcontractor’s obligations under the EPC Contract, all in accordance with the requirements of the
Agreement.
“Contractor’s Safety Assurance Program” means that certain safety program created and
administered by Contractor pursuant to the EPC Contract, to be attached as Appendix M.
“Control” of any Person means the possession, directly or indirectly, of the power either to (a) vote
fifty percent (50%) or more of the equity, capital or profits, or other interests having ordinary voting
power for the election of directors (or other comparable controlling body) of such Person or (b) direct
or cause the direction of management or policies of such Person, whether through the ownership of
voting securities or interests, by contract or otherwise, excluding in each case, any secured lender of
such Person.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 181 of 1056
“Construction Costs” the amounts actually incurred by the Project Company, Developer or its
Affiliates for payments made under the EPC Contract.
“Corrupt Practices Laws” means (i) the Foreign Corrupt Practices Act of 1977 (Pub. L. No. 95-213,
§§101-104), as amended, and (ii) any other applicable law relating to bribery, kick-backs or anti-
corruption.
“Credit Support” shall mean [(a) cash collateral, (b) a Payment and Performance Bond, or (c) a letter
of credit in the form of Exhibit E,]2 attached hereto, from a Creditworthy Bank.
“Creditworthy Bank” shall mean a U.S. state or federally chartered commercial bank (or U.S. branch
of a foreign commercial bank) which has (a) assets of at least ten billion dollars ($10,000,000,000)
and (b) senior unsecured long term debt or deposits that are rated at least “A-” (or its current
equivalent) by S&P or Fitch and at least “A3” (or its then current equivalent) by Moody’s.
“Critical Milestones” means certain Milestones, set forth in Appendix J, designated in the Project
Schedule as milestones that are critical to the ability of the Project to achieve Substantial Completion
by the Outside Closing Date.
“Critical Milestone Completion Date” means the completion date, set forth in Appendix J, by which
Developer will achieve the corresponding Critical Milestone.
“Data Room” means the virtual data room set up for the Project Company and Project, accessible at
[___].
“Defect” shall have the meaning set forth in 19.1(a)(i).
“Deferred Permit” means, as of any date, all Project Company Permits that have not yet been obtained,
(a) the procurement of which is not required to have occurred on or before such date by applicable
Law or the requirements of any Project Company Contract and (b) as to which Developer has a
reasonable expectation that such Project Company Permits will be obtained in the ordinary course
of business.
“Delay Liquidated Damages” means either Mechanical Completion Liquidated Damages or
Substantial Completion Liquidated Damages, or both.
“Delay Liquidated Damages Cap” shall have the meaning set forth in Section 20.2(b).
“Design Documents” shall have the meaning set forth in 14.2(a)
“Developer” shall have the meaning set forth in the preamble of this Agreement.
“Developer Consents” shall have the meaning set forth in 3.4(b).
“Developer Default” shall have the meaning set forth in 25.1.
“Developer Firm Date Conditions” shall mean those conditions to achievement of the Firm Date, as
set forth in 2.3(a)(iii).
“Developer IT Asset” means all of the software, computer systems, workstations, routers, hubs,
switches, circuits, servers and other information technology equipment of the Developer used in
connection with the Project Company or the Project Assets.

2 Note to Bidders: Forms of credit support remain subject to IPC review.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 182 of 1056
“Developer Party” means each of Developer, Contractor, any Subcontractor, and, if applicable,
Developer’s guarantor.
“Developer Security” shall have the meaning set forth in 25.1.
“Developer’s Equipment” means all of the equipment, materials, apparatus, structures, tools,
consumables, supplies and other goods provided and used by Developer, Contractor, and any
Subcontractors for performance of the Work but which are not intended to be incorporated into the
Project.
“Developer’s Knowledge” means, as of the date on which any representation and warranty or other
matter qualified by Developer’s Knowledge is required to be made by Developer, the actual
knowledge, after reasonable inquiry of the employees of the Developer or any of its Affiliates who are
responsible for, or have direct involvement, in the subject matter of the representation and warranty
or other matter involved, of any of one or more of the following persons (and any successor person
holding the same title or the functional equivalent and having responsibility for the Project or
transaction contemplated by this Agreement): [______].
“Developer’s Parent” means [____].
“Developer’s Representative” shall have the meaning set forth in 8.13(a).
“Developer-Initiated Change” shall have the meaning set forth in 12.2(a).
“Dollars” and the “$” symbol means the lawful currency of the United States of America.
“Draft Manuals” shall have the meaning set forth in 8.9(c).
“Easements” shall have the meaning set forth in 4.13(b).
“Emerging Contaminants” shall mean chemicals and other substances that are not currently
regulated under any Environmental Law, have been discovered in natural streams, and potentially
cause deleterious effects in aquatic life, including vegetation and water quality, at environmentally
relevant concentrations, including but not limited to per- and polyfluoroalkyl substances.
“EMS” means the control and monitoring system, including central computer, remote PC system and
ancillary communication terminals and cables installed inside individual storage facility controllers,
as well as inside central control location, as more fully described in Appendix A.
“Energy Capacity” shall have the meaning set forth Appendix O.
“Environmental Law” means any applicable Law that is in effect as of the Execution Date and relates
to Regulated Materials, pollution, occupational health and safety (to the extent such relates to
exposure to Regulated Materials), or the protection of the environment, natural resources, or wildlife,
including, without limitation, (a) the Comprehensive Environmental Response, Compensation and
Liability Act, 42 U.S.C. § 9601 et seq. (“CERCLA”), (b) the Resource Conservation and Recovery Act,
42 U.S.C. § 6901 et seq., (c) the Federal Water Pollution Control Act, 33 U.S.C. § 1251 et seq. (the
“Clean Water Act”), (d) the Clean Air Act, 42 U.S.C. § 7401 et seq. (“CAA”), (e) the Hazardous Materials
Transportation Authorization Act of 1994, 49 U.S.C. § 5101 et seq., (f) the Occupational Safety and
Health Act, 29 U.S.C. § 651 et seq., (g) the Toxic Substances Control Act, 15 U.S.C. §§ 2601 through
2629, (h) the Oil Pollution Act, 33 U.S.C. § 2701 et seq., (i) the Emergency Planning and Community
Right-to-Know Act, 42 U.S.C. § 11001 et seq., (j) the Safe Drinking Water Act, 42 U.S.C. §§ 300f through
300j, (k) the Federal Insecticide, Fungicide, & Rodenticide Act, 7 U.S.C. § 136 et seq., (l) the
Endangered Species Act, 16 U.S.C. § 1531 et seq., (m) the Migratory Bird Treaty Act, 16 U.S.C. § 703
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 183 of 1056
et seq., (n) the Bald and Golden Eagle Protection Act, 16 U.S.C. § 668 et seq., (o) the National Historic
Preservation Act, 16 U.S.C. §§ 470a et seq., (p) the National Environmental Policy Act, 42 U.S.C. § 4321
et seq., (q) the Rivers and Harbors Act of 1899, (r) state equivalents to items (a) through (q), and (s)
applicable implementing rules and regulations of Governmental Authorities for items (a) through (r).
“EPC Change Order” means any order identified as a “Change Order” and issued by the Project
Company to Contractor, pursuant to the EPC Contract.
“EPC Contract” means that certain Engineering, Procurement, and Construction Contract, to be
entered into by and between the Project Company and Contractor for the engineering, procurement,
construction, and commissioning of the Project, in form and substance acceptable to Buyer.
“EPC Contract Price” means the total amount that would be due to Contractor under the EPC Contract
for the full satisfaction of all of Contractor’s obligations thereunder, including the completion of the
Project at the Planned Capacity.
“Equipment” means the equipment relating to the Project required for Developer to complete the
Work, as described in Appendix E, excluding any Developer’s Equipment.
“Estoppels” shall have the meaning set forth in 2.5(a)(vii).
“Execution Date” shall have the meaning set forth in the preamble to this Agreement.
“Final Completion” means the Project demonstrates that all of the Final Completion Criteria have
been satisfied in accordance with the requirements of this Agreement.
“Final Completion Criteria” shall have the meaning set forth in Appendix P.
“Final Performance Test Report” shall have the meaning set forth in 15.5(b).
“Final Purchase Price Allocation” shall have the meaning set forth in 17.3.
“Firm Date” shall have the meaning set forth in 2.3(a).
“Firm Date Deadline” shall have the meaning set forth in 2.11(a)(viii).
“Firm Date Reports” shall mean those Reports specifically identified on Schedule 2.3(a)(i)(D).
“Force Majeure” means an event or circumstance which causes a delay to the critical path of any
portion of the Work that in turn delays the completion of such Work, but only if and to the extent
such event or circumstances (a) was not reasonably foreseeable, (b) is not within the reasonable
control of or caused by the fault or negligence of the Party affected thereby, (c) is such that the
affected Party has been unable to remedy, prevent, or overcome the event or circumstance, despite
having taken commercially reasonable precautions and measures in order to prevent or avoid such
event or circumstance or mitigate the effect of such event or circumstance, and (d) which by the
exercise of reasonable diligence consistent with Prudent Industry Practice such party could not
reasonably have been expected to avoid. To the extent that such event satisfies the requirements set
forth in the preceding sentence, Force Majeure may include: acts of God, earthquake, volcano,
tornado, or flood; sabotage, terrorism, war, revolution, civil disturbance, expropriation, confiscation
or nationalization, blockades, embargoes or sanctions (for the avoidance of doubt, excluding the
imposition of taxes, duties, and tariffs); long-term port of entry closure, rationing or allocation, at the
request or insistence of any Governmental Authority; Judgment by court order of a Governmental
Authority; emergencies declared by a Governmental Authority requiring shutdown or forced
curtailment of the Project; or worldwide, national or regional labor disputes. Regardless of the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 184 of 1056
preceding sentences,none of the following shall constitute Force Majeure, except to the extent caused
by an independent, identifiable event of Force Majeure causing such condition: (A) delay or failure
by Developer or Contractor to obtain any Project Company Permit, other than the delay or failure to
obtain Project Company Permits by: (1) revocation, stay, or similar action by a Governmental
Authority of a Project Company Permit after issuance thereof by a Governmental Authority, or (2)
the failure of a Governmental Authority to comply with rules, procedures, or other Law applicable to
such Governmental Authority; (B) delay or failure by Developer or Contractor to obtain permission
to operate or any other required approval to interconnect to the grid; (C) shipping accidents or
unavailability of preferred shipping methods; (D) supply chain issues; or (E) delays in customs
clearance or delays or other problems associated with the issuance, suspension, renewal,
administration or withdrawal of, or any other problem directly or indirectly relating to, any
governmental approval or the applications therefor, including but not limited to any such delays or
failures with respect to the Withhold Release Order issued by U.S. Customs and Border Protection on
June 24, 2021 pursuant to Section 307 of the Tariff Act of 193.
“Full Notice to Proceed” shall mean the notice to proceed, issued pursuant to the EPC Contract, that
authorizes the Contractor to begin the full scope of work of the EPC Contract and is not limited or
contingent upon the satisfaction of any condition.
“Fundamental Representation” means any of Sections 3.1 (Organization), 3.2 (Authority), 3.3
(Binding Agreement), 3.4 (No Conflicts), 3.7 (Membership Interests),4.1 (Organization of Project
Company), 4.2 (No Conflicts of Project Company), 4.5 (No Prior Business of Project Company), 4.7
(Subsidiaries and Joint Ventures), 5.1 (Organization), 5.2 (Authority), 5.3 (Binding Agreement), and
5.4 (No Conflicts).
“GAAP” means United States generally accepted accounting principles.
“Gap Warranty” shall have the meaning set forth in 19.1(c).
“Governmental Authority” means any supranational, federal, state, or other political subdivision
thereof, including any municipality, township, and county, and any entity exercising executive,
legislative, judicial, regulatory, or administrative functions of or pertaining to government, including
any corporation or other entity owned or controlled by any of the foregoing, in each case, having
jurisdiction over Developer, Contractor, any Subcontractor, Buyer, the Project, or this Agreement or
any other Transaction Document.
“Guaranteed Roundtrip Efficiency Liquidated Damages” shall have the meaning set forth in 20.3(b).
“Guaranteed Availability Liquidated Damages” shall have the meaning set forth in 20.3.
“Guaranteed Capacity Liquidated Damages” shall have the meaning set forth in 20.3.
“Guaranteed Power Capacity” shall have the meaning set forth in Appendix O.
“Guaranteed Rated Energy Capacity” shall have the meaning set forth in Appendix O.
“Guaranteed Substantial Completion Date” shall have the meaning set forth in 20.2(b).
“Indebtedness” means (a) any indebtedness for borrowed money or issued in substitution for or
exchange of indebtedness for borrowed money, (b) any indebtedness evidenced by any note, bond,
debenture, or other debt security, (c) any indebtedness for the deferred purchase price of property
or services, (d) Liabilities under any interest rate protection agreement, interest rate future
agreement, interest rate option agreement, interest rate swap agreement, or other similar agreement
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 185 of 1056
designed to protect the Project Company against fluctuations in interest rates or other currency
fluctuations, (e) all Liabilities with respect to any commitment by which the Project Company assures
a creditor against loss (including contingent reimbursement obligations with respect to letters of
credit) and all other Liabilities guaranteed in any manner by the Project Company, (f) any obligations
under capitalized leases, conditional sales contracts, and other similar title retention instruments
whether short term or long term, (g) any indebtedness secured by a Lien on any property or assets
of the Project Company and/or any off-balance sheet financings.
“Indemnified Party” shall have the meaning set forth in 22.1(c).
“Indemnifying Party” shall have the meaning set forth in 22.1(d).
“Indemnity Period” shall have the meaning set forth in 22.4.
“Independent Engineer” the engineering firm selected by the Parties for the Project from the list of
mutually acceptable nationally-recognized engineering firms included in Appendix Q,
“Initial Credit Support” shall have the meaning set forth in 6.1(a).
“Interconnection Agreement” means an agreement for interconnection services, by and between
Project Company and Transmission Provider, in form and substance reasonably acceptable to Buyer
and shall, at a minimum, provide Network Resource Interconnection Service.
“Interconnection Costs” means costs, including transmission customer interconnection costs,
transmission provider interconnection costs, network upgrades, and affected systems costs, if any,
charged by the Transmission Provider, applicable balancing authority, or operators of affected
systems, or costs incurred by the Developer, Project Company, or Contractor in connection with the
interconnection of the Project.
“IPUC” means the Idaho Public Utility Commission.
“IPUC Approval” shall have the meaning set forth in Section 2.1.
“IRS Notice” means IRS Notice 2018-59, 2018-28 I.R.B. 196 (as modified by Notice 2019-43, 2019-
31 I.R.B. 487, Notice 2020-41, 2020-25 I.R.B. 954, and Notice 2021-41, 2021-29 I.R.B.), and any
subsequent amendment or modification thereto or successor guidance.
[“ITC” means the energy credit pursuant to Section 48 of the Code.
“ITC Representations” means the representations in Section 4.17(k) and in the Beginning of
Construction Certificate.]3
“Judgment” means any judgment, order, award, injunction, writ, or decree of any Governmental
Authority.
“Key Personnel” means, with respect to Developer, Contractor, and any Major Subcontractor
performing a material portion of the Work, a project executive, a project manager, a project senior
superintendent, and a project superintendent for the Project.
“Late Payment Rate” means an amount equal to the Prime Rate plus 200 basis points; provided, that
in no event shall the Late Payment Rate exceed the maximum allowable usurious rate permitted by
Applicable Law.

3 Note to bidders: This would apply to any storage projects co-located with solar projects.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 186 of 1056
“Law” means all laws (including each Environmental Law), statutes, codes, acts, ordinances, orders,
judgments, decrees, injunctions, rules, regulations, permits, licenses, authorizations, directions, and
requirements of any Governmental Authority having the force and effect of law, and as to any Person,
the organizational, or governing documents of such Person.
“Lender” means the lender and/or equity investor (including any trustee or agent on behalf of such
lender and/or equity investor (including tax equity investors)) of any Party or any of its Affiliates
(including Project Company) directly or indirectly providing development, bridge, construction
and/or permanent equity and/or debt financing or refinancing of the development, construction,
ownership, leasing, operation or maintenance (including working capital) of the Project, whether
that financing or refinancing takes the form of private or public debt or equity or any other form, and
any Person providing interest rate protection agreements to hedge any of the foregoing obligations.
“Level 3 Project Schedule” shall mean a project coordination schedule using an integrated critical
path methodology that includes detailed input from the project management team. The Level 3
Project Schedule shall include, at a minimum, all major milestones, including the Critical Path
Milestones, and all material elements of design, engineering, procurement, construction, testing,
commissioning, and/or start-up.
“Liabilities” means all Claims including those relating to Environmental Laws, demands, damages,
losses, Taxes, liabilities, or judgments, including all interest, penalties, fines and other sanctions, and
any reasonable costs or expenses in connection therewith, including attorneys’ and consultants’ fees
and expenses.
“Lien” means any mortgage, pledge, security interest, encumbrance, option, defect, lien, charge, or
other similar right of any Person of any kind, including any lien or charge arising by statute or other
law.
“Made Available” shall mean that the materials (a) with respect to materials required to be provided
on or prior to the Execution Date, the Firm Date, or the Closing Date, (i) were posted to the Data Room
or otherwise provided by Developer at least seven (7) days prior to the relevant date or (ii) were
otherwise received by Buyer at least seven (7) days prior to the relevant date, and (b) with respect
to other materials, were posted to the Data Room or otherwise provided by Developer, with notice
thereof provided to Buyer’s Representative.
“Major Equipment” means the electrochemical cells consisting of an anode and a cathode separated
by an electrolyte, power converters/inverters with controller, battery energy management system,
EMS, and transformers and switchgears. forming part of the Project.
“Major Equipment Warranties” means those certain manufacturer warranties for the Major
Equipment set forth in Appendix E.
“Major Subcontractors” means [____]and those other Subcontractors supplying Major Equipment.
“Major Supply Agreements” means the agreements pursuant to which the Major Subcontractors will
supply the Major Equipment, specifically: [__], forms of which are attached hereto as Exhibit H.
“Manager” means [______________].
“Material Adverse Change” means any change in condition after the Execution Date that has, or is
reasonably likely to have, a significant adverse effect on: (a) the validity or enforceability of this
Agreement, the Transaction Documents, or any of the other Project Company Contracts; (b) the
business, assets, prospects, operations, property, or condition (financial or otherwise) of the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 187 of 1056
Developer, Project Company, Contractor, any Major Subcontractor, any guarantor, or the Project; (c)
the Project’s ability to operate and deliver energy to the System; (d) the performance of or the ability
of Developer, Project Company, Contractor, any Subcontractor, or any guarantor, if applicable, to
perform its respective obligations under the Transaction Documents or the Project Company
Contracts to which it is a party; or (e) Developer fails to meet the Credit Support requirements of
Article 6. For the avoidance of doubt, the following will not be considered when determining whether
a Material Adverse Change has occurred: any change, event, effect or occurrence (or changes, events,
effects, or occurrences taken together) resulting from (i) any change generally affecting the
international, national, or regional electric storage, supply chain, transmission, or distribution
industry; (ii)any change generally affecting the international, national, or regional wholesale or retail
markets for or costs of electric power; (iii) any change generally affecting the energy storage business;
(iv) any change in general regulatory or political conditions, including any engagements of hostilities,
acts of war, or terrorist activities or changes imposed by a Governmental Authority associated with
additional security; (v) any change in GAAP or other applicable accounting or auditing standards or
industry standards; (vi) any change in the financial, banking, or securities markets (including any
suspension of trading in, or limitation on prices for, securities on the New York Stock Exchange,
American Stock Exchange, or Nasdaq Stock Market), or any change in the general national or regional
economic financial conditions; or (vii) any actions or omissions required to be taken or not taken by
Developer or the Project Company in compliance with this Agreement, the Transaction Documents, or
otherwise consented to by, or at the written request of, Buyer pursuant to this Agreement.
“Material Update” shall have the meaning set forth in 7.4(b).
“Materials” means the Intellectual Property, equipment, machinery, apparatus, materials, articles,
and things of all kinds to be provided and incorporated into the Project by Developer, Contractor and
the Subcontractors pursuant to this Agreement (including spare parts and tools to be supplied
hereunder), other than the Equipment.
“Mechanical Completion” means all of the Mechanical Completion Criteria has been satisfied in
accordance with the requirements of this Agreement.
“Mechanical Completion Criteria” shall have the meaning set forth in Appendix P.
“Mechanical Completion Delay Liquidated Damages” shall have the meaning set forth in 20.2(a).
“Membership Interests” shall have the meaning set forth in the recitals to the Agreement.
“Milestone” shall have the meaning set forth in 11.1.
“Milestone Completion Dates” shall have the meaning set forth in 11.1.
“Moody’s” means Moody’s Investors Service, Inc.
“Mutual Firm Date Conditions” shall mean those conditions to achievement of the Firm Date, as set
forth in 2.3(a)(i).
“Network Resource Interconnection Service” shall have the meaning set forth in the Transmission
Provider’s Open Access Transmission Tariff.
“Noise Guarantee” means the noise guarantee set forth in Appendix O.
“Noise Test” means the test performed in accordance with the requirements of Appendix O, and
Appendix A and related Design Documents to determine whether the Noise Guarantee has been
achieved.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 188 of 1056
“Operating Period Credit Support” shall have the meaning set forth in 6.1(d).
“Outside Closing Date” shall have the meaning set forth in 2.11(a)(v), as may be extended pursuant
to Section 20.2(a).
“Party” and “Parties” shall have the meanings set forth in the preamble of this Agreement.
“Performance Guarantee Tests” means the Auxiliary Load Test, the Availability Test, the Capacity
Test, the Charge Rate Test, the Noise Test, the Power Factor Test, the Ramp Rate Test, the Response
Time Test, and the Roundtrip Efficiency Test, all as set forth in Appendix O and intended, in each case,
to determine whether the respective Performance Guarantees have been achieved.
“Performance Guarantees” means the Auxiliary Load Guarantee, the Availability Guarantee, the
Capacity Guarantee, the Charge Rate Guarantee, the Noise Guarantee, the Power Factor Guarantee,
the Ramp Rate Guarantee, the Response Time Guarantee, and the Roundtrip Efficiency Guarantee, in
each case as set forth in Appendix O.
“Performance Liquidated Damages” means the Guaranteed Capacity Liquidated Damages, the
Guaranteed Roundtrip Efficiency Liquidated Damages, and the Guaranteed Availability Liquidated
Damages.
“Performance Liquidated Damages Cap” shall have the meaning set forth in 20.3.
“Permit” means any written authorization, approval, consent, waiver, exception, variance, order,
notice, license, filing, registration, ruling, permit, tariff, certification, exemption, and other action by,
to, or with any Governmental Authority.
“Permitted Equity Exceptions” means (a) restrictions on transfer of the Membership Interests under
any applicable federal, state, or foreign security laws and (b) the Liens described in clauses (d) and
(g) of the definition of Permitted Liens.
“Permitted Indebtedness” means (a) any Indebtedness that is (or will be) released on or prior to
Closing and (b) any Indebtedness set forth on Schedule 4.9.
“Permitted Liens” means any: (a) Lien for Taxes (i) not yet due and payable, or (ii) being contested
in good faith and for which adequate reserves have been established and held by the Project Company
in accordance with GAAP; (b) easements or other encumbrances on Real Property affecting the
Project required to be granted (i) pursuant to applicable Laws or (ii) by order of a Governmental
Authority; (c) mechanics’, materialmen’s (and other similar liens for construction in progress),
carriers’, workers’, repairers’, and other similar Liens arising or incurred in the ordinary course of
business which are (i) not yet due and payable or (ii) being contested in good faith and for which
adequate reserves have been established and held by the Project Company in accordance with GAAP;
(d) Liens created pursuant to, or as a result of the existence of, this Agreement or any Transaction
Document; (e) any Liens approved or consented to in writing by Buyer, including any Liens expressly
granted under, or created by, existing, or pursuant to, the terms and conditions of the Project
Company Contracts or Project Company Permits included in Developer’s disclosure schedules as of
the Execution Date or in any Accepted Update; (f) Liens relating to any Contract executed with a
Lender; (g) any Lien that is (or will be) released on or prior to Closing; (h) minor defects, easements,
rights-of-way, restrictions, and other similar encumbrances and minor imperfections in title that do
not impair the affected property or impair the development, construction, commissioning, ownership,
and commencement of operation of the Project at the Site; (i) any fee mortgage (other than where the
applicable Real Property is a fee) or ground lease or similar Lien that is superior to the interest granted
under the applicable Real Property Contract but is subject to a fully executed and recorded non-
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 189 of 1056
disturbance agreement reasonably acceptable to Buyer; (j) exceptions to title listed in the Title Policy
and approved by Buyer; and (k) Liens arising by, through, or under Buyer.
“Person” means any natural person, corporation, general or limited partnership, limited liability
company, firm, joint venture, estate, association, trust, government, governmental agency, or any
other entity, whether acting in an individual, fiduciary, or other capacity.
“Phase I ESA” shall have the meaning set forth in 2.3(a)(ii)(E).
“Phase II ESA” shall have the meaning set forth in 2.3(a)(ii)(E).
“Planned Roundtrip Efficiency Rate” means [_____] ([__]%]).
“Planned Capacity” means [____] megawatts ([_] MW) of storage capacity at [____] ([_]) hours of
continuous discharge.
“Power Factor Guarantee” means the power factor guarantee set forth in Appendix O.
“Power Factor Test” means the test performed in accordance with the requirements of Appendix O,
and Appendix A and related Design Documents to determine whether the Power Factor Guarantee
has been achieved.
“Pre-Closing Tax Period” means any taxable year or other taxable period ending on or before the
Closing Date.
“Pre-Closing Taxes” means (a) any Taxes imposed on or with respect to the Project Company, the
Project Assets, or the Project with respect to any taxable period ending on or prior to the Closing Date
and, in the case of any Straddle Period, the portion of such period ending on and including the Closing
Date; (b) any Taxes imposed on or with respect to the Developer, Contractor, any Subcontractor, or
any of their respective Affiliates; (c) any Taxes for which Developer is responsible under Section 17.2
and Section 17.7; (e) any Claims and Liabilities (including any Tax Benefits Loss) attributable to a
breach by Developer of any of its representations, warranties, or covenants pursuant to Section 4.17,
Section 4.18, or Article 17; (f) any Taxes and Tax Benefits Losses attributable to a breach by
Developer of any of its representations, warranties, or covenants in this Agreement; (g) Taxes
imposed on Buyer or any of its Affiliates, as a transferee or successor, by contract or pursuant to any
Law, which Taxes relate to an event or transaction occurring prior to the close of business on the
Closing Date; (h) payment of any Tax as a result of any obligation to indemnify any other Person or
as a result of any obligation under any agreement or arrangement (other than any obligation or
indemnification for Tax pursuant to any Project Company Contract relating to a Tax period beginning
after the Closing Date or the portion of any Straddle Period beginning after the Closing Date) entered
into on or prior to the Closing Date; (i) any withholding Taxes on Buyer or any of its Affiliates
resulting from the transactions contemplated by this Agreement to the extent not withheld pursuant
to Section 2.7; and (j) any reasonable costs and expenses associated with the investigation, review,
remediation, and resolution of any of the foregoing items described in clauses (a) to (i), including
reasonable legal fees and expenses attributable thereto.
“Pre-Closing Liabilities” means each of the following with respect to the Developer or, on and prior
to the Closing Date, the Project Company:
(a) Liabilities from any violation of applicable Law (including Environmental Laws) at
the Site or with respect to the Project on or prior to the Closing Date and Liabilities from
any violations of applicable Law (including Environmental Laws) at the Site or with respect
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 190 of 1056
to the facility on or prior to Final Completion of the Project to the extent caused by
Developer, Subcontractors, or any of its or their Affiliates or representatives;
(b) Liabilities from any environmental condition on or under the Site existing on or
prior to the Closing Date and Liabilities from any environmental condition on or under the
Site existing on or prior to Final Completion of the Project to the extent caused or worsened
by Developer, Subcontractors, or any of its or their Affiliates or representatives, in each
case, including remediation costs, natural resource damages, bodily injury, or property
damage;
(c) Liabilities from off-site transportation, disposal, recycling, or storage of any
hazardous substances or substance or material controlled by an Environmental Law on the
Site on or prior to the Closing Date and Liabilities from off-site transportation, disposal,
recycling, or storage of any hazardous substances or substance or material controlled by
an Environmental Law on the Site on or prior to Final Completion of the Project to the
extent caused by Developer, Subcontractors, or any of its or their Affiliates or
representatives, in each case, including Liabilities related to remediation, natural resource
damages, bodily injury, or property damage;
(d) Liabilities related to any employee benefit plan of Developer (or its Affiliates
(including ERISA Affiliates)) or any of its contractors with respect to its or their current or
former employees or contractors;
(e) Liabilities under the Project Contracts, the Real Property Contracts, and Project
Permits incurred or arising prior to Final Completion of the Project;
(f) Liabilities related to the development, engineering, procurement, construction,
commissioning, and operation, maintenance, repair, or use of the Project prior to Final
Completion of the Project, including construction costs;
(g) Liabilities for personal injury, property damage, or tort arising out of the
engineering, development, construction, commissioning of the Project Assets or the Project
(h) Liabilities for personal injury, property damage, or tort arising out of the operation,
maintenance, repair, or use of the Project Assets or the Project on or prior to the Closing
Date;
(i) Liabilities with respect to pending or threatened litigation, the Claim for which
arises on or before the Closing Date in connection with the Project Company, Project Assets,
or the Project (regardless of whether such Claim is asserted before or after the Closing
Date); and
(j) Liabilities for Pre-Closing Taxes.
“Preliminary Performance Test Report” shall have the meaning set forth in 15.5(a).
“Prime Rate” means the rate per annum (rounded upwards to the nearest 1/100th of 1% per annum)
equal to the rate of interest which JP Morgan Chase in New York, New York or its successor announces
from time to time as its “prime lending rate” or equivalent rate or if such rate is not available, another
rate published as the “prime rate” as agreed by Buyer and Developer, with each change in such rate
to be effective on the day on which such change is effective.
“Pro-ratable Items” shall have the meaning set forth in 2.6(c).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 191 of 1056
“Procedures” shall have the meaning set forth in 18.1(b).
“Progress Report” shall have the meaning set forth in 11.6(a).
“Project” shall have the meaning set forth in the recitals of the Agreement.
“Project Assets” means all assets, properties, rights,and interests of every kind, nature, character and
description (whether real, personal, or mixed, whether tangible or intangible, and whether at or
deliverable to the Project Site (as defined below)) and any goodwill related thereto, owned or leased
by, or licensed to, or possessed by the Developer or, if applicable, the Project Company, as of the
Closing Date (as defined below), in each case, which relate to or are used or held for use in connection
with the development, construction, operation, maintenance, repair, ownership, or use of the Project,
including the shared facilities, if applicable, including but not limited to: (a) studies, data, books, and
records related to the Project (together with the real property agreements referenced in clause (b)
below, the Project Contracts, the Project permits referenced in clause (g) and the Project reports
referenced in clause (h) below, the “Books and Records”); (b) the Real Property (including any
leasehold interest, licenses, rights of way or easements) on which any portion of the Project is located
or which is used to access any portion of the Project and including any Project real property
agreements (collectively, the “Project Site”); (c) the Project fixtures and equipment, including any
buildings, fixtures and equipment on or associated with the Project Site; (d) all contracts, agreements
or other arrangements to which Developer, Project Company (if applicable) or any of their affiliates
is a party with respect to the Project, Project Site or any Project Asset (collectively the “Project
Contracts”); (e) the Project improvements; (f) intellectual property necessary for the development,
construction, operation, maintenance, repair, ownership or use of the Project; (g) the Project permits;
(h) the Project reports; (i) meteorological data and any perfor; (j) all interconnection rights; (k) any
warranties associated with the equipment and/or workmanship of the Project; and (l) any and all
attributes of the Project (including all tax credits and other credits, certificates, tags, offsets,
allowances, or similar products or rights, howsoever entitled, associated with the Project or such
attributes).
“Project Company” shall have the meaning set forth in the recitals of the Agreement.
“Project Company Consents” shall have the meaning set forth in 4.2(b).
“Project Company Contracts” means any Contract to which any Project Company is a party, or by the
terms of which any Project Company is bound, or to which the Project or any Project Assets are
subject, including any (a) Contract that is primarily or exclusively related to the development,
permitting, acquisition, design, installation, ownership, marketing, sale, or planned operation of the
Project or Project Company; (b) Contract between Developer and any of its Affiliates concerning the
Project or the related Project Assets; (c) teaming agreement in connection with the development of
the Project; (d) interconnection or transmission-related agreements or applications for
interconnection or transmission of or from the Project; (e) any agreement for the sale of power or
environmental attributes of the Project, (f) the EPC Contract and Major Supply Agreements; (g)
exclusivity agreements with any contractor, or other supplier or utility to which the Project Company
is bound; (h) [contract providing for the borrowing of Indebtedness or the mortgaging, pledging or
otherwise placing a Lien on any of the Project Assets,] or the guarantying of any obligation (other
than endorsements made for collection) or otherwise material and related to any Indebtedness;
(i) contract that provides for non-monetary obligations in connection with the Project or Project
Assets, the non-performance of which obligations could reasonably be expected to have a Material
Adverse Change; (j) lease, license, easement, or other real property interest necessary for the
installation or operation of the Project, including any Real Property Contracts; (k) any agreement
with or award from a Governmental Authority with respect to environmental, financial, or tax
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 192 of 1056
incentives; (l) any warranty agreement with respect to the procurement of Equipment for the Project;
and (m) amendment or supplement to any of the foregoing.
“Project Company Permits” shall have the meaning set forth in 4.12(a).
“Project Company Regulatory Approvals” shall mean [__].4
“Project Problem” has the meaning set forth in 11.6(b)(i).
“Project Schedule” shall have the meaning set forth in 11.1.
“Proposed Purchase Price Allocation” shall have the meaning set forth in 17.3.
“Prudent Industry Practice” means any of the practices, methods, and acts relating to construction,
interconnection, and electrical work engaged in or approved by a significant portion of the energy
storage industry in the Pacific Northwest for energy storage facilities of a type and size and having
geographical and climatic attributes similar to the Project which, including guidance from the Edison
Electric Institute, OSHA Best Practices, and other generally accepted industry practices, in the
exercise of reasonable judgment in light of the facts known at the time the decision was made, would
have been expected to accomplish the desired result in a cost-efficient manner consistent with good
business practices and reliability criteria, safety considerations and expediency. Prudent Industry
Practice is not intended to be limited to the optimum practice, method, or act to the exclusion of all
others but, rather, to be a spectrum of acceptable industry practices, methods, or acts.
“Punch List Holdback Amount” means 200% of the value of any Punch List items outstanding as of
Substantial Completion as valued and certified by the Buyer’s Engineer as part of its Substantial
Completion certification.
“Purchase Price” shall have the meaning set forth in 2.6(b).
“Qualified Operator” means a Person that directly or indirectly through its Affiliates has developed,
owned, or operated for (or has hired another Person to develop and operate the Project that has for)
at least [five (5) consecutive] years utility scale battery storage assets in the United States with an
aggregate storage capacity of [____].
“Ramp Rate Guarantee” means the ramp rate guarantee set forth in Appendix O.
“Ramp Rate Test” means the test performed in accordance with the requirements of Appendix O, and
Appendix A and related Design Documents to determine whether the Ramp Rate Guarantee has been
achieved.
“Real Property” means all real property and interests in real property (including any leasehold
interests, licenses, rights of way, or Easements, and including the rights and interests in the Real
Property Contracts) to develop, construct, commission, own, and commence operations of the Project
at the Site.
“Real Property Contracts” shall have the meaning set forth in 4.13(a).
“Real Property Estoppels” shall have the meaning set forth in 2.5(a)(viii).
“Regulated Materials” means any substance, material, or waste, including special waste, which is now
or hereafter becomes listed, defined, or regulated in any manner as hazardous, extremely hazardous,

4 Note to Bidders: Please provide a list, if any.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 193 of 1056
corrosive, toxic, ignitable, explosive, radioactive, or flammable by any United States federal, state, or
local Environmental Law and includes any oil, petroleum, petroleum products, polychlorinated
biphenyls, asbestos in any form, and polyfluorinated and per fluorinated aromatic compounds.
“Release” means any release, deposit, discharge, emission, leaking, spilling, seeping, migrating,
injecting, pumping, pouring, emptying, escaping, dumping, disposing, or other movement of
Regulated Material.
“Reliability Run Period” has the meaning set forth in Appendix O.
“Remediation” includes any response, remedial, removal, or corrective action, any activity to cleanup,
detoxify, decontaminate, contain, or otherwise remediate any Regulated Material, any actions to
prevent, cure, or mitigate any Release of any Regulated Material, any action required to comply with
any Environmental Laws or with any Permits issued pursuant thereto, any inspection, investigation,
study, monitoring, assessment, audit, sampling and testing, laboratory or other analysis, or
evaluation required under Environmental Laws and relating to any Regulated Material.
“Reports” means the Phase I ESA, as well as all other environmental impact studies, geotechnical
reports, interconnection system impact studies, cultural assessments, hydrology reports, and
wetland delineation reports, in each case, with respect to the Project and the Site.
“Required Change Order” shall have the meaning set forth in 12.2(c).
“Response Time Guarantee” means the response time guarantee set forth in Appendix O.
“Response Time Test” means the test performed in accordance with the requirements of Appendix
O, and Appendix A and related Design Documents to determine whether the Response Time
Guarantee has been achieved.
“Roundtrip Efficiency Guarantee” means the roundtrip efficiency guarantee set forth in Appendix O.
“Roundtrip Efficiency Test” means the test performed in accordance with the requirements of
Appendix O, and Appendix A and related Design Documents to determine whether the Roundtrip
Efficiency Guarantee has been achieved.
“Scope of Work” shall have the meaning set forth in Appendix A.
“Serial Defect” means a Defect occurring during the Warranty Period that includes [_____]([_] %) or
more of the same or substantially similar component(s) resulting from the same failure mode of the
same manufacturer.
“Serial Defect Warranty Period” means a period of [_] years beginning on [_______].
“Significant Defect” means a single or recurring Defect which occurs at any time within the Warranty
Period which results in the cessation of operation of the Project or will not, unless corrected, allow
Buyer to operate the Project within parameters required to comply with applicable Law for a period
of either three (3) consecutive days or an aggregate of five (5) days in the case of a recurring Defect.
“Site Acreage” means the total number of acres that comprise the Site.
“Straddle Period” means a taxable period that includes but does not end on the Closing Date.
“Subcontractor” means any Person (including vendors, suppliers, contractors, and consultants),
other than Contractor, retained by Developer to perform a part of Developer’s obligations under any
Transaction Document, including the Major Subcontractors.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 194 of 1056
“Substantial Completion” means the Project has successfully completed commissioning to allow
routine and normal operations and demonstrates that all of the Substantial Completion Criteria has
been satisfied in accordance with the requirements of this Agreement.
“Substantial Completion Criteria” shall have the meaning set forth in Appendix P.
“Substantial Completion Date” means the date on the Certificate of Substantial Completion provided
by Developer which is accepted in accordance with the requirements of 16.3.
“Substantial Completion Delay Liquidated Damages” shall have the meaning set forth in 20.2(b).
“System” means the electric transmission sub-station and distribution facilities owned, operated, or
maintained by Transmission Provider, which shall include, after construction and installation of the
Project, the circuit reinforcements, extensions, and associated terminal facility reinforcements or
additions required to complete the Project, all as set forth in the Interconnection Agreement.
“Tax” or “Taxes” means any and all federal, state, local, foreign, or other taxes, charges, fees, levies,
tariffs, duties, liabilities, impositions, or other assessments in the nature of a tax (together with any
and all interest, penalties, additions to tax, and additional amounts imposed relating or attributable
to any failure to comply with any requirement regarding Tax Returns) imposed by any tax authority
or other Governmental Authority, including income, gross receipts, profits, excise, real or personal
property, environmental, sales, use, value-added, ad valorem, withholding, social security,
retirement, rollback, employment, unemployment, customs duties, worker’s compensation,
occupation, escheat, unclaimed property, recapture, service, license, net worth, capital stock, payroll,
franchise, gains, stamp, transfer and recording taxes, and shall include any liability for the Taxes of
any other person or entity under Treasury Regulations Section 1.1502-6 (or similar provisions of
state or local law), or as a transferee or successor, by indemnification, contract, or otherwise.
“Tax Benefit” means the [ [__]% ITC], accelerated depreciation (including bonus depreciation),
amortization and state level credits, deductions, and incentives.
“Tax Benefits Loss” means any denial, disallowance, loss, reduction, or recapture of, or any inability
to claim, any Tax Benefits (including any Claim or Liability thereto) resulting from a breach by
Developer of any of its representations, warranties, or covenants in this Agreement.
“Tax Returns” means any return, declaration, report, Claim for refund, or information return or
statement relating to Taxes, in each case, including any such document prepared on a consolidated,
combined, or unitary basis and also including any schedule or attachment thereto, filed or
maintained, or required to be filed or maintained, in connection with the calculation, determination,
assessment, or collection of any Tax and includes any amended returns required as a result of
examination adjustments made by the Internal Revenue Service or other Governmental Authority.
“Technical Specification” means the specification for the Work set forth in Appendix A and Appendix
P, and any modifications thereof made pursuant to the terms of this Agreement.
“Ten Percent Holdback” shall have the meaning set forth in 2.7(b).
“Tipping Basket Amount” shall have the meaning set forth in 22.1(c).
“Title Company” means [_______] or such other title insurance company reasonably acceptable to Buyer
and Seller.
“Title Policy” means a title insurance policy issued by Title Company at Developer’s expense (except
as set forth herein) insuring Buyer’s leasehold and fee simple rights, as applicable, in the Real
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 195 of 1056
Property, including the Easements as appurtenant easements, that (a) is in form and substance and
contains such requirements, modifications, and endorsements as Buyer may reasonably approve, (b)
contains such additional affirmative coverage and endorsements (at Buyer’s cost and expense) as
Buyer may reasonably request (provided, that Buyer shall bear the expense of any requested tax
credit endorsements), (c) is in such amount as Buyer may negotiate with the Title Company, which
shall in no event exceed the Purchase Price, (d) insures that Buyer is the sole holder of all insured
leasehold and fee simple rights, as applicable, title and interests with respect to the Real Property,
subject to such exceptions to title as Buyer may reasonably approve, (e) names Buyer and Project
Company as the insured, (f) is issued on or before the Closing Date by the Title Company, (g) shows
as exceptions only the Permitted Liens, and (h) does not contain the standard pre-printed exceptions
that appear in the related title insurance commitment, which are able to be deleted with the delivery
of affidavits and certifications signed or obtained by Developer and acceptable to the Title Company.
“Transaction” shall have the meaning set forth in 29.1(b).
“Transaction Documents” means once executed and in full force and effect, this Agreement, the
Assignment and Assumption Agreement, and any other assignments, novation agreements,
delegation agreements, conveyances, and other ancillary documents necessary to effect the
transaction contemplated herein; provided, that the Project Company Contracts shall not be
considered Transaction Documents hereunder.
“Transfer Tax” shall have the meaning set forth in 17.2.
“Transferred Warranties” means all those warranties offered or transferred by Developer to Buyer
pursuant to ARTICLE 19.
“Transmission Provider” means Idaho Power Transmission.
“Treasury Regulations” means the United States Treasury Regulations promulgated under the Code.
“Unidentified Project Problem” shall have the meaning set forth in 11.6(c).
“Updating Information” shall have the meaning set forth in 7.4(a).
“Warranty” shall have the meaning set forth in 19.1(a).
“Warranty Period” shall have the meaning set forth in 19.2.
“Work” means the Equipment and Materials to be supplied and the entire works and services to be
performed, or caused to be performed, by Developer under this Agreement, including all Equipment,
Materials, and services in connection with the development, design, permitting, engineering,
procurement, and construction of the Project, together with any modifications thereto in accordance
with the terms hereof.
1.2 Interpretation.
(a) Unless the context requires otherwise, in this Agreement:
(i) Headings and the rendering of text in bold or italics are for convenience and
reference purposes only and do not affect the meaning or interpretation of this Agreement.
(ii) A reference to an Appendix, Exhibit, Schedule, Article, Section, or other
provision shall, unless otherwise specified, be deemed to be a reference to appendices, exhibits,
Exhibit No. 4
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schedules, articles, sections, or other provisions of this Agreement, which appendices, exhibits, and
schedules are incorporated herein by reference.
(iii) Any reference in this Agreement to another Contract or document shall be a
reference to that other Contract or document as the same may be amended, modified, supplemented,
or replaced from time to time.
(iv) Any reference in this Agreement to “this Agreement,” “herein,” “hereof,”
“hereunder,” or “herewith” shall be a reference to this Agreement as a whole and not limited to the
particular Appendix, Article, Section, Exhibit, Schedule, or provision in which the relevant reference
appears and to this Agreement as amended, modified, supplemented, or replaced from time to time.
(v) References to any Party shall include any successors and assigns of the Party
but, if applicable, only if such successors and assigns are permitted by this Agreement.
(vi) References to the term “includes” or “including” shall mean “includes, without
limitation” or “including, without limitation.”
(vii) Words importing the singular shall include the plural and vice versa and the
masculine, feminine, and neuter genders shall include all genders.
(viii) The word “or” shall be deemed to be disjunctive but not necessarily exclusive
(i.e., unless the context dictates otherwise, “or” shall be interpreted to mean “or” rather than
“either/or”).
(ix) The terms “shall” and “will” are each mandatory, meaning must; and the term
“may” is permissive.
(x) Relative to the determination of any period of time, “from” shall mean
“including and after,” “to” shall mean “to but excluding,” and “through” shall mean “through and
including.”
(xi) If the time for performing an obligation under this Agreement occurs or
expires on a day that is not a Business Day, the time for performance of such obligation shall be
extended until the next succeeding Business Day.
(xii) References to Laws shall be references to the same as amended, modified,
supplemented, or reenacted and in effect from time to time, and shall include references to all bylaws,
instruments, orders, rules, and regulations for the time being made thereunder or deriving validity
therefrom, unless the context otherwise requires.
(xiii) References to any amount of money shall mean a reference to the amount in
United States dollars.
(xiv) Any reference in this Agreement to time of day refers to the prevailing
Mountain Time.
(xv) Unless specifically stated to the contrary, all references to days, months and
years in this Agreement refer to calendar days, months, and years, respectively.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 197 of 1056
INTERESTS
2.1 IPUC Approval.
Buyer will agree to submit to the IPUC an application (“IPUC Submission”) for necessary
regulatory approvals of cost recovery through rates (“IPUC Approval”) no later than sixty (60) days
following the execution of the Agreement.
2.2 Interests.
On the terms and subject to the conditions set forth in this Agreement, Developer shall
irrevocably and unconditionally sell, convey, transfer, deliver, and assign to Buyer, and Buyer shall
purchase, receive, and accept from Developer, the Membership Interests, free and clear of all Liens
and Liabilities, and the Parties shall take or cause to be taken the other actions described herein.
2.3
(a) Following the Execution Date, each Party shall use commercially reasonable efforts
to ensure the achievement of the “Firm Date,” which shall be the first date on which all of the
following conditions (“Firm Date Conditions”) have been satisfied (or waived by the Party entitled to
do so) and signifies completion of Project development and commencement of construction activities
for the Project:
(i) veloper The following conditions
must be satisfied or otherwise waived in whole or in part by either Party in its sole discretion:
(A) The final form of the CCMA has been mutually agreed to by the Parties;
(ii) . The following conditions must be satisfied or
otherwise waived by Buyer in its sole discretion:
(A) An agreed upon list of Project permits to be specified in the
Agreement as being required by the Firm Date (a) have been obtained and issued for the Project, (b)
are in full force and effect, and (c) satisfy any requirements of the Agreement with respect to review
and approval of permits;
(B) An agreed upon list of consents to be specified in the Agreement as
required to be in place by the Firm Date have been duly obtained, made or given and are in full force
and effect;
(C) Developer has delivered to Buyer the agreed upon list of reports to be
specified in the Agreement as required and any additional reports or Design Documents required
pursuant to the Agreement and such reports or Design Documents have satisfied any other
requirements of the Agreement with respect to the preparation, sufficiency and material findings
thereof;
(D) The Interconnection Agreement has been finalized and executed by
the parties thereto in accordance with the requirements of the Agreement and is in form and
substance acceptable to Buyer in its reasonable discretion;
(E) Developer has delivered to Buyer a Phase I ESA (and, if indicated in
the Phase I ESA, a Phase II ESA) with respect to the Project Site, current and valid on the Firm Date
under ASTM Standard Practice E1527-13, addressed to Buyer, and accompanied by a reliance letter
Exhibit No. 4
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incorporating user-provided information from Buyer in form and substance reasonably satisfactory
to Buyer;
(F) Developer’s representations and warranties are true, correct and
complete as of the Firm Date in all material respects except for Developer’s fundamental
representations and warranties and representations and warranties qualified by a materiality
standard, which will be true, correct and complete in all respects;
(G) Developer has performed its obligations in the Agreement to be
performed prior to the Firm Date in all material respects;
(H) There is no Developer, Project Company (if applicable) or Project
Material Adverse Change;
(I) Developer and Buyer have agreed on all Firm Date title objections and
required exceptions and Developer has delivered all non-disturbance agreements and curative
documents in accordance with the standards and processes set forth in the Agreement;
(J) The form of ALTA title policy to be issued as of the Closing Date has
been finalized and agreed; and
(K) Developer has caused the relevant title company to issue a pro forma
policy of title insurance consistent with the updated title commitment and the agreed upon Firm Date
title objections and required exceptions.
(iii) . The following conditions must be
satisfied or otherwise waived by Developer in its sole discretion:
(A) Buyer’s representations and warranties are true, correct, and
complete as of the Firm Date in all material respects except for Buyer’s Fundamental Representations
and its representations and warranties that are qualified by a materiality standard, which will be
true, correct, and complete in all respects.
(B) There is no Buyer Material Adverse Change.
(C) Buyer has performed its obligations under the Agreement in all
material respects.
2.4
At or following satisfaction of the Firm Date Conditions, the Developer, or if applicable, the
Project Company shall issue a Full Notice to Proceed with respect to the performance of the
construction of the Project.
2.5
(a) Developer’s Deliverables. At the Closing, Developer shall execute and deliver to Buyer
the following documents and such other documents, bills of sale, assignments, and other instruments
of transfer or assignment:
(i) a counterpart signature page to an assignment and assumption agreement
with respect to the Membership Interests (the “Assignment and Assumption Agreement”), in form
and substance set forth in Exhibit C, duly executed by an Authorized Signatory of Developer;
(ii) a duly completed and executed IRS Form W-9;
Exhibit No. 4
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(iii) a certificate of a duly authorized officer of Developer certifying that:
(A) attached thereto is a true, correct, and complete copy of a certificate of good standing with respect
to Developer, issued by the Secretary of State of [___] as of a date not more than ten (10) days prior
to the Closing Date; (B) attached thereto are true, accurate,and complete copies of the organizational
documents of Developer, and all amendments thereto, as in effect at Closing; (C) attached thereto are
copies of resolutions duly adopted by the Manager, authorizing the sale of the Membership Interests
to Buyer and the execution, delivery, and performance by Developer of this Agreement and the
transactions contemplated hereby and attesting that such resolutions are in full force and effect
without amendment or modification at Closing; (D) attached thereto is the name, title, and signature
of each of the Authorized Signatory authorized to execute and deliver this Agreement and the
Transaction Documents, and any other document or instrument contemplated hereby or thereby, by
or on behalf of Developer; and (E) the conditions specified in 2.9(a) and 2.9(b) have been satisfied;
(iv) a certificate of a duly authorized officer of Project Company certifying that:
(A) attached thereto is a true, correct, and complete copy of a certificate of good standing with respect
to Project Company, issued by the [______] as of a date not more than ten (10) days prior to the Closing
Date; (B) attached thereto are true, accurate, and complete copies of the organizational documents
of Project Company, and all amendments thereto, as in effect at Closing; and (C) attached thereto is
the name, title, and signature of each of the Authorized Signatories authorized to execute and deliver
the Transaction Documents and any other document or instrument contemplated hereby or thereby,
by and on behalf of Project Company;
(v) the Title Policy naming Project Company as the insured, together with a date
down endorsement showing any new matters of record and an endorsement naming Buyer as an
additional insured, such endorsements to be issued no earlier than five (5) Business Days before the
Closing Date in form and substance reasonably acceptable to Buyer;
(vi) an ALTA/ACSM standard survey of the Real Property, dated no more than
thirty (30) days before the date Full Notice to Proceed is issued, in accordance with minimum
ALTA/ACSM standards then in effect and sufficient in form and substance to permit issuance of the
Title Policy, prepared and certified as correct by a licensed land surveyor reasonably satisfactory to
Buyer. Such survey shall show the location of the Site and all planned improvements based on the
issued for construction civil engineering plans for the Project thereon, and the location of all
easements and rights-of-way, whether above or underground, and shall show no encroachments of
any improvements onto such easements or rights-of-way (except as permitted under the documents
governing such easements and rights-of-way or pursuant to a consent, crossing agreement, or similar
agreement) or onto property outside the boundaries of the Site as shown on the survey;
(vii) estoppels, in form and substance reasonably acceptable to Buyer, from each
applicable counterparty to all Project Company Contracts that are not executed with a Governmental
Authority (except the Real Property Contracts which are to be delivered in accordance with
subsection (viii)below), including the EPC Contract and the Major Supply Agreements, dated no more
than fifteen (15) days prior to the Closing, each of which shall include a statement that the respective
Contract is in full force and effect (the “Estoppels”);
(viii) estoppels, in form and substance reasonably acceptable to Buyer, from each
applicable counterparty to the Real Property Contracts and dated no more than sixty (60) days prior
to the Closing Date, each of which shall include a statement that the respective Real Property Contract
is in full force and effect (the “Real Property Estoppels”).
(ix) a Beginning of Construction Certificate substantially in the form of Exhibit D,
duly executed by Developer and current as of the Closing Date.
Exhibit No. 4
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Page 200 of 1056
(x) such releases of Liens and Liabilities and certificates as Buyer shall deem
necessary or Buyer may reasonably request to affect the Closing contemplated by this Agreement, all
of which shall be in form and substance reasonably satisfactory to Buyer.
(b) Buyer’s Deliverables. At the Closing, Buyer shall execute and deliverto Developer the
following documents and such other documents, deeds, bills of sale, assignments, and other
instruments of transfer or assignment:
(i) a counterpart signature page to the Assignment and Assumption, duly
executed by an Authorized Signatory of Buyer; and
(ii) a certificate of the Secretary or an Assistant Secretary of Buyer certifying that:
(A) attached thereto is a true, correct, and complete copy of a certificate of good standing with respect
to Buyer, issued by the Secretary of State of the State of Idaho as of a date not more than thirty (30)
days prior to the Closing Date; (B) attached thereto are copies of resolutions duly adopted by Buyer’s
board of directors (or similar body), authorizing the purchase of the Membership Interests by Buyer
and the execution, delivery, and performance by Buyer of this Agreement and the transactions
contemplated hereby and attesting that such resolutions are in full force and effect without
amendment or modification at Closing; (C) attached thereto is the name, title, and signature of each
of the Authorized Signatories of Buyer authorized to execute and deliver this Agreement and the
Transaction Documents, and any other document or instrument contemplated hereby or thereby;
and (D) the conditions specified in 2.10(a) and 2.10(b) have been satisfied;
2.6
(a) Base Purchase Price. Subject to Section 2.6(b), the aggregate consideration payable
by Buyer to Developer for (i) the Membership Interests and (ii) the Developer’s obligations to deliver
a Project that has achieved Final Completion shall be $[______] (the “Base Purchase Price”).
(b) Purchase Price Adjustments. The Base Purchase Price shall be adjusted as follows:
(i) decreased for the Guaranteed Capacity Liquidated Damages, if any;
(ii) decreased for Guaranteed Roundtrip Efficiency Liquidated Damages, if any;
(iii) decreased for Guaranteed Availability Liquidated Damages, if any;
(iv) increased or decreased, as applicable, for Buyer’s or Developer’s net pro-rata
share of the Pro-Ratable Items;
(v) increased for the Buyer-Caused Delay Costs, if any; and
(vi) increased for the Buyer-Initiated Change Order Costs, if any.
(as so adjusted, the “Purchase Price”).
(c) Pro-Ratable Items. The “Pro-Ratable Items” include each of those Project-related
liabilities as set forth on Schedule 2.6(c).5 Buyer’s pro-rata share shall not exceed the amount set
forth on Schedule 2.6(c).

5 Note to Bidders: Schedule 2.5(d) to provide for proration of (a) post-closing property taxes, (b) rents or property taxes
due to increased valuation due to the installation of the Project that is applied pre-closing, to the extent applicable, and/or
(c) specified prepayments under specified Project Contracts paid prior to Closing but relating to periods after Closing, such
as completion or operation-based lease payments.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 201 of 1056
(d) Buyer-Caused Delay Costs. The “Buyer-Caused Delay Costs” shall be equal the
reasonable, documented actual costs incurred by Developer as a direct result of liabilities arising
under the EPC Contract to the extent caused by a Change Order issued due to a circumstance set forth
in 12.2(c)(ii)
(e) Buyer-Initiated Change Order Costs. The “Buyer-Initiated Change Order Costs” shall
be equal to the reasonable documented actual costs incurred by Developer and approved by Buyer
in accordance with 12.2(b) as a direct result of liabilities arising under the EPC Contract that are
directly and solely caused by a Buyer-Initiated Change Order.
(f) Withholding. Notwithstanding any other provision in this Agreement to the contrary,
Buyer and each of its Affiliates shall be entitled to deduct and withhold from amounts otherwise
payable to any Person pursuant to this Agreement such amounts as it determines are required to be
deducted and withheld with respect to the making of such payment under any provision of applicable
Law. Such deducted or withheld amounts shall be treated for all purposes of this Agreement as
having been paid to the relevant Person in respect of which such deduction and withholding was
made. If Buyer determines that withholding of payments to a Person are required to be made
pursuant to this 2.6(f), Buyer shall, as soon as reasonably practicable, notify such Person of such
determination and, to the extent possible consistent with applicable Law, provide such Person with
a reasonably opportunity to produce any required documentation to reduce or eliminate such
withholding requirement.
2.7 Closing .
(a) Closing Date, Place and Time. The closing of the transactions contemplated by this
ARTICLE 2 (the “Closing”) shall take place at [________] or such other location as the Parties shall agree,
at 10:00 a.m. (Mountain Time) on the date that is three (3) Business Days from the date that all of the
conditions precedent set forth in 2.9 and 2.1010 have been satisfied (or waived in writing by Buyer
or Developer, as applicable), which date shall be on or before the Outside Closing Date, as such date
may be extended in accordance with 20.2(a), or at such other time and date as the Parties shall
mutually designate in writing (the “Closing Date”). The Closing shall be effective as of 12:01 a.m.
(Mountain Time) on the Closing Date.
(b) Closing Payment. At the Closing, Buyer shall pay to Developer the ninety percent
(90%) of the Base Purchase Price (the “Closing Payment”) via wire transfer of immediately available
federal funds to an account that is (i) located in the United States and (ii) designated by Developer at
least ten (10) Business Days prior to the Closing Date.
(c) Substantial Completion Payment. Within ten (10) Business Days after the Buyer’s
Engineer certifies that the Project has achieved Substantial Completion, Buyer will pay to Developer
the Purchase Price, less the Closing Payment, less the Punch List Holdback Amount.
(d) Payment of Punch List Holdback Amount. Within ten (10) Business Days after the
Buyer’s Engineer certifies that the Project has achieved Final Completion, Buyer will pay to Developer
the Punch List Holdback Amount, provided that, after Substantial Completion but before Final
Completion, Developer may submit invoices for partial release of the Punch List Holdback Amount
prior to Final Completion for Punch List items completed to the extent such items completed
aggregate to $[____] or more.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 202 of 1056
2.8
From time to time after the Closing Date, Developer shall, at the request of Buyer but without
further consideration, promptly execute and deliver to Buyer such other agreements, certificates and
further instruments of sale, assignment, transfer, and conveyance and take such other and further
actions as Buyer may reasonably request in order to vest or perfect in Buyer or its assigns, and put
Buyer or its assigns in possession of, the Membership Interests, the Project Assets, and the Project
Company Contracts and to carry out and implement the Closing and the transactions contemplated
in this ARTICLE 2, including any regulatory requirements of Buyer.
2.9 Buyer
The obligation of Buyer to effect the Closing and the transactions contemplated in this
ARTICLE 2 is subject to the satisfaction or waiver by Buyer on or prior to the Closing Date of each of
the following conditions:
(a) Accuracy of Representations and Warranties. The representations and warranties
made by Developer in this Agreement that are qualified with respect to materiality shall be true and
accurate in all respects, the representations and warranties made by Developer in this Agreement
that are not so qualified shall be true and accurate in all material respects, and the Fundamental
Representations and warranties shall be true and correct in all respects, on and as of the Closing Date
(or on the date when made in the case of any representation and warranty which specifically relates
to an earlier date).
(b) Performance. Developer and the Project Company, as the case may be, shall have
performed or complied in all material respects with all obligations and covenants required by this
Agreement to be performed or complied with by it on or prior to the Closing Date.
(c) Deliveries. Developer shall have executed and Made Available or caused to be
executed and Made Available to Buyer the items set forth in 2.5(a) and any other final reports and
Design Documents required to be delivered on or prior to the Closing Date.
(d) Absence of Orders; Law. No preliminary or permanent injunction or other Judgment
of any Governmental Authority to prevent the consummation of the transactions contemplated by
this Agreement, including the Closing, shall be in effect or pending, and no applicable Law shall have
been enacted by any Governmental Authority that makes consummation of such transactions illegal.
(e) Transaction Documents and Credit Support. All of the Transaction Documents
(together with all amendments, supplements, schedules,and exhibits thereto) and the Credit Support
provided by Developer, shall be in full force and effect, and shall be in form and substance
substantially similar to the form attached hereto or otherwise satisfactory to Buyer in its discretion.
(f) Project Company Permits. All of the Project Company Permits necessary for the
development, construction, ownership, operation, maintenance, repair, and use of the Project shall
have been duly issued and obtained and shall be in full force and effect and shall be in form and
substance satisfactory to Buyer in its reasonable discretion.
(g) Project Company Consents. All of the Project Company Consents shall have been duly
obtained, made or given, shall be in full force and effect, and shall be in form and substance
satisfactory to Buyer in its reasonable discretion.
(h) Project Company Reports. All of the Reports shall be in form and substance
satisfactory to Buyer in its reasonable discretion.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 203 of 1056
(i) Material Adverse Change. NoDeveloperMaterial Adverse Change shall have occurred
and be continuing.
(j) Substantial Completion. Developer shall have achieved Substantial Completion, as
certified by the Independent Engineer, and Developer shall have Made Available to Buyer the
unabridged and unredacted final report concerning the energy storage potential of the Project
prepared by the Independent Engineer.
(k) [reserved]
(l) Beginning of Construction Certificate. Buyer shall have received a Beginning of
Construction Certificate substantially in the form of Exhibit D, and current as of the Closing Date, duly
executed by Developer and current as of the Closing Date.
(m) Project Company Contracts. The Project Company Contracts, including the EPC
Contract and the Major Supply Agreements, shall be in full force and effect, in form and substance
required by this Agreement, without any modifications, amendments, or change orders thereto, other
than such modifications, amendments, or change orders that have been approved by Buyer in writing
and no party to the Project Company Contracts shall be in breach. The Independent Engineer shall
have certificated that the Project Contracts and schedules support achievement of applicable
milestones.
(n) Regulatory Approvals. All of the Project Company Regulatory Approvals shall have
been duly obtained, made, or given, shall be in full force and effect, and shall be in form and substance
satisfactory to Buyer in its reasonable discretion.
(o) Conformity with Standards. Developer has certified to Buyer that to Developer’s
Knowledge, the Project conforms to applicable engineering and installation standards set forth
herein, including the technical specifications and Applicable Laws, and the Developer has no
knowledge of any defects in workmanship or equipment caused by the Contractor or Subcontractors
with respect to the Project.
(p) Title Matters. Any objections to the Title Policy and survey matters have been cured
to Buyer’s reasonable satisfaction.
(q) Tax Benefit. Developer has provided documentation satisfactory to Buyer with
respect to qualification for any applicable tax credits or other benefits (or, in each case, payments or
deemed refunds in lieu thereof), for the Project including under [specify applicable sections of the
Code based on the applicability of any relevant tax credits].
(r) Credit Support. Developer’s or, if applicable, Project Company’s credit support is in
full force and effect.
2.10
The obligation of Developer to effect the Closing and the transactions contemplated in this
ARTICLE 2 is subject to the satisfaction or waiver by Developer on or prior to the Closing Date of
each of the following conditions:
(a) Accuracy of Representations and Warranties. The representations and warranties
made by Buyer in this Agreement that are qualified with respect to materiality shall be true and
accurate in all respects, the representations and warranties made by Buyer in this Agreement that
are not so qualified shall be true and accurate in all material respects, and the Fundamental
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 204 of 1056
Representations and warranties shall be true and accurate in all respects, on and as of the Closing
Date (or on the date when made in the case of any representation and warranty which specifically
relates to an earlier date).
(b) Performance. Buyer shall have performed or complied in all material respects with
all obligations and covenants required by this Agreement to be performed or complied with by it on
or prior to the Closing Date.
(c) Deliveries. The Closing Payment has been paid and Buyer shall have executed and
Made Available or caused to be executed and Made Available to Developer the items set forth in
2.5(b).
(d) Absence of Orders; Law. No preliminary or permanent injunction or other Judgment
of any Governmental Authority to prevent the consummation of the transactions contemplated by
this Agreement, including the Closing, shall be in effect or pending, and no applicable Law shall have
been enacted by any Governmental Authority that makes consummation of such transactions illegal.
(e) Transaction Documents. All of the Transaction Documents (together with all
amendments, supplements, schedules,and exhibits thereto) shall be in full force and effect, and shall
be in form and substance substantially similar to the form attached hereto or otherwise satisfactory
to Developer in its reasonable discretion.
(f) Buyer Consents. All of the Buyer Consents shall have been duly obtained, made or
given, shall be in full force and effect, and shall be in form and substance satisfactory to Developer in
its reasonable discretion.
(g) Buyer Regulatory Approvals. Buyer shall have received final non-appealable
regulatory approval providing for satisfactory cost recovery assurance and any necessary regulatory
accounting authorization from the IPUC, All of the Buyer’s other regulatory approvals shall have been
duly obtained, made, or given, shall be in full force and effect, and shall be in form and substance
satisfactory to Buyer in its discretion.
(h) Material Adverse Change. No Buyer Material Adverse Change shall have occurred and
be continuing.
2.11 .
(a) Notwithstanding anything contained in this Agreement to the contrary, in addition to
the termination rights of the Parties set forth in Article 26, this Agreement may be terminated at any
time prior to the Closing Date as follows:
(i) by the mutual written agreement of the Parties;
(ii) Prior to Closing, by either Party, if any Law shall become effective after the
Execution Date or a Governmental Authority shall have issued a final and non-appealable order,
injunction, Judgment, decree, or ruling, in each case, restraining, enjoining, or otherwise prohibiting
or making illegal the Closing or the transactions contemplated in connection therewith;
(iii) Prior to Closing, by either Party, as applicable: (a) if the other Party breaches
any representation, warranty, or covenant in the Agreement, and (i) such breach would result in a
failure of, or inability of the other Party to satisfy the applicable closing conditions, and (ii) such
breach has not been cured to Buyer’s or Developer’s, as applicable, reasonable satisfaction within
thirty (30) days following receipt of written notice of such breach or an extended cure period not to
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 205 of 1056
exceed the Outside Closing Date; or (b) a disclosure schedule update is delivered by a Party in
accordance with 7.4, which discloses a matter or matters resulting in Developer Material Adverse
Effects or Buyer Material Adverse Effects, as applicable, and which has not been cured within thirty
(30) days following receipt of written notice of such breach or an extended cure period not to exceed
the Outside Closing Date;
(iv) By either Party, upon the bankruptcy of the other Party;
(v) By Developer, if a Change in Law or similar event increases Developer’s costs
to develop and construct the Project by a dollar amount in excess of $[__];by either Party, if the Closing
has not occurred by [___]6 (the “Outside Closing Date,” subject to any extension granted pursuant to
20.2(a)); provided, further, that the right to terminate this Agreement pursuant hereto shall not be
available to any Party whose breach of this Agreement has been the cause of, or resulted in, the failure
of the Closing to occur on or before the Outside Closing Date;
(vi) By either Party, if a Force Majeure event or delay event causes a delay in
development or construction of the Project that will last longer than the Outside Closing Date;
(vii) Prior to IPUC Approval: by Buyer, if a Material Adverse Change occurs
(including as a result of a disclosure schedule update is delivered by a Party in accordance with 7.4)
with respect to Developer; and by Developer, if a Buyer Material Adverse Change occurs (including
as a result of a disclosure schedule update is delivered by a Party in accordance with 7.4) with respect
to Buyer;
(viii) by either party, if the Firm Date has not occurred by [___]7 (the “Firm Date
Deadline”); provided, however, that the right to terminate this Agreement pursuant hereto shall not
be available to Developer, if Developer is in breach of this Agreement and such breach has been the
cause of, or resulted in, the failure of the Project to achieve the Firm Date on or before the Firm Date
Deadline;
(ix) by Buyer, if a Change in Law regarding taxes increases Buyer’s costs to own
and operat the Project in a dollar amount in excess of $[__];
(x) by Buyer, if the EPC Contract and the Major Supply Agreements have not been
agreed to by the Project Company and applicable contractors in form and substance on terms equal
to or better than those attached hereto as Exhibit G and Exhibit H, within sixty [60] days of execution
of the Agreement;
(xi) by Buyer, if the EPC Contract and the Major Supply Agreements havenot been
executed by the Project Company and applicable contractors on terms equal to or better than those
attached hereto as Exhibit G and Exhibit H, within one hundred eighty (180) days of the execution of
the Agreement;
(xii) by Buyer, if this Agreement has not been approved by the Board of Directors
of Buyer or Buyer has not received all required internal approvals, including formal approvals by its
executive management, prior to the date that is fifteen (15) days after execution of this Agreement;

6 Note: Project development timeline to be discussed.
7 Note: Project development timeline to be discussed.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 206 of 1056
(xiii) By either Party, if (a) IPUC Approval is not obtained by twelve (12) months
following Buyer’s submission of the Agreement to the IPUC or (b) Buyer’s other regulatory approvals
in form and substance satisfactory to Buyer in its discretion are not obtained on or prior to [___];
(xiv) by Buyer, if the Closing has not occurred by [___]8 (which date, for the
avoidance of doubt, is not subject to extensions); provided, further, that the right to terminate this
Agreement pursuant hereto shall not be available if Buyer’s material breach of this Agreement has
been the cause of, or resulted in, the failure of the Closing to occur on or before such date;
(b) Either Party desiring to terminate this Agreement pursuant to 2.11(a) shall give
written notice thereof to the other Party.
(c) If validly terminated, then all further obligations of the Parties will end (other than
those specified herein this Agreement that are intended to survive termination), with respect to a
termination due to a breach as set forth in clause 2.11(a)(iii) or 2.11(a)(iv), the terminating Party
will be entitled to pursue all rights or remedies available at law or in equity; provided, however, that
liability for such a pre-closing termination shall be capped at [$ ___ million]. If validly terminated by
either Party pursuant to 2.11(a)(i), 2.11(a)(ii), 2.11(a)(v), 2.11(a)(vi), 2.11(a)(vii), 2.11(a)(viii),
2.11(a)(x), or 2.11(a)(xiv) then neither Party shall have any liability to the other with respect to such
termination.
(d) If this Agreement is terminated by Buyer pursuant to 2.11(a)(viii), 2.11(a)(xi),
2.11(a)(xii), 2.11(a)(xv) then Developer shall be liable to Buyer for an early termination fee in the
amount of [_____], all further obligations of the Parties under this Agreement (other than the
provisions which by their terms are intended to survive the expiration or termination of this
Agreement) shall be terminated (with no fees or damages payable by Buyer).
(e) The Parties agree that, to the extent that liquidated damages are provided for in this
2.11, it is because actual damages as a result of termination of this Agreement pursuant to the
applicable section would be extremely difficult or impracticable to determine. After negotiation, the
Parties have agreed that the above liquidated damages are in the nature of liquidated damages and
are a reasonable and appropriate measure of the damages that Buyer or Developer, as applicable,
would incur as a result of such delays or failures, and do not represent a penalty.
Developer hereby represents and warrants to Buyer that all of the statements contained in
this ARTICLE 3 are true and correct: (a) as of the Execution Date, except to the extent such
representations and warranties are specifically made as of a particular date (in which case such
representations and warranties are true and correct as of such date); (b) as of the Firm Date; and (c)
as of the Closing Date.
3.1 ,
Developer is duly formed, validly existing and in good standing, under the applicable Laws of
the jurisdiction of its formation. Developer has the requisite limited liability company power and
authority to own, operate, and lease its properties and assets and to carry on its business as now
being conducted and as proposed to be conducted pursuant hereto. Developer is duly qualified or
licensed to do business and is in good standing in all jurisdictions in which the character of the
properties owned or held under lease by it or the nature of the business now being transacted by it

8 Note: Project development timeline to be discussed.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 207 of 1056
or proposed to be transacted by it pursuant hereto makes qualification necessary, including the State
of Idaho.
3.2 Delivery.
Developer has full limited liability company power and authority to execute and deliver this
Agreement and the Transaction Documents to which it is a party in connection with the transactions
contemplated hereby, to perform its obligations hereunder and thereunder, and to complete the
transactions contemplated hereby and thereby. The execution and delivery by Developer of this
Agreement and the Transaction Documents to which it is a party, and the performance by Developer
of its obligations hereunder and thereunder, have been duly and validly authorized by all necessary
limited liability company action.
3.3
This Agreement and the Transaction Documents to which Developer is a party have been duly
executed and delivered by Developer and, assuming due and valid authorization, execution and
delivery thereof by Buyer and each other party thereto, this Agreement and the Transaction
Documents to which it is a party are valid and binding obligations of Developer enforceable against
Developer in accordance with their terms, subject to applicable bankruptcy, insolvency,
reorganization, moratorium, or other similar applicable Laws relating to or affecting the enforcement
of creditors’ rights generally and to general principles of equity.
3.4 licts.
The execution and delivery by Developer of this Agreement and the Transaction Documents
to which Developer is a party does not, and the performance by Developer of its obligations
hereunder and thereunder and the completion of the transactions contemplated hereby and thereby,
shall not:
(a) conflict with or result in a violation or breach of any of the terms, conditions or
provisions of Developer’s organizational documents;
(b) assuming all of the consents and approvals set forth on Schedule 3.4(b) (the
“Developer Consents”) have been obtained or given, result in a breach, default or violation (or give
rise to any right of termination, cancellation or acceleration) under any of the terms, conditions or
provisions of any Contract associated with the Project to which Developer or any Affiliate of
Developer (other than Project Company) is a party or Permit associated with the Project obtained by
Developer or any Affiliate of Developer (other than Project Company) (with or without notice or lapse
of time or both), except for such breaches, defaults, or violations (or rights of termination,
cancellation or acceleration) as to which requisite waivers or consents have been obtained in writing
(true and correct copies of which have previously been furnished to Buyer);9
(c) assuming all of the Developer Consents have been obtained or given, conflict with or
result in a violation or breach in any term or provision of any applicable Law applicable to Developer
or the Project; or

9 Note to Bidders: Parties to discuss whether any Developer Consents will be relevant to the development and construction
of the Facility.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 208 of 1056
(d) assuming all of the Developer Consents have been obtained or given, result in the
imposition or creation of any Lien of any nature on the Membership Interests or Project, other than
Permitted Liens or Permitted Equity Exceptions.
3.5
Except as set forth on Schedule 3.5, there are no actions, suits, investigations, or proceedings
by or before any Governmental Authority or arbitrator or, to Developer’s Knowledge, threatened
against or affecting Developer, which would reasonably be expected to impact the transactions
contemplated herein.
3.6
Developer is, and at all times has been, and to Developer’s Knowledge, Contractor and each
Subcontractor is, and at all times has been compliance with all applicable Laws, including those
relating to occupational health and safety, data privacy, and anti-corruption and anti-bribery, and the
Project Company Permits with respect to the Project, including the design, engineering, supply,
construction, installation, testing, commissioning, operation, and ownership of the Project.
3.7
The Membership Interests held by Developer represent one hundred percent (100%) of the
ownership interests in the Project Company. Developer has good title to and is the lawful, legal,
record, and beneficial owner of the Membership Interests and Buyer, at the Closing, will receive good
title to the Membership Interests, free and clear of all Liens. Other than with respect to Permitted
Equity Exceptions, there is no subscription, option, warrant, purchase right, call, or commitment of
any character relating to or entitling any Person to purchase or otherwise acquire the Membership
Interests. Other than with respect to Permitted Equity Exceptions, there is no outstanding security,
instrument, or obligation that is or may be convertible into or exercisable or exchangeable for any
Membership Interest or other ownership interest in the Project Company. Other than with respect
to Permitted Equity Exceptions, there are no contracts under which the Project Company may
become obligated to sell or otherwise issue any ownership interests in the Project Company. The
Membership Interests are an “uncertificated security” within the meaning of such term under
ARTICLE 8 of the Delaware Uniform Commercial Code. Developer has owned the Membership
Interests of Project Company continuously since the date of Project Company’s formation, and the
Membership Interests have been duly authorized, validly issued, fully paid, and non-assessable, in
each case to the extent applicable.
3.8 .
Developer has the financial resources, assets, operating capital, credit, and other resources
and means necessary to fulfill, on a timely basis, all of (a) Developer’s obligations under this
Agreement and the other Transaction Documents to which Developer is or will be a party and (b)
Developer’s and Project Company’s obligations under the EPC Contract and Major Supply
Agreements.
3.9 Reports.
(a) Developer has Made Available to Buyer a true, accurate, and complete copy of each
Firm Date Report on or before the Firm Date.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 209 of 1056
(b) Prior to the Closing Date, Developer has Made Available to Buyer (a) all updates and
supplements to the Firm Date Reports and (b) true, accurate, and complete copies of any additional
Reports received by Developer or the Project Company prior to the Closing Date.
(c) To Developer’s Knowledge, there has been no material change in any findings or
conclusions of any Report delivered or Made Available by Developer to Buyer other than for which
Developer has Made Available and redelivered such Report to Buyer in final form as revised to
address any such change.
3.10 .
Developer has Made Available for Buyer’s review all material information in its possession or
control or in the possession or control of its Affiliates relating to the Project Company and the Project
requested by Buyer in connection with Buyer’s due diligence examination conducted with respect to
the transactions contemplated by this Agreement. To Developer’s Knowledge, none of the
information provided by Developer or its Affiliates to Buyer contains any untrue or incorrect
statement of fact, or omits to state any fact necessary to make the information, in light of the
circumstances in which it was provided, not misleading.
3.11
No Material Adverse Change has occurred and is continuing and, to Developer’s Knowledge,
no event, result, occurrent, development, fact, change, or effect of whatever natures or kind exists
that would reasonably be expected to result in a Material Adverse Change.
3.12
Except as set forth on Schedule 3.12, (a) neither Developer nor any of its Affiliates nor any
manager, officer, employee, director, member, or stockholder of Developer or any of its Affiliates is a
party to any contract, agreement, instrument, or transaction with the Project Company; and (b) none
of such Persons has any beneficial or contractual interest in or will derive any financial gain from any
property or assets, real or personal, tangible or intangible, used in or pertaining to the Membership
Interests or the Project, except for prior to the Closing, the normal rights of a stockholder or member.
3.13 Brokers.
All negotiations relative to this Agreement and the other Transaction Documents and the
transactions contemplated hereby and thereby have been carried out by Developer directly with
Buyer without the intervention of any Person on behalf of Developer in such manner as to give rise
to any valid Claim by any Person against Buyer or any of its Affiliates for a finder’s fee, brokerage
commission, or similar payment.
3.14
Neither Developer nor Project Company, nor any of their respective directors, officers,
employees or agents, or any other Person acting on their behalf, directly or indirectly, have to
Developer’s Knowledge, given or agreed to give any gift or similar benefit to any customer, supplier,
governmental employee, or any other person that would violate Corrupt Practices Laws, or could
reasonably be expected to subject Project Company to any material damage or penalty in any civil,
criminal, or governmental litigation or proceeding under Corrupt Practices Laws. Developer further
represents and warrants that (a) no unrecorded fund or asset of Project Company has been
established for any purpose, (b) no accumulation or use of corporate funds of Project Company has
been made without being properly accounted for in the books and records of Project Company, and
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 210 of 1056
(c) no payment has been made by or on behalf of Project Company with the understanding that any
part of such payment is to be used for any purpose other than that described in the documents
supporting such payment. Neither Developer nor Project Company, nor any current director, officer,
employee or, to Developer’s Knowledge, any agent or other Person acting on behalf of Project
Company, have made, accepted, or received any unlawful contribution, payment, gift, kickback,
expenditure, or other item of value in violation of Corrupt Practices Laws.
3.15 Solvency.
No petition or notice has been presented, no order has been made and no resolution has been
passed for the bankruptcy, liquidation, winding-up, or dissolution of Developer. No receiver, trustee,
custodian, or similar fiduciary has been appointed over the whole or any part of Developer’s assets
or the income of Developer. Developer does not have any plan or intention of, or has received any
notice that any other Person has any plan or intention of, filing, making, or obtaining any such
petition, notice, order, or resolution or of seeking the appointment of a receiver, trustee, custodian,
or similar fiduciary.
10
Developer hereby represents and warrants to Buyer that all of the statements contained in
this ARTICLE 4 are true and correct: (a) as of the Execution Date, except to the extent such
representations and warranties are specifically made as of a particular date (in which case such
representations and warranties are true and correct as of such date); (b) as of the Firm Date; and (c)
as of the Closing Date.
4.1 ,
The Project Company is a limited liability company, duly organized, validly existing, and in
good standing under the Laws of Delaware. Project Company is duly qualified or licensed to do
business and is in good standing in all jurisdictions in which the character of the Real Property owned
or held under lease by it or the nature of the business now being transacted by it or proposed to be
transacted by it pursuant hereto makes qualification necessary, including the State of Idaho. True,
correct, and complete copies of the charter documents of the Project Company, all in such form as
currently in effect, have been Made Available to Buyer. The only business activity that has been
carried on or is currently carried on by the Project Company is the development, construction,
operation, and ownership of the Project.
4.2
The execution and delivery by Developer of this Agreement and the Transaction Documents
to which Developer is a party does not, and the performance by Developer of its obligations
hereunder and thereunder and the completion of the transactions contemplated hereby and thereby,
shall not:
(a) conflict with or result in a violation or breach of any of the terms, conditions or
provisions of Project Company’s organizational documents;

10 Note to Bidders: All project representations and warranties are subject to IPC’s ongoing due diligence review of the
project. Parties to discuss process for updating the disclosure schedules before the Closing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 211 of 1056
(b) assuming all of the consents and approvals set forth on Schedule 4.2(b) (the “Project
Company Consents”) have been obtained or given, result in a breach, default,or violation (or give rise
to any right of termination, cancellation or acceleration) under any of the terms, conditions, or
provisions of any Contract to which Project Company is a party (or by which the Assets of the Project
Company may be bound) or Permit obtained by Project Company (with or without notice or lapse of
time or both), except for such breaches, defaults, or violations (or rights of termination, cancellation,
or acceleration) as to which requisite waivers or consents have been obtained in writing (true and
correct copies of which have previously been furnished to Buyer);
(c) assuming all of the Project Company Consents have been obtained or given, conflict
with or result in a violation or breach in any term or provision of any applicable Law applicable to
the Project Company or the Project; or
(d) assuming all of the Project Company Consents have been obtained or given, result in
the imposition or creation of any Lien of any nature on the Project, other than Permitted Liens.
4.3
Except as set forth in Schedule 4.3(a), there have been no actions, suits, or legal or arbitration
proceedings pending to which the Project Company is or was a party or pertaining to any Project
Assets or the Membership Interests, and neither Developer nor the Project Company nor any of their
respective Affiliates has received written or oral notice of any threatened actions, suits or legal or
arbitration proceedings against or affecting the Project Assets, the Membership Interests, or the
Project Company, nor have any of their respective directors, managers, members, or officers received
written or oral notice of any such threatened proceedings, in any such case at law or in equity before
any Governmental Authority or arbitral body against or affecting the Project Company, the Project
Assets or the Project. The Project Company does not owe any indemnity pursuant to a claim for
indemnity that has been made against the Project Company by any counterparty to any Project
Company Contract. Developer has Made Available all notices of force majeure or any similar notices
with respect to any Project Company Contract, as set forth in Schedule 4.3(b).
4.4
(a) Project Company is, and at all times has been, in compliance with all applicable Laws,
including those relating to occupational health and safety, and the Project Company Permits with
respect to the Project. Neither the Developer nor the Project Company has received any written
notice or claim that the Developer or the Project Company has violated any applicable Law relating
to the Project Company or the Project Assets.
(b) The Project is being, and at all times has been, developed, constructed, and permitted
in compliance with all applicable Laws, all Project Company Permits, and Prudent Industry Practices.
As constructed, the Project shall conform to and comply with all zoning, environmental, wildlife, land
use, and other applicable Laws and the requirements of all Project Company Permits.
4.5
Since the date of its formation, Project Company has not conducted any business or acquired
any property or asset, except in each case in connection with the development and construction of
the Project. Project Company does not own any interest in any other Person. Project Company has
good and valid title to its assets and properties, free and clear of all Liens (other than Permitted
Liens).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 212 of 1056
4.6 Employees.
The Project Company does not have, nor has it ever had any employees. The Project
Company does not have, nor has it ever, maintained or participated in any Benefit Plan.
4.7
The Project Company does not own, nor has it ever owned, any capital stock, security,
membership, or partnership interest or other equity interest of any kind in any corporation,
partnership, limited liability company, joint venture, association, or other entity.
4.8
The Project Company does not have any managers, officers, or directors. The Project
Company does not have any bank accounts.
4.9
Except as otherwise disclosed in Schedule 4.9 and Made Available to Buyer, the Project
Company does not have any Liabilities of any nature (whether secured or unsecured, accrued,
absolute or contingent, unliquidated, or otherwise and whether due or to become due) including
book entry between Affiliates or any other method or means except for Liabilities for future
performance arising in the ordinary course under the Project Company Contracts and Project
Company Permits listed in the Schedule 4.9 (none of which is a Liability for breach of contract, breach
of warranty or tort). Except as set forth in Schedule 4.9, all invoices or other demands for payment
received prior to Closing by the Project Company or by Developer or its Affiliates with respect to any
existing Project Company Contracts have been paid in full, and the Project Company does not
otherwise have any obligations to make any payment as of the Closing Date. Upon the Closing, the
Project Company has no Indebtedness, except for Permitted Indebtedness.
4.10
As of the Execution Date and the Firm Date, Schedule 4.10 contains a true, correct, and
complete list of all Project Assets. As of the Closing Date, Schedule 4.10 contains a true, correct, and
complete list of all Project Assets that are not the Project or the subcomponents thereof. Other than
as set forth on Schedule 4.10, the Project Company has good and valid title (or leasehold title, as
applicable) to each of its Project Assets, free and clear of Liens (other than Permitted Liens), and will
continue to have such title notwithstanding the Closing hereunder.
4.11 Project Company Contracts.
11
(a) Schedule 4.11 contains a true, correct, and complete list of all Project Company Contracts
(other than any real property agreements, which are listed on Schedule 4.13(a)), (b) true, correct,
and complete copies of all such Project Company Contracts have been Made Available to Buyer, and
(c) neither the Project Company nor any Affiliate thereof that is a party to any such Project Company
Contract is in default (and, to Developer’s Knowledge, no other party thereto is in default) of any
material obligation under any such Project Company Contract, and, to Developer’s Knowledge, no
conditions exist that, with the passage of time or the giving of notice, would be reasonably expected
to constitute a default of any material obligation under any such Project Company Contract. Each
Project Company Contract constitutes the legal, valid, binding, fully effective, and enforceable
obligation of the Project Company and any Affiliate thereof that is a party to any such Project

11 Note to Bidders: Please confirm that all contracts will be with the Project Company and not the Developer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 213 of 1056
Company Contract and, to Developer’s Knowledge, any other party thereto except as may be limited
by applicable bankruptcy and similar laws affecting the enforcement of creditors’ rights and general
equitable principles. All of the representations and warranties made under each Project Company
Contract by the Project Company or any Affiliate thereof that is a party to any such Project Company
Contract were true and correct when made. Neither the Project Company nor any Affiliate thereof
has received any written notice from any counterparty to any Project Company Contract that such
Person is considering the amendment, termination, revocation, or cancellation of any of such Project
Company Contract. Neither is the Project Company a party to, nor is the Project or the Project Assets
bound by or subject to, any Contract other than a Project Company Contract.
4.12 12
(a) Schedule 4.12(a) sets forth all Permits (other than Deferred Permits) required by
applicable Law in connection with the development, engineering, procurement, construction,
commissioning, ownership, and commencement of operation of the Project (the “Project Company
Permits”). Developer has Made Available to Buyer all Project Company Permits.
(b) Schedule 4.12(b) sets forth all Deferred Permits required by applicable Law in
connection with the development, engineering, procurement, construction, commissioning,
ownership, operation, and maintenance of the Project in accordance with this Agreement and the
other Transaction Documents as of the date that the Project achieves Final Completion. Developer
has Made Available to Buyer all Deferred Permits that it has obtained as of the Closing Date and as of
the date the Project achieves Final Completion. For the avoidance of doubt, once the Project Company
obtains a Deferred Permit, Developer shall revise Schedules 4.12(a) and 4.12(b) accordingly.
(c) All Project Company Permits that are required by applicable Law on or prior to the
date this representation is made or deemed made pursuant to this Agreement listed on Schedule
4.12(a) have been obtained in the name of the Project Company, are in full force and effect, are final
(and all public comment and/or appeal periods under applicable Law have expired or terminated)
and satisfy all requirements of this Agreement with respect to review and approval thereof. To
Developer’s Knowledge, no event has occurred and is continuing that reasonably would be
anticipated to permit, or after notice or lapse of time or both reasonably would be anticipated to
permit, any materially adverse modification, revocation, or termination of, or any other material
change in, any Project Company Permit. Except as set forth in Schedule 4.12(c), there is no action,
suit, investigation, or proceeding with respect to the Project Company, any Project Assets, or the
Project, nor, to Developer’s Knowledge, threatened, that reasonably would be anticipated to result in
any material adverse modification, or the rescission, termination, or suspension of any Project
Company Permit.
(d) To Developer’s Knowledge, no facts or circumstances concerning the Project, the
Project Assets, or the Project Company exist that would reasonably be expected to hinder, impair,
restrict, limit, or disqualify Project Company or the Project from obtaining any Deferred Permit or
any ministerial Permit in the ordinary course prior to the time it is required to be obtained
hereunder, under the other Transaction Documents, the EPC Contract, and, in any event, prior to the
time required by applicable Law. There does not exist any condition that, with notice, passage of time,
or both, would reasonably be expected to cause the Project Company to not be able to acquire the
Deferred Permits and any necessary ministerial Permits in the ordinary course, on reasonable terms,
and in a reasonable period of time

12 Note to Bidders: Please confirm that all permits will be in the name of the Project Company.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 214 of 1056
4.13 Estate.13
(a) Schedule 4.13(a) sets forth all “Real Property Contracts” that grant the Project
Company real property rights required for the Project, including the design, engineering, supply,
construction, installation, testing, commissioning, operation, and ownership of the Project. Neither
Developer nor any of its Affiliates (other than Project Company) owns or leases any real property
associated with the Project Company, the Site, or the Project. Except as set forth in Schedule 4.13(a),
the Project Company does not own or lease any Real Property. The Real Property Contracts are in
full force and effect, and the applicable landlords have not given Developer, the Project Company, or
any of its Affiliates any notice of breach, default, or termination of any of the Real Property Contracts.
There exists no breach, default, or event or condition which, with the giving of notice or the passage
of time or both, would constitute a breach or default under the Real Property Contracts by the
Developer, the Project Company or, to Developer’s Knowledge, the applicable landlord. The rent,
fees, and other sums due and payable under the Real Property Contracts have been paid through the
Closing Date. There exists no lease superior to the Real Property Contracts, and there is no mortgage,
deed of trust, or security interest which may disturb or encumber the Real Property Contracts, as
long as there is no tenant default under the Real Property Contracts. To Developer’s Knowledge,
other than uses reserved to landlord in the Real Property Contracts and rights holders identified in
the Title Policy, no other Person has the right to occupy the Real Property. As of the Closing Date, the
Project Company will have good and Af to the Real Property Contracts, and such Real Property
Contracts are free and clear of all Liens other than Permitted Liens. Without limiting the generality
of the foregoing, as of the Closing Date, any oral farming leases pertaining to any part of the Site have
been properly and legally terminated in accordance with Idaho Law.
(b) Schedule 4.13(b) sets forth all easements (other than those easements included in
Real Property Contracts) required for the installation and maintenance of overhead or underground
transmission for the Project, collection or communication lines and facilities for the Project, and other
appliances and fixtures for use in connection with such lines and facilities (“Easements”). The
Easements are in full force and effect, and the applicable landowners under the Easements have not
given Developer, Project Company, or any of its Affiliates any notice of breach, default, or termination
of any of the Easements. There exists no breach, default, or event or condition which, with the giving
of notice or the passage of time or both, would constitute a breach or default under the Easements by
the Developer, the Project Company, or the applicable landowner. Any amounts due and payable
under the Easements have been paid through the Closing Date. There is no mortgage, deed of trust,
or security interest which may disturb or encumber the Easements, as long as there is not default by
grantee under the Easements. As of the Closing Date, the Project Company will have good and
marketable title to the Easements, and such Easements are free and clear of all Liens other than
Permitted Liens.
(c) Developer has delivered and Made Available to Buyer true, correct, and complete
copies of (i) the Real Property Contracts, (ii) the Easements, and (iii) the most recent leasehold title
insurance commitments or proforma title policy (together with exceptions thereto), as applicable,
and survey with respect to the Real Property and the Site that are in the possession of Developer and
Project Company.

13 Note to Bidders: Please confirm that all site control will be in the name of the Project Company. Please confirm that no
real property is currently owned by the Project Company. For the parcels that will be purchased, please describe the process
and timing for purchase.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 215 of 1056
(d) Developer has Made Available and delivered to Buyer true, correct, and complete
copies of all Contracts providing for the sale, lease, transfer, or other disposition, including any option
Contracts, on, for, or with respect to the Real Property or the Site.
(e) Except as set forth on Schedule 4.13(e), there arenopending zoning or other land use
or Permit-related proceedings (including condemnation or eminent domain proceedings) and there
is no contemplated or threatened zoning or other land use or Permit-related proceedings (including
condemnation or eminent domain proceedings) affecting the Real Property or the Site or any part
thereof, or any sale or other disposition of the Real Property or the Site or any part thereof in lieu of
condemnation.
(f) To Developer’s Knowledge, except for assessments occurring on a regular basis in
accordance with applicable Law, there is no pending or contemplated reassessment of any parcel
included in the Site that is reasonably expected to increase the real estate Tax assessment for such
parcels.
(g) Developer has not violated, and to Developer’s Knowledge there is no violation of, any
applicable Law relating to or affecting the Real Property or the Site.
(h) The Real Property, including the Site and any setbacks and associated borders, within
the fence line does not exceed an area of [__] acres. The aggregate costs and expenses under the Real
Property and Easements for the total Real Property, including developed and undeveloped land, does
not exceed an average of $[__]/acre/year (subject to an escalation equal to the greater of (i) 2% per
year on a compounded basis or (ii) by the percentage change, if any, in the CPI for the preceding
available four quarters), for a minimum of [25] years after Substantial Completion.
4.14
(a) Schedule 4.14(a) sets forth all environmental reports, assessments, and audits,
including reports, assessments, and audits relating to wetlands, air quality, and air pollutant
emissions or discharges, and studies relating to threatened or endangered species and avian species,
including those species protected by Environmental Law, and studies relating to archaeological,
cultural, and historical resources prepared by or on behalf of Project Company 14 in connection with
the Project or otherwise in Developer’s possession or control with respect to the Project. Developer
has Made Available and provided Buyer with copies of the materials set forth in Schedule 4.14(a).
(b) (i) as of the Closing Date, Project Company holds and is in compliance with all Project
Company Permits, including all applicable environmental Permits; (ii) the Project has been
constructed, and the Work has been performed, in compliance with all Environmental Laws; (iii)
neither Developer nor Project Company has received any written notice of a pending or threatened
Claim, or inquiry by any Governmental Authority or other Person relating to any actual or alleged
violations of Environmental Laws or any actual or potential obligation on the part of Developer or
Project Company to investigate or take any corrective action relative to any Regulated Material or
threatened Release of any Regulated Material, in each case, related to the Project; (iv) neither
Developer nor Project Company has entered into or agreed in writing to any final decree or order
with any Governmental Authority and neither Developer nor Project Company is subject to any
Judgment relating to compliance of the Project with any Environmental Law or to the investigation
or cleanup of Regulated Materials at the Project; (v) to Developer’s Knowledge and except as set forth
in the Environmental Report, no Person has generated, transported, treated, stored, disposed of,
arranged to be disposed of, Released or threatened to Release any Regulated Materials at, on, from,

14 Note to Bidders: Please confirm that all environmental studies and reports will be for the benefit of the Project Company .
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 216 of 1056
or under the Site in violation of, or as would reasonably be expected to result in liability under, any
Environmental Laws; (vi) except as set forth in the Permits and Project Company Contracts, neither
Developer nor Project Company has assumed any contractual liabilities or obligations arising under
any Environmental Law in connection with the Project; and (vii) neither Developer nor Project has
utilized any underground storage tanks or Equipment using polychlorinated biphenyls, Emerging
Contaminants, or asbestos in violation of Environmental Law at the Site. For the avoidance of doubt,
compliance with Environmental Laws includes performance of all studies required or recommended
under Environmental Law to assess the impacts of the Project on the environment, wildlife, or
cultural resources and the development and implementation of best management practices and
mitigation measures to reduce or avoid impacts to environmental, wildlife, or cultural resources,
including, as applicable, any species conservation strategy or conservation agreement and any
cultural resources treatment plan
(c) Except as set forth in Schedule 4.14(c), no Environmental Law requires Developer or
Project Company to obtain the consent of a Governmental Authority to any transaction contemplated
by this Agreement or any Transaction Document, including (i) any requirement to modify or to
transfer any Project Company Permit, (ii) any requirement to file any notice or other submission with
any Governmental Authority, (iii) the placement of any notice, acknowledgment or covenant in any
land records, or (iv) the modification of or provision of notice under any Contract, consent order, or
consent decree. No Lien has been placed upon any Real Property under any Environmental Law.
4.15
(a) Developer has, or will have at the Closing, the power and right to sell, convey, deliver,
transfer, and assign to Buyer, the Membership Interests and, thereby, the Project Assets free and clear
of all Liens, other than Permitted Liens on the Project Assets.
(b) Other than the Transaction Documents, the Project Assets, the Project Company
Permits, the Project Company Contracts, the Real Property Contracts, the Easements, the EPC
Contract, the Major Supply Agreements, the Reports, the Transferred Warranties, the Equipment, and
the Materials, there are no other material assets or rights of any kind, whether tangible or intangible,
real or personal, owned or held by Developer or the Project Company or any of its Affiliates relating
to, associated with, or concerning the Project.
(c) As of the Firm Date, the Transaction Documents, the Project Assets, the Project
Company Permits, the Project Company Contracts, the Real Property Contracts, the Easements, the
EPC Contract, the Major Supply Agreements, and the Reports constitute all of the material Contracts,
Permits, assets, and properties necessary to develop, permit, design, engineer, supply, procure,
construct, install, test, commission, own, and commence operation of the Project in accordance with
applicable Law, Prudent Industry Practice, the Project Company Permits, and the Transaction
Documents.
(d) As of the Closing Date, the Transaction Documents, the Project Assets, the Project
Company Permits, the Project Company Contracts, the Real Property Contracts, the Easements, the
EPC Contract, the Major Supply Agreements, the Reports, the Transferred Warranties, the
Equipment, and the Materials, constitute all of the material Contracts, Permits, assets, and properties
necessary to develop, permit, design, engineer, supply, procure, construct, install, test, commission,
use, own, and commence operations of the Project in accordance with applicable Law, Prudent
Industry Practice, the Project Company Permits, and the Transaction Documents.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 217 of 1056
4.16 Project Expertise.
(a) There exist no facts or circumstances that reasonably could be expected to hinder,
delay, restrict, or prevent: (i) the ability of the Project to be developed, permitted, designed,
engineered, supplied, constructed, installed, tested, and commissioned in all material respects in
accordance with the terms and conditions of the Transaction Documents, applicable Laws, the Project
Company Permits, and Prudent Industry Practice; (ii) the Project from achieving Mechanical
Completion on or before the Outside Closing Date; or (iii) the Project from achieving Final Completion
in accordance with the Project Schedule.
(b) The Project Assets constituting the Project to be transferred, conveyed, assigned, or
otherwise acquired and delivered to Buyer pursuant to this Agreement or any other Project Company
Contract, include all of the assets used, held by, or necessary or convenient for the ownership and
operation of the Project, and collectively will provide to Buyer an operational Project at the Site in
accordance with all Project Company Permits, applicable Law, and Prudent Industry Practice, and no
Person other than Developer, Project Company, or Buyer owns or has any rights in or to the Project.
(c) The development, permitting, design, engineering, supply, procurement,
construction, installation, testing, commissioning, ownership, use, operation, and maintenance of the
Project in accordance with this and the other Transaction Documents is in compliance with all Project
Company Permits, applicable Law, and Prudent Industry Practice.
(d) Each of the Developer and Contractor have substantial experience and expertise in
the development, design, engineering, construction, and management of turnkey construction of
renewable energy facilities such as the Project and the capability to carry out the Work in accordance
with terms and conditions of this Agreement and the other Transaction Documents, and
acknowledges that Buyer is relying on such experience, expertise, and capability in entering into this
Agreement.
4.17
(a) To Developer’s Knowledge, no facts or circumstances concerning the Project or the
Project Company exist that would reasonably be expected to hinder, impair, restrict, limit, preclude,
or disqualify the Project or the Project Assets from qualifying for, and producing and giving rise to,
the Tax Benefits.
(b) The Project Company is the owner of the Project Assets and the Project for tax
purposes, and neither the Project Assets, the Project nor any property that is part of the Project has
been placed in service for federal income tax purposes (including Sections 48 and 168 of the Code).
Neither the Project nor any property that is part of the has been energized or synchronized to the
electric transmission system. Critical preoperational testing with respect to the Project has not been
completed. Daily operations at the Project have not commenced.
(c) There has been no “original use” (within the meaning of Section 48 or Section 168(k)
of the Code) of the Project Assets, the Project, or any property that is part of the Project. No property
that is a part of the Project Assets or the Project has been used by any Person other than in the
development, construction, or startup of the Project.
(d) Neither Developer nor any Developer Affiliate has claimed or intends to claim any
depreciation deductions, amortization deductions, tax credits (including the ITC), or other credits,
deductions, or allowances with respect to the Project or any property that is part of the Project or the
Project Assets.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 218 of 1056
(e) No property in the Project or the Project Assets is “dual use equipment” within the
meaning of Treasury Regulations Section 1.48-9(d)(6).
(f) No portion of the basis of the property in the Project is attributable to “qualified
rehabilitation expenditures” within the meaning of Section 47(c)(2)(A) of the Code.
(g) No portion of any property that is part of the Project or the Project Assets has
benefited from the proceeds of any grant or rebate program that would cause a reduction in the
amount of the ITC with respect to the Project or the Project Assets, and no application with respect
to any such grant or rebate has been filed or submitted. No portion of the Site is currently enrolled in
the U.S. Department of Agriculture’s Conservation Reserve Program.
(h) No property that is part of the Project or the Project Assets is or has been (i) “tax-
exempt bond financed property” or “tax-exempt use property” within the meaning of Section 168 of
the Code, (ii) imported property of the kind described in Section 168(g)(6) of the Code, or (iii)
property used by a Person described in Section 50(b)(3) of the Code.
(i) The Project is located entirely within the United States.
(j) [Construction of the Project began before [____] and after [____] within the meaning of
Sections 48(a)(2)(A)(i)(II), 48(a)(3)(A)(i) and 48(a)(6) of the Code and the IRS Notice.] The
certifications set forth in the Beginning of Construction Certificate are true, correct, and complete in
all respects.
(k) The transactions contemplated by this Agreement will not have an adverse effect on
the continuing validity and effectiveness of any Tax exemption, Tax holiday, other Tax abatement, or
incentives for which the Project is currently eligible.
(l) The Site has not been subject to a preferential or special property tax assessment,
value limitation, or other favored Tax treatment. The Site is not, has not been, and will not be (as a
result of the Closing and the transactions contemplated hereby) subject to rollback Taxes.
(m) All Tax Benefits attributable to, resulting from or arising in connection with the
Project shall belong to Buyer. Neither Developer nor Project Company has any legal obligation,
absolute or contingent, to any Person other than Buyer to transfer or effect a transfer of all or any
portion of the Project, including any electric power or Tax Benefits attributable to, resulting from, or
arising in connection with the Project.
4.18 Taxes.
(a) The Project Company is and has at all times been classified as an entity disregarded
as separate from Developer for U.S. federal tax purposes (and state and local tax purposes, as
applicable), and no election has been filed by or with respect to the Project Company to treat the
Project Company as an association taxable as a corporation for U.S. federal tax purposes.
(b) All Tax Returns that are required to be filed by or with respect to the Project
Company, the Project Assets, the Work, or the Project have been duly and timely filed in accordance
with all applicable Laws, all such Tax Returns are true, correct, and complete in all aspects and have
been prepared in substantial compliance with all applicable Laws, and all Taxes due and payable by
or with respect to the Project Company, the Project Assets, the Work, or the Project have been duly
and timely paid in full (whether or not shown as due on such Tax Returns).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 219 of 1056
(c) All Taxes that are required to be withheld or collected by or with respect to the Project
Company, the Project Assets, the Work, or the Project have been duly and timely withheld and
collected and have been duly and timely paid, remitted, or deposited to or with the appropriate
Governmental Authority.
(d) There are no Liens for Taxes (other than statutory Liens for Taxes that are not yet due
and payable) upon any assets of the Project Company, the Project Assets, the Work, or the Project,
nor are any such Liens pending or threatened.
(e) The Project Company (i) has no liability for the Taxes of any other Person (A) under
Treasury Regulations Section 1.1502-6 (or any similar provision of state, local, or foreign law) or (B)
as a transferee or successor, and (ii) is not and has not been a party to, and does not have has any
liability under, any Tax sharing, Tax allocation, Tax indemnity, Tax reimbursement, or similar
agreement or arrangement, other than any agreement or arrangement entered into in the ordinary
course of business the primary purchase of which is not Tax sharing, allocation, indemnity, or
reimbursement.
(f) Neither the Project Company nor Buyer or any of its Affiliates (as a result of Buyer
being a direct or indirect owner of the Project Company after the Closing) is required to include any
item of income in, or exclude any item of deduction from, taxable income for any Tax period (or
portion thereof) ending after the Closing as a result of any (i) change in method of accounting for any
taxable period (or portion thereof) ending on or before the Closing Date, (ii) use of an improper
method of accounting for a Tax period ending on or prior to the Closing, (iii) “closing agreement” as
described in Section 7121 of the Code (or any corresponding or similar provision of state, local or
foreign Law) executed on or prior to the Closing, (iv) installment sale or open transaction disposition
made on or prior to the Closing, (v) prepaid amount received on or prior to the Closing, or (vi) election
under Section 108(i) of the Code (or any corresponding or similar provision of state, local, or foreign
Tax Law) made prior to the Closing.
(g) The Project Company has not engaged in any “reportable transaction” as defined in
Treasury Regulations Section 1.6011-4(b)(2) (or any transaction requiring disclosure under a
corresponding or similar provision of state, local, or foreign Tax law).
(h) No Claim has been made by a Governmental Authority in a jurisdiction where Tax
Returns of a particular type are not filed by or with respect to the Project Company, the Project Assets,
the Work, or the Project that the Project Company, the Project Assets, the Work, or the Project is or
may be subject to such type of taxation by that jurisdiction.
(i) The Project Company is in compliance with all state unclaimed property and escheat
Laws and has timely and accurately filed all required unclaimed property or escheat reports or Tax
Returns.
(j) There is no audit, action, claim, assessment, examination, levy, deficiency, adjustment,
or other judicial or administrative proceeding pending, threatened, or to Developer’s Knowledge,
proposed or contemplated with respect to any Tax imposed on or with respect to the Project
Company, the Project Assets, the Work or the Project.
(k) There are no agreements, consents, or waivers extending the statutory period of
limitation applicable to the collection or assessment of any Taxes imposed on or with respect to the
Project Company, the Project Assets, the Work, or the Project and no Governmental Authority has
requested any such agreement, consent, or waiver. The Project Company is not the beneficiary of any
extension of time within which to file any Tax Return.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 220 of 1056
(l) No power of attorney is currently in effect, and no private letter ruling, technical
advice memorandum, closing agreement, or similar item has been requested or obtained from any
Governmental Authority with respect to the Project Company, the Project Assets, the Work, or the
Project, including any application for a ruling, advice, agreement, or similar item that has been
withdrawn.
(m) Developer is not a “foreign person” within the meaning of Section 1445 of the Code.
4.19 FERC.
The Project Company is not subject to, or is exempt from, regulation as a “holding company”
under the Public Utility Holding Company Act of 2005 and FERC’s regulations and orders issued
thereunder. The Project Company is not a “public utility” under Section 201(e) of the Federal Power
Act and FERC’s regulations and orders issued thereunder. The Project Company is not subject to
financial, organizational, or rate regulation as a “public utility,” “electric utility,” or similar
designation under any Law.
4.20 Insurance.
Schedule 4.20 contains (a) copies of certificates of insurance for all current insurance policies
that insure the Project Company, the Project Assets and the Project until the date of the Closing, and
(b) a true, complete, and correct list of all Claims made under such insurance policies since the
formation of the Project Company. All such insurance policies are in full force and effect, neither
Developer nor the Project Company has defaulted in any material respect (or is in material breach of
such insurance policies, including any such breach or default with respect to the payment of
premiums or the giving of notice of Claims), with respect to its obligations under any such insurance
policies or have been denied insurance coverage thereunder, and no written notice of cancellation or
termination has been received by Developer or the Project Company respect to any such policy which
was not replaced on substantially similar terms prior to the date of such cancellation.
4.21
True and correct copies of the Project Company’s Books and Records have been Made
Available to Buyer, including such Books and Records that may be maintained by Developer.
4.22
Except as set forth in Schedule 4.22, Project Company does not own any copyright, intellectual
property right, patent, patent application, domain name, trade secret, trademark, trademark
application, service mark, service mark application, assumed name, or trade name. Neither Project
Company nor, with respect to the Project, Developer have interfered with, infringed upon,
misappropriated, or violated any intellectual property rights of third parties in any respect, and
neither Project Company nor, with respect to the Project, Developer have received any charge or
complaint, claim, demand, or notice alleging any such interference, infringement, misappropriation,
or violation.
4.23
There has been no security breach, cyberattack, other data security or cyber incident or
unauthorized access to any Developer IT Asset, which resulted in the unauthorized use,
misappropriation, modification, encryption, corruption, disclosure, or transfer of any material
information or data contained therein relating to the Project Company or the Project Assets that
would reasonably be expected to result in a Material Adverse Change.
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4.24
P
BUYER
Buyer hereby represents and warrants to Developer that the statements contained in this
ARTICLE 5 are true and correct: (a) as of the Execution Date, except to the extent such
representations and warranties are specifically made as of a particular date (in which case such
representations and warranties are true and correct as of such date); (b) as of the Firm Date; and (c)
as of the Closing Date.
5.1 ,
Buyer is duly formed, validly existing, and in good standing under the applicable Laws of the
jurisdiction of its formation. Buyer has the requisite corporate power and authority to own, operate,
and lease its properties and assets and to carry on its business as now being conducted and as
proposed to be conducted pursuant hereto. Buyer is duly qualified or licensed to do business and is
in good standing in all jurisdictions in which the character of the properties owned or held under
lease by it or the nature of the business now being transacted by it or proposed to be transacted by
it where qualification or license is necessary.
5.2
Buyer has full corporate power and authority to execute and deliver this Agreement and the
Transaction Documents to which it is a party in connection with the transactions contemplated
hereby, to perform its obligations hereunder and thereunder, and to complete the transactions
contemplated hereby and thereby. The execution and delivery by Buyer of this Agreement and the
Transaction Documents to which it is a party, and the performance of its obligations hereunder and
thereunder, have been duly and validly authorized by all necessary corporate action.
5.3
This Agreement and the Transaction Documents to which Buyer is a party have been duly
executed and delivered by Buyer and, assuming due and valid authorization, execution and delivery
thereof by Developer and each other party thereto, this Agreement and the Transaction Documents
to which it is a party are valid and binding obligations of Buyer enforceable against Buyer in
accordance with their terms, subject to applicable bankruptcy, insolvency, reorganization,
moratorium, or other similar applicable Laws relating to or affecting the enforcement of creditors’
rights generally and to general principles of equity.
5.4
Buyer’s execution and delivery of this Agreement and the Transaction Documents to which it
is a party does not, and the performance by Buyer of its obligations hereunder and thereunder, and
the completion of the transactions contemplated hereby and thereby, shall not:
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(a) conflict with or result in a violation or breach of any of the terms, conditions, or
provisions of Buyer’s organizational documents;
(b) assuming all of the consents and approvals set forth on Schedule 5.4(b) (the “Buyer
Consents”) have been obtained or given, result in a breach, default, or violation (or give rise to any
right of termination, cancellation, or acceleration) under any of the terms, conditions, or provisions
of any material Contract or Permit (with or without notice or lapse of time or both) with respect to
which Buyer is a party or by which Buyer or its assets may be bound, except for such breaches,
defaults, or violations (or rights of termination, cancellation, or acceleration) as to which requisite
waivers or consents have been obtained in writing (true and correct copies of which have previously
been furnished to Developer) or which would not reasonably be expected to result in a Material
Adverse Change; or
(c) assuming all of the BuyerConsents have been obtained or given, conflict with or result
in a violation or breach in any term or provision of any applicable Law applicable to Buyer.
5.5
Except as set forth on Schedule 5.5, there are no actions, suits, investigations,or proceedings
by or before any Governmental Authority or arbitrator pending against Buyer or, to Buyer’s
Knowledge, threatened against Buyer, which would reasonably be expected to result in a Buyer
Material Adverse Change.
5.6 Approvals.
(a) Schedule 5.6(a) sets forth all Permits required with respect to the design, engineering,
development, construction, startup, testing, commissioning, and completion of the Project that are
the responsibility of Buyer to obtain (the “Buyer Permits”).
(b) Except for IPUC Approval and as set forth on Schedule 5.6(b), no consent or approval
of, filing with, or notice to, any Governmental Authority by Buyer is required in connection with the
execution, delivery, and performance by Buyer of this Agreement or any of the Transaction
Documents to which it is a party or the completion of the transactions contemplated hereby or
thereby.
5.7 Brokers.
All negotiations relative to this Agreement and the other Transaction Documents and the
transactions contemplated hereby and thereby have been carried out by Buyer directly with
Developer without the intervention of any Person on behalf of Buyer in such manner as to give rise
to any valid Claim by any Person against Developer or any of its Affiliates for a finder’s fee, brokerage
commission or similar payment.
5.8 Solvency.
No petition or notice has been presented, no order has been made and no resolution has been
passed for the bankruptcy, liquidation, winding-up, or dissolution of Buyer. No receiver, trustee,
custodian, or similar fiduciary has been appointed over the whole or any part of Buyer’s assets or the
income of Buyer. Buyer does not have any plan or intention of, or has received any notice that any
other Person has any plan or intention of, filing, making, or obtaining any such petition, notice, order,
or resolution or of seeking the appointment of a receiver, trustee, custodian, or similar fiduciary.
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5.9
Upon satisfaction of the conditions precedent set forth in 2.9, Buyer will have sufficient cash
on hand or other sources of, or access to, immediately available funds to enable it to pay the Purchase
Price in accordance with 2.7(b).
6.1
(a) Within five (5) Business Days of Buyer’s submission of the executed Agreement to the
IPUC in accordance with 2.1 and thereafter until the Firm Date, Developer shall be obligated to
furnish Credit Support to Buyer, in the aggregate amount of $[____] (the “Initial Credit Support”).
(b) Within five (5) Business Days of the Firm Date until Final Completion, Developer shall
be obligated to furnish Credit Support to Buyer in the aggregate amount of $[____] (the “Construction
Period Credit Support”).
(c) Within five (5) Business Days of Final Completion until the first (1st) anniversary of
Final Completion, Developer shall be obligated to furnish Credit Support to Buyer in the aggregate
amount of $[____] (the “Post-Construction Period Credit Support”).
(d) Within five (5) Business Days of the first anniversary of Final Completion and
continuing until the fifth (5th) anniversary of Final Completion, Developer shall be obligated to
furnish Credit Support to Buyer in the aggregate amount of $[____] (the “Operating Period Credit
Support”).
6.2
Buyer shall be entitled to draw upon and/or be paid from any Credit Support provided by the
Developer for any obligation of Developer arising under this Agreement and the Transaction
Documents that is not paid when due (subject to any applicable cure periods).
6.3
The Initial Credit Support shall be returned to Developer within fifteen (15) Business Days
after Developer furnishes the Construction Period Credit Support in accordance with 6.1(b). The
Construction Period Credit Support shall be returned to Developer within fifteen (15) Business Days
after Developer furnishes the Post-Construction Period Credit Support in accordance with 6.1(c).
The Post Construction Period Credit Support shall be returned to Developer or released within fifteen
(15) Business Days after Developer furnishes the Operating Period Credit Support in accordance with
6.1(d). The Operating Period Credit Support shall be returned to Developer within fifteen (15)
Business Days after the fifth (5th) anniversary of Final Completion. Notwithstanding anything herein
to the contrary, upon the expiration or earlier termination of this Agreement, the Credit Support
required under 6.1 shall remain in place in an amount equal to the aggregate value of the Claims by
Buyer under this Agreement made in good faith and then pending, if any, but no more than the
aggregate amount required under 6.1, which Credit Support provided under 6.1 shall only then be
released once such pending Claims are resolved and any monies due in connection therewith have
been paid to Buyer.
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6.4 Contractor
Developer shall cause the EPC Contract to require the Contractor to post Credit Support or
obtain a guaranty from a creditworthy parent company, in the aggregate amount of the EPC Contract
Price. The amount of any such Credit Support may be reduced dollar-for-dollar with any EPC
Contract Price sums paid to Contractor. If Contractor’s Credit Support is furnished by way of a parent
guaranty or a letter of credit, such guaranty, or letter of credit shall name Buyer as an additional
beneficiary.
7.1
(a) Each Party shall each (a) as promptly as is reasonably practicable, diligently and in
good faith use commercially reasonable efforts to cause each Firm Date condition and Closing
condition in this Agreement to be satisfied as soon as reasonably possible, and (b) coordinate and
cooperate with the other Party in providing such information and supplying such assistance as may
be reasonably requested by such other Party up to the Final Completion of the Project. Without
limiting the generality of the foregoing or any other provision of this Agreement regarding approvals,
the Developer and Buyer shall each individually use commercially reasonable efforts to obtain all
authorizations, consents, orders, and approvals of, and to give all notices to and make all filings with,
all Governmental Authorities (including those pertaining to the Permits and Regulatory Approvals)
and third parties up to Final Completion of the Project that may be or become necessary for the
performance of its obligations under this Agreement and shall cooperate fully with the other Party in
promptly seeking to obtain all such authorizations, consents, orders, and approvals, giving such
notices, and making such filings; provided, however, that Developer shall be primarily responsible
for seeking and obtaining such approvals, consents, and orders and preparing and submitting such
notices and filings (other than Buyer’s obligation to submit this Agreement for IPUC Approval).
(b) Each Party shall use commercially reasonable efforts to do and perform or cause to
be done and performed all further acts and things and shall execute and deliver all further
agreements, certificates, instruments, and documents as any other Party may reasonably request in
order to effect the agreements set forth in the Transaction Documents and the consummation of the
transactions contemplated herein. Developer shall promptly provide Buyer with all materials and
documentation reasonably requested by Buyer for its due diligence review of the Membership
Interests and the Project. Developer shall promptly and diligently cooperate with Buyer in such due
diligence process, including responding within a commercially reasonable period to all reasonable
inquiries.
7.2
(a) Prior to the Closing Date, Developer shall take the following actions:
(i) Design the Project so as to achieve the Performance Guarantees, each as
confirmed by the Performance Guarantee Tests, respectively;
(ii) Obtain and maintain, or cause to be obtained or maintained, insurance on the
Project and Project Site effective as of the start of construction in accordance with Appendix L-1;
(iii) Deliver true, correct, and complete copies of draft and final Project reports,
studies and Design Documents required to be delivered pursuant to this Agreement with respect to
the Project;
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(iv) E
name of the Project Company prior to Closing;
(v) Ensure Buyer and the Buyer’s Engineer and their respective representatives
have a right to a representative with a full-time presence at the Project Site and a right to reasonably
access and inspect the Project Site, the Project Assets, and the Books and Records;
(vi) deliver to Buyer (i) one or more commitments for title insurance for the
Project Site, and (ii) a current preliminary ALTA survey. Buyer may provide to Developer a title
objection letter that identifies Firm Date title objections and required exceptions; and
(vii) conduct its business and, if applicable, that of the Project Company in the
ordinary course (subject to certain approval rights of Buyer pursuant to the terms of this Agreement),
protecting Buyer’s and, if applicable, the Project Company’s interests against material changes, but
affording Developer and, if applicable, Project Company the flexibility to continue necessary
development of the Project.
(b) Prior to the Closing Date, Developer shall cause the Project Company to conduct its
business in the ordinary course of business, consistent with past practice; provided that Developer
shall not, and shall cause the Project Company and its Affiliates not to, take any of the following
actions without the prior written consent of Buyer;
(i) except as required by this Agreement, modify in any material respect, amend,
or terminate any Project Company Contract (including, but not limited to the EPC Contract, the Major
Supply Agreements, and the Interconnection Agreement) or Real Property Contract; provided
however, that such actions will only be deemed “material” if the adverse impact to Buyer (or after
the Closing, the Project Company or the Project), individually or in the aggregate, is greater than
$[_______];
(ii) enter into an engineering procurement and construction agreement or major
supply agreement that does not conform (in all material respects) to the requirements of this
Agreement, including the forms of such agreements attached hereto as Exhibits I and Exhibit H.
(iii) other than the EPC Contract, the Major Supply Agreements, and the
Interconnection Agreement, enter into any material Project Company Contract or Real Property
Contract; provided however, that such actions will only be deemed “material” if the adverse impact
to Buyer (or after the Closing, the Project Company, or the Project), individually or in the aggregate,
is greater than $[________];
(iv) send any notices declaring an event of force majeure or the default of any
counterparty to a Project Company Contract, or any notice that could reasonably be expected to have
a Material Adverse Change, under any Project Company Contract without first notifying Buyer;
(v) initiate or threaten to initiate any litigation or adversarial proceeding that
would reasonably be expected to impact the Project Company, the Site, the Project Assets, or the
Project;
(vi) release, waive, settle, or compromise any dispute or pay damages under any
settlement or compromise of any proceeding relating to the Project, the Project Company, or the
applicable Project Assets;
(vii) sell, lease, license, assign, transfer, or encumber (including transfers to
Developer or any of its Affiliates) any Project Assets to any Person;
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(viii) make any material change in the book or accounting methods used by or
applicable to the Project Company or Project, except as required by GAAP;
(ix) merge or consolidate with any other Person or adopt any plan of dissolution
or liquidation, or make any voluntary bankruptcy or insolvency filing (or consent to any such
involuntary filing) or reorganization;
(x) loan, gift, sell, convey, or transfer in any manner any applicable Project Assets
to Developer or any other Person, other than as contemplated under this Agreement;
(xi) incur or assume Indebtedness (excluding any Indebtedness outstanding as of
the Execution Date), other than the Permitted Indebtedness;
(xii) admit any new member, manager, or holder of membership interests or other
Membership Interests;
(xiii) redeem or repurchase, directly or indirectly, any Membership Interest of the
Project Company or declare, set aside or pay any dividends or make any other distributions (whether
in cash or in kind) with respect to any Membership Interests;
(xiv) issue, sell, or transfer any notes, bonds, other debt securities, or any
membership interest (including the Membership Interests) of the Project Company;
(xv) acquire (by merger, consolidation, or acquisition of stock or assets or
otherwise) any corporation, partnership, or other business organization or division thereof or
collection of assets constituting all or substantially all of a business or business unit;
(xvi) make, revoke, or change any Tax election, change any Tax accounting
methods, policies, or practices, file any amended Tax Return or claim for refund, enter into any
closing agreement, settle, or otherwise compromise any Tax claim or assessment relating to the
Project Company, the Project Assets or the Project, file any request for rulings or special Tax
incentives with any Governmental Agency, surrender any right to claim a refund of Taxes, or consent
to any extension or waiver of the limitation period applicable to any Tax claim or assessment relating
to the Project Company, the Project Assets or the Project, enter into any Tax allocation, sharing,
reimbursement, or indemnity agreement, or take any other similar action;
(xvii) incur, create, or assume any Lien other than Permitted Liens created in the
ordinary course of business;
(xviii) enter into any transaction or contract with Developer or any of its Affiliates
(except as contemplated by this Agreement);
(xix) change or authorize any change in the organizational documents of the
Project Company;
(xx) amend or materially modify the organizational documents of Developer in a
manner that would have a material adverse effect on the ability of Developer to consummate the
transactions contemplated by this Agreement
(xxi) take any action that would result in any additional Governmental Authority
having jurisdiction over the Project Company or the Project, except as contemplated 4.12, 4.16(d),
and 5.6; or
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(xxii) amend, modify, terminate, or fail to renew any insurance policy listed on
Schedule 4.20, or cause any such policy to no longer be in full force and effect, fail to pay premiums
owed with respect to any such policy and provide a notice of cancellation or termination of any such
policy;
(xxiii) materially and adversely amend or modify, fail to maintain or obtain, or
terminate any Permit;
(xxiv) hire any employees or establish, adopt, amend, or commence participation in,
or incur any liability under, any Benefit Plan in respect of Project Company;
(xxv) solicit third parties to acquire the Project or the Project Company;
(xxvi) take any action or fail to take any action that would reasonably be expected
to materially adversely affect the Project or the Project Assets;
(xxvii) Make or change any material tax election related to the Project or, if
applicable, the Project Company, and
(xxviii) commit or agree to do any of the foregoing.
(c) Notwithstanding anything herein to the contrary, Developer is responsible for all EPC
Contract, Major Supply Agreement, and other Project Contract payments, milestone payments, and
any other obligations under the arising thereunder, whether incurred or payable prior to, on, or after
the Closing Date. Developer is responsible for all costs associated with EPC Change Orders whether
submitted or approved prior to or after Closing; provided, however, that certain Required Change
Orders may allow for an adjustment to the Purchase Price in accordance with 2.6(b). For the
avoidance of doubt, Buyer shall not be responsible for any costs associated with EPC Change Orders,
whether they arise or are payable before, on, or after the Closing Date.
(d) Within three (3) Business Days of receipt, Developer shall provide to Buyer a copy of
any feasibility studies, systems studies, and/or facilities studies that contain an estimate or a final
determination of Interconnection Costs. Developer is responsible for all Interconnection Costs
incurred or payable on or prior to Closing. To the extent that any refund of any portion of the
Interconnection Costs shall be received by the Developer or otherwise due from the Transmission
Provider, the full amount of such refund shall be paid to the Buyer. If any additional Interconnection
Costs are assessed by Transmission Provider against the Project Company after Closing, Buyer shall
be responsible for such additional Interconnection Costs.
7.3
Buyer will submit the executed Agreement for IPUC Approval in accordance with 2.1;
7.4
(a) Developer may supplement or amend the Developer’s disclosure schedules after the
Execution Date with respect to (a) deletions of Contracts that expire in accordance with their terms,
in the absence of any breach or default, (b) additions of and amendments to Contracts executed in
accordance with this Agreement, (c) additions of and amendments to Project Company Permits, (d)
additions of, updates to, and supplements to Reports, and (e) any other changes that have occurred
with respect to the Project Company, the Project Assets, or the Project since the Execution Date
(“Updating Information”). Such updates shall occur no more than monthly and shall be Made
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Available on the same day and in the same manner as the Progress Reports delivered in accordance
with 11.6.
(b) If any Updating Information includes information which relates to events or changes
since the Execution Date that, individually or in the aggregate, has had or would reasonably be
expected to have a Material Adverse Change then such Updating Information shall be a “Material
Update.” Buyer may, in its sole discretion, as a result of a Material Update proposed by Developer
that has not been cured, elect to terminate this Agreement pursuant to 26.1(a) (after expiration of
the cure periods set forth therein) and Buyer shall be the non-defaulting Party in connection
therewith. If Buyer consents in writing to any Material Update, notwithstanding the Updating
Information provided prior to each such date, then the information constituting such Updating
Information shall be deemed an “Accepted Update.” With respect to any Accepted Update, (i) any
incorrectness or breach caused by the Accepted Update shall be deemed cured as of the applicable
Closing Date, (ii) the relevant Developer disclosure schedules shall be deemed to be supplemented,
modified, or amended by such Accepted Update for all purposes of this Agreement, and (iii) any
applicable representations and warranties to which such Accepted Update refers shall be deemed
qualified by such Accepted Update.
8.1
(a) In consideration of the Purchase Price, Developer’s general obligations under this
Agreement are as follows:
(i) Prior to Closing, cause the Project to achieve Mechanical Completion in
accordance with the terms of this Agreement and the EPC Contract.
(ii) At Closing, convey to Buyer the Membership Interests, which shall thereby
convey all Project Assets and rights to the Project; and
(iii) After Closing, cause the Project to be completed and achieve Final Completion
in accordance with the terms of this Agreement and the EPC Contract.
(b) On and prior to Closing, Developer shall work to accomplish its obligations, both
independently and by and through the Project Company, as applicable.
(c) The Work shall be manufactured and executed in the manner set forth in the
Technical Specification set forth in Appendix A, Appendix O, and Appendix P, or, where not so set
forth, to the reasonable satisfaction of Buyer’s Representative and all Work on the Site shall be
carried out in accordance with Prudent Industry Practice and such reasonable directions as Buyer or
Buyer’s Representative may give.
(d) Obligations Prior to Closing. The key terms and conditions of the EPC Contract and
the Major Supply Agreements are attached to this Agreement as Exhibit G and Exhibit H, respectively.
Developer shall: (i) cause the Project Company to promptly (but in no event later than sixty (60) days
after the Firm Date) enter into an EPC Contract on terms equal to or better (from Buyer’s perspective
as the future owner of the Project Company) than those attached hereto as Exhibit G and, within two
(2) Business Days thereafter, issue the Full Notice to Proceed under each such Contract, (ii) cause the
Project Company to promptly (but in no event later than sixty (60) days after the Firm Date) enter
into the Major Supply Agreements on terms equal to or better (from Buyer’s perspective as the future
owner of the Project Company) than those attached hereto as Exhibit H and, within two (2) Business
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Days thereafter, issue the notice to proceed (or similar) under each such Contract, (iii) cause
Contractor and Major Subcontractors to carry out and complete the Work in accordance with the
requirements, duties and obligations imposed on Contractor and Major Subcontractors pursuant to
the EPC Contract and the Major Supply Agreements; (iv) ensure that Contractor and every Major
Subcontractor design and perform the Work in compliance with applicable Laws and the other
requirements of this Agreement and the Transaction Documents; (v) maintain the requisite
resources, experience, qualifications, and capabilities as are required to fully perform its obligations
under this Agreement; (vi) keep Buyer informed as to the status of deliveries, and if any such
Materials or Major Equipment are not being properly manufactured or fabricated in accordance with
the requirements of the Transaction Documents and, if different, the Project Company Contracts
pursuant to which they were purchased, or do not otherwise conform with such requirements,
promptly making Buyer aware thereof and taking necessary corrective action; (vii) subject to Buyer’s
prior review and approval, enter into all necessary Project Company Contracts (including the Real
Property Contracts for necessary site control of the Site); (viii) manage the interconnection queue
process and ensure the completion of all necessary interconnection studies and processes, including
any affected system studies; (ix) subject to Buyer’s prior review and approval, execute, and perform
under the Interconnection Agreement; (x) obtain all Permits necessary for the design, engineering,
development, construction, startup, testing, commissioning, completion, ownership, and
commencement of operation of the Project, consistent with the Project Schedule; (xi) ensure that all
of the Project Assets are legally and beneficially owned and titled in the name of the Project Company
prior to Closing; and (xii) accomplish all other tasks that are incidental and necessary to Developer’s
general obligation hereunder to ensure that the Project is completed in accordance with this
Agreement.
(e) Obligations After Closing. Developer shall accomplish all tasks that are incidental and
necessary to Developer’s general obligation hereunder to ensure that the Project is completed in
accordance with this Agreement and to achieve Final Completion. For the avoidance of doubt,
Developer shall be fully liable to Buyer hereunder for all acts and omissions of Contractor to the same
extent as though any such act or omission had been performed or omitted to be performed by
Developer directly until the achievement of Final Completion.
8.2
(a) In connection with its performance of this Agreement, Developer shall purchase the
Major Equipment from the Major Subcontractors set forth in Appendix C pursuant to the Major
Supply Agreements, and Developer shall cause Contractor to procure any other materials, equipment,
or other goods and services required for performance of the work under the EPC Contract. For
procurement of services or equipment (other than the Major Equipment) from any Subcontractor
not identified on Appendix C, Developer will be required to obtain the prior approval of Buyer prior
to engaging such Subcontractor and any contract with any such Subcontractor shall comply with the
minimum warranty requirements set forth herein; provided that, Developer shall cause any such
contract to include without limitation, the provision of assignability of applicable warranties
thereunder.
(b) Prior to Closing, Developer shall be fully liable to Buyer hereunder for all acts and
omissions of Contractor and each Subcontractor to the same extent as though any such act or
omission had been performed or omitted to be performed by Developer directly. In no case shall
Developer’s or the Project Company’s engagement of Contractor or any Subcontractor relieve
Developer of any of its obligations or Liabilities hereunder and, notwithstanding the use of
Contractor or any Subcontractors hereunder, Developer shall remain fully and primarily liable to
Buyer for the full and complete performance of Developer’s obligations hereunder.
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(c) Buyer shall have no contractual obligation to and shall not be deemed to be in privity
with Contractor or any Subcontractor until Buyer takes assignment of the Membership Interests at
Closing. Notwithstanding the above, after Closing, Buyer will indirectly be party to the EPC Contract,
solely by and through its ownership of the Project Company.
8.3 w
(a) Developer shall comply with all applicable Laws and Prudent Industry Practices, and
shall cause Contractor and each Major Subcontractor to comply with all applicable Laws and Prudent
Industry Practices with respect to the Work to be performed by such Contractor or Major
Subcontractor. As between Developer and Buyer, Developer shall be responsible for ascertaining the
nature and extent of any applicable Law, which may affect the Work, the Project or the operation of
the Project prior to Substantial Completion, or the Site as a result of the performance by Developer
of its obligations under this Agreement. Prior to Closing, Developer shall ensure that all the Work
complies with applicable Laws, Prudent Industry Practice, the Project Company Permits, and the
product manuals, copies of which are included in Appendix F.
(b) Subject to the preceding paragraph, Developer shall be responsible for Liabilities
which may arise (including those that Buyer pays or becomes liable to pay) as a direct result of
Developer’s, Contractor’s, or Major Subcontractor’s non-compliance with applicable Law, or as a
result of Buyer’s inability to operate the Project in compliance with applicable Law due to the
inaccuracy of Developer’s representations and warranties or the breach by Developer of any of its
obligations under this Agreement, other than Liabilities arising directly from any act or omission of
Buyer or its employees and agents or, after the Closing Date, the Project Company.
8.4 Permits.
(a) Developer shall obtain and maintain in accordance with applicable Laws all Project
Company Permits required in connection with the design, engineering, development, construction,
startup, testing, commissioning, completion, ownership, and operation of the Project in accordance
with this Agreement and the other Transaction Documents. Buyer shall be properly included as the
permitee, co-permitee, or authorized party with respect to all Project Company Permits.
(b) Developer shall and shall cause Contractor and the Major Subcontractors to
undertake commercially reasonable efforts to support Buyer in obtaining the Buyer Permits,
including providing such engineering and environmental data and statistical information as may be
reasonably requested by Buyer.
(c) Developer shall and cause Contractor and any Subcontractor to, at its or their sole
cost and expense, obtain and maintain all applicable construction and construction-related Permits
which are required by applicable Law in order to undertake and perform the Work and their
respective obligations under the Project Company Contract to which they are a party.
8.5 Interconnection.
Developer shall establish a queue position with Transmission Provider for all requisite
systems studies in order for Project Company and Transmission Provider to enter an Interconnection
Agreement that allows for the Project to achieve Substantial Completion in accordance with the
Project Schedule. Developer shall oversee and manage all necessary system studies and affected
systems studies and shall engage in all necessary Transmission Provider processes. Developer shall
pay for any and all Interconnection Costs, in accordance with 7.2(d). Developer shall be responsible
for the management of the interconnection queue process. In the event that a Project is
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interconnected with the Buyer’s transmission system, the Parties will also acknowledge in the
Agreement that Buyer is acting solely in its capacity as an electric supplier as defined by Idaho Code
61-332A, that its activities under the Agreement are separate and apart from its duties as a
transmission provider and that Buyer shall have no liability in its role as a transmission provider
arising out of the Agreement.
8.6 .
Developer shall, in accordance with Buyer’s reasonable instructions, afford to other
contractors identified by Buyer all reasonable opportunities for carrying out their observation and
inspection at the Site, provided that the same shall not materially obstruct or disturb the progress of
the Work. Developer shall also afford access to Buyer’s employees, including employees who will
operate and maintain the Project, to perform their work at the Site.
8.7 ployment.
(a) Developer shall, and shall cause Contractor and each Major Subcontractor to, ensure
that all construction Contracts and subcontracts of any tier for the Project be awarded in compliance
with all applicable Law. Developer shall, and shall cause Contractor and each Major Subcontractor to,
refrain from any discrimination against any employee on the basis of such employee’s membership
in any labor organization, or his or her lack of such membership. All employees working on the
Project shall be permitted to exercise their right to engage in protected concerted activity, as defined
in Section 7 of the National Labor Relations Act, as amended, or to refrain from doing so, without any
discrimination or other adverse consequence. Developer shall, and shall cause Contractor and each
Major Subcontractor to, comply with applicable Law regarding labor relations and employment
matters. Any administrative or civil proceedings filed against a Developer Party shall be promptly
reported to Buyer. Nothing in this provision shall affect any obligation of a Major Subcontractor
under a lawful collective bargaining agreement applicable to some or all of such Person’s operations
on the Project.
(b) Developer shall be aware of, and familiar with, all collective bargaining agreements,
which do or may pertain to or affect the work under this Agreement. Developer shall plan and
conduct its operations so that its employees and Subcontractors of any tier will work harmoniously
with Buyer employees and other workers employed on the same or related projects to assure that
there will be no delays, work stoppages, excessive labor costs, or other labor difficulties. Developer
shall ensure that Contractor and each and every Major Subcontractor comply with all applicable Laws
pertaining to such labor and employment.
(c) Scarcity and Quality of Labor. Notwithstanding anything to the contrary set forth
herein, Developer shall have no Claim for an extension of the Outside Closing Date or a Claim for loss,
damage, or additional costs and expenses of any kind in respect of any alleged or proved unsuitability,
scarcity, inefficiency of the labor it may engage or wish to engage or any requirement to engage union
labor.
(d) Equal Employment Opportunity and Other Non-Discrimination Clauses.
(i) Developer shall and shall cause Contractor and all Subcontractors, to at all
times, comply with all applicable Laws applicable to employees, including those governing wages,
hours, employment discrimination, disability and medical leave, employment of minors, health and
safety. Developer shall comply with equal opportunity applicable Laws to the extent that they are
applicable.
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(ii) Developer shall indemnify, defend, and hold harmless Buyer Indemnified
Parties from, for, and against all losses, costs, and damages by reason of any violation thereof and
from, for, and against any Claims and Liabilities and other costs arising out of Developer’s failure to
comply with the provisions set forth in Section 8.7(d).
(iii) Developer shall execute and Make Available to Buyer a certificate of
compliance with respect to equal employment opportunity compliance using applicable Buyer’s form
of certificate before starting to perform Work under this Agreement.
(e) Workers Compensation. Developer shall comply with all applicable Laws regarding
workers’ compensation and shall, prior to commencing Work, furnish proof thereof satisfactory to
Buyer. Developer shall ensure Contractor and Subcontractors have obtained workers’ compensation
insurance required by Law and as further set forth in this Agreement.
8.8
Inspection of the Work at the Site and attendance at meetings (whether conducted in-person,
telephonically or through similar medium) relating to the Project which are attended by Developer
and Contractor or Major Subcontractor and related to status, progress, quality, scope, schedule and
coordination shall at all times be afforded by Developer to Buyer, Buyer’s Representative, and such
other Persons as shall be designated by Buyer or Buyer’s Representative. Buyer, in its inspection,
shall give due consideration to the needs of Developer to carry out Developer’s obligations and strive
not to hinder or unduly impede Developer while carrying out such inspection. Buyer, in its
inspection, may observe the progress and quality of the Work to determine if the Work is proceeding
in accordance with the Transaction Documents and Project Company Contracts. Inspections under
this 8.8 are solely for the benefit of Buyer and any inspection or failure to inspect and any objection
or failure to object by Buyer shall not (a) relieve Developer, Contractor, or any Major Subcontractor
of its respective obligations under any Project Company Contract, or (b) be used as evidence that
Buyer agreed that Developer, Contractor, or any Major Subcontractor had fulfilled any obligations
under any Transaction Document or Project Company Contract or that Buyer had waived any of its
rights under any Transaction Document. Buyer, Buyer’s Representative, Buyer’s employees, Buyer’s
invitees, and such other Persons as shall be designated by Buyer or Buyer’s Representative shall
follow and comply with the Contactor’s Safety Assurance Program at all times while present on the
Site.
8.9
(a) Developer shall at all times keep a copy of the most recent version of the Contractor
Drawings and Manuals at Developer’s office on the Site to be made available for Buyer’s review. In
addition, Developer shall provide and make available to Buyer electronic versions of the Contractor
Drawings and Manuals accessible by Buyer through a file transfer protocol site to be maintained by
Developer.
(b) Developer shall cause to be set forth in the Contractor Drawings and Manuals
provided to Buyer such information as is required to operate and maintain the Work, including the
information set forth in Appendix G. The Contractor Drawings and Manuals shall be (i) prepared in
accordance with the Technical Specification, Appendix F and Appendix G, and when completed, shall
be in sufficient detail to accurately represent the Project as constructed. The Contractor Drawings
and Manuals shall be maintained and be available, with up-to-date drawings, specifications, and
design sheets, for the training of Buyer’s personnel as set forth in 8.10.
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(c) At least sixty (60) days prior to the expected Closing Date, Developer shall provide
Buyer with initial drafts of the final Contractor Drawings and Manuals for review (the “Draft
Manuals”). The Draft Manuals shall contain such information described in 8.9(b), other than the
drawings which, in accordance with this 8.9, will be maintained to be up-to-date. Two (2) complete
sets of the Draft Manuals shall be provided to Buyer at least sixty (60) days prior to Substantial
Completion and shall be a condition to the achievement of Substantial Completion.
(d) Developer shall provide to Buyer both hard and electronic final copies of the
Contractor Drawings and Manuals. Developer shall provide to Buyer five (5) final hard copies of the
Contractor Drawings and Manuals within sixty (60) days after achievement of Substantial
Completion. Neither Buyer nor the Project Company shall be required to deliver the Certificate of
Final Completion until all such Contractor Drawings and Manuals have been so delivered.
(e) Any modifications to the Contractor Drawings and Manuals made necessary as a
consequence of any punch list items or modifications to the Work shall be issued as addenda to the
Contractor Drawings and Manuals within thirty (30) days following completion thereof.
8.10 Training.
(a) Training of Buyer’s personnel (or other employees or agents of Buyer) shall be given
by Developer or Contractor prior to the Substantial Completion Date as required by the Technical
Specification, in accordance with the EPC Contract, and shall include training (including on-site and
classroom) on the interconnection and technical specifications of the Project and operation and
maintenance of the Project. Such training shall be provided directly to Buyer’s personnel and shall be
conducted by a trainer experienced in the operation, and maintenance of the Project.
(b) Starting at least sixty (60) days prior to the energization of the Project at the Site and
continuing until Final Completion, Developer shall oversee the development of and provide qualified
and experienced support for Buyer’s execution of a practical and participatory training program at
the Site for an adequate number of employees designated by Buyer, which personnel shall be
experienced in energy storage facility operations appropriate to their respective job descriptions.
8.11 Safety.
(a) Developer shall be solely responsible for being aware of and initiating, maintaining
and supervising compliance with all safety Laws, regulations, precautions, and programs in
connection with the performance of this Agreement. Prior to Closing, the Contractor’s health and
safety plan for the Project will be attached hereto as Appendix M (the “Contractor’s Safety Assurance
Program”). Prior to the start of, and throughout the performance of, the Work, Developer shall ensure
that each of its employees, together with all employees of its Contractor and each Major
Subcontractor, are fully informed concerning all safety, health, and security Laws and requirements
pertaining to the Work and the Contractor’s Safety Assurance Program; are qualified to perform the
Work under applicable Occupational Safety and Health Administration (“OSHA”) regulations; have
completed all training required under applicable OSHA regulations to perform the Work; have all
licenses and certifications required to perform the Work; and understand Prudent Industry Practice.
Developer shall conduct all operations under this Agreement in accordance with the Contractor’s
Safety Assurance Program.
(b) In the event Developer, Contractor, or Major Subcontractor fails to promptly correct
any violation of applicable Law, Prudent Industry Practice, or the Contractor’s Safety Assurance
Program, Buyer may suspend all or any part of the Work until such time as Developer corrects the
violation. Developer shall not be entitled to any extension of time or reimbursement for costs caused
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by any such suspension order. Failure of Buyer to order discontinuance of any or all of Developer’s
operations shall not relieve Developer of its responsibility for breaches of applicable Law or the
Contractor’s Safety Assurance Program. Developer shall maintain an accurate record of and shall
promptly report to Buyer all cases of property damage in excess of One Hundred Dollars ($100.00)
to property of third parties (not including Contractor or any Subcontractor) and of death,
occupational diseases, or injury to employees or any other third parties and incident to performance
of Work under this Agreement. Developer shall promptly notify Buyer and provide a copy of any
safety citation issued by any Governmental Authority.
8.12
(a) Developer shall not take any action that would violate or infringe any Person’s
intellectual property rights.
(b) Developer shall, at its sole expense, settle or defend and pay any costs (including
attorneys’ fees) and damages awarded in connection with, and shall defend, indemnify, and hold
harmless each Buyer Indemnified Party from, for, and against any and all Claims and Liabilities,
including without limitation, suits or proceedings based on a Claim that any part of the Work or the
ownership or operation of the Project infringes or violates any patent, copyright, or any other
intellectual property right belonging to a third party. Buyer shall give Developer notice of any such
Claim promptly after Buyer has actual knowledge thereof; provided, that the omission of Buyer to
give such notice shall not relieve Developer of its obligations hereunder except to the extent that such
omission results in a failure of actual notice to Developer and Developer is damaged as a result of
such failure. The provisions of ARTICLE 22 and Article 31 shall also apply to any Claim under 8.12(b).
(c) Developer shall obtain and transfer to Buyer perpetual, fully-paid up, royalty free,
transferable licenses to use all computer programs and any other intellectual property necessary for
the ownership and operation of the Project from and after the Closing, together with all warranties
related thereto.
8.13
(a) Developer shall employ (directly or through contract) one or more competent
representatives (each, a “Developer’s Representative”), whose name or names and details of
qualifications and previous experience shall have been provided to Buyer and Buyer’s Representative
by Developer, to manage the Work and who shall have Developer’s authority in respect of all matters
arising out of or in connection with this Agreement and the Work. Any orders or instructions which
Buyer or Buyer’s Representative may give to Developer’s Representative shall be deemed to have
been given to Developer.
(b) Key Personnel.
(i) Prior to beginning the Work, Developer shall provide to Buyer, a list setting
forth the name of the natural Person for each Key Personnel position for itself, Contractor and all
Major Subcontractors performing material portions of the Work. Throughout performance of the
Work, all employees assigned by Developer to perform any of Developer’s or Project Company’s
obligations shall be fully qualified, certified, and licensed to perform the tasks assigned them.
(ii) Appendix H shall be amended when Key Personnel change during the
performance of the Work.
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(iii) Developer shall give Buyer fifteen (15) days advance written notice in the
event Developer intends to remove or change any of its Key Personnel assigned to the Work or to
reassign any such Key Personnel to another project.
8.14
With regard to the performance of the Work, Developer shall, and shall ensure that
Contractor and any Major Subcontractor shall, only employ Persons qualified to perform the Work.
Developer represents that Developer maintains a workplace violence standard that prohibits
violence, firearms, and other weapons on the Work site and a drug-free workplace policy that
complies with all Laws and prohibits the use of controlled substances or alcohol while performing
the Work under this Agreement, and Developer shall ensure Contractor, Subcontractors at all tiers,
and their respective employees and agents shall not possess, use, sell or be under the influence of
alcohol, drugs, or other controlled substances (excluding those used or possessed pursuant to a valid
prescription and which do not adversely affect the Work.)
8.15 16.7
(a) The EPC Contract shall include all spare parts and consumables necessary for the
installation, startup, and commissioning of the Project and the complete performance of the Work
through Final Completion. Such spare parts and consumables shall be located at the Site and
immediately available to Developer Parties to ensure that all Work, including testing and
commissioning activities continue unimpeded by the absence of such onsite spare parts and
consumables. Buyer shall not be liable in any way for Developer’s inability to achieve Substantial
Completion or Final Completion due to lack of any spare parts or consumables and the Contractor
shall not be entitled to a Change Order in respect of the same.
(b) Developer shall submit to Buyer a proposed list of spare parts and associated pricing
for the operation of the Project following Final Completion in accordance with the EPC Contract.
Within thirty (30) days of receipt of the proposed list, Buyer shall determine, in its discretion, to
procure such spare parts or, at Buyer’s election pursuant to a Buyer-Initiated Change, request
Developer to procure or cause to be procured such spare parts and have such spare parts delivered
to the Site prior to the Closing Date. Upon the request of Buyer, Developer shall meet with Buyer and
its designees to discuss the proposed inventory of spare parts.
(c) If available, Buyer shall allow Developer to use any spare parts or consumables
owned by Buyer, but in no event shall Buyer be liable or shall Developer be entitled to a Change Order
in the event that the absence of any particular spare part or consumable impacts completion of the
Work. In the event Developer uses Buyer’s spare parts and consumables with Buyer’s written
consent, such spare parts and consumables shall be expeditiously replaced by Developer at its sole
cost and expense. Buyer does not warrant the condition, quality, suitability, absence of defects,
fitness for any purpose, or aspect of any Buyer-supplied spare part and if Developer uses any Buyer-
supplied spare part, it does so at its own risk.
8.16 .
(a) Developer shall take all such further actions and execute all such further documents
and instruments as Buyer may at any time reasonably determine to be necessary to further carry out
and consummate the transactions contemplated by the Transaction Documents.
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8.17 .
(a) Developer shall not create, incur, assume, or suffer to exist, directly, or indirectly, any
Lien on any of the Project Assets or the Project Company, whether now owned or hereafter acquired
in connection with the Project.
(b) On or prior to the Closing Date, Developer shall cause Contractor and all Major
Subcontractors to deliver Lien releases to Project Company covering all work performed and
materials furnished as of the Closing Date, in the forms attached in Appendix I.
8.18
(a) Until after Final Completion shall have occurred, Developer shall not, without Buyer’s
prior written consent, enter into any business combination, merger, or consolidation, or liquidate,
wind-up, dissolve (or suffer any liquidation or dissolution), or discontinue its business.
(b) Until after Final Completion shall have occurred, and except in the ordinary course of
business (such as the replacement or substitution of items from customary wear and tear), Developer
shall not convey, sell, lease, assign, transfer, or otherwise dispose of any of Project Assets.
8.19
Developer and Project Company shall maintain all records and accounts in accordance with
GAAP consistently applied and in Dollars in order to support any and all invoices, Claims, and
disputes under this Agreement. Developer shall permit Buyer, upon reasonable prior notice and
during business hours, to audit Developer’s records and accounts related to the Membership
Interests and the Project to verify invoice amounts and to confirm any increases or decreases to the
EPC Contract Price and any EPC Change Orders, as well as any report or correspondence related to
Project Company Permits or safety or environmental compliance.
8.20 .
Developer shall promptly notify Buyer upon the occurrence of any security breach,
cyberattack, other data security, or cyber incident or unauthorized access to any Developer IT Asset,
which resulted in the unauthorized access, unauthorized use, misappropriation, modification,
encryption, corruption, disclosure, or transfer of any material information or data contained therein
relating to the Project Company or the Project Assets.
BUYER
9.1
Buyer shall:
(a) keep Developer informed as to the status of any governmental or regulatory or other
activities undertaken by Buyer that relates to the Project and that is likely to materially and adversely
affect Developer’s ability to perform the Work;
(b) comply with all applicable Laws;
(c) plan and conduct its operations so that its employees and subcontractors of any tier
will work harmoniously with Developer employees and other workers employed on the same or
related projects; and
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(d) maintain its records and accounts in accordance with GAAP consistently applied in
order to support any and all invoices, Claims, and disputes under this Agreement.
9.2
(a) Buyer’s Power to Delegate. Buyer may at any time delegate to its representative (the
“Buyer’s Representative”) any of its duties and obligations (other than its payment obligations) under
this Agreement. Except as explicitly provided herein, any written decision, instruction, or order given
by Buyer’s Representative to Developer in accordance with such delegation shall have the same effect
as though it had been given by Buyer.
(b) Duties of Buyer’s Representative. Buyer’s Representative shall carry out such duties
as are specified in this Agreement but except as expressly provided in this Agreement neither the
performance of or the failure to perform such duties whether properly or at all by Buyer’s
Representative, nor the fact that a Buyer’s Representative has been appointed by Buyer shall in any
way relieve Developer of any responsibility or liability for any of its obligations under this
Agreement. No approval of, or consent to, or failure to approve or consent to any matter by Buyer or
Buyer’s Representative shall relieve Developer of any liability or any of its obligations under this
Agreement.
9.3
Unless explicitly stated otherwise in this Agreement, whenever the Parties or their
representatives are required to exercise their discretion: (a) to make a decision, (b) to give consent
or approval, (c) to express satisfaction or approval, (d) to determine value, or (e) otherwise to take
action which may affect their respective rights and obligations hereunder, the exercise of such
discretion shall be made in a reasonable manner and in good faith consistent with this Agreement so
as to reasonably minimize any disruption to the other Party, and having regard to all the
circumstances reasonably applicable thereto.
9.4
If Developer is required to obtain the approval of, or consent from, Buyer pursuant to the
terms of this Agreement, upon receipt of a request for such approval or consent from Developer,
Buyer shall, in its reasonable discretion (which shall not be unreasonably withheld, conditioned, or
delayed), respond (a) granting such approval or consent, (b) denying such approval or consent or (c)
requesting supporting material or information, in the time expressly specified in this Agreement or
when no time is referenced, within a reasonable time.
10.1
(a) Developer shall be responsible for Site security, which shall be in accordance with
Developer’s established security procedures, which, at a minimum, shall ensure compliance with all
requirements of applicable Laws, the Project Company Permits, the Technical Specification and this
ARTICLE 10. All Developer Parties shall strictly adhere to all Site security provisions.
(b) Unless and until care, custody, control and risk of loss transfer to Buyer pursuant to
this Agreement, Developer shall be fully responsible for all Materials and Equipment.
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10.2 Preservati
Developer Parties shall not damage, close, or obstruct any highway, road, or other public or
private easement, except to the extent allowed by applicable Laws or the Project Company Permits.
If such facilities are closed, obstructed, damaged, or made unsafe by Developer Parties, Developer
shall, at its sole cost and expense, make such repair as necessary and shall also provide such
temporary guards, lights, and other signals as may be necessary or required for safety or by
applicable Laws or the Project Company Permits.
10.3
All Work at the Site shall be carried out in such a way as to minimize noise and disturbance
and Developer shall defend, indemnify, and hold harmless all Buyer Indemnified Parties from and
against all third party Claims and Liabilities for injury, including death, and property damage caused
by, arising out of, or in connection with noise or other disturbance, falling outside of the limits
specified in applicable Laws or the Project Company Permits and created by Developer Parties in
connection with performing the Work.
10.4
Developer Parties shall provide adequate safety barriers, signs, lanterns, and other warning
devices and service to properly protect any person having access to or near the Site in accordance
with the requirements of applicable Laws, Permits, and the Technical Specification. Developer shall
be solely responsible for any act of trespass or any damage to adjacent property resulting from or in
connection with the Work or its operations under this Agreement.
10.5
Developer Parties shall be responsible for obtaining and the cost of electricity, water, fuel, air,
or other services as the Developer Parties may require for the purposes of the Work.
10.6 Cleanup.
Developer Parties shall keep the Site, including the Work area and storage areas used by
Developer Parties, free from accumulation of waste materials or garbage arising out of the Work, and
shall, prior to completion of the Work, remove and properly dispose of any such waste materials or
garbage from and about the Site in accordance with applicable Laws. Upon completion of the Work,
Developer Parties shall leave the Site in a condition reasonably satisfactory to Buyer.
10.7
At all times Developer is responsible for preventing Releases of Regulated Materials brought
to or generated at the Site by Developer Parties or preexisting at the Site. On and prior to the Closing
Date, Developer shall manage and be responsible for any Regulated Materials, whether brought on
to or generated at the Site by Developer Parties or pre-existing at the Site, according to applicable
Law.
10.8 .
(a) If any species surveys or studies indicate that a direct or indirect taking of wildlife
listed as threatened, endangered, or other special status under Environmental Laws, or any impacts
to habitat of such wildlife, will occur as a result of development or construction activities (including
due to grading, ground disturbance, tree clearing, or nest removal) or during operation of the Project,
Developer shall consult with the relevant Governmental Authorities to determine whether incidental
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take authorization or a species habitat conservation or management plan is required under
Environmental Laws for the Project or the Site. If required by any Project Company Permit,
Developer shall coordinate with Buyer to develop a plan for addressing such impacts, which may
include coordination with federal and state wildlife Governmental Authorities. During development
and construction of the Project, any wildlife protected by Environmental Laws discovered on the Site
shall be reported in accordance with any applicable conservation or management plans, if any.
(b) Developer shall prepare and implement an unanticipated discoveries plan that
specifies the procedures Developer and its contractors and subcontractors will follow if any relics,
items, or structures with archaeological, cultural, or historical value or any articles (including fossils,
coins, articles of value or antiquity, or any Native American relics) are discovered on Site.
11.1
Attached hereto as Appendix B is a preliminary project schedule setting forth the major tasks
that must be completed by Developer or Project Company, as the case may be (each a “Milestone”),
and completion dates for such tasks (“Milestone Completion Dates”) as provided by Developer in
accordance with the Technical Specification, including the Critical Milestones and associated Critical
Milestone Completion Dates which will be consistent with Appendix J. The preliminary project
schedule shall include a Milestone (and a corresponding Milestone Completion Date) for
development of a final project schedule (the “Project Schedule”) setting forth in more detail the
Milestones and Milestone Completion Dates, including the Critical Milestones and Critical Milestone
Completion Dates. Subject to 11.4, Developer may update the Project Schedule, in accordance with
the EPC Contract at its sole discretion, provided that the Milestone Completion Dates for the final
three Milestones (Mechanical Completion, Substantial Completion, and Final Completion) remain
unchanged.
11.2
The Project Schedule shall be in the form set forth in Appendix B. The Project Schedule shall
specify any tasks, obligations, or responsibilities under this Agreement (each a “Buyer Obligation”)
which Buyer must perform or fulfill for Developer to achieve the Milestone Completion Dates for each
Milestone, and the date by which Buyer is required to fulfill each Buyer Obligation in accordance with
this Agreement. Developer shall deliver the Project Schedule and any updates thereto in a native
scheduling software format reasonably acceptable to Buyer.
11.3
(a) No later than thirty (30) days following execution of the EPC Contract, Developer shall
submit a final Project Schedule to Buyer’s Representative for its review and comment (provided that
the Critical Milestones and associated Critical Milestone Completion Dates are not different from the
Critical Milestones and Critical Milestone Completion Dates set forth in Appendix J).
(b) Subject to 9.2(b), if Buyer’s Representative comments on any Project Schedule
submitted by Developer, Developer shall, within seven (7) days of such comments, submit a copy to
Buyer’s Representative of the final form of Project Schedule consistent with the Buyer’s
Representative’s comments.
(c) Buyer’s Representative shall have the right to reasonably request Developer to vary,
amend, substitute, or otherwise change the Project Schedule after approval thereof. Any such
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variation, amendment, substitution, or other change (other than as provided in 11.5 or caused by
Developer’s failure to perform any of its obligations in accordance with the terms of this Agreement)
shall be considered a Buyer-Initiated Change under 12.1.
11.4
Following Buyer’s acceptance of the final Project Schedule, Developer shall not, without the
prior written consent of Buyer’s Representative, make any material change to the Project Schedule,
including changing any Critical Milestone or Critical Milestone Completion Date; provided, that Buyer
shall respond to such request by Developer within seven (7) Business Days of receipt from Developer,
and Buyer’s failure to respond within such seven (7)-Business Day period shall be a Buyer-Caused
Delay. Developer shall provide a Level 3 Project Schedule and any updates thereto on (a) prior to the
issuance of the Full Notice to Proceed, a monthly basis and (b) following the issuance of the Full
Notice to Proceed, a weekly basis, including the incorporation of delay and acceleration analyses
where appropriate.
11.5 Re
If, at any time or from time to time, Developer fails to achieve a date or Milestone on the
Project Schedule, then, upon the written request of Buyer, Developer shall promptly, but in any event
within five (5) Business Days of such request, submit a written recovery plan to complete all
necessary Work to the extent reasonably practicable to achieve the remaining dates or milestones in
the Project Schedule. Buyer shall promptly submit reasonable suggestions to such written recovery
plan. To the extent reasonable and feasible, Developer shall incorporate such suggestions into such
recovery plan or shall provide reasonable explanation for why such suggestions were not
incorporated, which reasonable explanations may include alternative Work acceleration proposals.
Developer shall diligently prosecute the Work in accordance with such recovery plan. Neither
approval by Buyer of such recovery plan nor Developer’s prosecution of the Work in compliance with
such recovery plan shall (a) be deemed in any way to have relieved Developer of its obligations under
this Agreement relating to the failure to timely achieve a date or Milestone on the Project Schedule
or (b) be a basis for a Change Order or any other compensation or an increase in the Purchase Price.
11.6
(a) Developer shall Make Available to Buyer a progress report addressing all material
elements of the Work (each, a “Progress Report”) on or before the fifth (5th) day of each month for
Work during the previous month. Developer shall Make Available an update to any Progress Report
upon Buyer’s reasonable request. Developer shall promptly notify Buyer in writing at any time that
Developer has reason to believe that there will be a material deviation in the Project Schedule and
shall set forth in such notice the corrective action planned by Developer to remedy the same.
(b) In addition to the applicable requirements set forth in the Technical Specification and
Appendix K, the Progress Reports submitted by Developer shall specify in detail:
(i) any fact, event, or circumstance (each a “Project Problem”) encountered by
any Developer Party during the preceding month (including the failure of Buyer to perform any Buyer
Obligations under this Agreement) which might (A) prevent Developer from completing any
Milestone by its respective Milestone Completion Date or (B) cause Developer to incur additional
expenses in completing any Milestone;
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 241 of 1056
(ii) the estimated length of any delay and the estimated amount of any additional
costs and expenses, if any, which may be chargeable to Buyer hereunder, as a result of any Project
Problem identified pursuant to this Agreement; and
(iii) to Developer’s Knowledge, the cause of any Project Problem specified
pursuant to this Agreement and the specific steps taken or proposed to be taken by Developer to
correct such Project Problem.
(c) In the event that Developer fails to specify in writing any Project Problem (an
“Unidentified Project Problem”) with respect to a given monthly period in the appropriate Progress
Report and in such manner and at such time as specified pursuant to this Agreement as a Project
Problem, Developer shall not be entitled to rely on any such Unidentified Project Problem as a
purported justification for either (i) claiming that it is entitled to receive any additional amounts
pursuant to this Agreement (including damages arising out of any alleged failure by Buyer to perform
any of Buyer Obligations) or (ii) failing to complete any Milestone by the specified Milestone
Completion Date.
11.7
Progress meetings will be held as deemed necessary by Buyer, but normally shall be held
once every two (2) weeks. Buyer, Buyer’s Representative, and Buyer’s Engineer shall be entitled to
attend such progress meetings. Progress meetings will be utilized to review the progress of the Work
and its compliance with the Project Schedule and discuss any delays, unusual conditions, or critical
items, which have affected or could affect the progress of the Work.
11.8
Developer will be entitled to schedule relief for certain events affecting Developer’s
performance under the Agreement, including:
(a) Material delays caused by a delay of Buyer or its representatives beyond the response
time period specified in the Agreement in responding to or commenting upon Project engineering
and designs (“Buyer-Caused Delays”), which shall entitle Developer to cost relief for demonstrable
additional direct costs due to such delay as provided in the Agreement in addition to schedule relief;
and
(b) Force Majeure events with mutually agreed upon mitigation, notice, materiality
thresholds, and documentation requirements as set forth in Article 24.
12.1 Changes.
(a) No Change shall be effective unless authorized by Buyer’s Representative and issued
by the Project Company in accordance with the provisions of this ARTICLE 12. The EPC Contract
shall include provisions similar to those contained in this ARTICLE 12, to ensure its enforcement,
including a form of Change Order that substantially conforms to Appendix N-1.
(b) Buyer shall, when reviewing each potential Change and determining the nature and
extent of any Change Order which is requested or required in connection with this Agreement,
consider the following information:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 242 of 1056
(i) The nature, scope, and extent of the Change, including any additions or
deletions from the Scope of Work;
(ii) The effect, if any, of the Change on the Project Schedule, including the Outside
Closing Date;
(iii) For Buyer-Caused Delays, the effect, if any, of the Change on the Purchase
Price; and
(iv) Such other information as may reasonably be necessary for the
implementation of the Change Order, including the effect on any other provisions hereof which may
be impacted by the Change.
Buyer shall, in the case of a Buyer-Initiated Change or Required Change Order and may, if it elects to
do so, in the case of a Developer-Initiated Change, approve such Change Order having regard to all
such circumstances as is just and equitable and in a form substantially similar to the form of Change
Order attached hereto as Appendix N-1 which shall address, to the extent required, all of the issues
set out in this 12.1(b).
(c) Developer shall make any request for a Change Order which is permitted to be made
in accordance with 12.2 in the form of a Change Order Request which shall be delivered to Buyer in
writing as soon as possible and in any event within five (5) days after Developer becomes aware of
the facts or circumstances giving rise to a Change which it reasonably believes necessitates a Change
Order. In no case shall Developer Parties be entitled to recover costs in a Change Order that arise
prior to the date of the Change Order Request. Any Change Order Request shall be substantially and
in all material respects in the form attached hereto as Appendix N-2 and include the following
information: (i) the facts or circumstances giving rise to the Change; (ii) the impact, if any, which the
proposed Change is likely to have on Project Company or Developer’s costs under the third-party
Project Company Contracts, including the EPC Contract Price, the Project Schedule, including the
Outside Closing Date, and any other provisions hereof; and (iii) such other information which Buyer
may reasonably request in connection with such proposed Change.
(d) The issuance of a Change Order shall not result in the invalidation of this Agreement.
(e) Notwithstanding any provision to the contrary in this Agreement, no facts or
circumstances will constitute grounds for a Change Order unless and only to the extent that the costs
of such Change Order is in excess of [____] ($[____]). Neither Party shall manipulate the foregoing
process, by aggregating or disaggregating cost or facts or circumstances, as the case may be, for the
purpose of recovering or avoiding additional cost or time in accordance with the foregoing.
(f) For the avoidance of doubt, a Change Order will only result in an adjustment to the
Purchase Price if the Project Company or Developer’s costs under any third-party Project Company
Contract, including the EPC Contract Price, are increased due to (i) a Buyer-Caused Delay or (ii) a
Buyer-Initiated Change. EPC Change Orders that increase Project Company or Developer’s costs
under any third-party Project Company Contract, including the EPC Contract Price, for any reason
other than a Buyer-Caused Delay or a Buyer-Initiated Change, whether such Change Order is issued
before, on or after Closing, will be the sole responsibility of Developer and will not result in an
increase of the Purchase Price.
12.2
(a) Changes Initiated by Developer. Developer may, at any time, submit a Change Order
Request to Buyer pursuant to 12.1(c) for improvements, efficiencies, cost savings, and other similar
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 243 of 1056
Changes to the Work (each a “Developer-Initiated Change”), but no such Change Order Request shall
be carried out by Developer except pursuant to a Change Order executed by Buyer’s Representative,
which execution shall be in Buyer’s discretion. Any Change Order Request submitted pursuant to
this 12.2(a) shall also contain and be supplemented with such information as Buyer may reasonably
require in order to determine whether to accept or reject the Change Order Request.
(b) Changes Initiated by Buyer. If Buyer desires to make a Change to the Scope of Work
or to the Project Schedule (each a “Buyer-Initiated Change”) not comprising recovery Work due to
the negligence of or breach of this Agreement by any Developer Party, Buyer will submit a written
Change Order Notice to Developer, substantially in the form of Appendix N-3, comprising the nature
and extent of the proposed change to the Scope of Work together with, to the extent available or
applicable, Buyer’s opinion as to those matters required to be taken into account in accordance with
12.1. Developer will promptly review the Change Order Notice and notify Buyer in writing within a
reasonable amount of time of the options for implementing the proposed Buyer-Initiated Change
(including, if possible, any option that does not involve an increase in Project Company or Developer’s
costs under any third-party Project Company Contract, including the EPC Contract Price, and an
extension of the Project Schedule) and the estimated effect(s), if any, that each such option would
have on Project Company or Developer’s costs under any third-party Project Company Contract,
including the EPC Contract Price, and Project Schedule, and any other affected provision herein, as
applicable. Such response shall also contain all those matters required to be set out in a Change Order
Request. Based upon such information, Buyer’s Representative may, in his or her discretion, issue a
Change Order for a Buyer-Initiated Change.
(c) Required Change Orders. Project Company shall be entitled to the issuance of a
Change Order pursuant to this ARTICLE 12 in connection with any circumstances which constitute a
Change and which are attributable to the matters identified in subparagraphs (i) and (ii) below (each
a “Required Change Order”):
(i) Due to Change in Law. If and to the extent that a Change in Law after the
Execution Date but before Final Completion, results in a material increase in the cost of the Work or
a material extension of the Project Schedule.
(ii) Change Order Due to Buyer-Caused Delay. If and to the extent that Developer
is entitled to a Change Order due to a Buyer-Caused Delay pursuant to 9.4, provided that such failure
is not the result of Developer Parties’ negligence or breach of this Agreement.
Developer shall use or have used commercially reasonable efforts to mitigate potential delays to the
Project Schedule or potential increases to Project Company or Developer’s costs under any third-
party Project Company Contract, including the EPC Contract Price (the cost of such mitigation efforts
to be addressed in any applicable Change Order). For the avoidance of doubt, a Change Order will
only result in an adjustment to the Purchase Price if Project Company or Developer’s costs under any
third-party Project Company Contract, including the EPC Contract Price, are increased due to (i) a
Buyer-Caused Delay or (ii) a Buyer-Initiated Change. Any costs or expenses (including those incurred
as a result of a delay) associated with Required Change Orders due to a Change in Law, as set forth in
12.2(c)(i), will be the sole responsibility of Developer except to the extent an adjustment to the
Purchase Price is expressly required in accordance with 2.6(b).
(d) Except in the circumstances as set out in this 12.2 and with respect to which an
application is properly made in accordance with this ARTICLE 12, Developer shall not be entitled to
seek a Change, a Change Order, extension of the Project Schedule, including the Outside Closing Date,
an increase of Project Company or Developer’s costs under any third-party Project Company
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 244 of 1056
Contract, including the EPC Contract Price, or the receipt of additional remuneration or
reimbursement with respect to the Work.
12.3
Notwithstanding and pending the resolution of any dispute with respect to a Change or
Change Order, Developer Parties must proceed with the Work and the performance of any Change
ordered by Buyer as a result of a Buyer-Initiated Change or a Required Change Order, unless Buyer’s
Representative directs Developer not to proceed.
12.4
Where any proposed Change may give rise to an extension of the Project Schedule or an
increase in Project Company or Developer’s costs under any third-party Project Company Contract,
including the EPC Contract Price, then Buyer reserves, in its discretion and to the extent possible, the
right to require Developer to vary, amend, or effect such other Change to the Work in such a manner
as will mitigate or avoid the requirement for such extension of the Project Schedule or increase in
Project Company or Developer’s costs under any third-party Project Company Contract, including the
EPC Contract Price.
13.1
The Work to be supplied, including all materials, manufactured components and labor and
services to be performed, shall be designed and executed in the manner set out in this Agreement
and the EPC Contract. Except where the manner of design, manufacture, and execution is otherwise
specifically set out in this Agreement or the EPC Contract, the Work shall be designed, manufactured
and executed in a proper and workmanlike manner, all in accordance with accepted industry
standards, applicable safety standards, and Prudent Industry Practice.
13.2
The Materials and Equipment, including any rented Equipment, fixtures, software, any
related items of personal property, and other tangible personal property of Developer Parties
constituting the Project shall be new and carrying the manufacturer’s warranties and guarantees
required under ARTICLE 19, and shall be suitable for their current use in the storage of energy in
accordance with the Technical Specification. All Equipment and Materials shall be procured solely for
use in connection with the Project.
13.3 Inspection.
Developer shall require that Contractor use commercially reasonable efforts to include rights
in all contracts with Subcontractors to permit Buyer and the Buyer’s Engineer to audit, inspect, test,
and observe the Major Equipment at the facilities of any Subcontractor or the manufacturer of Major
Equipment, or the location where such Major Equipment is being transported or stored, and, if
permitted, Developer shall ensure reasonable, adequate, and safe access to such facilities for such
purposes, subject to any reasonable safety rules or restrictions imposed by such Subcontractor or
manufacturer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 245 of 1056
DRAWINGS
14.1 Drawings.
(a) Following receipt and approval of the Project Schedule, Developer shall prepare a
contract documentation and drawing list identifying those key data, calculations (as required for
regulatory purposes and consents), drawings, technical specifications, and concepts required for
review for conformance with this Agreement.
(b) Developer shall, within the time detailed in the Project Schedule or elsewhere in this
Agreement, submit to Buyer’s Representative in hard copy and electronic form (the specific form of
which shall be agreed to by the Parties) such key data, calculations, drawings, technical specifications,
and concepts.
(c) Developer shall timely submit to Buyer’s Representative drawings of temporary and
permanent buildings and structures and any other information required under the terms and
conditions of consents, licenses, and planning permissions obtained by Developer or Buyer.
(d) Buyer’s Representative may, in its discretion, disapprove any drawing; provided,
however, it shall notify Developer of any such disapproval within ten (10) Business Days of receipt,
except for documents and information (including calculations) which are required by Buyer’s
Representative for consultation with Buyer’s third-party contractors for the purposes of the
interconnections at terminal points, where the period shall be fifteen (15) Business Days. Developer
shall supply additional copies of documents or information (including calculations) in the form and
numbers stated in this Agreement. Without waiver of or prejudice to any rights of Buyer, Developer
shall bear all risk in relation to its performance of work arising from or in relation to all documents
or information (including calculations).
14.2
(a) Developer will ensure that the EPC Contract provides Buyer, Buyer’s Representative,
and Buyer’s Engineer (the “Buyer Design Review Parties”) with commercially reasonable review
rights, in respect of certain design drawings, specifications, and similar documents which shall set
forth in detail the requirements for the construction of the Project, including the right to review [(i)
thirty percent (30%) systems designs, (ii) sixty percent (60%) systems designs, (iii) ninety percent
(90%) systems designs], and (iv) issued for construction designs (“Design Documents”). The Design
Documents shall incorporate engineering and design specifications for the Project for an installed
capacity equal to the Planned Capacity.
(b) The Buyer Design Review Parties will have fifteen (15) Business Days from receipt of
the Design Documents to provide comments. Such comments will address conformance of such
Design Documents to the Technical Specification and the Transaction Documents.
(c) If the Buyer Design Review Parties timely provide comments on any Design
Documents, Developer Parties must resubmit revised Design Documents that are responsive to such
comments. The Buyer Design Review Parties will then have ten (10) Business Days from receipt of
the resubmission to provide any additional comments. The Developer Parties may only proceed with
the Work once the Buyer Design Review Parties either approve of the Design Documents without
comment or offer written consent that the comments do not have to be incorporated into the Design
Documents.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 246 of 1056
(d) A delay or lack of comments from the Buyer Design Review Parties will not relieve
the Developer from meeting its obligations under the Transaction Documents or the Contractor from
meeting its obligations in the EPC Contract, and Buyer reserves the right to allow the work to proceed
“under protest.”
14.3
Any documents or information (including calculations) which Buyer’s Representative
identifies as not in compliance with this Agreement shall be modified to be in compliance and
resubmitted without delay.
14.4
Developer shall not deviate from drawings accepted or approved by Buyer or Buyer’s
Representative or issued by Developer as approved for construction, except with the prior written
consent of Buyer or Buyer’s Representative.
14.5
Developer shall maintain and provide to Buyer’s Representative from time to time or upon
request of Buyer’s Representative a complete list of drawings, identifying which are approved for
construction. Buyer and Buyer’s Representatives shall have the right at all reasonable times to
inspect all drawings of any part of the Work.
14.6
(a) All operating and maintenance manuals, startup and shutdown manuals, and
drawings of the Work as-built shall be in such detail as will enable Buyer to operate, maintain, and
repair all parts of the Work, as described in Appendix F and Appendix G.
(b) The provision by Developer of the final operation and maintenance manuals and
drawings of the Work as-built in accordance with the provisions of this 14.6 shall be identified as a
Milestone in Appendix B and the provisions of ARTICLE 11 shall apply.
14.7
(a) Drawings and information created by Developer Parties for purposes of designing,
developing, constructing, commissioning, and operating the Project constitute “work made for hire,”
and Developer hereby transfers and assigns all rights in and to such drawings and information to
Buyer. The EPC Contract shall similarly require that Contractor so transfer and assign all rights in
and to such drawings and information.
(b) Drawings and information supplied by Developer Parties that are not created by
Developer specifically for or in connection with the Project, but that are necessary or useful for the
operation and maintenance of the Project, the Work, or any portion of thereof, may be used by Buyer
for the purposes of completing, maintaining, operating, improving, adapting, renewing, enlarging,
dismantling, re-assembly, adjusting, and repairing the Work, and for any other legal purpose,
pursuant to the license granted in 14.7(c).
(c) Developer grants to Buyer an irrevocable, perpetual, royalty free license to use all
drawings and information for the foregoing purposes and Developer shall provide Buyer with copies
of such drawings and information.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 247 of 1056
14.8
(a) Developer shall be responsible for the accuracy, completeness, and suitability of all
drawings, samples, patterns, models, calculations, or information submitted by Developer Parties in
connection with the Work. Notwithstanding Buyer’s or Buyer’s Representative’s inspection or
approval of drawings, samples, patterns, models, calculations, or information submitted by
Developer Parties, Developer shall not be relieved of any responsibility or liability imposed on it by
any provisions of this Agreement and shall be responsible for any errors, omissions, or discrepancies
therein.
(b) Developer shall bear any and all third-party costs Developer or Buyer may incur as a
result of delay in providing such drawings, samples, patterns, models, calculations, or information or
as a result of material errors, omissions, or discrepancies therein or for the correction thereof.
(c) Developer shall, at its sole cost and expense, carry out or cause to be carried out any
alterations or remedial work necessitated by such errors, omissions, or discrepancies for which it is
responsible and modify the drawings, samples, patterns, models, calculations, or information
accordingly.
PERFORMANCE TESTS
15.1
(a) Prior to Substantial Completion, Developer shall conduct or cause to be conducted
the Performance Guarantee Tests (with the exception of the Availability Test, which is addressed in
(b), below) as soon as practicable in accordance with the Technical Specification, the procedures and
protocols of Appendix O and the other tests, procedures, and protocols as may be developed by the
Parties pursuant hereto. At least 60 days prior to each Performance Guarantee Test, Developer shall
deliver to Buyer a supplement to Appendix O further outlining in detail the tests, procedures and
protocols to be followed in conducting the Performance Guarantee Tests. Such supplement shall
include, at a minimum, provisions addressing: (a) testing procedures for each item of Major
Equipment; and (b) any other activities that, in accordance with Prudent Industry Practices, should
be included. Thereafter, the Parties shall promptly agree on modifications to such supplement so
that Appendix O, as supplemented, is satisfactory Buyer.
(b) Prior to Final Completion, Developer shall perform the Availability Test and related
obligations and provide the Availability Guarantee, as provided in Appendix O; provided, if Developer
does not achieve the Availability Guarantee as determined in accordance with the terms of Appendix
O on or before the Final Completion Date, then Developer shall pay as liquidated damages for such
failure and not as a penalty, the Guaranteed Availability Liquidated Damages for each Day during the
Reliability Run Period in which Developer fails to demonstrate compliance with the Availability
Guarantee.
15.2
(a) Buyer will cooperate with Developer’s reasonable requests in connection with each
Performance Guarantee Test but shall not be required to provide any materials, electricity, fuel,
water, or stores in connection therewith.
(b) Developer shall provide all materials, charging electricity, consumables, and stores,
and all personnel necessary to supervise startup and the conducting of the Performance Guarantee
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 248 of 1056
Tests and shall provide all necessary technical assistance and advice in connection with the
Performance Guarantee Tests. Except as approved by Buyer in writing, Developer shall not use
personnel in excess of the normal contingent of Project operations staff to operate the Project during
the PerformanceGuarantee Tests. During training and conducting thePerformanceGuarantee Tests,
Buyer’s operating personnel shall be working under the technical direction and instruction of
Developer and Developer shall be responsible for the accuracy of its instructions/directions provided
to Buyer’s operating personnel.
15.3
Buyer and Buyer’s Representative shall have the right and opportunity to be present and
observe the Performance Guarantee Tests and shall have the right and opportunity in advance or
during the Performance Guarantee Tests to inspect and validate all meters, meter readings, and other
pertinent data necessary to verify the results of the Performance Guarantee Tests. Buyer shall
provide reasonable notice to Developer of any such observation and inspection, including the specific
information desired and method of obtaining such information. Developer and Buyer shall
coordinate such observation, inspection, and validation so as not to interfere with the Performance
Guarantee Tests and provide for a verifiable result.
15.4 Timing.
Developer shall provide Buyer at least [ninety (90)] days’ prior written notice of the
anticipated date on which the Performance Guarantee Tests will begin and at least five (5) days’ prior
notice of the actual date (or any change to the actual date) on which the Performance Guarantee Tests
will begin.
15.5 Reports.
(a) Developer shall Make Available to Buyer a preliminary test report, including the test
data sheets and calculated results for each Performance Test (the “Preliminary Performance Test
Report”), promptly after completion of each Performance Guarantee Test, together with a notice to
Buyer certifying completion of the applicable Performance Test in accordance with this Agreement
and the results of each such Performance Guarantee Test. Promptly after receipt of such Preliminary
Performance Test Report, Buyer and Developer shall consult concerning the results of each such
Performance Guarantee Test, and within three (3) days thereafter, Buyer shall provide Developer
written notice that it either accepts or disputes the results of the applicable Performance Guarantee
Test, including the reasons for any dispute.
(b) Within fifteen (15) Business Days following completion of an applicable Performance
Guarantee Test, Developer shall provide to Buyer a final test report, including test data sheets and
calculated results of each Performance Test (the “Final Performance Test Report”) and a final notice
to Buyer certifying completion of the Performance Guarantee Test. Each Final Performance Test
Report shall reflect the Parties’ consultation with one another with respect to the Preliminary
Performance Test Report. Within fifteen (15) days of receipt of such documentation from Developer,
Buyer shall provide Developer written notice that it either accepts or disputes the results of the
applicable Performance Guarantee Test, including the reasons for any dispute. If Buyer disputes the
results of the Performance Guarantee Test in the Final Performance Test Report, then Developer shall
re-perform the applicable Performance Test (or part thereof) in accordance with the procedures set
forth in Appendix O. If the results of the re-test confirm the accuracy of the initial Performance
Guarantee Test, then Buyer shall pay the increased costs directly resulting from the re-test. If the
results of the re-test do not confirm the accuracy of the initial Performance Guarantee Test, then
Developer shall pay the increased costs directly resulting from the re-test.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 249 of 1056
15.6
Following any failed Performance Guarantee Test, Developer shall replace or repair the
applicable Work, Project, Equipment or Materials and re-submit the same for test or inspection in
accordance with this ARTICLE 15. All expenses reasonably incurred by or on behalf of Buyer in
connection with such re-testing or inspection shall paid for by Developer. Buyer’s rights pursuant to
this 15.6 are in addition to its rights pursuant to ARTICLE 15.
15.7 ,
Developer shall promptly advise Buyer upon it becoming aware of any Defect in any Work
performed or Equipment, Materials or the Project supplied or used by Developer Parties or error or
omission that might affect the Work, the Equipment, the Materials, or the Project and its operability,
operational life, or maintenance.
16.1
Developer shall cause the EPC Contract to have the following final EPC Milestones: (i)
Mechanical Completion; (ii) Substantial Completion; and (iii) Final Completion.
16.2
(a) Developer shall provide Buyer and Buyer’s Engineer with no less than ten (10)
Business Days’ notice prior to its expected delivery of the Certificate of Mechanical Completion.
When Developer determines that the Work meets the Mechanical Completion Criteria set forth in
Appendix Q, Developer shall so notify Buyer and Buyer’s Engineer and provide Buyer and Buyer’s
Engineer a certificate of an Authorized Signatory of Developer, in the form of Appendix D-1, certifying
that the Mechanical Completion Criteria have been achieved and the date thereof (the “Certificate of
Mechanical Completion”).
(b) Within five (5) Business Days after receipt of each Certificate of Mechanical
Completion, Buyer’s Engineer shall provide written notice to Developer and Buyer of either: (i) its
rejection of such Certificate of Mechanical Completion (if reasonable cause exists for doing so) or
(ii) its acceptance of the Certificate of Mechanical Completion. Within five (5) Business Days after
receipt of notice from Buyer’s Engineer in the preceding sentence, Buyer shall either: (i) if reasonable
cause exists for doing so (including but not limited to a rejection by Buyer’s Engineer), reject such
Certificate of Mechanical Completion and by written notice specify the Mechanical Completion
Criteria Developer failed to achieve; or (ii) accept the Certificate of Mechanical Completion by
countersigning the Certificate of Mechanical Completion, in which case, Mechanical Completion shall
be deemed to occur on the date set forth in the Certificate of Mechanical Completion. Any failure of
Buyer to respond within such five (5)-Business Day period may serve as the basis of a Required
Change Order, in accordance with 12.2(c)(ii).
(c) If Buyer rejects a Certificate of Mechanical Completion pursuant to 16.2(b)(i), then
Developer shall promptly provide to Buyer a plan and schedule for remedying the deficiencies
specified in Buyer’s written notice, and shall carry out such plan at its own cost and expense. Upon
completion of such remedial work and Developer’s belief that the Mechanical Completion Criteria are
satisfied, Developer shall issue a new Certificate of Mechanical Completion to Buyer pursuant to
16.2(a).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 250 of 1056
(d) The foregoing procedure shall be repeated until Buyer accepts the Certificate of
Mechanical Completion pursuant to 16.2(b)(ii). Disputes as to whether Developer has achieved
Mechanical Completion shall be resolved pursuant to ARTICLE 27.
(e) In no event shall Mechanical Completion be achieved if the installed storage capacity
is less than the Planned Storage Capacity.
16.3
(a) Developer shall provide Buyer and Buyer’s Engineer with no less than ten (10)
Business Days’ notice prior to its expected delivery of the Certificate of Substantial Completion.
When Developer determines that the Work meets the Substantial Completion Criteria set forth in
Appendix Q, Developer shall so notify Buyer and Buyer’s Engineer and provide Buyer and Buyer’s
Engineer a certificate of an Authorized Signatory of Developer, in the form of Appendix D-2, certifying
that the Substantial Completion Criteria have been achieved and the date thereof (the “Certificate of
Substantial Completion”).
(b) Within five (5) Business Days after receipt of each Certificate of Substantial
Completion, Buyer’s Engineer shall provide written notice to Developer and Buyer of either: (i) its
rejection of such Certificate of Substantial Completion (if reasonable cause exists for doing so) or
(ii) its acceptance of the Certificate of Substantial Completion. Within five (5) Business Days after
receipt of notice from Buyer’s Engineer in the preceding sentence, Buyer shall either: (i) if reasonable
cause exists for doing so (including but not limited to a rejection by Buyer’s Engineer), reject such
Certificate of Substantial Completion and by written notice specify the Substantial Completion
Criteria Developer failed to achieve; or (ii) accept the Certificate of Substantial Completion by
countersigning the Certificate of Substantial Completion, in which case, Substantial Completion shall
be deemed to occur on the date set forth in the Certificate of Substantial Completion. Any failure of
Buyer to respond within such five (5)-Business Day period may serve as the basis of a Required
Change Order, in accordance with 12.2(c)(ii).
(c) If Buyer rejects a Certificate of Substantial Completion pursuant to 16.3(b)(i), then
Developer shall promptly provide to Buyer a plan and schedule for remedying the deficiencies
specified in Buyer’s written notice, and shall carry out such plan at its own cost and expense. Upon
completion of such remedial work and Developer’s belief that the Substantial Completion Criteria are
satisfied, Developer shall issue a new Certificate of Substantial Completion to Buyer pursuant to
16.2(a).
(d) The foregoing procedure shall be repeated until Buyer accepts the Certificate of
Substantial Completion pursuant to 16.2(b)(ii). Disputes as to whether Developer has achieved
Substantial Completion shall be resolved pursuant to ARTICLE 27.
(e) In no event shall Substantial Completion be achieved if the Planned Capacity, as set
forth in the Technical Specification, is less than the Capacity Guarantee.
16.4
(a) Developer shall provide Buyer and Buyer’s Engineer with no less than ten (10)
Business Days’ notice prior to its expected delivery of the Certificate of Final Completion. When
Developer determines that the Work meets the Final Completion Criteria set forth in Appendix Q,
Developer shall so notify Buyer and Buyer’s Engineer and provide Buyer and Buyer’s Engineer a
certificate of an Authorized Signatory of Developer, in the form of Appendix D-3, certifying that the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 251 of 1056
Final Completion Criteria have been achieved and the date thereof (the “Certificate of Final
Completion”).
(b) Within five (5) Business Days after receipt of each Certificate of Final Completion,
Buyer’s Engineer shall provide written notice to Developer and Buyer of either: (i) its rejection of
such Certificate of Final Completion (if reasonable cause exists for doing so) or (ii) its acceptance of
the Certificate of Final Completion. Within five (5) Business Days after receipt of notice from Buyer’s
Engineer in the preceding sentence, Buyer shall either: (i) if reasonable cause exists for doing so
(including but not limited to a rejection by Buyer’s Engineer), reject such Certificate of Final
Completion and by written notice specify the Final Completion Criteria Developer failed to achieve;
or (ii) accept the Certificate of Final Completion by countersigning the Certificate of Final Completion,
in which case, Final Completion shall be deemed to occur on the date set forth in the Certificate of
Final Completion. Any failure of Buyer to respond within such five (5)-Business Day period may
serve as the basis of a Required Change Order, in accordance with 12.2(c)(ii).
(c) If Buyer rejects a Certificate of Final Completion pursuant to 16.4(b)(i), then
Developer shall promptly provide to Buyer a plan and schedule for remedying the deficiencies
specified in Buyer’s written notice, and shall carry out such plan at its own cost and expense. Upon
completion of such remedial work and Developer’s belief that the Final Completion Criteria are
satisfied, Developer shall issue a new Certificate of Final Completion to Buyer pursuant to 16.2(a).
(d) The foregoing procedure shall be repeated until Buyer accepts the Certificate of Final
Completion pursuant to 16.2(b)(ii). Disputes as to whether Developer has achieved Final Completion
shall be resolved pursuant to ARTICLE 27.
(e) In no event shall Final Completion be achieved if any Performance Guarantee Test
demonstrates that a Performance Guarantee is not met.
16.5
(a) Developer shall cause the EPC Contract to provide that risk of loss with respect to the
Work, including all Equipment, Materials, and the Project, shall pass to the Project Company prior to
the Substantial Completion Date.
(b) Developer shall be responsible for risk of loss of the Work, including all Equipment,
Materials, and the Project, and shall make good at Developer’s own cost and expense any loss or
damage that may occur to the Work or any part thereof from any cause whatsoever on or before the
Substantial Completion Date.
(c) Care, custody, and control of the Work, including all Equipment, Materials, and the
Project, shall be transferred to the Project Company prior to the Substantial Completion Date. Buyer
shall begin to compile a preliminary punch list as the Work progresses (with Developer and Buyer,
with the advisement of Buyer’s Engineer and in good faith, mutually determining the Dollar value of
such list). Buyer shall submit to Developer the completed preliminary punch list at least fifteen (15)
Business Days prior to the anticipated Substantial Completion Date. At least five (5) Business Days
prior to the Substantial Completion Date, Developer and Buyer, with the advisement of Buyer’s
Engineer, shall mutually agree on the final punch list of items, the value related thereto and on a
schedule for completion of such items (the “Final Punch List”). All of the items on the Final Punch
List shall be completed expeditiously after the Substantial Completion Date and in accordance with
the schedule for completion provided as part of the Final Punch List. Buyer shall provide to
Developer for such purpose reasonable access to the Work. Developer’s Credit Support shall remain
in place until all items on the Final Punch List have been completed or otherwise waived by Buyer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 252 of 1056
(d) Buyer shall begin to compile a preliminary punch list as the Work progresses (with
Developer and Buyer, with the advisement of Buyer’s Engineer and in good faith, mutually
determining the Dollar value of such list). The list of punch list items with respect to Work not
completed as of the Substantial Completion and the applicable Punch List Holdback Amount with
respect thereto, shall be certified by Buyer’s Engineer. Upon the Final Completion, Buyer shall pay to
Developer the Punch List Holdback Amount.
16.6
During the startup, testing, and commissioning of the Project, Developer shall coordinate
with Buyer’s Representative and Buyer’s operating personnel for the orderly startup and shut-down
of the Project. Sixty (60) days prior to the initial startup of the Project, Developer shall provide to
Buyer a schedule of dispatch for the Project during the commissioning period, including expected net
Project output and duration of the commissioning activities. Developer shall also provide seventy-
two (72) hours’ advance notice to Buyer of the planned dispatch profile including net Project output
and duration of the commissioning period.
16.7
(a) Prior to Final Completion, Developer shall remove from the Site all Developer’s
Equipment, materials, temporary structures constructed by or on behalf of Developer or other items
of any nature required for execution or completion of the Work, but excluding equipment, materials,
appliances, or other items intended to form or forming part of the Work, including the Equipment,
Materials, and the Project.
TA
17.1
Developer shall defend, indemnify, and hold harmless the Buyer Indemnified Parties from,
for, and against any Pre-Closing Taxes.
17.2
Developer shall be responsible for any sales, use, value added, gross receipts, excise,
registration, stamp duty, transfer, or other similar Taxes or governmental fees (including any interest
or penalties related thereto) that may be payable in connection with the development, design,
engineering, construction, and commissioning of the Project and the Work and Buyer’s purchase of
the Membership Interests in the Project Company (the “Transfer Tax”). Developer shall prepare and
file all Tax Returns for any Transfer Tax and shall remit the Transfer Tax shown as due on each such
Tax Return. Buyer and Developer shall, upon request, use their commercially reasonable efforts to
obtain any certificate or other document from any Governmental Authority or any other person that
may be necessary to mitigate, reduce, or eliminate any Tax described in this 17.2.
17.3
The Parties acknowledge and agree that, for federal income Tax purposes (and state, local,
and foreign income Tax purposes, as applicable), the sale of the Membership Interests is properly
treated as a sale to Buyer of all of the assets of the Project Company and an assumption by Buyer of
all of the liabilities of the Project Company. Within ninety (90) days after the Closing Date, Buyer
shall prepare and provide to Developer an allocation of the Purchase Price and any liabilities properly
included for U.S. federal income Tax purposes among the assets of the Project (the “Proposed
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 253 of 1056
Purchase Price Allocation”). Within thirty (30) days of receipt of such Proposed Purchase Price
Allocation, Developer shall provide to Buyer any comments with respect to such Proposed Purchase
Price Allocation, and Buyer and Developer will thereafter work together in good faith to resolve any
disagreement with respect to such Proposed Purchase Price Allocation to agree on a final Purchase
Price allocation (the “Final Purchase Price Allocation”). Buyer and Developer shall file all Tax Returns
in a manner consistent with the Final Purchase Price Allocation and shall not take any position on
any Tax Return, in any audit, administrative, or judicial proceeding, or otherwise that is inconsistent
with the Final Purchase Price Allocation except as otherwise required applicable Law; provided,
however, that if Developer and Buyer are unable to resolve any disagreements with respect to the
Proposed Purchase Price Allocation within thirty (30) days after Buyer’s receipt of Developer
comments (if any) to the Proposed Purchase Price Allocation (or such longer period as may be agreed
upon in writing by Developer and Buyer), the Developer and the Buyer may take inconsistent Tax
reporting positions with respect to the allocation of purchase price hereunder.
17.4
(a) Neither Developer nor any Affiliate of Developer will engage in any action or fail to
take any action that would be reasonably likely to jeopardize the realization by or allowance to Buyer
or any of its Affiliates of any Tax Benefits or the eligibility of the Project (or any property that is part
of the Project) for any other Tax benefit.
(b) Neither Developer nor any Affiliate of Developer will take any action that would, or
omit to take any action the omission of which would, cause the construction of the Project to have
begun on or after [____] within the meaning of Sections 48(a)(2)(A)(i)(II), 48(a)(3)(A)(i) and 48(a)(6)
of the Code and the IRS Notice or otherwise cause to be untrue, incorrect or incomplete any
certification contained in the Begun Construction Certificate. Developer will notify Buyer in writing
within ten (10) days of Developer or any of its Affiliates becoming aware of any Safe Harbor
Controversy
(c) Developer shall cause the Project to be placed in service within the meaning of
Sections 48 and 168 of the Code and the IRS Notice no later than [____].15
17.5
(a) Developer shall prepare and duly and timely file all Tax Returns required to be filed
by or with respect to the Project Company, the Project Assets and the Project for any taxable period
ending on or before the Closing Date, and such Tax Returns shall be prepared in accordance with
applicable Laws and this Agreement. Developer shall provide Buyer with copies of all such Tax
Returns (except, for the avoidance of doubt, federal and applicable state income Tax Returns of
Developer) at least fifteen (15) Business Days prior to the due date of such return (taking into account
any valid extensions thereof) for Buyer’s review and comment, and Developer shall take into account
any of Buyer’s reasonable comments that are requested at least five (5) Business Days in advance of
the due date (taking into account any valid extensions thereof).
(b) Buyer shall prepare and duly and timely file all Tax Returns required to be filed by or
with respect to the Project Company, the Project Assets, and the Project with respect to any Straddle
Period, and such Tax Returns shall be prepared in accordance with applicable Laws and this
Agreement. Buyer shall provide Developer with copies of all such Tax Returns (except, for the
avoidance of doubt, federal and applicable state income Tax Returns of Buyer) at least fifteen (15)
Business Days prior to the due date of such return (taking into account any valid extensions thereof)

15 Note to Bidders: Applicable to storage projects co-located with solar.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 254 of 1056
for Buyer’s review and comment, and Buyer shall consider in good faith any of Developer’s comments
that are requested reasonably at least five (5) Business Days in advance of the due date (taking into
account any valid extensions thereof). Developer shall remit Developer’s allocable share of any Taxes
due by or with respect to the Project Company, the Project Assets or the Project in respect of any
Straddle Period to Buyer within five (5) days of Buyer’s request therefor, except to the extent such
Taxes were taken into account in the Purchase Price as Pro-ratable Items.
(c) All real and personal property Taxes that are due or become due with respect to the
assets and properties of the Project Company, the Project Assets or the Project for any Straddle
Period shall be apportioned between Developer, on the one hand, and Buyer, on the other hand, as of
the Closing Date, based on the ratio of the number of days in the Straddle Period through (and
including) the Closing Date, on the one hand, to the number of days in the Straddle Period after the
Closing Date, on the other hand. Subject to the foregoing sentence, with respect to any Straddle
Period, the amount of Taxes allocable to the portions thereof ending on (and including) the Closing
Date and beginning on the day after the Closing Date shall be determined using an interim closing of
the books method as of the close of business on the Closing Date.
(d) Neither Buyer nor the Project Company may file an amended Tax Return with respect
to any Pre-Closing Tax Period or Straddle Period without the written consent of Developer, which
shall not be unreasonably withheld, conditioned, or delayed. Any refund of Tax with respect to any
Pre-Closing Tax Period relating to the Project Company, the Project Assets and the Project shall be
the property of Developer, and any refund of any Tax with respect to any Straddle Period relating to
the Project Company, the Project Assets and the Project shall be apportioned between Buyer and
Developer in the manner set forth in 17.5(b) hereof.
17.6
Buyer shall notify Developer upon receipt by Buyer, the Project Company, or any of Buyer’s
other Affiliates of a written notice of a U.S. federal or state Tax audit or assessments that may
materially affect the Tax liabilities of the Project Company, and for which Developer is or may be
liable hereunder, as soon as reasonably practicable after receiving such notice but in any event within
fifteen (15) days of such receipt, provided that failure to comply with this provision shall not affect
Buyer’s right to indemnification hereunder, except to the extent such failure actually and materially
prejudices Developer. Developer shall have the sole right to control any audit, action, claim,
assessment, examination, levy, deficiency, adjustment, or other judicial or administrative proceeding
by any Governmental Authority, and contest, resolve, and defend against any assessment for
additional Taxes, notice of Tax deficiency or other adjustment of Taxes of or relating solely to one or
more of the Project Company, the Project Assets, or the Project and solely with respect to a Pre-
Closing Tax Period; provided that (a) that Developer must first acknowledge its liability for any
resulting Taxes in writing, (b) Developer shall provide written notice to Buyer of any such proceeding
and keep Buyer reasonably apprised of the initiation and status of any such proceeding, (c) Buyer
shall have the right, at its own expense, to review and comment on any written submissions and to
participate in any proceedings relating to any such proceeding controlled by Developer,
(d) Developer shall not settle any such proceeding without Buyer’s written consent, which shall not
be unreasonably withheld, conditioned, or delayed, and (e) Developer shall have no right control or
contest any audit, action, claim, assessment, examination, levy, deficiency, adjustment, or other
judicial or administrative proceeding with respect to Taxes reported on any consolidated, combined,
unitary or similar Tax Return for which Buyer is a member. Buyer shall have the sole right to control
any audit, action, claim, assessment, examination, levy, deficiency, adjustment, or other judicial or
administrative proceeding by any Governmental Authority, and contest, resolve, and defend against
any assessment for additional Taxes, notice of Tax deficiency or other adjustment of Taxes of or
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 255 of 1056
relating to the Project Company, the Project Assets, or the Project for all other taxable periods;
provided, that with respect to any administrative or court proceeding relating to any Straddle Period,
(i) Developer shall have the right, at its own expense, to review and comment on any written
submissions and to participate in any proceedings relating to any such proceeding controlled by
Buyer, (ii) Buyer shall provide written notice to Developer of any such proceeding and keep
Developer reasonably apprised of the initiation and status of any such proceeding, and (iii) Buyer
shall not settle any such proceeding without Developer’s written consent, which shall not be
unreasonably withheld, conditioned, or delayed.
17.7
The Purchase Price includes any and all Taxes (including any related customs broker fees or
similar charges) imposed on the sale or delivery of the Project Company, the Project Assets, the Work
or the Project, and Developer shall duly and timely remit any such Taxes in accordance with all
applicable Laws (including all customs and import duties arising upon the importation of the Project,
Equipment, and Materials into the applicable port of entry). Developer shall provide Buyer such
information and data as requested by Buyer, and fully cooperate, in connection with (i) the reporting
of any such Taxes, (ii) any audit relating to any such Taxes, or (iii) any assessment, claim, or
proceeding relating to any such Taxes.
17.8 Cooperation.
Buyer and Developer shall cooperate fully, as and to the extent reasonably requested, in
connection with the filing of Tax Returns and any audit, litigation, or other proceeding with respect
to Taxes. Such cooperation shall include the retention and (upon request) the provision of records
and information that are reasonably relevant to the filing of such Tax Returns and any such audit,
litigation, or other proceeding and making employees available on a mutually convenient basis to
provide additional information and explanation of any material provided hereunder.
17.9
The provisions of this ARTICLE 17 shall govern the indemnification rights and obligations of
Buyer, Developer, and their Affiliates with respect to Tax matters in the event of any conflict or
overlap between the provisions of Article 22 and this ARTICLE 17, and, for the avoidance of doubt,
any Claim arising under both ARTICLE 17 and ARTICLE 22 shall be treated for all purposes of the
Agreement (including and ARTICLE 22) as arising solely under
this ARTICLE 17.
18.1 General Obligations.
(a) Neither Developer nor Project Company shall (a) install or operate or permit its
contractors or other representatives to install or operate any underground storage tanks on the Site,
(b) disturb (other than through demolition and removal or other abatement) any asbestos contained
in or that forms part of any building, building component, structure, or office space on the Site, and
(c) use or store any polychlorinated biphenyls at the Site in connection with construction of the
Project.
(b) Not less than ninety (90) days prior to the Closing, Developer shall prepare and
submit to Buyer materials management and emergency response procedures in accordance with
Environmental Law covering any Regulated Materials Developer expects to be used in the completion
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 256 of 1056
and testing of the Work, which procedures shall be reasonably satisfactory to Buyer. Unless Buyer
provides written comments on the procedures within fourteen (14) days of receipt from Developer,
Buyer shall be deemed to have approved the procedures. Developer shall materially comply, and
shall cause all other Developer Parties to materially comply, at all times with the Buyer-approved
materials management and emergency response procedures (the “Procedures”). No Regulated
Materials shall be Released on the Site in violation of Environmental Laws.
18.2 -Site.
Developer shall immediately notify Buyer of any Release of Regulated Materials at the Site by
the Developer Parties or otherwise that violates or, to Developer’s Knowledge, has the potential to
violate Environmental Laws, including but not limited to state and federal laws and regulations
relating to water pollution, hazardous material disposal, and hazardous materials Release
requirements. In addition, Developer shall immediately notify any applicable Governmental
Authorities of any Release that is reportable to Governmental Authorities under applicable
Environmental Laws and take such emergency measures consistent with Prudent Industry Practice
and necessary to comply with the Procedures and applicable Law, including with respect to the
immediate containment of any such Release and Remediation of the affected area.
18.3 -Site.
In the event of a Release by any Developer Party of a Regulated Material off the Site but
related to the Work which is reportable to Governmental Authorities under applicable
Environmental Laws, Developer shall be responsible for notifying all applicable federal, state, and
local Governmental Authorities in accordance with applicable Law or for causing such notification to
occur by the Developer Party responsible for such action. Developer shall take all appropriate steps
consistent with the Procedures and required by applicable Law for containment of any such Release
and Remediation of the affected area.
18.4 Liability.
Developer shall be liable to Buyer for any Release of Regulated Materials at or from the Site
to the extent such Release has occurred as of the Closing Date, except to the extent such Release is
negligently or intentionally exacerbated by Buyer or any third party after the Closing Date.
18.5 Pre-
(a) Developer shall develop a contingency plan to address the investigation and, if
required under Applicable Law, corrective action with respect to the presence or Release of
Regulated Materials encountered in surface or subsurface soils, surface water, or groundwater
during construction of the Project. The contingency plan shall, at a minimum, provide for:
(i) a staging area for soil containing Regulated Materials to avoid or minimize
construction delays;
(ii) the handling of any groundwater containing Regulated Materials in
accordance with applicable Permits and Environmental Laws; and
(iii) the off-site disposal of all Regulated Materials and impacted soil and
groundwater that does not qualify under Environmental Law for return to or placement at the Site.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 257 of 1056
(b) Developer shall be responsible for implementing any requirements under
Environmental Law relating to pre-existing Regulated Materials identified in any environmental
surveys or reports.
18.6 Notice.
Developer shall notify Buyer as soon as reasonably practicable of the occurrence of any event
that would reasonably be expected to result in any actual or potential violation of or noncompliance
with any Environmental Law relating to the Work, the Project, or the Site, or otherwise constitutes a
Material Adverse Change under this Agreement.
19.1 Warranties.
(a) Developer shall cause the EPC Contract to provide a warranty (the “Warranty”), for
the duration of the applicable Warranty Period, as set forth in this ARTICLE 19. The scope of the
Warranty shall include:
(i) that the Project and all Equipment and Materials and other Work furnished
by Contractor or any Major Subcontractor, including installation, but excluding the Major Equipment
to which the Major Equipment Warranties in Appendix E apply (provided, that Work related to such
Equipment shall not be excluded) shall: (A) be free from improper workmanship and defects in
design, engineering, construction, fabrication, workmanship, materials, and operations (collectively,
“Defects,” and individually “Defect”), (B) be new and unused (except for use as part of the Project),
(C) be of good quality, undamaged, and in good condition, and (D) conform to the applicable
requirements of this Agreement and the other Transaction Documents, including the Scope of Work
and Technical Specification, in each case, in effect as the Final Completion Date;
(ii) that the procurement, design, engineering, and construction services included
as part of the Work (including for the avoidance of doubt, Work related to installation of the
Equipment) shall be performed with Contractor’s and Major Subcontractor’s best skill and judgment,
in a good and workmanlike manner, and conform to and be designed, engineered, and constructed in
accordance with the terms and conditions of the Transaction Documents, including the Scope of Work
and Technical Specification, Prudent Industry Practice, applicable Laws, and the Project Company
Permits, in each case, in effect as of the Final Completion Date, and conform with, and be designed
and engineered according to professional standards and skill, expertise and diligence of design
professionals regularly involved in energy storage projects similar to the Project, and contain the
Equipment, Materials, and supplies described in the Scope of Work;
(iii) that the completed Work shall perform its intended functions as a complete,
integrated energy storage system as explicitly described or implied in the Transaction Documents;
and
(iv) that none of the Work, the Project, the Equipment, the Materials, the final
plans, and the design, engineering, and other services rendered by Contractor or any Major
Subcontractor hereunder, nor the use or ownership thereof by Project Company or Buyer in
accordance with the licenses granted hereunder, infringes, violates, or constitutes a
misappropriation of any trade secrets, proprietary rights, intellectual property rights, patents,
copyrights, or trademarks.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 258 of 1056
(b) The Warranty shall not extend to Defects or deficiencies to the extent resulting from:
(i) operation by Buyer’s personnel in a manner inconsistent with or contrary to instructions
contained in the operation and maintenance manuals provided by Developer pursuant to 14.6; (ii)
repairs or alterations by Buyer’s personnel in a manner inconsistent with or contrary to instructions
provided by Developer or as contained in the operation and maintenance manuals provided by
Developer pursuant to 14.6; or (iii) normal wear and tear.
(c) Developer shall provide a gap warranty (the “Gap Warranty”), for the duration of the
applicable Warranty Period, as set forth in this ARTICLE 19. The scope of the Gap Warranty shall
include:
(i) that the Project and all Equipment and Materials and other Work furnished
by Developer, including installation, but excluding the Major Equipment to which the Major
Equipment Warranties in Appendix E apply (provided, that Work related to such Equipment shall
not be excluded) shall: (A) be free from improper workmanship and Defects, (B) be new and unused
(except for the beginning of construction transformer, which began production in [____]), (C) be of
good quality, undamaged, and in good condition, and (D) conform to the applicable requirements of
this Agreement and the other Transaction Documents, including the Scope of Work and Technical
Specification, in each case, in effect as the Final Completion Date;
(ii) that the procurement, design, engineering, and construction services
performed by Developer as part of the Work (including for the avoidance of doubt, Work related to
installation of the Equipment) shall be performed with Developer’s best skill and judgment, in a good
and workmanlike manner, and conform to and be designed, engineered, and constructed in
accordance with the terms and conditions of the Transaction Documents, including the Scope of
Work, and Technical Specification, Prudent Industry Practice, applicable Laws, and the Project
Company Permits, in each case, in effect as of the Final Completion Date, and conform with, and be
designed and engineered according to professional standards and skill, expertise, and diligence of
design professionals regularly involved in energy storage projects similar to the Project, and contain
the Equipment, Materials, and supplies described in the Scope of Work;
(iii) that the Work completed by Developer shall perform its intended functions
as a complete, integrated energy storage system as explicitly described or implied in the Transaction
Documents; and
(iv) that none of the Work, the Project, the Equipment, the Materials, the final
plans and the design, engineering, and other services rendered by Developer hereunder, nor the use
or ownership thereof by Project Company or Buyer in accordance with the licenses granted
hereunder, infringes, violates, or constitutes a misappropriation of any trade secrets, proprietary
rights, intellectual property rights, patents, copyrights, or trademarks.
19.2
Subject to the provisions in this ARTICLE 19, the Warranty and Gap Warranty and shall
remain in full force and effect for a period beginning on the Final Completion Date and ending on the
date that is thirty-six (36) months thereafter (“Warranty Period”); provided, however, that if a Serial
Defect occurs within the Warranty Period, then the Warranty or Gap Warranty, as applicable, for
such components of that type or the components that were the subject of the successful claim,
respectively, shall be automatically extended for an additional one (1) year from the date of Buyer
became aware of the failure that caused the Serial Defect.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 259 of 1056
19.3
If Buyer or Developer discovers that the Work, or any portion thereof, fails to meet the
Warranty or the Gap Warranty, then it shall notify the other Party of such failure within a reasonable
time after discovery, along with the reasonable basis therefore. Buyer shall immediately relay any
notice of Defect to Contractor or Developer upon Buyer’s discovery of the Defect or Developer’s
notice of the Defect to Buyer. Upon receipt of such notice, Contractor (with respect to the Warranty)
or Developer (with respect to the Gap Warranty), as applicable, shall (a) cure such failure in
accordance with the Warranty or Gap Warranty, as applicable and (b) perform such tests as Buyer
may reasonably require demonstrating the cure of such failure. Contractor and Developer shall
coordinate repairing, replacing, or re-performing any of the Work with Project Company and Buyer
so as to minimize any adverse effects on the operation of the Project.
19.4
(a) Extension for Corrected Work. Any Work re-performed and any part of the Site that
is reworked, repaired, or replaced in satisfaction of Contractor’s obligations in connection with the
Warranty or Gap Warranty will be re-warranted by Contractor or Developer, pursuant to the same
Warranty or Gap Warranty, as applicable, as set forth in this ARTICLE 19, and Contractor and
Developer will have the same obligations in relation thereto as set forth in this ARTICLE 19 for a
period ending either (i) twelve (12) months from the date such re-performance, rework, repair or
replacement is completed or (ii) as of the end of the applicable warranty period, whichever is later.
(b) Extension for Total Shutdown. If, during the Warranty Period, the Project is shut
down (other than for the purpose of scheduled or routine maintenance) and such shutdown is caused
by a defect or failure covered by the Warranty or Gap Warranty, then the Warranty Period will be
extended by a period equal to the duration of the shutdown required to repair such defect or failure.
19.5
Developer will procure from each Major Subcontractor the Major Equipment Warranties set
forth in Appendix E. Any Major Equipment Warranties still in effect at the expiration of the Warranty
Period, to the extent assignable, will be assigned to Buyer or, if applicable, Project Company.
19.6
If any such Defect or damage is not remedied by Contractor or Developer within a reasonable
time or requires prompt remediation as a result of an emergency situation existing at the Site, then
Buyer may proceed to do the Work or have others perform such Work at Contractor’s or Developer’s
risk and expense provided that it does so in a reasonable manner and notifies Developer and
Contractor of Buyer’s intention so to do. Developer reserves the right to investigate and determine
the eligibility for such Work to classify as part of a warranty claim. All costs incurred by or on behalf
of Buyer in connection with such Work shall be deducted from the Purchase Price or be paid by
Developer to Buyer within thirty (30) days of Buyer’s demand for such payment.
19.7
With respect to the Equipment, if a Serial Defect occurs during the Serial Defect Warranty
Period, Developer shall:
(a) Prepare a root cause report for the component(s) subject to the Serial Defect and
deliver such report to Buyer within ten (10) Business Days from discovery of or notice of a Serial
Defect.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 260 of 1056
(b) If the root cause is determined to be a manufacturing Defect, prosecute and
administer the applicable Major Equipment Warranty or other warranty with the manufacturer to
ensure the repair, replacement, or otherwise correction of the Defect.
(c) If the root cause is determined to be a design defect, prosecute and administer the
applicable Major Equipment Warranty or other with the manufacturer to ensure the manufacturer
formulates a reasonable retrofit design that resolves the cause and effect of such component(s) and
causes all affected components of the Project to be retrofitted with the new design as promptly as
possible.
19.8
Unless otherwise assigned to the Project Company in the Major Supply Agreements,
Developer and each Subcontractor shall enter into a partial assignment agreement, in form and
substance acceptable to Buyer, pursuant to which Developer and each Subcontractor shall assign to
Buyer or Project Company all of Developer’s rights with respect to the warranties provided by such
Subcontractor on or before the Final Completion Date (including but not limited to such other
existing Developer, Contractor, and Major Subcontractor warranties as may exist with respect to
19.5).
20.1 General.
(a) The Parties agree that it is difficult or impossible to determine with precision the
amount of damages that would be incurred by Buyer as a result of Developer Party’s failure to timely
achieve Mechanical Completion and to timely achieve Substantial Completion by the Guaranteed
Substantial Completion Date, or achieve the Planned Capacity, if applicable. Accordingly, the Parties
expressly agree that if Developer fails to timely achieve Substantial Completion by the Guaranteed
Substantial Completion Date, or achieve certain of the Performance Guarantees as described below,
any sums which would be payable under this ARTICLE 20 because of such failures are liquidated
damages and not a penalty, and are fair and reasonable and any such sums represent a reasonable
estimate of fair compensation for the losses that may reasonably be anticipated from such failures.
20.2
(a) If the Project fails to achieve Mechanical Completion on or prior to _________, then
Developer shall pay Buyer liquidated damages of [____] ($[_]) per day that the Project fails to achieve
Mechanical Completion (the “Mechanical Completion Delay Liquidated Damages”).
(b) Projectfails to achieve Substantial Completion March 1, 2024 (the
“Guaranteed Substantial Completion Date two
hundred dollars ([$200]) per MWh per day of Planned Capacity that has not achieved Substantial
Completion, escalating to three hundred dollars ([$300]) per MWh per day beginning on May 1, 2024
(“Substantial Completion Delay Liquidated Damages”) The Guaranteed Substantial Completion Date
will be extended due to Buyer-provided
June 1,
2024
(c) In the event that the Project achieves Substantial Completion by the Guaranteed
Substantial Completion Date, but Developer previously paid Mechanical Completion Delay
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 261 of 1056
Liquidated Damages, then Buyer shall reimburse to Developer all such Mechanical Completion Delay
Liquidated Damages through an adjustment to the Purchase Price.
20.3 .
(a) Notwithstanding the foregoing, Developer may declare that it has achieved
Substantial Completion if the Project achieves less than the Planned Capacity in the Capacity Test,
but in no case less than the Capacity Guarantee, by paying Buyer the Guaranteed Capacity Liquidated
Damages. In the event that the Project’s actual capacity achieved in the Capacity Test is less than the
Capacity Guarantee, then Developer shall not be entitled to declare Substantial Completion and
Developer shall, at Developer’s sole cost and expense, promptly rectify any such deficiencies so that
the capacity of the Project achieved in the Capacity Test at least meets or exceeds the Capacity
Guarantee (and to the extent, after such repairs, the capacity of the Project achieved in a subsequent
Capacity Test is less than the Planned Storage Capacity but greater than the Guaranteed Capacity, pay
Buyer the Guaranteed Capacity Liquidated Damages). As used herein, the “Guaranteed Capacity
Liquidated Damages” shall be the greater of two hundred Dollars per MW ([$200/MW]), prorated for
fractional MWs, below the Guaranteed Power Capacity, or two hundred Dollars per MWh
([$200/MWh]), prorated for fractional MWhs, below the Guaranteed Rated Energy Capacity, for each
Day after the Guaranteed Substantial Completion Date in which Developer does not demonstrate
compliance with the Capacity Guarantee.
(b) Developer may declare that it has achieved Substantial Completion if the Facility
achieves less than the Planned Roundtrip Efficiency Rate in the Roundtrip Efficiency Test, but in no
case less than the Roundtrip Efficiency Guarantee, by paying Buyer the Guaranteed Roundtrip
Efficiency Liquidated Damages. In the event that the Project’s actual efficiency achieved in the
Roundtrip Efficiency Test is less than the Roundtrip Efficiency Guarantee, then Developer shall not
be entitled to declare Substantial Completion and Developer shall, at Developer’s sole cost and
expense, promptly rectify any such deficiencies so that the efficiency of the Project achieved in the
Roundtrip Efficiency Test at least meets or exceeds the Roundtrip Efficiency Guarantee (and to the
extent, after such repairs, the efficiency of the Project achieved in a subsequent Roundtrip Efficiency
Test is less than the Planned Roundtrip Efficiency Rate but greater than the Roundtrip Efficiency
Guarantee, pay Buyer the Guaranteed Roundtrip Efficiency Liquidated Damages). As used herein, the
“Guaranteed Roundtrip Efficiency Liquidated Damages” shall be product of (i) the percentage amount
by which theefficiency achieved in the Roundtrip Efficiency Testis less than the Roundtrip Efficiency
Guarantee and (ii) $[__] per MWh.
(c) Developer may declare that it has achieved Final Completion if the Project achieves
less than the Planned Availability by paying Buyer the liquidated damages set forth in Appendix O,
Section 2 (the “Guaranteed Availability Liquidated Damages”). In the event that the Availability,
based on the Availability Test, is [____] ([_]%) less than the Availability Guarantee, then Developer
shall not be entitled to declare Final Completion and Developer shall, at Developer’s sole cost and
expense, promptly rectify any such deficiencies so that the Availability Guarantee is achieved based
on the results of one or more retests of the Availability Test.
(d) In no event shall Developer be required to pay liquidated damages in connection with
the Performance Guarantees in excess of [____] ($[_]) (the “Performance Test Liquidated Damages
Cap”).
20.4 .
After the Closing, with respect to any failure by the Contractor to achieve Mechanical
Completion (as defined in the EPC Contract) on or prior to the Guaranteed Mechanical Completion
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 262 of 1056
Date (as defined in the EPC Contract), Buyer shall cause the Project Company to seek Delay
Liquidated Damages (as defined in the EPC Contract) from the Contractor to the maximum extent
available under the EPC Contract. The amount of any Mechanical Completion Liquidated Damages
payable by Developer under 20.2 shall be reduced dollar-for-dollar by the amount of any Delay
Liquidated Damages (as defined in the EPC Contract) received by the Project Company from the
Contractor under the EPC Contract.
20.5
(a) All amounts payable as liquidated damages under this ARTICLE 20 shall be made by
Developer to Buyer no later than ten (10) days after the final day of each month during which
liquidated damages became payable. Buyer shall have the right to audit Developer’s calculations of
all liquidated damages. Developer shall itemize such calculations and such calculations shall include
such supporting documentation as Buyer may reasonably request and shall be in sufficient detail to
permit Buyer to verify each calculation. Buyershall notify Developer, as soon as reasonably possible,
of any portion of the calculations with which Buyer disagrees.
(b) Liquidated damages shall bear interest at the Late Payment Rate, compounded daily
from the date such amount was due, but not to exceed the maximum rate of interest permitted by
applicable Law.
21.1
Except for losses indemnified pursuant to ARTICLE 17, but subject to any right or remedy
which the Party may have under or by virtue of this Agreement, the Party establishing or alleging a
breach or default of this Agreement or a right to recover damages or to be indemnified in accordance
with this Agreement shall be under a duty to take all commercially reasonable actions necessary to
mitigate any loss which has occurred.
21.2
SUBJECT TO THE OBLIGATION OF DEVELOPER TO PAY LIQUIDATED DAMAGES TO BUYER
UNDER THIS AGREEMENT AND OTHERWISE AS PROVIDED IN 2.11 AND 21.3, AND EXCEPT AS TO A
PARTY’S GROSS NEGLIGENCE, WILLFUL MISCONDUCT, OR FRAUD, NEITHER DEVELOPER NOR
BUYER SHALL BE LIABLE TO THE OTHER BY WAY OF INDEMNITY OR BY REASON OF ANY BREACH
OR DEFAULT OF THIS AGREEMENT OR ANY STATUTORY DUTY OR TORT (INCLUDING NEGLIGENCE
BUT EXCLUDING ANY DAMAGES PAYABLE TO A THIRD PARTY CAUSED BY A TRESPASS OR
NUISANCE FOR WHICH DEVELOPER IS RESPONSIBLE PURSUANT TO THIS AGREEMENT) FOR ANY
INDIRECT OR CONSEQUENTIAL (INCLUDING LOST PROFITS, TO THE EXTENT SUCH DAMAGES ARE
INDIRECT), MULTIPLE, PUNITIVE, OR EXEMPLARY DAMAGES THAT MAY BE SUFFERED BY THE
OTHER; PROVIDED, THAT LOSSES OR DAMAGES ATTRIBUTABLE TO, RESULTING FROM OR
ARISING IN CONNECTION WITH THE LOSS, DISALLOWANCE, REDUCTION OR RECAPTURE OF, OR
INABILITY TO CLAIM, TAX BENEFITS SHALL NOT CONSTITUTE SPECIAL, INDIRECT,
CONSEQUENTIAL, MULTIPLE, PUNITIVE, OR EXEMPLARY DAMAGES FOR PURPOSES OF THIS
AGREEMENT.
21.3 Enforceabilit
The Parties explicitly agree and intend that the provisions of ARTICLE 20 shall be fully
enforceable by any court exercising jurisdiction over any dispute between the Parties arising under
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 263 of 1056
this Agreement. Each Party hereby irrevocably waives any defenses available to it under law or
equity relating to the enforceability of the liquidated damages provisions set forth in ARTICLE 20.
INDEMNIFICATION
22.1 Indemnification.
(a) From and after the Closing, Developer shall defend, indemnify, and hold harmless
Buyer and the other Buyer Indemnified Parties from, for, and against all Claims and Liabilities
(including third party Claims and Liabilities) caused by, arising out of, or in connection with: (i)
breach by Developer of its representations and warranties under this Agreement; (ii) breach by
Developer of its covenants, agreements, or obligations pursuant to this Agreement or any
Transaction Document; (iii) Developer’s fraud, gross negligence, or willful misconduct; (iv) any loss
in value of, or any inability to claim or otherwise take advantage of, relevant federal, state, and local
tax credits and accelerated deprecation (MACRS) due to any act or omission by Developer; (v) any
security breach, cyber-attack, other data security, or cyber incident or unauthorized access to any
Developer IT Asset, which resulted in the unauthorized use, misappropriation, modification,
encryption, corruption, disclosure, or transfer of any material information or data contained therein
relating to the Project Company or the Project Assets, (vi) Intellectual property infringement with
regard to the Project Assets; (vii) Claims or Liabilities arising from any oral farming leases pertaining
to the any part of the Site that were not properly and legally terminated in accordance with Idaho
law prior to the Closing Date, (viii) Claims or Liabilities of the Project Company arising on or prior to
the Closing Date, including Pre-Closing Liabilities, (ix) of any ITC benefit, and (x) any payments or
other obligations to the Contractor or other Subcontractors under any of the Project Contracts
(including but not limited to Construction Costs, Interconnection Costs, or other payments under the
EPC Contract and Major Supply Agreements), whether such payments or obligations arise or are
incurred prior to, on, or after the Closing Date.
(b) From and after the Closing, Buyer shall defend, indemnify, and hold harmless
Developer and its Affiliates, directors, officers, employees, and agents, from, for, and against all
Claims and Liabilities (including third-party Claims and Liabilities) caused by, arising out of, or in
connection with: (i) breach by Buyer of its representations and warranties under this Agreement;
(ii) breach by Buyer of its covenants, agreements, or obligations pursuant to this Agreement or any
Transaction Document; (iii) Buyer’s fraud, gross negligence, or willful misconduct; and (iv) and,
except to the extent part of Developer’s obligations under this Agreement (including its
indemnification obligations set forth herein, including pursuant to 22.1(a)), Claims or Liabilities of
the Project Company first arising after the Closing Date.
(c) Notwithstanding any other provision of this Agreement or any other Transaction
Document, following the Closing Date, a Party seeking indemnification under this Agreement (the
“Indemnified Party”) shall not be entitled to make any Claim for indemnification under 22.1(a) or
22.1(b), above with respect to the inaccuracy of any representation or warranty unless and until the
aggregate amount of all Claims and Liabilities for indemnification exceeds one percent (1%) of the
Purchase Price (the “Tipping Basket Amount”). If and when the Tipping Basket Amount is reached,
the Indemnified Party shall be entitled to make a Claim for indemnification for all Claims and
Liabilities with respect to the inaccuracy of representations or warranties.
(d) An Indemnified Party’s claim shall not exceed one hundred percent (100%) of the
Purchase Price (the “Liability Cap”), except in the case of fraud, willful misconduct, or gross
negligence of a Party or its related persons, and for intellectual property infringement, liens,
construction costs, and specified Pre-Closing Liabilities, for which there will be no Liability Cap.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 264 of 1056
(e) Buyer’s right to indemnification based on representations, warranties, covenants,
and other obligations in the Agreement will not be limited, diminished, or otherwise affected by any
investigation conducted or knowledge obtained by Buyer before or after Closing with respect to the
accuracy or inaccuracy of such representations, warranties, covenants or other obligations.
(f) The Indemnified Party shall give notice to the Party required to provide
indemnification hereunder (the “Indemnifying Party”) promptly after the Indemnified Party has
actual knowledge of any Claim as to which indemnity may be sought hereunder, and the Indemnified
Party shall permit the Indemnifying Party (at the expense of the Indemnifying Party) to assume the
defense of any Claim resulting therefrom; provided that:
(i) counsel for the Indemnifying Party who shall conduct the defense of such
Claim shall be reasonably satisfactory to the Indemnified Party;
(ii) the Indemnified Party may participate in such defense at its own expense,
except the Indemnifying Party shall reimburse the Indemnified Party for its participation in such
defense to the extent that the Indemnifying Party requests the Indemnified Party to participate in its
own defense; and
(iii) the omission by the Indemnified Party to give notice as provided herein shall
not relieve the Indemnifying Party of its indemnification obligations hereunder except to the extent
that such omission results in a failure of actual notice to the Indemnifying Party and the Indemnifying
Party is damaged as a result of such failure to give notice.
Notwithstanding the foregoing, the Indemnifying Party may not settle any Claim or Liability related
to the indemnity being provided hereunder without the consent of the Indemnified Party, such
consent not to be unreasonably withheld or delayed.
(g) With regard to any Claim or Liability which is the result of the joint or concurrent
fault or negligence of Developer and Buyer or either Party and the Project Company, as the case may
be, the Parties agree to jointly defend any Claim or Liability with respect thereto that is based on such
joint or concurrent fault or negligence of Buyer and Developer or either Party and the Project
Company, as the case may be. Any Liability or Claim of contribution or indemnification between
Buyer and Developer relating to such Liabilities Claims shall be resolved on the basis of the
percentage of fault or negligence and the Parties agree to reserve the determination of such
percentage until after resolution of such Claim or Liability. Such pro rata share shall be based upon
a final judicial determination of the Parties’ comparative fault or negligence or, in the absence of such
determination, by mutual agreement of the Parties.
(h) Nothing in this 22.1 is intended to allow any Indemnified Party to be indemnified
from and against any third party Claims and Liabilities caused by, arising out of, or in connection with
the performance of this Agreement or any other Transaction Document to the extent any of such
Claims or Liabilities were caused by, arose out of, or were in any way incidental to or in connection
with its own breach of any representation, warranty, or obligation under this Agreement or any other
Transaction Document to which it is a party or its negligence, gross negligence or willful misconduct.
(i) For the purposes of determining whether an Indemnified Party has the right to
indemnification under 22.1 and for the purposes of determining the amount of Claims or Liabilities
under 22.1, the representations and warranties contained in this Agreement that are qualified by
reference to “material,” “materially,” “Material Adverse Change,” or any similar term shall be deemed
to have been made without giving effect to such materiality qualifiers and such certificates shall be
deemed to have been delivered without any “material” qualification.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 265 of 1056
(j) The amount of any indemnity payment made under this 22.1 shall be reduced by the
amount of any indemnity or other payment received by the Indemnified Party from any counterparty
to a Project Company Contract in respect of the event giving rise to the right of indemnity under this
22.1.
22.2
(a) Developer shall promptly pay or cause to be paid when due all obligations for labor
and material in connection with the Work. Developer shall discharge at once, or bond with a bonding
company or surety acceptable to Buyer or otherwise secure against all Liens and attachments which
are filed in connection with the Work.
(b) Developer shall keep the Work and the Site free and clear of and shall promptly
release or cause the release of all Liens and Claims, including recorded notices, Claims for
nonpayment and , arising from the performance of any Work covered by this Agreement
or any other Transaction Document by the Developer Parties and all laborers, materialmen,
mechanics, and other such persons. Developer shall have the right to contest any such Lien or Claim;
provided, that Developer first provide to Buyer financial assurances in amount, form, and substance
satisfactory to Buyer and otherwise complies with applicable Law with respect to removal of such
Lien or Claim.
(c) Developer shall indemnify, defend, and hold harmless all Buyer Indemnified Parties
from, for, and against (i) all laborers’, material men’s, and mechanics’ Liens, or Claims made or filed
upon the Work or the Site on account of any labor performed or labor, services, equipment, and
materials furnished by the Developer Parties and all laborers, materialmen, mechanics, and other
persons in connection with the Work and (ii) any defect in title upon any of Work, including the
Equipment, Materials, and the Project, supplied pursuant to this Agreement.
(d) If any Lien or Claim arising out of this Agreement or any other Transaction Document
is filed before or after Work is completed, Developer, within ten (10) days after receiving from Buyer
written notice of such Lien or Claim, shall obtain release or provide financial assurance satisfactory
to Buyer to protect Buyer from or otherwise satisfy such Lien or Claim. If Developer fails to do so,
Buyer may take such steps and make such expenditures as in its discretion it deems advisable to
obtain release of or otherwise satisfy any such Lien or Claim, and Developer shall upon demand
reimburse Buyer for all costs incurred and expenditures made by Buyer in obtaining such release or
satisfaction including administrative costs, attorneys’ fees and other expenses or Buyer shall have
the right to deduct the amount of such costs from the amount payable to Developer.
(e) Developer’s obligation to indemnify, defend, and hold harmless Buyer Indemnified
Parties from Liens and Claims shall not in any way be rendered unenforceable, or altered, amended,
eliminated, or otherwise conditioned by any applicable Laws related to processing such Liens or
Claims. Buyer shall have no obligation to deliver a copy of any notice of Claim or right to a Lien to
Developer or any other person or entity.
(f) Developer shall at its own expense defend any suit or proceeding based on any Claim
for which Developer is responsible under this 22.3. Buyer shall give Developer such assistance as
Developer may reasonably require in the defense of such Claim, and Buyer shall have the right to be
represented therein by counsel of its own choosing at its own expense. If Developer fails to defend
diligently any such Claim, Buyer may, in its reasonable discretion, either defend or settle the Claim
without the consent of Developer and without relieving Developer of the obligation to indemnify as
provided herein. In such a case Developer’s obligation to defend shall include reimbursement of
Buyer’s reasonable legal fees and related costs incurred in defending or settling the Claim.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 266 of 1056
22.3 .
In case any part of the Work or the ownership or operation of the Project is held to infringe
or violate any patent, copyright, or other intellectual property right of a third party, and the use of
the Work, or the operation of the Project is restricted or prohibited as a result thereof, Developer
shall, at its sole cost and expense, at Developer’s option, either (i) procure for Buyer the right to
continue using the Work, (ii) replace the same with non-infringing comparable substitute Work, or
(iii) modify the Work so that it becomes non-infringing; provided, that such modification does not
adversely affect the Work.
22.4
The Parties’ obligation to indemnify one another consistent with the provisions of this
ARTICLE 22 shall continue after the Closing Date as follows (collectively, the “Indemnity Period”):
(a) Developer Indemnity of Buyer Indemnified Parties.
(i) Except as set forth in 22.4(ii)-(iii) below, Developer’s obligation to indemnify
Buyer Indemnified Parties pursuant to 22.1(a)(i) and 22.1(a)(iv) shall survive for two (2) years
following the Closing Date.
(ii) Developer’s obligation to indemnify Buyer Indemnified Parties pursuant to
22.1(a)(i) for a breach of Developer’s Fundamental Representation and a breach of the
representations and warranties set forth in 4.6, 4.17, 4.18 and ARTICLE 17, and pursuant to
22.1(a)(iii), 22.1(a)(v), 22.1(a)(vi) and 22.1(a)(vii), in each case, shall survive indefinitely.
(iii) Developer’s obligation to indemnify Buyer Indemnified Parties pursuant to
22.1(a)(i) for a breach of the representations and warranties set forth in 4.14 shall survive for a
period of five (5) years following the Closing Date.
(iv) Developer’s obligation to indemnify Buyer Indemnified Parties pursuant to
22.1(a)(ii) shall survive until such covenants are fully performed.
(b) Buyer Indemnity of Developer.
(i) Buyer’s obligation to indemnify Developer Indemnified Parties pursuant to
22.1(a)(i) for a breach of Buyer’s Fundamental Representation or pursuant to 22.1(a)(iv), shall
survive indefinitely.
(ii) For all other Claims and Liabilities, Buyer’s obligation to indemnify Developer
Indemnified Parties pursuant to 22.1(a) shall survive for twenty-four (24) months following the
Closing Date.
22.5
All indemnity payments under ARTICLE 17 or this ARTICLE 22 will be treated as a non-
taxable adjustment of the Purchase Price, unless otherwise required by applicable Laws (as
reasonably determined by Buyer), in which case the payment will be paid on an After-Tax Basis.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 267 of 1056
INSURANCE
23.1
Developer shall maintain, shall cause the Project Company to maintain, and shall require and
cause Contractor and all Major Subcontractors, while performing work on the Site, to provide, pay
for, and continuously maintain in full force and effect insurance coverage in accordance with the
requirements of Appendix L-1.
23.2
Buyer shall during the term of this Agreement maintain in full force and effect insurance
coverage in accordance with the requirements of Appendix L-2.
23.3 Buyer.
Developer agrees to provide such assistance and documentation as Buyer may request in
connection with Claims Buyer may make under its insurance policies purchased in connection with
the Project for damage or events that occur after the Execution Date and prior to the expiration of
the applicable Warranty Period.
24.1
With the exceptions of Developer’s obligation to completely fund all Construction Costs and
Interconnection Costs and all of Developer’s payment and indemnity obligations hereunder, neither
Party shall be in default or in breach of its obligations under this Agreement or otherwise be liable to
the other Party for any delay or failure in the performance of any of its obligations under this
Agreement if and to the extent such delay or failure is a result of Force Majeure. The protections
afforded under this 24.1 to a Party shall be of no greater scope and no longer duration, than is
required by the Force Majeure. Notwithstanding anything to the contrary contained in this 24.1, no
Force Majeure shall relieve, suspend, or otherwise excuse any Party from performing any obligation
to make any payment owed to another Party or to indemnify, defend, or hold harmless another Party
pursuant to this Agreement. In no event may Developer claim a Force Majeure for economic reasons
or for changes in Developer’s costs or the costs of Contractor or Subcontractors, including commodity
price changes, disruption in supply chain, changes in labor markets, increased cost of labor or
transportation, or due to changes in scope due to changes in engineering, design, or applied
engineering not requested by Buyer. The Parties agree that no delay caused by any Force Majeure
will result in a change to the Purchase Price.
24.2
If either Party considers that any event of Force Majeure has occurred which may affect
performance of its obligations under this Agreement, it shall promptly notify the other Party thereof
stating the full particulars, including the obligations that are affected thereby, the estimated period
during which performance may be delayed or prevented, and the particulars of the program to be
implemented to resume normal performance hereunder. If a “Force Majeure” event under any of the
Project Company Contracts occurs with respect to or is claimed by Contractor or any Major
Subcontractor, then Developer shall promptly provide notice thereof to Buyer describing: (i) the
obligations of Contractor or Major Subcontractor that are affected; (ii) the estimated period during
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 268 of 1056
which performance may be delayed or prevented; and (iii) the particulars of the program to be
implemented by Contractor or Major Subcontractor in order to resume normal performance
thereunder; provided, that in no event shall Developer be relieved of any of its obligations under this
Agreement as a result of Contractor or any Major Subcontractor’s claimed “Force Majeure” event
under the applicable Project Company Contract unless such “Force Majeure” under the applicable
Project Company Contract independently qualifies as an event of Force Majeure under this
Agreement.
24.3
Upon the occurrence of any event of Force Majeure, the affected Party shall use reasonable
efforts to mitigate the effects of Force Majeure, resume normal performance of this Agreement within
the shortest time practicable and continue to perform its obligations under this Agreement insofar
as they are not affected by the Force Majeure.
24.4
If an event of Force Majeure continues for a period of one hundred twenty (120) days in the
aggregate that materially affects the ability of Developer to perform the Work, and as a result thereof
there is a corresponding delay in the schedule for performance of the Work and the Guaranteed
Substantial Completion Date of at least one hundred twenty (120) days, then, notwithstanding that
Developer may by reason thereof have been granted an extension of the schedule for performance of
the Work and the Outside Closing Date, by Change Order, Buyer shall be entitled to terminate this
Agreement upon thirty (30) days advance written notice to Developer. If at the expiration of such
thirty (30)-day period such Force Majeure shall still continue, this Agreement shall automatically
terminate without any further action on the part of either Party and the provisions of 26.1shall apply.
24.5
Prior to termination of this Agreement, nothing in this ARTICLE 24 shall change the allocation
to Developer of the risk of loss or damage prior to the Substantial Completion Date and any Change
Order resulting from a Force Majeure shall take into account such allocation of the risk of loss or
damage.
DEFAULT
25.1
Developer shall be in default (a “Developer Default”) hereunder if:
(a) Developer fails to pay Buyer any undisputed amount due Buyer under this
Agreement, and such failure continues for fifteen (15) Business Days after Developer receives notice
thereof from Buyer;
(b) Developer fails to pay Contractor any undisputed amount due Contractor under the
EPC Contract and such failure continues for fifteen (15) Business Days after Developer receives
notice thereof from Buyer;
(c) Developer fails to deliver and maintain Credit Support as required by ARTICLE 6, and
such failure continues for seven (7) Business Days after Developer receives notice thereof from
Buyer;
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 269 of 1056
(d) Contractor fails to deliver and maintain Credit Support as required by the EPC
Contract and such failure continues for five (5) Business Days after Developer receives notice thereof
from Buyer;
(e) Developer accrues Delay Liquidated Damages in excess of the Delay Liquidated
Damages Cap;
(f) Developer accrues Performance Liquidated Damages in excess of the Performance
Liquidated Damages Cap;
(g) Developer fails in any material respect to comply with any of its other material
obligations under this Agreement (not otherwise described in this 25.1) and such failure continues
for thirty (30) days after Developer receives notice thereof from Buyer; provided, however, that such
period of thirty (30) days shall be extended for a period not to exceed an additional thirty (30) days
if: (i) such breach is reasonably capable of cure and curing such breach reasonably requires more
than thirty (30) days; (ii) Developer commences such cure as soon as reasonably practicable after
Developer receives notice thereof; and (iii) Developer continuously and diligently pursues such cure;
(h) Developer shall (i) commence a voluntary case under the Bankruptcy Code; (ii) file a
petition seeking to take advantage of any other Laws, domestic or foreign, relating to bankruptcy,
insolvency, reorganization, winding up, or composition or adjustment of debts (collectively,
“Bankruptcy Laws”); (iii) consent to or fail to contest in a timely and appropriate manner any petition
filed against it in an insolvency case under Bankruptcy Laws; (iv) apply for, or consent to or fail to
contest in a timely and appropriate manner, the appointment of, or the taking of possession by, a
receiver, custodian, trustee, liquidator, or the like of itself or of a substantial part of its assets; (v)
admit in writing its inability to pay, or generally not be paying, its debts (other than those that are
the subject of bona fide disputes) as they become due; (vi) make a general assignment for the benefit
of creditors; (vii) take any action for the purpose of effecting any of the foregoing; or (viii) have a case
or other proceeding commenced by a third party against it seeking (A) relief under the Bankruptcy
Code or under any other Bankruptcy Laws or (B) the appointment of a trustee, receiver, custodian,
liquidator, or the like of such Developer Party of all or any substantial part of its assets, and such case
or proceeding shall continue undismissed or unstayed for a period of sixty (60) days;
(i) any representation or warranty made by Developer for which an express remedy is
not provided shall prove to have been false in any material respect as of the date made or deemed
made; provided, however, that if the circumstances which make such representation or warranty
false are subject to cure or remedy by Developer within a period of thirty (30) Business Days and
Developer is diligently pursuing such cure or remedy, then such representation or warranty being
false in any material respect shall not become a Developer Default until thirty (30) Business Days
after Developer receives notice thereof from Buyer (unless such representation and warranty is no
longer false in any material respect prior thereto); or
(j) Developer makes a Material Update to the disclosure schedules which has not been
cured within thirty (30) days following receipt of written notice of such Material Update.
25.2
Buyer shall be in default (a “Buyer Default”) hereunder if:
(a) Buyer fails to pay Developer any undisputed amount due Developer under this
Agreement, and such failure continues for fifteen (15) Business Days after Buyer receives notice
thereof from Developer;
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 270 of 1056
(b) Buyer fails in any material respect to comply with any of its other material obligations
under this Agreement (not otherwise described in this 25.2); provided, however, that if such failure
can be cured or remedied by Buyer within a period of thirty (30) Business Days and Buyer is
diligently pursuing such cure or remedy, then such failure shall not become a Buyer Default until
thirty (30) Business Days after Buyer receives notice thereof from Developer (unless such failure is
cured or remedied prior thereto);
(c) Buyer shall (i) commence a voluntary case under the Bankruptcy Code; (ii) file a
petition seeking to take advantage of any Bankruptcy Laws; (iii) consent to or fail to contest in a
timely and appropriate manner any petition filed against it in an insolvency case under the
Bankruptcy Laws; (iv) apply for, or consent to or fail to contest in a timely and appropriate manner,
the appointment of, or the taking of possession by, a receiver, custodian, trustee, liquidator, or the
like of itself or of a substantial part of its assets; (v) admit in writing its inability to pay, or generally
not be paying, its debts (other than those that are the subject of bona fide disputes) as they become
due; (vi) make a general assignment for the benefit of creditors; (vii) take any action for the purpose
of effecting any of the foregoing; or (viii) have a case or other proceeding commenced by a third party
against it seeking (A) relief under the Bankruptcy Code or under any other Bankruptcy Laws or (B)
the appointment of a trustee, receiver, custodian, liquidator or the like of Buyer of all or any
substantial part of its assets, and such case or proceeding shall continue undismissed or unstayed for
a period of sixty (60) days; or
(d) any representation or warranty made by Buyer in this Agreement for which an
express remedy is not provided shall have been false in any material respect as of the date made;
provided, however, that if the circumstances which make such representation or warranty false are
subject to cure or remedy by Buyer within a period of thirty (30) Business Days and Buyer is
diligently pursuing such cure or remedy, then such representation or warranty being false in any
material respect shall not become a Buyer Default until thirty (30) Business Days after Buyer receives
notice thereof from Developer (unless such representation and warranty is no longer false in any
material respect prior thereto).
25.3 .
(a) Cure Rights. During the occurrence and continuance of any Developer Default and
upon receipt of any notice that Developer is in default of any of its obligations under this or any of
the Transaction Documents, and in addition to any other rights Buyer may have hereunder or at law
or in equity, Buyer shall have the right, but not the obligation, to cure any Developer Default under
this or any Transaction Document. If Buyer at any time exercises its right under this 25.3(a),
Developer shall indemnify Buyer from, for, and against any third-party costs incurred to exercise its
right under this 25.3(a).
(b) No Excuse. Notwithstanding the exercise by Buyer of any of its rights under this 25.3,
nothing set forth in this 25.3 shall excuse Developer of its obligations to remedy a Developer Default
and perform its obligations hereunder.
TERMINATION
26.1
(a) Upon the occurrence and continuation of a Developer Default, this Agreement shall
terminate as follows:
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(i) with respect to a Developer Default described in 25.1, upon delivery to
Developer of written notice of termination after the end of the applicable cure period provided for in
25.1, and if no such cure period is provided for in 25.1, then fourteen (14) days after delivery to
Developer of such written notice of termination.
(b) Notwithstanding anything to the contrary in this Agreement, in the event of any
termination by Buyer under this 26.1 or otherwise, Buyer shall be entitled to seek all damages
available at law or in equity with respect to any Claims or Liabilities arising as a result of such
Developer Default, notwithstanding a termination of this Agreement.
26.2
(a) Upon the occurrence and continuation of a Buyer Default, this Agreement shall
terminate as follows:
(i) with respect to a Buyer Default described in 25.2(c), immediately; and
(ii) with respect to a Buyer Default described in 25.2 (other than 25.2(c)), upon
delivery to Developer of written notice of termination after the end of the applicable cure period
provided for in 25.1, and if no such cure period is provided for in 25.1, then fourteen (14) days after
delivery to Developer of such written notice of termination.
Notwithstanding anything to the contrary in this Agreement, in the event of any termination by
Developer under this 26.2 with respect to a Buyer Default set forth in 25.2(a), Developer shall be
entitled to seek all damages available at law or in equity with respect to any Claims or Liabilities
arising as a result of such Buyer Default, notwithstanding a termination of this Agreement. OTHER
THAN AS EXPRESSLY SET FORTH IN THE IMMEDIATELY PRECEDING SENTENCE, THE RIGHTS AND
REMEDIES OF DEVELOPER SET FORTH IN 26.2(a) FOR A BUYER DEFAULT ARE THE EXCLUSIVE
REMEDIES OF DEVELOPER AND NO OTHER REMEDIES OF ANY KIND WHATSOEVER SHALL EXIST
OR APPLY IN THE EVENT OF A BUYER DEFAULT OR TERMINATION OF THIS AGREEMENT BY
DEVELOPER IN ACCORDANCE WITH THIS ARTICLE 26.
Following written notice from either Party to the other Party setting forth a dispute arising
from, relating to or otherwise in connection with or arising out of this Agreement, the Parties shall
use good faith efforts to settle such dispute through negotiation between Buyer’s Representative and
Developer’s Representative. If the dispute is not resolved by such negotiations within fifteen (15)
days after delivery of such initial notice, either Party may, by delivering a subsequent written notice
to the other Party, cause the matter to be referred to a meeting of appropriate senior management
representatives of the Parties with the power and authority to resolve such dispute. Such meeting
shall be held within thirty (30) days following the delivery of the subsequent notice. If the matter is
not resolved within thirty (30) days after the first such meeting of the senior management
representatives or such later date as may be mutually agreed upon by the Parties, either Party may
then, subject to the terms of this Agreement, commence legal action in a court of competent
jurisdiction in order to resolve the dispute.
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ASSIGNMENT
28.1
(a) Developer shall not sell, transfer, or otherwise assign (directly or indirectly, through
merger, Change of Control, or otherwise), in whole or part, this Agreement without the prior written
consent of Buyer; provided, however, that Buyer’s consent shall not be required for (i) a collateral
assignment of the Agreement to any Lender for the purpose of construction financing of the Project;
or (ii) to an Affiliate that is wholly-owned by the ultimate parent of Developer; provided, that such
assignment to an Affiliate shall only be allowed if (A) such Affiliate remains an Affiliate of Developer
(B) the Credit Support provided by Developer or, if applicable, Project Company remains in place and
covers such Affiliate’s obligations, (C) such Affiliate shall execute an assumption agreement assuming
all of Developer’s obligations under this Agreement, (D) such Affiliate is (or has contracted with) a
Qualified Operator, and (E) such Affiliate (or its parent company) has experience in project
development and construction management of similar projects of a similar size.
(b) A Change of Control with respect to Developer’s Parent shall be considered an
assignment of this Agreement to a third party and shall be subject to 28.1(a).
(c) In the event Developer desires to make an assignment pursuant to 28.1(a)(i), above,
Buyer agrees to use commercially reasonable efforts to cooperate with Developer’s pursuit of
construction financing, including by providing such customary certificates, opinions, and consents as
lenders may reasonably require in connection therewith, provided that any such consents shall be in
the form attached to this Agreement as Exhibit I unless Buyer agrees to any deviations thereto, and
provided further that Developer shall reimburse Buyer for its out-of-pocket costs and expenses
(including reasonable attorney’s fees and expenses) in regards to such certificates, opinions, and
consents.
28.2 Buyer
Buyer shall not sell, transfer, or otherwise assign (directly or indirectly, through merger,
Change of Control, or otherwise), in whole or part, this Agreement without the prior written consent
of Developer; provided, however, that Developer’s consent shall not be required for Buyer’s
assignment of the Agreement to an Affiliate or successor-in-interest that is equally creditworthy (or
better) to Buyer and which assignee executes an assumption agreement assuming all of Buyer’s
obligations under this Agreement.
CONFIDENTIALITY
29.1 Confidentiality
(a) Information may be exchanged between Buyer and Developer that is CEII or the
disclosing Party considers proprietary and confidential. Each Party agrees that it shall and shall
cause its Affiliates and its and their respective officers, directors, consultants, employees, legal
counsel, agents, and representatives (together with the Affiliates, the “Confidentiality Affiliates”) to:
(i) hold confidential and not disclose (other than to its Confidentiality Affiliates having a reasonable
need to know in connection with the permitted purposes hereunder), without the prior consent of
the other Party, all CEII, known confidential or proprietary written or oral information or data
(including sources of equity or other financing, development strategy, competitor information, cost
and pricing data, warranties, technical information, research, developmental, engineering,
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manufacturing, marketing, sales, financial, operating, performance, business and process
information or data, knowhow and computer programming and other software techniques) provided
or developed by the other Party or its Confidentiality Affiliates in connection herewith or the Work
(“Confidential Information”); and (ii) use such Confidential Information or CEII only for the purposes
of performing its obligations or exercising its rights hereunder. In no event shall any Confidential
Information or CEII be disclosed to any competitor of Developer or Buyer. For Confidential
Information that is not CEII or a trade secret under applicable Law, the foregoing obligations shall
expire three (3) years after the Substantial Completion Date. The obligation to not disclose and hold
CEII as confidential survives indefinitely.
(b) The obligations contained in the preceding paragraph shall not apply, or shall cease
to apply, to Confidential Information if or when, and to the extent that, such Confidential Information
(i) was known to the receiving Party or its Confidentiality Affiliates prior to receipt from the
disclosing Party or its Confidentiality Affiliates; (ii) was, or becomes through no breach of the
receiving Party’s obligations hereunder, known to the public; (iii) becomes known to the receiving
Party or its Confidentiality Affiliates from other sources under circumstances not involving any
breach of any confidentiality obligation between such source and the disclosing Party’s or disclosing
Party’s Confidentiality Affiliates or a third party; (iv) is independently developed by the receiving
Party or its Confidentiality Affiliates; (v) is required to be publicly disclosed by applicable Law or
Governmental Authority or applicable legal process (this does not include disclosures that are made
under a protective agreement or similar instrument); or (vi) relates to the tax treatment or tax
structure of any transaction contemplated by this Agreement (the “Transaction”). The Parties (and
any employee, representative, or agent of any party) may disclose to any and all persons, without
limitation of any kind, the tax treatment and tax structure of the Transaction and all other materials
of any kind (including opinions or other tax analyses) that are provided to any party hereto to the
extent relating to such tax treatment and tax structure, it being understood that this ARTICLE 29 is
intended to prevent the Transaction from being treated as a “reportable transaction” as a result of it
being a transaction offered to a taxpayer under conditions of confidentiality within the meaning of
Sections 6011, 6111 and 6112 of the Code (or any successor provision) and the Treasury Regulations
thereunder (as clarified by Notice 2004-80 and Notice 2005-22) and shall be construed in a manner
consistent with such purpose. Developer acknowledges that Buyer is subject to regulation as a public
utility, and as such may be required to disclose all or substantially all information provided by
Developer pursuant to this Agreement, including the terms of this Agreement and any Transaction
Document, by order of state and federal Governmental Authorities, and that such disclosure shall in
no event be deemed a violation of this ARTICLE 29.
(c) When required by a Governmental Authority, a Party may disclose the Confidential
Information (but not CEII) of the other Party to such Governmental Authority; provided, however,
that prior to making any such disclosure, such Party shall (unless prohibited from doing so by
applicable Law or the Governmental Authority): (i) provide the other Party with timely advance
notice of the Confidential Information requested by such Governmental Authority and the intent of
such Party to so disclose; (ii) minimize to the extent possible (consistent with applicable Law and the
requirements of the Governmental Authority involved) the amount of Confidential Information to be
provided to the Governmental Authority involved; and (iii) make every reasonable effort (which shall
include participation by the other Party in discussions with the Governmental Authority involved) to
secure confidential treatment and to minimize the Confidential Information to be provided. In the
event that efforts to secure confidential treatment are unsuccessful, the other Party shall have the
prior right to revise such information to minimize the disclosure of such Confidential Information in
a manner consistent with applicable Laws and the requirements of the Governmental Authority
involved
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(d) Notwithstanding anything to the contrary contained herein, Buyer may disclose
Confidential Information upon reasonable notice to Developer if Buyer reasonably determines, based
upon its status as a regulated public utility, that disclosure to a Governmental Authority is necessary
or appropriate in connection with any submission or application to, or response from, any such
authorities regarding this Agreement, the effect thereof on Buyer’s rates or investment return or
similar matters; provided, that Buyer shall (i) use commercially reasonable efforts to keep Developer
informed with respect to such disclosures, (ii) file a written request in the form of a motion for
protective order or for confidential treatment or other comparable written request that any
Confidential Information be afforded confidential treatment and otherwise endeavor to obtain
confidential treatment of Confidential Information, and (iii) notify Developer promptly if it receives
notice of any challenge to the request that such Confidential Information be afforded confidential
treatment.
(e) Buyer’s disclosure of drawings and manuals received from Developer Parties to third
parties in accordance with Buyer’s rights and obligations hereunder shall not be a breach of this
ARTICLE 29.
30.1 ,
Contact information for notices, requests, demands and other communications required or
permitted hereunder is as follows:
(a) if to Developer, to:
[_______]
or to such other person(s) or address(es) as Developer shall provide to Buyer from time to time in
accordance with this 30.1;
(b) if to Buyer, to:
[_______]
and:
[_______]
:
or to such other person(s) or address(es) as Buyer shall provide to Developer from time to time in
accordance with this 30.1.
(c) All notices (including acceptances, consents, approvals, agreements, deliveries of
information, designations), requests, demands, and other communications required or permitted
hereunder shall be in writing, properly addressed as provided in paragraphs (a) and (b) above, and
given by (i) hand delivery, (ii) a national overnight courier service, (iii) confirmed e-mail
transmission, followed by a hard copy, or (iv) certified or registered mail, return receipt requested,
and postage prepaid. Any such notice, request, demand, or other communication shall be deemed to
have been duly given as of the date delivered if by hand delivery, national overnight courier service,
or confirmed e-mail transmission (provided a hard copy promptly follows by other means provided
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herein). Any notice shall be deemed delivered five (5) days after mailing if by certified or registered
mail.
30.2
This Agreement, together with the Appendices, Schedules, and Exhibits attached hereto,
contains the entire agreement and understanding of the Parties with respect to the subject matter
hereof and supersedes all prior agreements and understandings, whether written or oral, of the
Parties relating to the subject matter hereof. Any oral or written representation, warranty, course of
dealing, or trade usage not contained or referenced herein shall not be binding on either Party.
30.3
No amendment or other modification of any provision of this Agreement shall be valid or
binding unless it is signed by each of the Parties. No waiver of any provision of this Agreement shall
be valid or binding unless it signed by the Party waiving compliance with such provision. No delay
on the part of either Party in exercising any right, power, or privilege hereunder shall operate as a
waiver thereof, nor shall any waiver or any partial exercise of any such right, power, or privilege
preclude any further exercise thereof or the exercise of any other such right, power, or privilege. No
waiver of any breach, term, or condition of this Agreement by any Party shall constitute a subsequent
waiver of the same or any other breach, term, or condition of this Agreement.
30.4
Each and all of the rights, obligations, covenants, terms, provisions, and agreements herein
contained shall be binding upon and inure to the benefit of the Parties hereto and, to the extent
permitted by this Agreement, their respective successors and assigns.
30.5
The provisions of this Agreement shall only be for the benefit of, and enforceable by, the
Parties hereto and shall not inure to the benefit of or be enforceable by any third party.
30.6 Severability.
In the event any one or more of the provisions contained in this Agreement should be held
invalid, illegal, or unenforceable in any respect, the validity, legality, and enforceability of the
remaining provisions contained herein shall not in any way be affected or impaired thereby.
30.7
Each Party shall execute and deliver or cause to be executed and delivered such documents
and instruments not otherwise specified herein, and take or cause to be taken all such other actions,
as the other Party may reasonably request to more fully and effectively carry out the intent and
purposes of this Agreement.
30.8 Publicity.
Except as required by applicable Law, the Parties agree that neither Party will issue or release
for external publication any press release, article, advertising, or other publicity matter in any form
(including print, electronic, or interview) relating to the Project, or to this Agreement without first
consulting with and obtaining the prior written consent of the other Party, which consent shall not
be unreasonably withheld or delayed; provided, however, that a press release or other public
announcement, regulatory filing, statement, or comment made without such consent shall not be in
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violation of this 30.8 if it is made in order for the disclosing Party or any of its Affiliates to comply
with applicable Laws or applicable stock exchange rules and in the reasonable judgment of the Party
making such release or announcement, and prior review and joint approval by the Parties, despite
reasonable efforts to obtain the same, would prevent dissemination of such release or announcement
in a sufficiently timely fashion to comply with such applicable Laws or rules.
30.9
Developer is an independent contractor with respect to the Work, and each part thereof, and
in respect of all work to be performed hereunder. Neither Developer nor any of the other Developer
Parties shall be deemed to be agents, representatives, joint ventures, employees, or servants of Buyer
by reason of their performance hereunder or in any manner dealt with herein. Neither Party shall
perform any act or make any representation to any Person to the effect that Developer or any other
Developer Parties is the agent of Buyer.
30.10
Developer hereby acknowledges that (i) Buyer is acting solely in its capacity as a local
distribution company, (ii) the activities of Buyer or its Affiliates as Transmission Provider are outside
the scope of this Agreement, and (iii) neither Buyer nor its Affiliates shall not have any liabilities or
obligations hereunder arising out of any actions or inactions of Buyer or its Affiliates acting in its role
as Transmission Provider.
30.11 Survival.
The provisions of ARTICLE 20 () ARTICLE 21 (
LIABILITY), ARTICLE 22 (INDEMNIFICATION), ARTICLE 27 (), ARTICLE 29
(CONFIDENTIALITY), 8.19 (), and 30.12 (.)
of this Agreement shall survive the expiration or earlier termination of this Agreement indefinitely;
provided, that the foregoing enumeration shall not be interpreted to bar survival of any other
provision hereof which by its express terms or by operation of Law would otherwise be deemed to
survive.
30.12
(a) THIS AGREEMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE
WITH THE LAWS OF THE STATE OF IDAHO (WITHOUT GIVING EFFECT TO THE PRINCIPLES
THEREOF RELATING TO CONFLICTS OF LAW).
(B) EACH OF THE PARTIES HERETO HEREBY IRREVOCABLY CONSENTS AND AGREES
THAT ANY LEGAL ACTION OR PROCEEDINGS WITH RESPECT TO THIS AGREEMENT SHALL BE
BROUGHT EXCLUSIVELY IN ANY OF THE COURTS OF THE UNITED STATES OF AMERICA LOCATED
IN THE UNITED STATES DISTRICT COURT FOR THE DISTRICT OF IDAHO, HAVING SUBJECT MATTER
JURISDICTION, OR IF SUCH COURT LACKS SUBJECT MATTER JURISDICTION, THEN THE STATE
COURT IN ADA COUNTY, IDAHO.
(c) EACH PARTY HEREBY IRREVOCABLY WAIVES ALL RIGHT OF TRIAL BY JURY IN ANY
ACTION, PROCEEDING OR COUNTERCLAIM ARISING OUT OF OR IN CONNECTION WITH THIS
AGREEMENT OR ANY OTHER TRANSACTION DOCUMENT OR ANY MATTER ARISING HEREUNDER
OR THEREUNDER. EACH PARTY HEREBY WAIVES ANY RIGHT TO CONSOLIDATE ANY ACTION,
PROCEEDING OR COUNTERCLAIM ARISING OUT OF OR IN CONNECTION WITH THIS AGREEMENT
OR ANY OTHER TRANSACTION DOCUMENT OR ANY MATTER ARISING HEREUNDER OR
THEREUNDER IN WHICH A JURY TRIAL HAS NOT OR CANNOT BE WAIVED.
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30.13 Counterparts.
This Agreement may be executed by the Parties in two or more separate counterparts
(including by PDF transmission), each of which shall be deemed an original, and all of said
counterparts taken together shall be deemed to constitute one and the same instrument.
30.14 Captions.
The captions for Articles and Sections contained in this Agreement, including the Appendices,
Schedules and Exhibits attached hereto, are for convenience and reference only and in no way define,
describe, extend or limit the scope or intent of this Agreement or the intent of any provision
contained herein.
30.15 Offset.
Notwithstanding any other provision of this Agreement to the contrary, any and all amounts
owing and payable by Buyer or Developer to the other hereunder for the Work, shall be subject to
offset and reduction in an amount equal to any amounts that may be owing at any time. Further, for
the avoidance of doubt, with respect to any provision of this Agreement that allows Buyer to offset,
setoff or draw against a bond or other credit support any amount then owed to Developer, Buyer
shall have the express right to include in the amount offset, set-off or drawn under a bond or other
credit support all of the reasonable costs and expenses it incurs in connection with enforcing such
provision (including attorneys’ and other consultants’ fees).
30.16 .
Time is of the essence in the performance of the Work by Developer hereunder.
30.17 Non-
Except as otherwise provided in the Transaction Documents, duties and obligations imposed
by the Transaction Documents and rights and remedies available thereunder shall be in addition to
and not a limitation of duties, obligations, rights and remedies otherwise imposed or available at law
or in equity.
30.18 Recitals.
The Recitals in this Agreement are incorporated into this Agreement by reference.
30.19 Supplier .
At all times during the term of this Agreement, Contractor agrees to comply with IPC’s
Supplier Code of Conduct, as revised from time to time, and available at
www.idahopower.com/AboutUs/BusinessToBusiness/default.cfm .
30.20 .
Prohibited Technology. Pursuant to Section 889 of the John S. McCain National Defense
Authorization Act for Fiscal Year 2019 and Federal Acquisition Regulation (FAR) 52.204-25
(Aug. 2020), Seller agrees, represents, and warrants that Seller shall not supply or deliver to
IPC any “covered telecommunications equipment or services” as a substantial or essential
component of any system or critical technology of any system. As defined in FAR 52.204-
25(a), “covered telecommunications equipment or services” includes equipment, systems,
products, or services made by any of the following companies, or any subsidiary or affiliate
thereof (including companies with the same principal word in the name, e.g., “Huawei” or
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“Hytera”): Huawei Technologies Company; ZTE Corporation; Hytera Communications
Corporation; Hangzhou Hikvision Digital Technology Company; or Dahua Technology
Company. “Covered telecommunications equipment or services” may include, but are not
limited to, video/monitoring surveillance equipment/services, public switching and
transmission equipment, private switches, cables, local area networks, modems, mobile
phones, wireless devices, landline telephones, laptops, desktop computers, answering
machines, teleprinters, fax machines, and routers. “Covered telecommunications equipment
or services” do not include telecommunications equipment that cannot route or redirect user
data traffic or permit visibility into any user data or packets that the equipment transmits or
handles.
To the extent that the systems, products, or services to be provided by Seller under this
Agreement may be procured by IPC in support of or to satisfy IPC’s obligations under
agreements with a federal governmental entity, Seller further agrees that FAR 52.204-25
(Aug. 2020), except for paragraph (b)(2) thereof, shall be incorporated by reference into this
Agreement and is binding on Seller, and that Seller does not use any equipment, system, or
service that uses covered telecommunications equipment or services and will not supply any
covered telecommunications equipment or services to IPC. Seller further agrees that, if it
identifies covered telecommunications equipment or services used as a substantial or
essential component of any system or as critical technology as part of any system during
contract performance, or Seller is notified of such by a subcontractor at any tier or any other
source, Seller shall immediately notify IPC and reasonably cooperate with IPC’s requests for
information

30.21 .
Within five (5) Business Days after IPUC Submission, Developer shall provide, or cause to be
provided cash collateral or a letter of credit, at the option of Developer, including, without limitation,
Buyer’s applicable credit support requirements, in the amount of $[__] million (“Developer Security”).
Within five (5) Business Days after IPUC Approval and through Final Completion, the amount
of Developer Security that Developer shall be required to provide shall increase to $[Project Cost]
million.
Within five (5) Business Days after Final Completion, through two years after the Final
Completion, the amount of Developer Security that Developer shall be required to provide shall be
decreased to $[__] million.

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Exhibit No. 4
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IN WITNESS WHEREOF, each of the authorized representatives of the Parties have executed
this Agreement as of the first date set forth above.

DEVELOPER: [____________]
By:
Name:
Title:
BUYER:
By:
Name:
Title:

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APPENDICES
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APPENDIX A
Appendix A-1
[See separate attachment]

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APPENDIX B
Appendix B-1
[See separate attachment]

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APPENDIX C
Appendix C-1
[See separate attachment]

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APPENDIX D
Appendix D-1
D-
D-
D-
[See separate attachments]

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APPENDIX E
Appendix E-1
[See separate attachment]

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APPENDIX F
Appendix F-1
[See separate attachment]

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APPENDIX G
Appendix G-1
[See separate attachment]

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APPENDIX H
Appendix H-1
Buyer’s Key Person
Name:
Title:
Phone:
Email:

Developer’s Key Person
Name:
Title:
Phone:
Email:

Contactor’s Key Person ()
Name:
Title:
Phone:
Email:

Major Subcontractor’s Key Person ()
Name:
Title:
Company:
Phone:
Email:

Major Subcontractor’s Key Person
Name:
Title:
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APPENDIX H
Appendix H-2
Company:
Phone:
Email:

Major Subcontractor’s Key Person
Name:
Title:
Company:
Phone:
Email:
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APPENDIX I
Appendix I-1
CLAIMS
[See separate attachments]

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APPENDIX J
Appendix J-1
[See separate attachment]

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APPENDIX K
Appendix K-1
1.0
Electronic copies of each complete and final Progress Report in accordance with the below
requirements and the requirements of Section 11.6 of the Agreement shall be provided in Microsoft
Word, Microsoft Excel, Microsoft Project, and Adobe Acrobat.
Each Progress Report shall satisfy the minimum requirements herein.
(a) Table of Contents – Progress Report
(b) Executive Summary – Current Month
A synopsis and narrative of project status, issues and near future plans addressing specific
aspects of the project shall be included in the Progress Report, including a description of
construction, engineering (by discipline), procurement (issuance of major purchase orders and
subcontracts), shipment/delivery of major items, and expected Milestone Completion Dates.
(c) Personnel Safety
A synopsis of Developer’s safety performance for the preceding month shall be included in
the Progress Report, including numbers and types of injuries and lost time accidents.
(d) Environmental Report
A synopsis of Developer’s environmental compliance for the preceding month shall be
included in the Progress Report, including a description of any deviations and reporting from
applicable regulations, codes, and standards.
(e) Summary of Progress and Status of Project.
Preceding Month – A synopsis of the project progress completed as of the preceding month
shall be included in the Progress Report. The reporting format shall be based on completion of
Critical Milestones and other critical path activities, and construction, engineering (organized by
discipline), procurement (issuance of purchase orders), shipment of materials and equipment to the
Site, status of material and equipment in storage, training, and start-up.
Next Month – The expected progress for the project in the next month shall be included in the
Progress Report in outline form based on engineering, procurement, shipment, construction, and
equipment installation and commissioning.
(f) Organization Chart
A current organization chart for the project, including all subcontractors on Site during the
previous month and expected to be on Site for the next month.
(g) Meeting Status
A summary with minutes of major meetings for the preceding month shall be included as well
as an agenda for next month’s meeting identifying the date, location, expected attendees, and a one
or two-sentence summary of anticipated topics of discussion for the next month and schedule for the
next month meeting date.
(h) Priorities/Issues/Concerns
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 294 of 1056
APPENDIX K
Appendix K-2
Identification and evaluation of critical issues shall be included in the Progress Report. Any
critical issues shall be highlighted in the relevant section of the Progress Report.
(i) Schedule Update
Reporting on important items and events, such as purchases and dates of arrival of major
Equipment components and the completion of Critical Milestones shall be included in the Progress
Report.
The reporting format (hard and electronic copy) shall use Microsoft Project. An updated copy
of the Project Schedule shall be attached to the Progress Report with a written analysis of schedule
status, including forecasted and actual versus planned progress as indicated by the initial base line
Project Schedule (and any updates thereof), with reference to the Critical Milestones and Project
Schedule.
Progress curves measuring actual progress versus planned progress for the total progress as
well as for individual bulk quantities such as cable pulled, terminations, duct bank, concrete poured,
steel erected, structures erected, conductor installed, etc., shall be included in the Progress Report.
(j) Permit Status
A list of Permits and Developer Regulatory Approvals shall be included in the Progress
Report, including current status and the date each Permit and Developer Regulatory Approval is to
be obtained.
(k) Drawings and Procurement Status
The updated engineering drawing list, engineering and procurement schedule, and current
status as compared to overall Project Schedule shall be included in the Progress Report. Depending
upon volume, this may be submitted on a monthly basis as a separate document.
(l) Project Financial Status
The section shall include the billing, forecast, and accrual breakdowns, for the preceding
month, a comparison of the progress payment schedule with the actual progress payments to date,
financial review of the project to date for each line segment and the substations, and updated
commodity curves for the project.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 295 of 1056
APPENDIX L
Appendix L-1
-1
RANCE
Developer shall obtain or cause Project Company or Contractor to obtain all insurance
policies as set forth in Section (C) below. For purposes of this Appendix L-1: Developer Insurance,
insurance requirements shall be met by either Developer, Project Company or its Contractor, as set
forth in Section (C) below. Each such policy shall be set forth in Schedule 4.20.
A.
Prior to the Execution Date, and as may be required pursuant to any Permit or Developer
Regulatory Approval, Developer (or Project Company) will obtain, maintain, and pay for such
insurance as may be required by the Agreement and to effect the provisions of the indemnification
sections herein. The coverage of such policies is set forth below.
B.
Upon request by Buyer, Developer shall (or shall cause the Contractor or the Project Company
to) furnish certificates of insurance to Buyer evidencing that the insurance required below is in force
and effect, whether such policy is that of Developer, Project Company, or Contractor. Upon request
by Buyer, Developer shall (or shall cause the Contractor or the Project Company to) provide new,
replacement certificates, evidencing the procurement of successor policies to the expiration of each
required policy for so long as this Agreement is in effect.
C.
Prior to the Execution Date, and as may be required pursuant to any Permit or Developer
Regulatory Approval, and until Final Completion, Developer, Project Company or Contractor, as the
case may be, shall obtain and maintain in force and effect, at Developer’s sole expense, insurance of
the following types and amounts from insurance companies authorized to engage in the business of
insurance in the state(s) in which Work will be performed, and rated by AM Best’s A – VII (or
equivalent rating from such other nationally recognized insurer rating firm such as S&P, Fitch, or
Moody’s) or better:
(i) WORKERS’ COMPENSATION INSURANCE
(A) Developer (to the extent Developer employs any Person) and
Contractor shall carry Worker’s Compensation Insurance affording statutory benefits in accordance
with all requirements of the applicable worker’s compensation laws in the state(s) in which the Work
will be performed and covering Developer’s and Contractor’s employees.
(B) If the exposure exists and Developer’s and/or Contractor’s
performance of the Work involves work on navigable waters, Developer shall also obtain and
maintain in force insurance complying with the U.S. Longshoreman’s and Harbor Worker’s Act, the
Outer Continental Shelf Act, and covering Jones Act liability.
(ii) EMPLOYER’S LIABILITY INSURANCE
(A) Developer and Contractor shall carry Employer’s Liability Insurance
with limits of not less than [$1,000,000] per accident or disease; [$1,000,000] disease-each
employee; [$1,000,000] disease-policy limit.
(iii) FEDERAL EMPLOYERS LIABILITY ACT (FELA) INSURANCE
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 296 of 1056
APPENDIX L
Appendix L-2
(A) If a railroad exposure exists, any railroad employee contracted by
Developer and/or Contractor to engage in the construction or work on railroads shall be covered
under the Federal Employers Liability Act of 1908 for injuries.
(iv) COMMERCIAL GENERAL LIABILITY INSURANCE
(A) Developer and Contractor shall carry Commercial General Liability
Insurance, including coverage for bodily injury and property damage, personal and advertising
injury, the products-completed operations hazard, insured contracts, and, if applicable, contractual
liability-railroads (CG 24 17) or equivalent, applicable in all states in which the Work is to be
performed, on a form no less broad that that promulgated by the Insurance Services Office dated
2004 or thereafter, and with limits of not less than:
Each Occurrence [$1,000,000]
General Aggregate [$2,000,000]
Products-Completed Operations Aggregate [$2,000,000]
Personal and Advertising Injury [$1,000,000]
(v) BUSINESS AUTOMOBILE LIABILITY INSURANCE
(A) Contractor shall carry Business Automobile Liability Insurance on a
form no less broad than that promulgated by the Insurance Services Office dated 1985 or thereafter,
will limits of not less than [$1,000,000] combined single limit for each accident and covering owned
(if any), hired or leased, and non-owned autos.
(vi) EXCESS OR UMBRELLA LIABILITY INSURANCE
(A) Developer and Contractor shall carry Excess or Umbrella Liability
Insurance applying excess of Employer’s Liability Insurance, Commercial General Liability Insurance,
and Business Automobile Liability Insurance with limits of not less than [$20,000,000] per
occurrence and in the aggregate.
(vii) MARINE LIABILITY INSURANCE
(A) If a marine liability exposure exists, Developer and/or Contractor
shall carry Marine Liability Insurance, including Hull and Machinery Insurance, to include collision
liability coverage with sistership clause un-amended (assuming collision coverage is not provided by
P&I insurance), with limits of liability not less than the full value of all vessels used in performing the
Work, and without navigational limitations impeding performance of the Work. If vessels will engage
in towing operations, such insurance shall include full towers’ liability with sistership clause un-
amended.
(B) If a marine liability exposure exists, Developer and/or Contractor
shall carry Marine Liability Insurance, including Protection and Indemnity (P&I) Insurance
evidenced through an entry with an international P&I Club or, alternatively, coverage under form SP-
23, such coverage to include, in either case, liability coverage for collision, towing, seepage, pollution,
contamination and cleanup, and to include coverage extensions for marine contractual liability,
removal of wreck and debris, with a limit of liability of not less than [$10,000,000] any one accident
or occurrence and in the aggregate.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 297 of 1056
APPENDIX L
Appendix L-3
If P&I coverage is not provided by a P&I Club, Developer and/or Contractor shall also carry vessel
pollution insurance with the Water Quality Insurance Syndicate (WQIS), or its equivalent, to include
coverages for liability under those U.S. statues applicable to pollution from operations in the U.S.
waters, including the Gulf of Mexico, with a limit of liability of not less than [$5,000,000] any one
accident or occurrence and in the aggregate.
(C) If Developer, Project Company and/or Contractor will use non-owned
watercraft under a time charter agreement for the Work, then Developer and/or Contractor, as
applicable, shall also carry Charterer’s Legal Liability Insurance or Comprehensive General Liability
Insurance with non-owned watercraft exclusions deleted, with a limit of liability of not less than
$5,000,000 any one accident or occurrence and in the aggregate.
(VIII) POLLUTION LIABILITY INSURANCE
(A) Contractor shall carry Pollution Liability Insurance in the form of
Contractor’s Pollution Liability (CPL) Insurance for sudden and accidental, and gradual, pollution
conditions, arising directly or indirectly from the Work or from Contractor’s operations with limits
of not less than [$5,000,000] per pollution event or claim and in the aggregate. Contractor’s CPL
Insurance shall provide Developer and Buyer with additional insured status, a waiver of, and notice
of cancellation with thirty (30) days’ written notice (except ten (10) days for non-payment of
premium).
(B) Contractor’s CPL insurance shall remain in full force for not less than
two (2) years after completion of the Work, shall not exclude damage to Buyer’s property, shall not
exclude liability assumed or indemnified for under this Agreement, and shall include coverage for
each of the following:
Completed Operations;
All premises where the Work will be performed, extending to pollution emanating from the premises
to adjacent or other property or waterways;
Bodily Injury (including death), Property Damage and Environmental Cleanup Costs, including for
mold, fungi, legionella, and silt and sedimentation. The coverage must apply to all premises and
extend to pollution emanating from premises;
Natural Resources Damages;
Fines and Penalties to the extent insurable under governing Law;
Transportation (by owned or non-owned vehicles) of any waste, including loading or unloading, from
jobsites to the final disposal location, as well as to any temporary storage location or transshipment
or transfer sites; and
Disposal locations, whether final or temporary, covered as non-owned disposal sites.
(ix) PROFESSIONAL LIABILITY INSURANCE
(A) Developer or Contractor shall carry Professional Liability Insurance
covering tortious errors and omissions in the performance of the Work, and not excluding damage to
Buyer, with limits of not less than [$1,000,000] per claim and in the aggregate.
(x) RAILROAD PROTECTIVE LIABILITY INSURANCE
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 298 of 1056
APPENDIX L
Appendix L-4
(A) If a railroad exposure exists, Developer and/or Contractor shall carry
Railroad Protective Liability Insurance with limits of liability of not less than[ $2,000,000] per claim
and [$6,000,000] in the aggregate or limits as specified by the railroad.
(xi) PROPERTY AND BUILDER’S RISK INSURANCE
(A) Developer shall obtain and maintain in force property insurance
covering the entire Work prior to commencing the Work and until Mechanical Completion. Such
insurance shall be written in the amount at least equal to the initial contract sum as well as
subsequent modifications of that sum (subject to usual and customary policy sublimits for certain
perils / coverages). The insurance shall apply on a replacement cost basis or completed value form
(including foundations and other property below the surface of the ground).
(B) Such insurance shall provide coverage to the same extent generally
available on commercially reasonable terms for similar work, and shall include coverage for loss
during the ordinary course of transit and/or during offsite storage. Buyer, Developer, Contractor and
Subcontractors shall be included as insureds. Any insured loss shall be payable to Buyer and
Developer as their interests may appear.
(C) Such property insurance shall have the following minimum
requirements and other customary coverage in amounts and on terms and conditions as described
below:
Coverage shall be afforded from the point of groundbreaking for the Project and through the
Mechanical Completion Date;
The insurance shall be written to cover all risks of physical loss except those specifically
excluded in the policy and shall insure at a minimum the perils of fire, lightning, flood, earth
movement, windstorm, hurricane, hail, explosion, machinery breakdown, marine cargo (to the extent
exposure exists) inland transit;
Coverage shall be provided for the cost of removing debris including demolition as may be
made legally by the operation of law, ordinance or regulation in an amount that is reasonable and
customary for projects of the type of the Project;
Policy shall include as insured property scaffolding, false work and temporary buildings
located at the site, as applicable;
Off-site storage coverage with a per occurrence limit sufficient to cover off-site storage of
equipment and materials but in an amount not less than [$100,000];
Transit coverage with a per occurrence limit of the full insurable value of any single shipment;
Coverage for operational testing and startup in an amount not less than full replacement
value of the Project for all assets related to the Project with cover running continuously for machinery
breakdown from the beginning of testing until Mechanical Completion; and
Any and all deductibles or self-insured retentions of all insurance policies required
hereunder shall be assumed by, for the account of and at the Developer’s or Contractor’s, as the case
may be, sole risk and expense and shall not be billed to or payable by Buyer or its direct and indirect
subsidiaries and affiliates, including limited liability companies. All such policies may have
deductibles of not greater than [$250,000] per loss except as respects natural catastrophe perils.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 299 of 1056
APPENDIX L
Appendix L-5
(D) Developer or Contractor shall provide property insurance on an ‘all
risk’ form covering all property, tools, equipment and machinery used by Developer or Contractor in
the performance of the Work (whether owned, leased, rented or borrowed) at full replacement cost
value and containing a waiver of subrogation in favor of Buyer; provided, that Contractor may self-
insure with respect to the above requirement regarding tools and equipment. In either case,
insurance or self-insurance, neither Developer nor Contractor may seek recovery from Buyer for
damaged or lost property, tools, equipment or machinery used by Developer or Contract in the
performance of the Work.
The forgoing required insurance is the minimum insurance required by this Agreement.
Developer may, in its sole discretion, procure additional insurance or higher limits of liability at
Developer’s sole expense.
D.
To the extent allowed by law, the Commercial General Liability Insurance, Business
Automobile Liability Insurance, and Excess or Umbrella Insurance, as required above, shall be
endorsed to provide that Buyer, together with its owned or controlled subsidiaries and affiliates, and
their respective directors, officers and employees (collectively, the “Additional Insureds”), are
granted status as additional insureds for liability arising out of the Work, with coverage not limited
to liability caused by Developer or Developer’s fault, and providing coverage for the Additional
Insureds’ fault or vicarious liability no less broad than one or the other of the following alternatives:
(1) the coverage afforded to the named insured under the policy for liability arising out of the Work;
or (2) the coverage afforded by the inclusion of both Insurance Services Office Additional Insured
Endorsements CG 20 33 07 04 and CG 20 37 07 04, or equivalents.
The insurance policies required by Commercial General Liability Insurance and Business
Automobile Liability Insurance, above, shall provide that the Additional Insureds are covered on a
primary basis. Also, the insurance policies required by Commercial General Liability Insurance,
Business Automobile Liability Insurance, and Excess or Umbrella Liability Insurance, above, shall
also be endorsed to provide that coverage for the Additional Insureds does not apply excess of other
insurance coverage available to the Additional Insureds, and that Developer’s insurers will not seek
contribution or recovery from such other insurance as may be available to the Additional Insureds.
E.
Developer shall require Contractor and all Subcontractors who will perform any of the Work
to obtain the same insurance and limits of liability as required by Workers’ Compensation Insurance,
Employer’s Liability Insurance, Commercial General Liability Insurance, and Business Automobile
Liability Insurance above. Developer shall require Contractor and all Major Subcontractors who will
perform any of the Work to obtain the same insurance and limits of liability as required by Excess or
Umbrella Liability Insurance above and all other Subcontractors who will perform any of the Work
to obtain Excess or Umbrella Liability Insurance with limits of not less than [$5,000,000] per
occurrence and in the aggregate; provided, that if any such Subcontractor does not carry Excess or
Umbrella Liability Insurance meeting such requirements but does carry Excess or Umbrella Liability
Insurance meeting generally accepted industry standards for the scope of work to be performed by
such Subcontractor, such Subcontractor’s coverage shall be deemed acceptable. Developer or
Contractor shall also require all such Subcontractors to cause their insurers to waive subrogation to
the same extent as required of Buyer’s insurers by the following provision, Waiver of Subrogation in
Favor of Buyer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 300 of 1056
APPENDIX L
Appendix L-6
F.Buyer.
The Parties intend that none of Developer’s insurers shall subrogate against Buyer, or any of
its owned or controlled subsidiaries or affiliates, or their respective directors, officers or employees.
Accordingly, Developer agrees to cause its insurers to waive subrogation against Buyer and all such
subsidiary or affiliated entities and persons. The foregoing release is effective even if Developer fails
to obtain the required insurance.
G. .
Notice of cancellation shall be provided with thirty (30) days’ written notice except ten (10)
days for non-payment of premium.
H.
Developer shall give written notice to Buyer no later than seven (7) days after the date on
which an impairment of an aggregate limit, due to the payment of a claim or defense expense, reduces
the available aggregate limit to an amount 50% or less than the aggregate limit required above. If
Developer’s excess insurance will not drop down and comply with the insurance requirements, Buyer
may require reinstatement of an impaired aggregate limit up to the amount required.
I. Buyer
If Buyer has questions concerning Developer’s casualty insurance program, Developer agrees
to promptly answer them. Complete, true and correct copies of each policy required above shall be
furnished to Buyer promptly upon Buyer’s request, but Developer may redact payroll, premium, and
other confidential information not related to the Project. Developer agrees to cooperate with Buyer,
and with Buyer’s insurance broker, in the event Buyer elects to seek or obtain additional insurance
benefiting Buyer.
J.
Developer shall comply with and not violate or knowingly permit to be violated any condition
of the insurance policies required above. Developer agrees to give its insurers timely written notice
of all occurrences, accidents or claims arising out of the Work, with copy to Buyer.
K.
Developer, not Buyer, shall be responsible for any and all policy premiums, deductibles, or
self-insured retentions payable in connection with Developer’s insurance, including the insurance
required above.
L. Non-–Buyer
Developer unilaterally agrees to comply with the provisions of this Appendix L-1.
Accordingly, Buyer’s knowledge concerning deficiencies in Developer’s insurance, including non-
compliance with this Appendix shown by any insurance certificate or other information furnished to
Buyer, shall not affect Buyer’s rights and shall not result in a waiver or otherwise limit or impair
Buyer’s remedies for Developer’s failure to comply with the requirements of this Appendix.
Nothing contained in this Appendix shall restrict, limit, impair or waive Buyer’s rights or
Developer’s duties under the other terms of this Agreement or under applicable Law. The
cancellation, expiration, or exhaustion of any of the insurance required shall not preclude Buyer from
recovery against Developer for any liability arising under this Agreement or Law.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 301 of 1056
APPENDIX L
Appendix L-7
M.
All of the foregoing insurance requirements shall survive the termination of this Agreement.
All required insurance shall continue for at least thirty (30) days after final completion of the Work,
to include the performance of all warranty work.
In addition, Developer shall maintain in force and effect any required claims-made coverage
for a minimum of two (2) years after final completion of the Work and shall purchase an extended
reporting period, or “tail coverage”, if necessary to comply with this requirement.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 302 of 1056
APPENDIX L
Appendix L-8
-2
A.
After Closing, Buyer will or will cause the Project Company to obtain, maintain, and pay for
such insurance as may be required by the Agreement and to effect the provisions of the
Indemnification section herein. The coverage of such policies is set forth below.
B.
Upon request by Developer, Buyer shall furnish certificates of insurance to Developer
evidencing that the insurance required below is in force and effect. Upon request by Developer,
Buyer shall provide new, replacement certificates, evidencing the procurement of successor policies
to the expiration of each required policy for so long as this Agreement is in effect.
Buyer warrants the accuracy of all information shown on each certificate furnished to
Developer by Buyer or on Buyer’s behalf by Buyer’s broker or other representative.
C.
After Closing, Buyer shall or shall cause Project Company to obtain and maintain in force and
effect, at Buyer’s sole expense, insurance of the following types and amounts from insurance
companies authorized to engage in the business of insurance in the state(s) in which Work will be
performed, and rated by a Best’s A – VII or better:
(i) COMMERCIAL GENERAL LIABILITY INSURANCE
(A) Buyer shall carry Commercial General Liability Insurance, including
coverage for bodily injury and property damage, personal and advertising injury, the products-
completed operations hazard, insured contracts, and contractual liability-railroads (CG 24 17),
applicable in all states in which the Work is to be performed, on a form no less broad that that
promulgated by the Insurance Services Office dated 2004 or thereafter, and with limits of not less
than:
Each Occurrence [$1,000,000]
General Aggregate [$2,000,000]
Products-Completed Operations Aggregate [$2,000,000]
Personal and Advertising Injury [$1,000,000]
(ii) BUSINESS AUTOMOBILE LIABILITY INSURANCE
(A) Buyer shall carry Business Automobile Liability Insurance on a form
no less broad than that promulgated by the Insurance Services Office dated 1985 or thereafter, will
limits of not less than [$1,000,000] combined single limit for each accident and covering owned, hired
or leased, and non-owned autos.
(iii) EXCESS OR UMBRELLA LIABILITY INSURANCE
(A) Buyer shall carry Excess or Umbrella Liability Insurance applying
excess of Employer’s Liability Insurance, Commercial General Liability Insurance, and Business
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 303 of 1056
APPENDIX L
Appendix L-9
Automobile Liability Insurance with limits of not less than [$10,000,000] per occurrence and in the
aggregate.
(iv) PROPERTY INSURANCE
(A) Buyer shall obtain and maintain in force all-risk property insurance
applying on a full replacement cost basis or completed value form (including foundations and other
property below the surface of the ground). Such insurance policy shall become effective as of
Mechanical Completion.
(B) Such property insurance shall have the following minimum
requirements and other customary coverage in amounts and on terms and conditions as described
below:
The insurance shall be written to cover all risks of physical loss except those specifically
excluded in the policy and shall insure at a minimum the perils of fire, lightning, flood, earth
movement, windstorm, hurricane, hail, explosion, machinery breakdown, marine cargo, inland
transit, and
Coverage shall be provided for the cost of removing debris including demolition as may be
made legally by the operation of law, ordinance or regulation in an amount not less than full
replacement value of the Project.
The forgoing required insurance is the minimum insurance required by this Agreement.
Buyer may, in its sole discretion, procure additional insurance or higher limits of liability at Buyer’s
sole expense.

]]

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 304 of 1056
APPENDIX M
Appendix M-1
[To be attached prior to Closing]

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 305 of 1056
APPENDIX N
Appendix N-1
N-
N-REQUEST
N-
[See separate attachments]

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 306 of 1056
APPENDIX O
Appendix O-1
Testing Frequency and Costs: The Performance Guarantee Tests will be run for the purpose of
achieving Substantial Completion and Final Completion at Developer’s sole cost and expense. In the
event the Performance Guarantee Tests fail to achieve the Guaranteed Rated Energy Capacity or
Guaranteed Power Capacity, Developer shall have the right to re-test and shall have the right to make
adjustments to the Project Equipment to remedy any deficiencies between test attempts. Purchaser
has the right to request additional Performance Guarantee Tests. No material modifications to the
plant will be permitted between Purchaser’s request and the performance of an additional
Performance Guarantee Test, but maintenance can be performed to address issues that have
occurred subsequent to a previous Performance Guarantee Test or are required to ensure equipment
is capable and set-up properly for a Performance Guarantee Test. Purchaser shall be responsible for
all costs incurred by conducting any additional Performance Guarantee Tests unless a Performance
Guarantee Test demonstrates that Developer has failed to achieve any of the Performance
Guarantees, in which case, Developer will be responsible for all costs of such Performance Guarantee
Tests until Developer demonstrates the Project meets the Performance Guarantees. Purchaser shall
be responsible for any costs associated with purchase or supply of power for the purpose of charging
the Project for all Performance Guarantee Tests and Project Commissioning.
Test Records: Developer shall record the results of each Performance Guarantee Test, provide all raw
data, records and results associated with each Performance Guarantee Test, and submit a testing
report detailing all results and findings of each Performance Guarantee Test to Purchaser within
eight (8) Business Days following completion of such Performance Guarantee Test. During the
performance of each Performance Guarantee Test, the Project shall be functioning in a manner to
permit Purchaser to remotely monitor, observe and independently verify the performance of the
Project through the Project’s remote monitoring and control systems.
For the purposes of the Performance Guarantee Tests, the following metering configuration is
assumed. If alternate auxiliary power arrangements are used, the Performance Guarantee Tests
below shall be changed accordingly.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 307 of 1056
APPENDIX O
Appendix O-2
1.
The “” shall mean the guaranteed energy capacity (MWhAC)
delivered over a full continuous discharge of the Project at the Guaranteed Power Capacity (MW)
as set forth in the applicable Subsequent Purchase Order.

The “” shall be defined as:

Energy Capacity =

Where the following terms are defined as:

MVD = Medium Voltage Main Meter reading during discharge cycle (“Gross
Metering” in the metering configuration)

AXD = Auxiliary Meter reading during the discharge cycle (“Aux Metering” in
the metering configuration)

MVC = Medium Voltage Main Meter reading during charge cycle (“Gross
Metering” in the metering configuration)

AXC = Auxiliary Meter reading during the charge cycle (“Aux Metering” in the
metering configuration)

AXM = Maximum auxiliary energy consumed based on nameplate rating of
the auxiliary power transformer(s)

The “” shall mean the guaranteed Power Capacity set forth
in the applicable Subsequent Purchase Order. The “” is defined as the
Energy Capacity divided by the measured time required for discharge of the Guaranteed
Rated Energy Capacity. The metered instantaneous power shall be within +/- 2% of the
guaranteed power for the duration of the guaranteed power capacity test, with infrequent
momentary excursions from this band being acceptable.

Energy Capacity and Power Capacity shall be calculated by the following testing
procedure:
i. Rest 2 hours with cell temperatures at 25-35 °C.
ii. Charge the batteries with 0.25 cp to its cut-off voltage, then charge via
constant current – constant voltage method to full charge. Record the AC
energy for both the Gross Metering (MVC) and the Aux Metering (AXC)
iii. Allow batteries to rest for up to 30 minutes
iv. Discharge the batteries with 0.25 cp to its cut-off voltage to starting SOC
using constant current method. Record the AC energy for both the Gross
Metering (MVD) and the Aux Metering (AXD)
v. Allow batteries to rest for up to 30 minutes
vi. Repeat steps (ii) through (iv) two (2) times in total

The “” is calculated as

={+,+,+}
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 308 of 1056
APPENDIX O
Appendix O-3
2.
The Project availability shall be at least ninety-eight percent (98%) for a period of fifteen (15)
Days of operation (the “”).

“Availability” shall be calculated based upon the following formula:
PH = period hours
PMH = period planned maintenance hours (zero for the Reliability Run
Period)
GPC = Guaranteed Power Capacity
PC = Available power capacity (MW) defined as battery power capability on-
line and available for operation in either charge or discharge
GEC = Guaranteed Rated Energy Capacity
AC = Available energy capacity (MWh) defined as the battery energy storage
capacity online and available for operation in either charge or discharge
PAC = Period unavailable average capability, calculated as the normalized
average of the maximum either energy storage capacity or power available
during the period. A sample is not valid if during planned maintenance or a
no-fault outage.
= 1 ,
PFO = Period at-fault outage hours, defined as hours during which all or a
portion of the available energy or power capacity is unavailable
PNFO = Period of not at fault (excused) outage hours, defined as hours during
which all or a portion of the available energy or power capacity is unavailable
due to no fault of Developer provided equipment

Therefore, Availability is calculated as the following:

= 100 ([])
()
“” shall be calculated in accordance with the
following formula:

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 309 of 1056
APPENDIX O
Appendix O-4
NDTA 15 Days
GA 98%
TA Tested Availability (%) = Maximum availability (%) in a 15 Day continuous period
within the 30 Day window for the Reliability Run
CA Corrective Period Availability (%) = Average availability (%) in the time period
from end of the contractually defined Reliability Run to Day when the GA was met
over a continuous 15 Day period
NDCA Number of Days from end of the Reliability Run to when the GA was met
GPC Guaranteed Power Capacity
3.
Roundtrip Efficiency Test shall be conducted in conjunction with the Capacity Test.
The guaranteed Roundtrip Efficiency is denoted Use Case 1 in Appendix A.
The “” is calculated as
=+,+,+
Where the following terms are defined as:

MVD = Medium Voltage Main Meter reading during discharge cycle

MVC = Medium Voltage Main Meter reading during charge cycle

AXC = Auxiliary Meter reading during charge cycle

AXD = Auxiliary Meter reading during discharge cycle
4.
The Project, not including auxiliary power, must be designed and capable of charging at 100% of
the proposed AC power and energy capacity at the POI.

The charge rate shall be determined as part of the Roundtrip Efficiency Test.

The charge rate shall be defined as the energy capacity divided by the time required to charge the
Guaranteed Rated Energy Capacity.

Charge Rate Guarantee = ()/

Where the following terms are defined as:

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 310 of 1056
APPENDIX O
Appendix O-5
MVC = Medium Voltage Main Meter (“Gross Metering”) reading during
charge cycle
TCH = Total Time to Charge

AXC = Auxiliary Meter (“Aux Metering”) reading during charge cycle

5.
The Project shall be capable of responding to input signals and reaching 98% of full power
charging and discharging within 200 ms. The testing shall correspond with the Response Time
Guarantee. The Response Time Test is conducted concurrent with the Ramp Rate Test.

6.
The Project shall be capable of responding to input signals and responding within 200 ms for the
duration of the Developer Warranty Period.
The response shall be defined as the time required for the Project output to transition from no
discharge to full rated discharge and from no charge to full rated charge when the breakers are
closed and the system is on-line.
The start time shall be when the signal is received at the Project boundary, and the end time shall
be when the measured discharge power reaches 100% ±2% of the rated power when the
breakers are closed and the system is on-line.
7.
The maximum instantaneous auxiliary power consumption of the Project will be lower than the
rating of the auxiliary power transformer. Developer shall guarantee the maximum amount of
auxiliary load to be consumed by the Project, expressed in kW, measured at the auxiliary load
meter.
The auxiliary load test condition, including but not limited to ambient temperature, duty cycle
will be agreed upon by Purchaser and Developer. Correction curves will be allowed with the
concurrence of both Parties.
Auxiliary Load Guarantee = ({,,})

Where the following terms are defined:

AXC = Auxiliary Meter maximum power reading during charge cycle

AXD = Auxiliary Meter maximum power reading during discharge cycle

AXS = Auxiliary Meter maximum power reading during standby

8.
In accordance with Appendix A, the power factor during charge and discharge operation shall be
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 311 of 1056
APPENDIX O
Appendix O-6
controlled to ± 0.95 at the POI, except as may be provided in a Subsequent Purchase Order. The
sizing and design requirements to meet Purchaser power factor requirements and any
modifications to BESS sizing shall be defined in Appendix A.
Details of the testing will depend on Project reactive power constraints and will be determined
as a part of Project design. Testing shall meet MRO MOD-025-02 including:
At the real power rating equal to the real power rating of the Project (i.e. ±0.95
PF at 25 MW for a 25 MW rated site)
Testing of active power under charge and discharge conditions

Testing shall be done with approval of and in coordination with WECC and Buyer.

9.
The noise shall be less than 85 decibels on the A weighted scale at a distance of 1 meter along the
perimeter of the Project. Sound shall be measured at 1.5 meters above the grade elevation.
Exhibit No. 4
Case No. IPC-E-24-16
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Page 312 of 1056
APPENDIX P
Appendix P-1
CRITERIA
[See separate attachment]
Exhibit No. 4
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Page 313 of 1056
APPENDIX Q
Appendix Q-1
[TBD]
Exhibit No. 4
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Page 314 of 1056
EXHIBITS
Exhibit No. 4
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EXHIBIT A
Exhibit A – 1

Battery Energy Storage Project to be located in [___], Idaho

Storage Capacity:[___]
[___]
Interconnection:[___]
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 316 of 1056
EXHIBIT B
Exhibit B – 1
[Reserved]
Exhibit No. 4
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E. Hackett, IPC
Page 317 of 1056
EXHIBIT C
Exhibit C – 4
ASSIGNMENT AGREEMENT
THIS ASSIGNMENT AND ASSUMPTION OF MEMBERSHIP INTEREST (this “Assignment”),
dated as of [__] (the “”), is by and between [___], a [___] (“Assignor”), and Idaho Power
Company., an Idaho public utility company, d (“Assignee”). Assignor and Assignee are sometimes
referred to herein collectively as the “Parties” and each individually as a “Party.” Capitalized terms
used but not defined in this Assignment have the meanings given to them in the BTA (as defined
below).
Recitals
A. Assignor owns all of the interests of [___], a Delaware limited liability company (the
“Company”), including (without limitation) all economic, membership and ownership rights, title
and interests in the Company (collectively, the “Interests”), including, but not limited
to, the right to a share of the profits and losses and capital of the Company, the right to receive
distributions from the Company, the right to inspect the Company’s books and records, and the right
to vote and manage the Company.
B. Assignor has agreed to sell to Assignee, and Assignee has agreed to purchase from
Assignor, all of Assignor’s Membership Interests in the Company, pursuant to that certain Build
Transfer Agreement, dated as of [_____] (the “BTA”).
NOW, THEREFORE, in consideration of the mutual covenants and agreements and other good
and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Assignor
and Assignee do hereby agree as follows:
AGREEMENT
1. Assignment. Assignor hereby sells, conveys, assigns, transfers and delivers to
Assignee, and Assignee hereby purchases, assumes and acquires from Assignor, all of Assignor’s
rights, title and interest in, to and under all of the Membership Interests free and clear of Liens.
2. Effective Time. This Assignment shall be deemed effective for all purposes at
12:01 A.M. Eastern Time on the Transfer Date.
3. Further Assurances. At any time, or from time to time after the date hereof, Assignor
and Assignee shall, at the other’s reasonable request, and at the requesting Party’s expense, execute
and deliver such instruments of transfer, conveyance, assignment and assumption, in addition to this
Assignment, and execute and deliver such other documents and take such other action as either of
them may reasonably request in order to evidence the transfer effected hereby.
4. Amendments. No amendment to the terms and conditions of this Assignment shall
be valid and binding on the Parties unless made in writing and signed by an authorized
representative of each of the Parties.
5. Waiver. No waiver of any provision of this Assignment, or breach hereof, shall be
effective unless it is in writing, signed by the Party waiving such provision.
6. Binding Effect; No Third-Party Beneficiaries. This Assignment shall be binding upon
and inure to the benefit of the Parties and their respective successors and permitted assigns. Nothing
contained herein, express or implied, is intended to confer on any person or entity other than the
Parties or their successors and permitted assigns, any rights, remedies, obligations or liabilities
under or by reason of this Assignment.
Exhibit No. 4
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EXHIBIT C
Exhibit C – 5
7. Governing Law. This Assignment shall be governed by and construed in accordance
with the laws of the State of New York without regard to principles of conflicts of law.
8. Entire Agreement. This Assignment constitutes the entire agreement and
understanding of the Parties with respect to the subject matter of this Assignment, and supersedes
all prior understandings and agreements, whether oral or written, between or among the Parties
hereto with respect to the specific subject matter hereof.
9. Conflict of Terms. This Assignment is delivered pursuant to and is subject to the
terms of the BTA. In the event of any conflict or ambiguity between the terms of the BTA and the
terms of this Assignment, the terms of the BTA shall control.
10. Severability. Each provision of this Assignment is intended to be severable. If any
term or provision is illegal or invalid for any reason whatsoever, such illegality or invalidity shall not
affect the legality or validity of the remainder of this Assignment.
11. Headings. The headings used in this Assignment are for purposes of convenience only
and shall not be used in construing the provisions hereof.
12. Counterparts. This Assignment may be executed in two or more counterparts, each
of which shall be deemed an original, but all of which together shall constitute one and the same
instrument. Delivery of a copy of this Assignment bearing an original signature by electronic mail in
“portable document format” or by any other electronic means intended to preserve the original
graphic appearance of a document, will have the same effect as physical delivery of the paper
document bearing the original signature.
13. Recitals. The Recitals in this Assignment are hereby incorporated into this
Assignment by reference.
, and intending to be legally bound hereby, the Parties have caused
this Assignment to be executed as of the Transfer Date.

ASSIGNOR: [_____]
By:
Name:
Title: _____________________________________________
ASSIGNEE:
By:
Name:
Title:
Exhibit No. 4
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Page 319 of 1056
EXHIBIT D
Exhibit D – 1
[See separate attachment]
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 320 of 1056
EXHIBIT E
Exhibit E – 1
FORM OF
[Date]
Irrevocable Standby Letter of Credit No. [__]
Beneficiary:
Idaho Power Company.
[____________]
[____________]
Attn: [Name]
[Title]
[Phone]
Applicant:
[____________]
[____________]
[____________]
[____________]
Attn: Credit Department
Dear Madam or Sir:
As the issuing bank, we, [Name of Issuing Bank] (“Issuer”), hereby establish for the account
of [______________] (“Applicant”), Issuer’s Irrevocable Standby Letter of Credit No. [______________] (this
“Letter of Credit”) in favor of the above-named beneficiary (“Beneficiary”) for an amount of
[_____________] United States Dollars (US$[______________________]) (the “Available Amount”). Applicant
has advised us that this Letter of Credit is issued in connection with the Build Transfer Agreement,
dated as of [____], between Applicant and Beneficiary (as amended and as may be further amended,
supplemented or otherwise modified). This Letter of Credit shall (i) become effective immediately
for the term of one (1) year and shall expire on [__] (the “Expiration Date”), and (ii) is subject to the
following:
1. Funds under this Letter of Credit shall be made available to Beneficiary against its
draft drawn on Issuer in the form of Annex 1 hereto (“Draw Certificate”), accompanied by the original
of this Letter of Credit and all amendments (if any), or photocopy of the original Letter of Credit for
partial drawings, and presented at Issuer’s office located at [____], attention [___] (or at any other office
which may be designated by Issuer by written notice delivered to Beneficiary). All Draw Certificates
must be signed on behalf of Beneficiary and the signatory must indicate his or her title or other official
capacity. No other documents will be required to be presented. A presentation under this Letter of
Credit may be made only on a day, and during hours, in which such office is open for business (a
“Business Day”). If Issuer receives Beneficiary’s presentation at such office on any Business Day, all
in conformity with the terms and conditions of this Letter of Credit, Issuer will unconditionally honor
the same by making payment in accordance with Beneficiary’s payment instructions on or before the
third (3rd) succeeding Business Day after such presentation. Payment shall be made in U.S. Dollars
with Issuer’s own funds in immediately available funds. Partial and multiple drawing of funds shall
be permitted under this Letter of Credit, and this Letter of Credit shall remain in full force and effect
with respect to any continuing balance; provided that the Available Amount shall be reduced by the
Exhibit No. 4
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EXHIBIT E
Exhibit E – 2
amount of each such drawing. Following any partial draw, Issuer will endorse this Letter of Credit
and return the original to Beneficiary.
2. This Letter of Credit shall terminate upon the earliest to occur of (i) Issuer’s receipt
of a notice in the form of Annex 2 hereto purportedly signed by an authorized officer of Beneficiary,
accompanied by this Letter of Credit and all amendment, if any, for cancellation, (ii) Issuer’s close of
business at Issuer’s aforesaid office on the Expiration Date, or if the Expiration Date is not a Business
Day, then on the preceding Business Day. This Letter of Credit shall be surrendered to Issuer by
Beneficiary upon the earlier of presentation or expiration.
3. It is a condition of this Letter of Credit that it shall be deemed to be automatically
extended without amendment for additional one (1)-year periods, unless at least sixty (60) days
prior to the Expiration Date Issuer sends Beneficiary notice by registered mail, return receipt
requested or courier service or hand delivery at the above address that Issuer hereby elects not to
consider this Letter of Credit extended for such additional period. However, in no even shall this
Letter of Credit be automatically extended beyond [________________] (the “Final Expiration Date”). In
the event of an act of God, riot, civil commotion, insurrection, war or any other cause beyond our
control that interrupts our business and causes the place for presentation of this Letter of Credit to
be closed for business on the last day for presentation, the Final Expiration Date of this Letter of
Credit will be automatically extended without amendment to a date thirty (30) days after the place
for presentation reopens for business.
4. This Letter of Credit shall be governed by, and construed in accordance with, the
terms of the International Standby Practices, ISP 98, International Chamber of Commerce Publication
No. 590 (the “ISP”), to the extent that such terms are not inconsistent with this Letter of Credit. As to
matters not governed by the ISP, this Letter of Credit shall be governed by, and construed in
accordance with, the laws of the State of New York, including, without limitation, the Uniform
Commercial Code as in effect in the State of New York.
5. This Letter of Credit sets forth in full our undertaking, and such undertaking shall not
in any way be modified, amended, amplified or limited by reference to any document, instrument or
agreement referred to herein, except for Annexes 1 and 2 hereto and the notices referred to herein;
and any such reference shall not be deemed to incorporate herein by reference any document,
instrument or agreement except as otherwise provided in this paragraph 5.
6. This Letter of Credit is non-transferable by Beneficiary. Issuer waives any rights it
may have, at law or otherwise, to subrogate to any claims Beneficiary may have against Applicant or
Applicant may have against Beneficiary.
7. Communications with respect to this Letter of Credit shall be in writing and shall be
addressed to Issuer at the address referred to in paragraph 1 above, and shall specifically refer to
this Letter of Credit No. [_____].
Very truly yours,
[LOC Issuer]
Authorized Signatory

Exhibit No. 4
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E. Hackett, IPC
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EXHIBIT E
Exhibit E – 3
The undersigned (“Beneficiary”) hereby certifies to [] (“Issuer”), with reference to
Irrevocable Standby Letter of Credit No. [________________] (the “Letter of Credit”) issued by Issuer in
favor of the Beneficiary, as follows:
(1) The undersigned is the [____________] of Beneficiary and is duly authorized by Beneficiary to
execute and deliver this Draw Certificate on behalf of Beneficiary.
(2) Beneficiary hereby makes demand against the Letter of Credit by Beneficiary’s presentation
of the draft accompanying this Draw Certificate, for payment of [_______________________] United
States Dollars (US$[__________]), which amount, when aggregated together with any additional
amount that has not been drawn under the Letter of Credit, is not in excess of the Available
Amount (as in effect of the date hereof).
(3) The conditions for a drawing by Beneficiary are pursuant to:
a)The pending expiration of this Letter of Credit in twenty (20) or fewer New York banking
days, Beneficiary has not received an extension of said Letter of Credit or other acceptable
replacement Credit Support as required under the Build Transfer Agreement, dated as of
[______], between Account Party and Beneficiary, as the same may have been amended;
b)An “Event of Default” (as defined in the Build Transfer Agreement dated as of [______],
between Account Party and Beneficiary) that has occurred and is continuing with respect
to Account Party, and Account Party’s payment to Beneficiary of $[amount] is due and
owing; or
c) The early termination of the Build Transfer Agreement, dated as of [______], between
Account Party and Beneficiary, pursuant to Section 2.11(a) thereof, and Account Party’s
payment to Beneficiary of $[amount] is due and owing pursuant to Section 2.11(g)
thereof.
Wherefore, Beneficiary hereby demands payment of the above referenced amount under
Letter of Credit No. [____].”
(4) Issuer is hereby directed to make payment to: []
Beneficiary Name and Address:
By:
Title:
Date:
(5) Capitalized terms used herein and not otherwise defined herein shall have the respective
meanings set forth in the Letter of Credit.

Exhibit No. 4
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Page 323 of 1056
EXHIBIT E
Exhibit E – 4
[BENEFICIARY]
By:
Title:
Date:

Exhibit No. 4
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EXHIBIT E
Exhibit E – 5
[Date]
[Beneficiary name and address]
Dear Madam or Sir:
Reference is made to that Irrevocable Standby Letter of Credit No. [_____] (the “Letter of Credit”) dated
[____________] issued by [] in favor of [____________] (the “Beneficiary”). Any
capitalized term used herein and not defined herein shall have its respective meaning as set forth in
the Letter of Credit.
This constitutes our notice to you pursuant to the Letter of Credit that the Letter of Credit shall
terminate on [__] [sixty (6
expiration] (the “Early Expiration Date”).
Pursuant to the terms of the Letter of Credit, the Beneficiary is authorized to draw (pursuant to one
or more drawings), prior to the Early Expiration Date, on the Letter of Credit in an aggregate amount
that does not exceed the then Available Amount (as defined in the Letter of Credit).
IN WITNESS WHEREOF, the undersigned has executed and delivered this request on this [____] day
of [____________].
[ISSUING BANK]
By:
Name:
Title:
cc:
[Applicant name and address]
Exhibit No. 4
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EXHIBIT F
Exhibit F – 1
[TBD]
Exhibit No. 4
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Page 326 of 1056
[TBD]

Exhibit No. 4
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EXHIBIT H
[TBD]
Exhibit No. 4
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Page 328 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements for Resource Based Bids
Respondent shall review and redline the following draft agreement into the submitted proposal for the
specific product type and ownership structure as defined in this RFP.
This draft Exhibit H is not comprehensive and does not constitute a binding offer, shall not form the bases
for an agreement by estoppel nor otherwise, and is not conditions upon each party’s receipt of all
requirement management approvals (including final credit and legal approval) and all regulatory
approvals. Any actions taken by a party in reliance on the terms set forth in this working draft or on
statements made during negotiations pursuant to this working draft shall be at that party’s own risk. Until
this agreement is negotiated, approved by management, executed, delivered, and approved by all required
regulatory bodies, no party shall have any other legal obligations, expressed or implied, or arising in any
other manner under this working draft or in the course of negotiations.
POWER PURCHASE AGREEMENT

BETWEEN

____________________

AND

IDAHO POWER COMPANY

Exhibit No. 4
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Exhibit No. 4
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TABLE OF CONTENTS
Page
-i-
SECTION 1 DEFINITIONS, RULES OF INTERPRETATION .................................................. 1
SECTION 2 REPRESENTATIONS AND WARRANTIES ......................................................15
2.1 Mutual Representations and Warranties..............................................................17
2.2 Seller’s Further Representations and Warranties.................................................18
2.3 No Other Representations or Warranties............................................................. 20
2.4 Continuing Nature of Representations and Warranties; Notice. ..........................20
SECTION 3 CONDITIONS TO ACCEPTANCE OF GENERATION, FIRST
GENERATION DATE........................................................................................20
3.1 Conditions to be granted First Generation Date.. ................................................ 20
3.2 Idaho Power’s Right to Monitor..........................................................................21
SECTION 4 TERM AND COMMERCIAL OPERATION DATE ............................................23
4.1 Term.....................................................................................................................23
4.2 Commercial Operation Date. ...............................................................................23
4.3 Continuing Obligations........................................................................................ 26
4.4 Commercial Operation Date Delay, Delay Damages and Deficit Damages. ...... 26
4.5 Damages Calculation. ..........................................................................................26
4.6 Damages Invoicing..............................................................................................27
4.7 Tax Credits. ..........................................................................................................27
SECTION 5 DELIVERIES OF NET OUTPUT AND GREEN TAGS ...................................... 27
5.1 Purchase and Sale. ...............................................................................................27
5.2 No Sales to Third Parties. ....................................................................................27
5.3 Title and Risk of Loss of Net Output...................................................................28
5.4 Curtailment. .........................................................................................................28
5.5 Idaho Power as Merchant..................................................................................... 29
5.6 Green Tags. .......................................................................................................... 29
5.7 Purchase and Sale of Capacity Rights. ................................................................31
5.8 Representation Regarding Ownership of Capacity Rights. ................................. 31
5.9 Authority to Make Sales. .....................................................................................31
5.10 Further Assurances...............................................................................................31
SECTION 6 CONTRACT PRICE; COSTS................................................................................ 31
6.1 Contract Price; Includes Green Tags and Capacity Rights. .................................31
6.2 Costs and Charges. ............................................................................................... 33
Exhibit No. 4
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ii
6.3 Station Service.....................................................................................................33
6.4 Taxes....................................................................................................................33
6.5 Costs of Ownership and Operation......................................................................33
6.6 Rates Not Subject to Review. ..............................................................................34
SECTION 7 OPERATION AND CONTROL ............................................................................ 34
7.1 As-Built Supplement............................................................................................ 34
7.2 Standard of Facility Operation.............................................................................34
7.3 Interconnection. ...................................................................................................35
7.4 Coordination with System....................................................................................35
7.5 Outages. ............................................................................................................... 35
7.6 Scheduling............................................................................................................37
7.7 Forecasting...........................................................................................................37
7.8 No Increase in Nameplate Capacity Rating .........................................................39
7.9 Electronic Communications.................................................................................39
7.10 Reports and Records. ...........................................................................................40
7.11 Financial and Accounting Information................................................................43
7.12 Output Guarantee. ................................................................................................ 43
7.13 Access Rights. ...................................................................................................... 45
7.14 Facility Images. ....................................................................................................45
SECTION 8 RIGHT OF FIRST OFFER ADDITIONAL GENERATION AND
OWNERSHIP OR PURCHASE OPTION......................................................................45
SECTION 9 SECURITY AND CREDIT SUPPORT .................................................................48
9.1 Project Development Security.............................................................................48
9.2 Default Security. ..................................................................................................49
9.3 Senior Lenders .....................................................................................................47
9.4 Change of Control .................................................Error! Bookmark not defined.
9.5 Security is Not a Limit on Seller’s Liability ........................................................ 50
SECTION 10 METERING, METERING COMMUNICATIONS AND SCADA
TELEMETRY ...................................................................................................... 50
10.1 Metering...............................................................................................................50
10.2 Metering Communications................................................................................... 50
10.3 Supervisory Control and Data Acquisition (SCADA) Telemetry.. ..................... 51
10.4 Metering Costs.. ...................................................................................................51
Exhibit No. 4
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TABLE OF CONTENTS
(continued)Page
- iii -
SECTION 11 BILLINGS, COMPUTATIONS AND PAYMENTS ...........................................51
11.1 Monthly Invoices. ................................................................................................52
11.2 Offsets. ................................................................................................................. 52
11.3 Interest on Late Payments.................................................................................... 52
11.4 Disputed Amounts. ..............................................................................................52
11.5 Audit Rights. ........................................................................................................52
SECTION 12 DEFAULTS AND REMEDIES............................................................................ 52
12.1 Defaults. ...............................................................................................................52
12.2 Remedies for Failure to Deliver/Receive............................................................. 55
12.3 Termination and Remedies..................................................................................56
12.4 Termination Damages..........................................................................................57
12.5 [Omitted] ..............................................................................................................57
12.6 Duty/Right to Mitigate......................................................................................... 57
12.7 Security. ...............................................................................................................57
12.8 Cumulative Remedies. .........................................................................................57
SECTION 13 INDEMNIFICATION AND LIABILITY............................................................ 57
13.1 Indemnities. ..........................................................................................................58
SECTION 14 INSURANCE .......................................................................................................59
14.1 Required Policies and Coverages.........................................................................59
14.2 Certificates of Insurance. .....................................................................................59
SECTION 15 FORCE MAJEURE ..............................................................................................59
15.1 Definition of Force Majeure................................................................................ 59
15.2 Suspension of Performance.................................................................................. 60
15.3 Force Majeure Does Not Affect Other Obligations. ............................................60
15.4 Strikes. .................................................................................................................60
15.5 Right to Terminate...............................................................................................60
SECTION 16 SEVERAL OBLIGATIONS.................................................................................61
SECTION 17 CHOICE OF LAW ............................................................................................... 61
SECTION 18 PARTIAL INVALIDITY .....................................................................................61
SECTION 19 NON-WAIVER ..................................................................................................... 61
SECTION 20 GOVERNMENTAL JURISDICTION AND AUTHORIZATIONS ...................61
SECTION 21 [INTENTIONALLY OMITTED].........................................................................62
Exhibit No. 4
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iv
SECTION 22 SUCCESSORS AND ASSIGNS..........................................................................62
22.1 Restriction on Assignments................................................................................. 62
22.2 Permitted Assignments........................................................................................62
SECTION 23 ENTIRE AGREEMENT .......................................................................................62
SECTION 24 NOTICES ..............................................................................................................62
24.1 Addresses and Delivery Methods. .......................................................................63
24.2 Changes of Address.............................................................................................63
SECTION 25 CONFIDENTIALITY........................................................................................... 64
25.1 Confidential Business Information. .....................................................................64
25.2 Duty to Maintain Confidentiality. ........................................................................64
25.3 Idaho Power Regulatory Compliance. ................................................................. 64
25.4 Irreparable Injury; Remedies...............................................................................65
25.5 News Releases and Publicity. ..............................................................................65
SECTION 26 DISAGREEMENTS .............................................................................................65
26.1 Negotiations. ........................................................................................................ 66
26.2 Choice of Forum. .................................................................................................66
26.3 Settlement Discussions........................................................................................66
26.4 Waiver of Jury Trial. ............................................................................................ 66
Exhibit No. 4
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Page 334 of 1056
-v-
EXHIBITS
Exhibit 1 Generation Scheduling and Reporting
Exhibit 2 Description of Facility
Exhibit 3 Point of Delivery/Interconnection Facilities
Exhibit 4 Estimated Monthly Net Output
Exhibit 5 Contract Prices
Exhibit 6 NERC Event Types
Exhibit 7 Start-Up Testing
Exhibit 8 Form of Security – Credit Support Obligation
Exhibit 9 Required Facility Documents
Exhibit 10 Leases
Exhibit 11 Engineer’s Certification of O&M Policy, Engineer’s Certification
of Ongoing O&M, Engineer’s Certification of Design and
Construction Adequacy.
Exhibit 12 [Reserved]
Exhibit 13 Required Insurance
Exhibit 14 Seller Authorization to Release Generation Data to Idaho Power
Exhibit 15 Attachments
Exhibit 16 As-Built Supplement
Exhibit 17 Marketing Communications Agreement
Exhibit 18 Form of Construction Progress Report
Exhibit 19 Form of Operations Report
Exhibit 20 Idaho Power form of Qualified Reporting Entity Agreement
Exhibit 21 Form of Lender Consent
Exhibit 22 Form of Estoppel Certificate

Exhibit No. 4
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Exhibit No. 4
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-1-
THIS WORKING DRAFT DOES NOT CONSTITUTE A BINDING OFFER, SHALL NOT
FORM THE BASIS FOR AN AGREEMENT BY ESTOPPEL OR OTHERWISE, AND IS
CONDITIONED UPON EACH PARTY’S RECEIPT OF ALL REQUIRED
MANAGEMENT APPROVALS (INCLUDING FINAL CREDIT AND LEGAL
APPROVAL) AND ALL REGULATORY APPROVALS. ANY ACTIONS TAKEN BY A
PARTY IN RELIANCE ON THE TERMS SET FORTH IN THIS WORKING DRAFT OR
ON STATEMENTS MADE DURING NEGOTIATIONS PURSUANT TO THIS
WORKING DRAFT SHALL BE AT THAT PARTY’S OWN RISK. UNTIL THIS
AGREEMENT IS NEGOTIATED, APPROVED BY MANAGEMENT, EXECUTED,
DELIVERED AND APPROVED BY ALL REQUIRED REGULATORY BODIES, NO
PARTY SHALL HAVE ANY OTHER LEGAL OBLIGATIONS, EXPRESSED OR
IMPLIED, OR ARISING IN ANY OTHER MANNER UNDER THIS WORKING DRAFT
OR IN THE COURSE OF NEGOTIATIONS.
POWER PURCHASE AGREEMENT

THIS POWER PURCHASE AGREEMENT (this “Agreement”), dated as of
____________, 202_, (the “Effective Date”), is entered into between ____________ (the
“Seller”) and Idaho Power Company, an Idaho corporation (“Idaho Power” or “Buyer”). Seller
and Idaho Power are sometimes hereinafter referred to collectively as the “Parties” and
individually as a “Party.”

WHEREAS, Seller intends to construct, own, operate and maintain a solar
powered generation facility for the generation of electric energy located in [_______ ____],
[Idaho] with an Expected Nameplate Capacity Rating (as defined below) of [ ] MW (AC)
(the “Facility”).
WHEREAS, Seller desires to sell, and Idaho Power desires to purchase, the Net
Output and Green Tags (as defined below) delivered by the Facility in accordance with the terms
and conditions hereof.

WHEREAS,

NOW, THEREFORE, in consideration of the foregoing and the mutual promises
set forth below and for other good and valuable consideration, the receipt and sufficiency of
which are hereby acknowledged, the Parties mutually agree as follows:
SECTION 1
DEFINITIONS, RULES OF INTERPRETATION

Defined Terms. Unless otherwise required by the context in which any term appears, initially
capitalized terms used herein shall have the following meanings:

1.1 “Abandonment” means (a) the relinquishment of all possession and control of the Facility
by Seller, other than pursuant to a transfer permitted under this Agreement, or (b) if after
commencement of the construction, testing, and inspection of the Facility, and prior to
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the Commercial Operation Date, there is a complete cessation of the construction, testing,
and inspection of the Facility for ninety (90) consecutive days by Seller and Seller’s
contractors, but only if such relinquishment or cessation is not caused by or attributable
to an Event of Default by Idaho Power, a request by Idaho Power, or an event of Force
Majeure.

1.2 “AC” means alternating current.
1.3 “Affiliate” means, with respect to any entity, each entity that directly or indirectly
controls, is controlled by, or is under common control with, such designated entity, with
“control” meaning the possession, directly or indirectly, of the power to direct
management and policies, whether through the ownership of voting securities or by
contract or otherwise.

1.4 “Agreement” is defined in the opening paragraph hereto.

1.5 “As-built Supplement” is a supplement to be added to Exhibit 16 that describes the
Facility as actually built, pursuant to Section 7.1 and includes an American Land Title
Association survey of the Premises.

1.6 “Anything of Value” includes, but is not limited to, cash or a cash equivalent (including
“grease”, “expediting” or facilitation payments), discounts, rebates, gifts, meals,
entertainment, hospitality, use of materials, facilities or equipment, transportation,
lodging, or promise of future employment.

1.7 “Book Value” means cost minus accumulated depreciation, and not deducting for debt or
other encumbrances, calculated in accordance with generally accepted accounting
principles consistently applied.

1.8 “Business Day” means any Monday through Friday except NERC recognized holidays
beginning at 6:00 a.m. and ending at 5:00 p.m. local time in Boise, Idaho.

1.9 “Capacity Rights” means any current or future defined characteristic, certificate, tag,
credit, reactive power, ancillary service or attribute thereof, or accounting construct,
including any of the same counted towards any current or future resource adequacy or
reserve requirements, associated with the electric generation capability and capacity of
the Facility or the Facility’s capability and ability to produce energy. Capacity Rights are
measured in MW and do not include any Tax Credits, or any other tax incentives existing
now or in the future associated with the construction, ownership or operation of the
Facility.

1.10 “Change of Control” means, with respect to Seller, any transaction or series of
transactions following which Seller’s Parent Entity no longer directly or indirectly (i)
remains the owner of more than fifty percent (50%) of the direct or indirect equity or
voting interests of Seller which are not otherwise held by Seller’s Lenders (excluding any
Tax Equity Investors), or (ii) retains the power to control the management and policies of
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Seller; provided, however, that a Seller Permitted Transfer shall not be a Change of
Control.
1.11 “Commercial Operation” means that not less than the Required Percentage of the
Expected Nameplate Capacity Rating of the Facility is fully operational and reliable and
the Facility is fully interconnected, fully integrated, and synchronized with the System,
all of which shall be Seller’s responsibility to receive or obtain, and without limiting
Seller’s other obligations under this Agreement, which occurs when all of the enumerated
events listed in Section 4.2 (a) have occurred, and (b) remain simultaneously true and
accurate as of the date and moment on which Seller gives Idaho Power written notice that
Commercial Operation has occurred:
1.12 “Commercial Operation Date” means the day commencing at 00:01 hours, Mountain
Time, following the day that all requirements of Section 4 have been completed and after
the Seller requested Operation Date.

1.13 “Confidential Business Information” is defined in Section 25.1.

1.14 “Construction Progress Report” is defined in Section 3.2.1.
1.15 “Contract Interest Rate” means the lesser of (a) the highest rate permitted under
Requirements of Law or (b) 200 basis points per annum plus the rate per annum equal to
the publicly announced prime rate or reference rate for commercial loans to large
businesses in effect from time to time quoted by Citibank, N.A. as its “prime rate.” If a
Citibank, N.A. prime rate is not available, the applicable prime rate shall be the
announced prime rate or reference rate for commercial loans in effect from time to time
quoted by a bank with $10 billion or more in assets in New York City, N.Y., selected by
the Party to whom interest is being paid.
1.16 “Contract Price” means the applicable price, expressed in dollars per
MWh for Net Output, Green Tags and Capacity Rights stated in Section 6.1.
1.17 “Contract Year” means any consecutive 12-month period during the Term, commencing
at 00:00 hours on the Commercial Operation Date or any of its anniversaries and ending
at 24:00 hours on the last day of such 12-month period.
1.18 “Costs” means, with respect to the non-defaulting Party, (a) brokerage fees, commissions
and other similar third party transaction costs and expenses reasonably incurred by such
Party either in terminating any arrangement entered into pursuant to this Agreement or
entering into new arrangements which replace this Agreement and (b) all reasonable
attorneys’ fees and expenses incurred by the non-defaulting Party in connection with the
termination of this Agreement.

1.19 “CPCN” means Certificate of Public Convenience and Necessity.

1.20 “Credit Requirements” means (a) three (3) years of audited financial statements, a view
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of the financial position and financial performance, financial statement analysis and
financial trend analysis; (b) Debt Agency Ratings - a senior, unsecured long term debt
rating (or corporate rating if such debt rating is unavailable) of BBB+ or greater from
S&P, or Baa1 or greater from Moody’s, and if such ratings are split, the lower of the two
ratings must be at least ‘BBB+’ or ‘Baa1’ from S&P or Moody’s, respectively. Idaho
Power performs a credit analysis, which considers both qualitative and quantitative
factors, to determine whether potential Counterparties have satisfied the Credit
Requirements.

1.21 “Customer” means [_________]and its permitted successors and assigns.

1.22 “default” is defined in Section 12.1.

1.23 “Default Security” is defined in Section 9.2.1.

1.24 “Deficit Damages” means a one-time payment equal to (a) the difference between (i)
Expected Nameplate Capacity Rating and (ii) the Nameplate Capacity Rating of the
Facility on the 120th day after the Guaranteed Commercial Operation Date, stated in
MWs, multiplied by (b) [$150,000.]

1.25 “Delay Damages” means for any given day the amount equal to [$XX] multiplied by the
Expected Nameplate Capacity Rating in MW.

1.26 “Effective Date” is the date stated in the opening paragraph hereto which represents the
date upon which this Agreement was fully executed by both Parties.

1.27 “Electric System Authority” means each of NERC, WECC, WREGIS, an RTO, a
regional or sub-regional reliability council or authority, and any other similar council,
corporation, organization or body of recognized standing with respect to the operations of
the electric system in the WECC region, as such are applicable to the Seller or Idaho
Power.

1.28 “Emissions Reduction Credit” means any credit, allowance or instrument issued or
issuable by a Governmental Authority under regulations of the Environmental Protection
Agency under the Clean Air Act.

1.29 “Energy Imbalance Market” means the California Independent System Operator’s
Western Energy Imbalance Market.

1.30 “Environmental Attributes” means the environmental and other attributes as may exist
from time to time that differentiate the Project or its Project Energy from energy
generated by fossil fuel or nuclear powered generating units, and any and all claims,
credits, benefits, emissions reductions, offsets, and allowances, howsoever entitled,
attributable to the generation from the Project, and its displacement of conventional
energy generation, or resulting from the avoidance of the emission of any gas, chemical,
or other substance to the air, soil or water. Environmental Attributes include but are not
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limited to: (a) any avoided emissions of pollutants to the air, soil, or water such as
(subject to the foregoing) sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide
(CO), and other pollutants; (b) any avoided emissions of carbon dioxide (CO2), methane
(CH4), and other greenhouse gases (GHGs) that have been determined by the United
Nations Intergovernmental Panel on Climate Change or any Governmental Authority to
contribute to the actual or potential threat of altering the Earth’s climate by trapping heat
in the atmosphere; (c) and Emission Reduction Credits; (d) any cryptocurrency,
blockchain, and similar or related matters, items commodities, tokens, or anything of
actual, potential, or theoretical value related to, measured by, or associated with anything
produced by Facility Energy and (e) credits, benefits or allowances resulting from the
compliance of the Facility or Facility Energy with the laws, rules and standards of the
United Nations Framework Convention on Climate Change (the “UNFCCC”) or the
Kyoto Protocol of the UNFCCC or crediting “early action” with a view thereto.
Environmental Attributes do not include (i) the ITC or any other Tax Credits, or certain
other tax incentives existing now or in the future associated with the construction,
ownership or operation of the Facility, (ii) matters designated by Idaho Power as sources
of liability, or (iii) adverse wildlife or environmental impacts.

1.31 “Environmental Contamination” means the introduction or presence of Hazardous
Materials at such levels, quantities or location, or of such form or character, as to
constitute a violation of federal, state or local laws or regulations, and present a material
risk under federal, state or local laws and regulations that the Premises will not be
available or usable for the purposes contemplated by this Agreement.

1.32 “Event of Default” is defined in Section 12.1.

1.33 “Expected Energy” means ________MWh of Net Output in the first, full Contract Year,
reduced by an annual degradation factor of 0.3 percent per Contract Year, measured at
the Point of Delivery, which is Seller’s best estimate of the projected long-term average
annual Net Output production, based upon typical solar conditions at the Facility as
determined by a Solar Performance Modeling Program, delivered to the Point of Delivery
and the Expected Nameplate Capacity Rating. Seller estimates that the Net Output will be
delivered during each Contract Year according to the estimates of Monthly Net Output
set forth in Exhibit 4. If at Final Completion the Facility’s Nameplate Capacity Rating is
less than the Expected Nameplate Capacity Rating, Expected Energy shall be reduced
proportionally per year for each full MW of Nameplate Capacity Rating below the
Expected Nameplate Capacity Rating. Seller acknowledges that Idaho Power will include
Expected Energy in Idaho Power’s resource planning. Idaho Power acknowledges that
solar insolation is variable and that the Facility’s actual annual output of Net Output in
the ordinary course in any given year will be subject to variation caused by differences in
the actual solar insolation at the Facility from year to year and month to month.
1.34 “Expected Nameplate Capacity Rating” means [____] MW (AC). The expected
maximum instantaneous generation capacity of the Facility.
1.35 “Facility” is defined in the Recitals and is more fully described in attached Exhibit 2 and
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includes the photovoltaic power generating equipment, including panels, arrays, tracking
system (if applicable), inverters, and all other equipment, devices, associated
appurtenances owned, controlled, operated and managed by Seller in connection with, or
to facilitate, the production, generation, transmission, delivery, or furnishing of electric
energy by Seller to Idaho Power and required to interconnect with the System and
Seller’s interests in the Premises, including Leases and any fee owned real property.

1.36 “FERC” means the Federal Energy Regulatory Commission.

1.37 “Final Completion” means the Facility is fully operational and reliable, at or greater than
the Required Percentage of the Expected Nameplate Capacity Rating, and fully
interconnected, fully integrated, and synchronized with the Transmission Provider’s
System, modified if necessary to reflect the Nameplate Capacity Rating and, if
applicable, through completion of all the items set forth on the Final Completion
Schedule.

1.38 “Final Completion Schedule” means the full list of all items to be completed in order to
achieve Final Completion, See Section 4.2, Commercial Operation Date.

1.39 “First Generation Date” means the day commencing at 00:01 hours, Mountain Time,
following the day that Seller has satisfied the requirements of Section 3 and after the
Seller requested First Generation Date.

1.40 “Force Majeure” and “event of Force Majeure” are defined in Section 15.1.

1.41 “Forced Outage” means NERC Event Types U1, U2 and U3, as set forth in attached
Exhibit 6, and specifically excludes any Maintenance Outage or Planned Outage.

1.42 “Forward Settlement Amount” means, with respect to the non-defaulting Party, the net
Losses and Gains, and Costs, expressed in U.S. Dollars, which such Party incurs as a
result of the termination of this Agreement plus all amounts then owed to the non-
defaulting Party by the defaulting Party. If the non-defaulting Party’s aggregate Gains
exceed its aggregate Losses and Costs, if any, resulting from the termination of this
Agreement, the Forward Settlement Amount shall be zero.

1.43 “Gains” means, with respect to any Party, an amount equal to the present value of the
economic benefit to it, if any (exclusive of Costs), resulting from the early termination of
this Agreement for the remainder of the Term that would have occurred but for the
occurrence of the Event of Default and early termination, determined in a commercially
reasonable manner.

1.44 “Generator Interconnection Agreement” or “GIA” means the large generator
interconnection agreement entered into separately between Seller and Interconnection
Provider concerning the Interconnection Facilities.

1.45 “GOLC” or “Generator Output Limit Control” means the equipment and capability of an
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electric generation facility to automatically adjust the generation quantity.
1.46 “GOLC Set-Point” means the analog or digital signal sent to the Facility by Idaho Power,
the Interconnection Provider, the Transmission Provider or the Market Operator
representing the maximum Net Output for the Facility.
1.47 “Government Official” means any official or employee of any multinational, national,
regional, or local government in any country, including any official or employee of any
government department, agency, commission, or division; any official or employee of
any government-owned or -controlled enterprise; any official or employee of any public
educational, scientific, or research institution; any political party or official or employee
of a political party; any candidate for public office; any official or employee of a public
international organization; and any person acting on behalf of or any relatives, family, or
household members of any of those listed above.
1.48 “Governmental Authority” means any supranational, federal, state or other political
subdivision thereof, having jurisdiction over Seller, Idaho Power or this Agreement,
including any municipality, township or county, and any entity or body exercising
executive, legislative, judicial, regulatory or administrative functions of or pertaining to
government, including any corporation or other entity owned or controlled by any of the
foregoing.

1.49 “Green Tags” means (a) the Environmental Attributes associated with all Output,
together with (b) the Green Tag Reporting Rights associated with such energy and
Environmental Attributes, however commercially transferred or traded under any or other
product names, such as “Renewable Energy Credits,” “Green-e Certified,” or otherwise.
One Green Tag represents the Environmental Attributes made available by the generation
of one MWh of electric energy from the Facility.

1.50 “Green Tags Price Component” means the greatest of: (1) the price for Green Tags
determined by arithmetically averaging quotes for Green Tags from three nationally
recognized independent Green Tag brokers selected by Idaho Power pursuant to which
Idaho Power could reasonably purchase substitute Green Tags similar to those Green
Tags that Seller failed to deliver, with delivery terms, vintage period and any renewable
program certification eligibility that are similar to those contained herein, calculated as of
the date of default or as soon as reasonably possible thereafter; (2) if after the Effective
Date a liquid market for Green Tags exists, the price established for Green Tags from the
established liquid market for Green Tags in a form and location that Idaho Power
determines reasonably states the market value of the Green Tags delivered hereunder; or
(3) Five Dollars ($5.00) per Green Tag.
1.51 “Green Tag Reporting Rights” means the exclusive right of a purchaser of Environmental
Attributes to report ownership of Environmental Attributes in compliance with federal or
state law, if applicable, and to federal or state agencies or other parties at such
purchaser’s discretion, including under any present or future domestic, international, or
foreign emissions trading program or renewable portfolio standard.
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1.52 “Guaranteed Commercial Operation Date” means the date that is ninety (90) days after
the Scheduled Commercial Operation Date.

1.53 “Hazardous Materials” means any waste or other substance that is listed, defined,
designated or classified as or determined to be hazardous under or pursuant to any
environmental law or regulation.

1.54 “Idaho Power” and “Buyer” are defined in the opening paragraph, and explicitly excludes
Idaho Power Transmission.

1.55 “Idaho Power’s Cost to Cover” means the positive difference, if any, between (a) the sum
of (i) the time weighted average of the Market Price Index for each day for which the
determination is being made, plus (ii) the Green Tags Price Component, and (b) the
Contract Price specified in Exhibit 5 in effect on such days, stated as an amount per
MWh. If on a given day (or month in the case of calculating Output Shortfall) the
difference between (a) minus (b) referenced above is zero or negative, then Idaho
Power’s Cost to Cover shall be zero dollars ($0), and Seller shall have no obligation to
pay any amount to Idaho Power on account of Section 7.12.3 or Section 12.2.1 with
respect to such day (or month in the case of calculating Output Shortfall).
1.56 “Idaho Power Indemnitees” is defined in Section 13.1.1.

1.57 “Idaho Power Representatives” is defined in Section 7.13.

1.58 “Idaho Power Transmission” means Idaho Power Company, an Idaho corporation, acting
in its interconnection or transmission function capacity.

1.59 “Indemnified Party” is defined in Section 7.2.3.2.

1.60 “Indemnifying Party” is defined in Section 7.2.3.2.

1.61 “Interconnection Facilities” means all the facilities installed, or to be installed, for the
purpose of interconnecting the Facility to the System, including electrical transmission
lines, upgrades, transformers and associated equipment, substations, relay and switching
equipment, and safety equipment.

1.62 “Interconnection Provider” means Idaho Power Transmission.

1.63 “Inverter” means the equipment installed at the Facility to convert direct current from the
Solar Panels to AC, as described in Exhibit 2.

1.64 “IPUC” means the Idaho Public Utilities Commission.

1.65 “IRP” means Idaho Power’s Integrated Resource Plan.

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1.66 “ITC” means the investment tax credit established pursuant to Section 48 of the Internal
Revenue Code, as such law may be amended or superseded.
1.67 “Leases” means the memoranda of lease and redacted leases recorded in connection with
the development of the Facility, as the same may be supplemented, amended, extended,
restated, or replaced from time to time.
1.68 “Lender” means an entity lending money or extending credit (including any financing
lease, monetization of tax benefits, transaction with a tax equity investor, backleverage
financing or credit derivative arrangement) to Seller or Seller’s Affiliates (a) for the
construction, term or permanent financing or refinancing of the Facility; (b) for working
capital or other ordinary business requirements for the Facility (including for the
maintenance, repair, replacement or improvement of the Facility); (c) for any
development financing, bridge financing, credit support, and related credit enhancement
in connection with the development, construction or operation of the Facility; or (d) for
the purchase of the Facility and related rights from Seller.

1.69 “Letter of Credit” means an irrevocable standby letter of credit in a form reasonably
acceptable to Idaho Power, naming Idaho Power as the party entitled to demand payment
and present draw requests thereunder that:

1.69.1 is issued by a Qualifying Institution;

1.69.2 by its terms, permits Idaho Power to draw up to the face amount thereof for the
purpose of paying any and all amounts owing by Seller hereunder;

1.69.3 permits Idaho Power to draw the entire amount available thereunder if such letter
of credit is not renewed or replaced at least thirty (30) days prior to its stated expiration
date;

1.69.4 permits Idaho Power to draw the entire amount available thereunder if such letter
of credit is not increased or replaced as and when provided in Section 9;

1.69.5 is transferable by Idaho Power to any party to which Idaho Power may assign this
Agreement; and

1.69.6 shall remain in effect for at least ninety (90) days after the end of the Term.

1.70 “Liabilities” is defined in Section 13.1.1.

1.71 “Licensed Professional Engineer” means a person proposed by Seller and acceptable to
Idaho Power in its reasonable judgment who (a) to the extent mandated by Requirements
of Law is licensed to practice engineering in the appropriate engineering discipline for
the required certification being made, in the state of Idaho, (b) has training and
experience in the engineering disciplines relevant to the matters with respect to which
such person is called upon to provide a certification, evaluation or opinion, (c) has no
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economic relationship, association, or nexus with Seller and is not an employee of its
members or Affiliates, other than with the prior written consent of Idaho Power, for
services previously or currently being rendered to Seller or its members or Affiliates, and
(d) is not a representative of a consulting engineer, contractor, designer or other
individual involved in the development of the Facility, or a representative of a
manufacturer or supplier of any equipment installed in the Facility.

1.72 “Losses” means, with respect to any Party, an amount equal to the present value of the
economic loss to it, if any (exclusive of Costs), resulting from the termination of this
Agreement for the remainder of the Term that would have occurred but for the
occurrence of the Event of Default and early termination of this Agreement, determined
in a commercially reasonable manner. If Seller is the non-defaulting Party, “Losses” will
exclude the loss, repayment or recapture of any Tax Credits. If Buyer is the non-
defaulting Party, “Losses” will include Buyer’s cost of replacing this Agreement with an
agreement for new renewable capacity from a facility with similar technology that has
not yet been constructed.

1.73 “Maintenance Outage” means NERC Event Type MO, as set forth in attached Exhibit 6,
and includes any outage involving ten percent (10%) of the Facility’s Net Output that is
not a Forced Outage or a Planned Outage.

1.74 “Market Operator” means the California Independent System Operator or any other entity
performing the market operator function for the Energy Imbalance Market.
1.75 “Market Price Index”means 82.4% of the monthly arithmetic average of each day’s
Intercontinental Exchange (“ICE”) daily firm Mid-C Peak Avg and Mid-C Off-
Peak Avg index prices in the month as follows:
The actual calculation being:

n
.824 * ( -C Peak Avgx * HLH hours for day) +
X=1
(ICE Mid-C Off-Peak Avgx * LLH hours for day)} / (n*24))

where n = number of days in the month
If the ICE Mid-C Index prices are not reported for a particular day or days, prices derived
from the respective averages of HLH and LLH prices for the immediately preceding and
following reporting periods or days shall be substituted into the formula stated in this
definition and shall therefore be multiplied by the appropriate respective numbers of HLH
and LLH Hours for such particular day or days with the result that each hour in such month
shall have a related price in such formula. If the day for which prices are not reported has in
it only LLH Hours (for example a Sunday), the respective averages shall use only prices
reported for LLH hours in the immediately preceding and following reporting periods or
days. If the day for which prices are not reported is a Saturday or Monday or is adjacent on
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the calendar to a holiday, the prices used for HLH Hours shall be those for HLH hours in
the nearest (forward or backward) reporting periods or days for which HLH prices are
reported

1.76 “Marketing Communications Agreement” means an agreement substantially in the form
of Exhibit “xx” attached hereto, with such revisions as may be mutually agreed upon by
Seller, Customer, and Buyer.

1.77 “Maximum Delivery Rate” means the maximum hourly rate of delivery of Net Output in
MWh from the Facility to the Point of Delivery, calculated on the basis of the Net Output
delivered in an hour accruing at an average rate equivalent to the actual Nameplate
Capacity Rating.

1.78 “Moody’s” means Moody’s Investor Services, Inc.

1.79 “Mountain Prevailing Time” or “MPT” means Mountain Standard Time or Mountain
Daylight Time, as applicable in Idaho on the day in question.

1.80 “MW” means megawatt.

1.81 “MWh” means megawatt hour.

1.82 “Nameplate Capacity Rating” means the maximum installed instantaneous generation
capacity of the completed Facility, expressed in MW (AC), when operated in compliance
with the Generator Interconnection Agreement and consistent with the recommended
power factor and operating parameters provided by the manufacturer of the Solar Panels
and Inverters, as set forth in a written notice from Seller to Idaho Power delivered prior to
the Commercial Operation Date and, if applicable, updated in a subsequent written notice
from Seller to Idaho Power as required for Final Completion. The Nameplate Capacity
Rating of the Facility shall not exceed the Expected Nameplate Capacity Rating.

1.83 “NERC” means the North American Electric Reliability Corporation.

1.84 “Net Output” means all electric energy and capacity produced by the Facility, less station
use and less transformation and transmission losses and other adjustments (e.g., Seller’s
load other than station use), if any. For purposes of calculating payment under this
Agreement, Net Output of electric energy shall be the amount of electric energy flowing
through the Point of Delivery.
1.85 “Network Resource” is defined in the Tariff.
1.86 “Network Service Provider” means Idaho Power Transmission, as a provider of network
service to Idaho Power under the Tariff.

1.87 “Non-Compensable Curtailment” is defined in Section 5.4.1.

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1.88 “Offer Notice” is defined in Section 8.2.
1.89 “Offered Interests” is defined in Section 8.4.1.
1.90 “Off-Peak Hours” or “LLH” means the daily hours from hour ending 2300 – 0600 MPT, (8
hours), plus all other hours on all Sundays and NERC designated holidays.
1.91 “On-Peak Hours” or “HLH” means the daily hours from hour ending 0700 - 2200 MPT, (16
hours), Monday through Saturday, excluding all hours on all Sundays and NERC
designated holidays.
1.92 “Operations Report” is defined in Section 3.2.2.

1.93 “OPUC” means the Public Utility Commission of Oregon.
1.94 “Output” means all electric energy produced by the Facility.
1.95 “Output Guarantee” is defined in Section 7.12.1.
1.96 “Output Shortfall” is defined in Section 7.12.3.2.
1.97 “Party” and “Parties” are defined in the opening paragraph hereto.
1.98 “Permits” means the permits, licenses, approvals, certificates, entitlements and other
authorizations issued by Governmental Authorities required for the construction,
ownership or operation of the Facility or occupancy of the Premises, and all amendments,
modifications, supplements, general conditions and addenda thereto.

1.99 “Planned Outage” means NERC Event Type PO, as set forth in attached Exhibit 6, and
specifically excludes any Maintenance Outage or Forced Outage.

1.100 “Point of Delivery” means the point of interconnection between the Facility and the
System, as specified in the Generator Interconnection Agreement and as further described
in Exhibit 3.

1.101 “Pre-COD Damages Payment” means liquidated damages in an amount equal to the
amount of Project Development Security required to be provided hereunder, plus the
Delay Damages Seller has paid to Buyer.

1.102 “Premises” means the real property on which the Facility is or will be located, as more
fully described on Exhibits 9, 10 and 15.

1.103 “Project Development Security” is defined in Section 9.1.1.

1.104 “Prudent Electrical Practices” means any of the practices, methods and acts engaged in or
approved by a significant portion of the independent electric power generation industry in
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the United States for solar facilities of similar size and characteristics or any of the
practices, methods or acts, which, in the exercise of reasonable judgment in the light of
the facts known at the time a decision is made, could have been expected to accomplish
the desired result at the lowest reasonable cost consistent with reliability, safety and
expedition.
1.105 “Qualified Operator” is (a) a partnership, corporation or limited liability company that
demonstrates acceptable experience operating a solar generation, or (b) any other Person
reasonably acceptable to Buyer.

1.106 “Qualifying Institution” means a United States commercial bank or trust company
organized under the laws of the United States of America or a political subdivision
thereof having assets of at least $10,000,000,000 (net of reserves) and a credit rating on
its long-term senior unsecured debt of at least “A” from S&P and “A2” from Moody’s.
1.107 “Reporting Month” is defined in Section 7.10.1.
1.108 “Required Facility Documents” means the Permits and other authorizations, rights and
agreements now or hereafter necessary for construction, ownership, operation, and
maintenance of the Facility, and to deliver the Net Output to Idaho Power in accordance
with this Agreement and Requirements of Law, including those set forth in Exhibit 9.

1.109 “Required Percentage” means ninety-three percent (93%).

1.110 “Requirements of Law” means any applicable and mandatory (but not merely advisory)
federal, state and local law, statute, regulation, rule, action, order, code or ordinance
enacted, adopted, issued or promulgated by any federal, state, local or other
Governmental Authority or regulatory body (including those pertaining to electrical,
building, zoning, environmental and wildlife protection and occupational safety and
health).

1.111 “Restricted Period” is defined in Section 8.2.

1.112 “Restricted Transaction” is defined in Section 8.4.1.

1.113 “ROFO” is defined in Section 8.2.

1.114 “ROFO Period” is defined in Section 8.4.1.

1.115 “ROFO Seller” is defined in Section 8.4.1.

1.116 “RTO” means any entity (including an independent system operator) that becomes
responsible as system operator for, or directs the operation of, the System.

1.117 “S&P” means Standard & Poor’s Rating Group (a division of S&P Global, Inc.).

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1.118 “Sanctions” means any economic or trade sanctions administered or enforced by any
Government Authorities of the United States, (including the Office of Foreign Assets
Control of the U.S. Department of the Treasury (“OFAC”) and the U.S. Department of
State), the United Nations, the European Community or, Her Majesty’s Treasury or any,
and each other sanctions authority which has jurisdiction in respect of any Party or the
Facility.
1.119 “Sanctioned Person” means any person (i) that is the target of Sanctions or owned or
controlled by any such person(s), or (ii) located, organized or resident in, or directly or
indirectly owned or controlled by the government of any Sanctioned Territory.
1.120 “Sanctioned Territory” means any country or territory now or hereafter subject to
comprehensive Sanctions.
1.121 “SCADA” means supervisory control and data acquisition.
1.122 “Scheduled Commercial Operation Date” means __________.

1.123 “Seller” is defined in the opening paragraph hereto.
1.124 “Seller Indemnitees” is defined in Section 13.1.2.
1.125 “Seller ROFO Notice” is defined in Section 8.4.1.
1.126 “Seller’s Cost to Cover” means the positive difference, if any, between (a) the Contract
Price per MWh specified in Exhibit 5, and (b) the time weighted average of the Market
Price Index of Net Output not purchased by Idaho Power as required hereunder. If on any
given day the difference between (a) minus (b) referenced above is zero or negative, then
Seller’s Cost to Cover shall be zero dollars with respect to such day, and Idaho Power
shall have no obligation to pay any amount to Seller on account of Section 12.2.2. For
any days prior to the Commercial Operation Date, the Contract Price applicable in the
first Contract Year shall be utilized for purposes of clause (a).

1.127 “Seller’s Parent Entity” means [_____].

1.128 “Seller Uncontrollable Minutes” means, for the Facility in any month, the total number of
minutes during such month during which the Facility was unable to deliver Net Output to
Idaho Power (or during which Idaho Power failed to accept such delivery) due to one or
more of the following events, each as recorded by SCADA and indicated by electronic
fault logs: (a) an emergency or Force Majeure event; (b) to the extent not caused by
Seller’s actions or omissions, a Non-Compensable Curtailment in accordance with
Section 5.4.1; (c) the System operating outside the voltage or frequency limits defined in
the applicable operating manual for the Inverters installed at the Facility; (d) Planned
Outages, but in no event exceeding thirty six (36) hours per Contract Year consistent with
such operating manual; (e) Compensable Curtailment as provided in Section 6.1.3; (f) a
default by Idaho Power; provided, however, that if any of the events described above in
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items (a) through (e) occur simultaneously, then the relevant period of time shall only be
counted once in order to prevent double counting. Seller Uncontrollable Minutes shall not
include minutes when (i) the Facility or any portion thereof was unavailable solely due to
Seller’s non-conformance with the Generation Interconnection Agreement or (ii) the
Facility or any portion thereof was paused or withdrawn from use by Seller for reasons
other than those covered in this definition.

1.129 “Senior Lenders” means Lenders being granted senior security interests on the Facility or
its assets, or Seller or its equity, other than Affiliates of Seller.

1.130 “Solar Array” means one or more Solar Panels connected to the same Inverter.

1.131 “Solar Energy Production Forecasting” is defined in Section 7.7.1.

1.132 “Solar Panels” means the photovoltaic electric energy generating panels installed at the
Facility, as described in Exhibits 2 and 15.

1.133 “Solar Performance Modeling Program” means a commercially available computer
modeling program that is generally accepted in the United States solar energy industry
capable of modeling the Expected Energy and other similar outputs. Solar Performance
Modeling Program includes, but is not limited to, the PVSYST program. If Seller elects a
Solar Performance Modeling Program to which Idaho Power does not have access, Seller,
at its cost, shall provide Idaho Power access to and the right to use the Solar Performance
Modeling Program in order for Idaho Power to fully analyze all modeling provided by
Seller under this Agreement.

1.134 “Special Contract” means that certain Special Contract between Idaho Power and
Customer dated _____.

1.135 “Start-Up Testing” means the start-up tests for the Facility as set forth in Exhibit 7.
1.136 “System” means the electric transmission substation and transmission or distribution
facilities owned, operated or maintained by Transmission Provider, which shall include,
after construction and installation of the Facility, the circuit reinforcements, extensions,
and associated terminal facility reinforcements or additions required to interconnect the
Facility, all as set forth in the Generation Interconnection Agreement.
1.137 “Tariff” means the Idaho Power FERC Electric Tariff Volume No. 11 Open Access
Transmission Tariff, as revised from time to time.
1.138 “Tax Credits” means any state, local and/or federal production tax credit, tax deduction,
and/or investment tax credit (including the ITC) specific to the production of renewable
energy and/or investments in renewable energy facilities.
1.139 “Term” is defined in Section 4.1.

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1.140 “Test Energy” means any Net Output during periods prior to the Commercial Operation
Date and related Capacity Rights.
1.141 “Transmission Provider” means Idaho Power Transmission.
1.142 “WECC” means the Western Electricity Coordinating Council.

1.143 “WREGIS” means the Western Renewable Energy Generation Information System.

1.144 “Compensable Curtailment Energy” is defined in Section 6.1.3.

1.145 “Compensable Curtailment Price” is defined in Section 6.1.3.2.

1.144 Rules of Interpretation.
1.144.1 General. Unless otherwise required by the context in which any term
appears, (a) the singular includes the plural and vice versa; (b) references to “Articles,”
“Sections,” “Schedules,” “Appendices” or “Exhibits” are to articles, sections, schedules,
appendices or exhibits hereof; (c) all references to a particular entity or an electricity
market price index include a reference to such entity’s or index’s successors; (d)
“herein,” “hereof” and “hereunder” refer to this Agreement as a whole; (e) all accounting
terms not specifically defined herein shall be construed in accordance with generally
accepted accounting principles, consistently applied; (f) the masculine includes the
feminine and neuter and vice versa; (g) “including” means “including, without limitation”
or “including, but not limited to”; (h) all references to a particular law or statute mean
that law or statute as amended from time to time; (i) all references to electric energy or
capacity are to be interpreted as utilizing alternating current, unless expressly stated
otherwise; and (j) the word “or” is not necessarily exclusive. Reference to “days” shall be
calendar days, unless expressly stated otherwise herein.
1.144.2 Terms Not to be Construed For or Against Either Party. Each term hereof
shall be construed according to its fair meaning and not strictly for or against either Party.
The Parties have jointly prepared this Agreement, and no term hereof shall be construed
against a Party on the ground that the Party is the author of that provision.
1.144.3 Headings. The headings used for the sections and articles hereof are for
convenience and reference purposes only and shall in no way affect the meaning or
interpretation of the provisions hereof.
1.144.4 Examples. Example calculations and other examples set forth herein are
for purposes of illustration only and are not intended to constitute a representation,
warranty or covenant concerning the example itself or the matters assumed for purposes
of such example. If there is a conflict between an example and the text hereof, the text
shall control.
1.144.5 Interpretation with FERC Orders. Each Party conducts and shall conduct
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its operations in a manner intended to comply with FERC Order No. 717, Standards of
Conduct for Transmission Providers, and its companion orders, requiring the separation
of its transmission and merchant functions. Moreover, the Parties acknowledge that
Interconnection Provider’s transmission function offers transmission service on its
system in a manner intended to comply with FERC policies and requirements relating to
the provision of open-access transmission service. The Parties recognize that Seller will
enter into the Generation Interconnection Agreement with the Interconnection Provider.
Nothing herein is intended to make any statement about FERC jurisdiction in relation to
the Seller.

1.145 Other Terms. The Parties acknowledge and agree that the Generator Interconnection
Agreement shall be a separate and free standing contract and that the terms hereof are not
binding upon the Interconnection Provider.
This Agreement shall not be construed to create any rights between Seller and the
Interconnection Provider or between Seller and the Transmission Provider.
Seller expressly recognizes that, for purposes hereof, the Interconnection Provider and
Transmission Provider each shall be deemed to be a separate entity and separate contracting
party from Idaho Power whether or not the Generation Interconnection Agreement is entered into
with Interconnection Provider or an Affiliate thereof.
SECTION 2
REPRESENTATIONS AND WARRANTIES

2.1 Mutual Representations and Warranties. Each Party represents, covenants, and warrants
to the other that:
2.1.1 Organization. It is duly organized and validly existing under the laws of the State
of its organization.

2.1.2 Authority. It has the requisite power and authority to enter this Agreement and to
perform according to the terms hereof.

2.1.3 Corporate Actions. It has taken all corporate or entity actions required to be taken
by it to authorize the execution, delivery and performance hereof and the consummation
of the transactions contemplated hereby.

2.1.4 No Contravention. The execution and delivery hereof does not contravene any
provision of, or constitute a default under, any indenture, mortgage, security instrument
or undertaking, or other material agreement to which it is a party or by which it is bound,
or any valid order of any court, or any regulatory agency or other Governmental
Authority having authority to which it is subject.

2.1.5 Valid and Enforceable Agreement. This Agreement is a valid and legally binding
obligation of it, enforceable against it in accordance with its terms, except as the
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enforceability hereof may be limited by general principles of equity or bankruptcy,
insolvency, bank moratorium or similar laws affecting creditors’ rights generally and
laws restricting the availability of equitable remedies.

2.1.6 Litigation. No litigation, arbitration, investigation or other proceeding is pending
or, to the best of either Party’s knowledge, threatened in writing against either Party or its
members, with respect hereto and the transactions contemplated hereunder. No other
investigation or proceeding is pending or threatened in writing against a Party, its
members, or any Affiliate, the effect of which would materially and adversely affect the
Party’s performance of its obligations hereunder.

2.1.7 Eligible Contract Participant. It, and any guarantor of its obligations under this
Agreement, is an “eligible contract participant” as that term is defined in the United
States Commodity Exchange Act.

2.1.8 Not a Sanctioned Person. It is not a Sanctioned Person.

2.2 Seller’s Further Representations and Warranties. Seller further represents, covenants, and
warrants to Idaho Power that:
2.2.1 Authority. Seller (a) has (or will have prior to the Commercial Operation Date) all
required regulatory authority to make wholesale sales from the Facility; (b) has the power
and authority to own and operate the Facility and be present upon the Premises for the
Term; and (c) is duly qualified and in good standing under the laws of the state of Idaho
and each other jurisdiction where its ownership, lease or operation of property or the
conduct of its business requires such qualification.

2.2.2 No Contravention. The execution, delivery, performance and observance by Seller
of its obligations hereunder do not and will not:
2.2.2.1 contravene, conflict with or violate any provision of any material
Requirements of Law presently in effect having applicability to either Seller or
any of Seller’s members;

2.2.2.2 require the consent or approval of or material filing or registration with
any Governmental Authority or other person other than such consents and
approvals which are (i) set forth in Exhibit 9 or (ii) required in connection with
the construction, operation, or maintenance of the Facility and expected to be
obtained in due course;

2.2.2.3 result in a breach of or constitute a default under any provision of any
security issued by any of Seller’s members or managers, the effect of which
would materially and adversely affect Seller’s performance of, or ability to
perform, its obligations hereunder, or any material agreement, instrument or
undertaking to which either Seller’s members or any Affiliates of Seller’s
members is a party or by which the property of any of Seller’s members or any
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Affiliates of Seller’s members is bound, the effect of which would materially and
adversely affect Seller’s performance of, or ability to perform, its obligations
hereunder.
2.2.3 Required Facility Documents. All Required Facility Documents are listed on
Exhibit 9. Pursuant to the Required Facility Documents, Seller holds as of the Effective
Date, or will hold by the Commercial Operation Date (or such other later date as may be
specified under Requirements of Law), and will maintain for the Term all Required
Facility Documents. The anticipated use of the Facility complies with all applicable
restrictive covenants affecting the Premises. Following the Commercial Operation Date,
Seller shall promptly notify Idaho Power of any additional Required Facility Documents.
2.2.4 Delivery of Energy. On or before the Commercial Operation Date, Seller shall
hold rights sufficient to enable Seller to deliver Net Output at the Nameplate Capacity
Rating from the Facility to the Point of Delivery pursuant to this Agreement throughout
the Term.

2.2.5 Control of Premises. Seller has all legal rights necessary for the Seller to enter
upon and occupy the Premises for the purpose of constructing, operating and maintaining
the Facility for the Term. All leases of real property required for the operation of the
Facility or the performance of any obligations of Seller hereunder are set forth and
accurately described in Exhibits 9 and 10. Seller shall maintain all leases or other land
grants necessary for the construction, operation and maintenance of the Facility as valid
for the Term. Upon request by Idaho Power, Seller shall provide copies of the
memoranda of lease recorded in connection with the development of the Facility.

2.2.6 Undertaking of Agreement; Professionals and Experts. Seller has engaged those
professional or other experts it believes necessary to understand its rights and obligations
pursuant to this Agreement. All professionals or experts including engineers, attorneys or
accountants, that Seller may have consulted or relied on in undertaking the transactions
contemplated by this Agreement have been solely those of Seller. In entering into this
Agreement and the undertaking by Seller of the obligations set forth herein, Seller has
investigated and determined that it is capable of performing hereunder and has not relied
upon the advice, experience or expertise of Idaho Power in connection with the
transactions contemplated by this Agreement.

2.2.7 Verification. All information relating to the Facility, its operation and output and
the Premises provided to Idaho Power and contained in this Agreement has been verified
by Seller and is true and accurate.

2.2.8 Renewable Claims. Seller has at all times complied with the Federal Trade
Commission requirements set forth in 16 CFR Part 260 in any communications
concerning the Output, the Facility and the Green Tags that have or may be generated
from the Facility. Seller has not claimed the Green Tags, Environmental Attributes or
other “renewable energy,” “green energy,” “clean energy” or similar attributes of the
Output or the Facility as belonging to the Seller or any Seller Affiliate and is not aware of
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any such claims made by third parties with respect to the Facility or the Output.
2.3 No Other Representations or Warranties. Each Party acknowledges that it has
entered into this Agreement in reliance upon only the representations and warranties set forth in
this Agreement, and that no other representations or warranties have been made by the other
Party with respect to the subject matter hereof.
2.4 Continuing Nature of Representations and Warranties; Notice. The
representations and warranties set forth in this Section are made as of the Effective Date and
deemed repeated as of the Commercial Operation Date. If at any time during the Term, a Party
obtains actual knowledge of any event or information that would have caused any of the
representations and warranties in this Section 2 to be materially untrue or misleading at the time
given, such Party shall provide the other Party with written notice of the event or information,
the representations and warranties affected, and the action, if any, which such Party intends to
take to make the representations and warranties true and correct. If at any time a Party obtains
actual knowledge that the representations and warranties in this Section 2 are not true, said Party
shall provide written notice to the other Party. The notice required pursuant to this section shall
be given as soon as practicable after the occurrence of each such event.
SECTION 3
CONDITIONS PRECEDENT TO TERM
3.1 Conditions to be granted First Generation Date. As a condition of the Buyer’s acceptance
of deliveries of Net Output from the Seller, the following conditions shall be satisfied.
3.1.1 Commission/Regulatory Approval. This Agreement shall only become finally
effective upon all regulatory approvals deemed appropriate by Idaho Power and
Customer in form and substance satisfactory to Idaho Power and Customer in all
respects, including the IPUC’s approval of this Agreement and the Special Contract
between Idaho Power and Customer, the OPUC’s approval of a waiver of its procurement
rules as it relates to this Agreement and the Special Contract, and compliance with Idaho
Power’s regulatory requirements with the IPUC and OPUC (“IPUC Approval”);
provided that, notwithstanding anything to the contrary herein, if such IPUC
Approval does not occur on or prior to the date that is six (6) months after the filing
of this Agreement for IPUC Approval, the Parties agree to consult with each other for
a period of five (5) Business Days in the event of any such delay to evaluate whether,
notwithstanding such delay, the Facility will achieve Commercial Operation by the
Scheduled Commercial Operation Date; provided, further, that if the Parties are
unable to so agree, then the Scheduled Commercial Operation Date and Commercial
Operation Date shall each be extended on a day-for-day basis for each day after the
date that is six (6) months after the filing of this Agreement for IPUC Approval, until
such time as IPUC Approval is obtained. If IPUC Approval does not occur by the
date that is twelve (12) months after the filing of this Agreement for IPUC Approval,
then Seller will have a right to terminate this Agreement and upon any such
termination neither Party shall have any obligation to the other under this Agreement,
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except with respect to the terms and provisions hereof that expressly survive the
termination of this Agreement.

3.1.2 This Agreement is subject to, and shall only become finally effective upon: (i)
the approval by the IPUC of all terms and provisions hereof without change or condition
and declaration that all payments to be made to Seller hereunder shall be allowed as
prudently incurred expenses for ratemaking purposes, and (ii) the approval by the OPUC
of a waiver of the application of the OPUC’s resource procurement rules, OAR Chapter
860, Division 89.

3.1.3 The Parties recognize and acknowledge that regulatory proceedings at both the
IPUC and the OPUC will be required. This Agreement shall not become finally effective
should the Agreement be disapproved by the IPUC, should the OPUC disapprove a
waiver of its procurement rules, or Idaho Power not obtain all regulatory approvals
deemed appropriate by Idaho Power and Customer. Idaho Power will file a case seeking
approval of this Agreement with the IPUC. Idaho Power will also file a case with the
OPUC requesting a waiver of the application of the OPUC’s procurement rules.
Additional and concurrent proceedings could include, but may not be limited to: the
Facility’s successful selection in a possible Request for Proposals (“RFP”) process that
complies with the OPUC’s procurement rules; cases before the IPUC and OPUC
regarding the waiver of process, timing, etc. related to compliance or lack thereof with
the OPUC procurement rules, and inclusion of the facility in Idaho Power Integrated
Resource Planning process.

3.2. Idaho Power’s Right to Monitor. After the Effective Date, Seller shall, and shall permit
Idaho Power and Customer, and each of their respective advisors and consultants to:
3.2.1 On and after the Execution Date through the Commercial Operation Date, by the
tenth (10th) Business Day of each month, Seller will provide Buyer a monthly report for
the prior month regarding development, financing and construction updates in the form
attached hereto as Exhibit 18, the form of which may be reasonably revised by Buyer
from time to time (the “Construction Progress Report”).

3.2.2 Thirty (30) days prior to the expected Commercial Operation Date and thereafter
from the Commercial Operation Date and throughout the Settlement Term of this
Agreement, no later than the end of the month immediately following the month for
which information is being reported, Seller shall provide Buyer with a monthly report for
the prior month regarding material data pertaining to the operation of the Facility in the
form of Exhibit 19, the form of which may be reasonably revised by Buyer from time to
time (the “Operations Report”). Each Operations Report shall include any information
provided in a similar report delivered pursuant to the Facility’s power purchase
agreement, and including, but not limited to, the following information for the Facility in
such month: (i) A description of any Outages or other performance issues or curtailments
in the prior month; (ii) Updated forecast (hourly) of Facility Energy for the immediately
succeeding twelve (12) month period, or shorter period ending through the end of the
Term if applicable; and (iii) A description of any issues that could materially impact (ii).
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3.2.3 Review and discuss with Seller and its advisors and consultants monthly status
reports on the progress of the acquisition, design, financing, engineering, construction
and installation of the Facility.

3.2.4 Monitor the status of the acquisition, Premises, land leasing, design, financing,
engineering, construction and installation of the Facility and the performance of the
contractors constructing the Facility.

3.2.5 Witness initial performance tests and other tests and review the results thereof;
with Seller to make best efforts to provide Idaho Power five (5) Business Days’ advance
written notice of each such major test. Seller shall provide Idaho Power with at least two
(2) Business Days prior written notice of each such test, with the understanding that if the
performance of such test is dependent on the presence of sufficient solar insolation or
other variables beyond the control of Seller, the date of such test may be postponed if, on
the date specified in the related notice, there is insufficient solar insolation or other
circumstances beyond the control of Seller that prevent the performance of such test on
the scheduled date.

3.2.6 Perform such examinations, inspections, and quality surveillance as, in Idaho
Power’s reasonable judgment, are appropriate and advisable to determine that the Facility
has been properly commissioned and Commercial Operation and Final Completion have
been achieved.
With respect to Idaho Power’s right to monitor under this Section 3.2, (i) Idaho Power is under
no obligation to exercise any of these monitoring rights, (ii) such monitoring shall occur subject
to reasonable rules developed by Seller regarding Facility construction, access, health, safety,
and environmental requirements, and (iii) Idaho Power shall have no liability to Seller for failing
to advise it of any condition, damages, circumstances, infraction, fact, act, omission or disclosure
discovered or not discovered by Idaho Power with respect to the Facility or any contractor. Any
review or monitoring of the Facility conducted by Idaho Power hereunder shall be performed in
a manner that does not impede, hinder, postpone, or delay Seller or its contractors in their
performance of the engineering, construction, design or testing of the Facility. Idaho Power shall
maintain one or more designated representatives for purposes of the monitoring activities
contemplated in this Section 3.2, which representatives shall have authority to act for Idaho
Power in all technical matters under this Section 3.2 as authorized by Idaho Power but not to
amend or modify any provision hereof. A Construction Progress Report and Operations Report
delivered pursuant to this Section 3.2 shall not constitute notice for any purpose under this
Agreement, including with respect to any fact, circumstance, request, issue, dispute or matter
included in such report. Seller does not herein grant Idaho Power the right to review, comment
on or approve of the terms or conditions of any contract or negotiation between Seller and a third
party, the terms and conditions of each such contract or negotiation being confidential and to be
determined by Seller in its sole discretion. Conversely, nothing in this Agreement shall be
construed to require Idaho Power to review, comment on, or approve of any contract between
Seller and a third party and any such review, comment or approval by Idaho Power shall not
constitute a waiver by Idaho Power or any of Seller’s obligations under this Agreement or create
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any obligation or liability for Idaho Power.
SECTION 4
TERM AND COMMERCIAL OPERATION DATE

4.1 Term. This Agreement shall become effective on the Effective Date and, subject to
earlier termination as provided in this Agreement, shall continue in full force and effect for a period of
__________ Contract Years from the Commercial Operation Date (the “Term”).
4.2 Commercial Operation Date. Seller will in good faith using commercially
reasonable efforts seek to achieve the Commercial Operation Date by the Scheduled Commercial
Operation Date. The Commercial Operation Date shall occur after all the following conditions
have been satisfied.
4.2.1 Idaho Power has received the Default Security, as applicable.

4.2.2 Seller shall notify Buyer of the Seller’s proposed Commercial Operation Date, in
written form no later than five (5) Business Days prior to the proposed Commercial
Operation Date.

4.2.3 Seller shall provide to Idaho Power a certificate from a Licensed Professional
Engineer licensed in the state of Idaho addressed to Idaho Power stating that Seller has
(a) the Required Facility Documents including the material permits, consents and
agreements necessary to operate and maintain the Facility and (b) obtained or entered
into all Permits and Required Facility Documents. Seller must provide copies of any or
all Required Facility Documents requested by Idaho Power.

4.2.4 Seller shall provide Idaho Power with documentation showing that Seller has
obtained retail electric service for the Facility.

4.2.5 Idaho Power has received a certificate addressed to Idaho Power from a Licensed
Professional Engineer stating that, in conformance with the requirements of the
Generation Interconnection Agreement: (1) all required Interconnection Facilities have
been constructed; (2) all required interconnection tests have been completed; and (3) the
Facility is physically interconnected with the System in conformance with the Generation
Interconnection Agreement and able to deliver electric energy consistent with the terms
of this Agreement.

4.2.6 Idaho Power has received, addressed to Idaho Power from a Licensed
Professional Engineer, an executed Engineer’s Certification of Design & Construction
Adequacy and an Engineer’s Certification of Operations and Maintenance (O&M)
Policy. These certificates will be in the form specified in Exhibit 11 but may be modified
to the extent necessary to recognize the different engineering disciplines providing the
certificates.

4.2.7 Idaho Power has received an opinion from a law firm or attorney licensed in the
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State of Idaho stating, after all appropriate and reasonable inquiry (1) Seller has obtained
or entered into all Required Facility Documents; and (2) neither Seller nor the Facility are
in violation of or subject to any liability under any Requirements of Law.
4.2.8 Idaho Power has received a certificate addressed to Idaho Power from an
authorized officer of Seller (1) stating that Seller has completed all of its obligations
under the Generation Interconnection Agreement that would permit Idaho Power to
designate the Facility as a Network Resource and receive firm transmission service from
the Transmission Provider in sufficient capacity to meet or exceed the Maximum
Delivery Rate; and (2) that includes a document from the Transmission Provider
confirming each of the items to which the Seller certifies in (1) above.
4.2.9 Seller has satisfied its obligation to pay for any required Network Upgrades as a
Network Resource pursuant to the Generation Interconnection Agreement (as those terms
are defined in the Generation Interconnection Agreement).
4.2.10 Seller shall submit written proof to the Buyer of all insurance required in Section
14.

4.2.11 Commercial Operation Date Notice. Seller shall provide written notice to Idaho
Power stating when Seller believes that the Facility has achieved Commercial Operation
and its Nameplate Capacity Rating accompanied by the certificates and opinions
described above.

4.2.12 Idaho Power shall have ten (10) Business Days after receipt of such written notice
from Seller either to confirm to Seller that all of the conditions to Commercial Operation
have been satisfied or have occurred, or to state with specificity what Idaho Power
reasonably believes has not been satisfied. If, within such ten (10) Business Day period,
Idaho Power does not respond or notifies Seller confirming that the Facility has achieved
Commercial Operation, the original date of receipt of Seller’s written notice shall be the
Commercial Operation Date. If Idaho Power notifies Seller within such ten (10) Business
Day period that Idaho Power reasonably believes the Facility has not achieved
Commercial Operation, Seller must address the concerns stated in Idaho Power’s notice
to the satisfaction of Idaho Power. In the event Idaho Power provides notice of deficiency
with regards to the information submitted to establish the Commercial Operation Date,
then the Commercial Operation Date will be the date upon which Seller has addressed the
concerns stated in Idaho Power’s notice to Idaho Power’s reasonable satisfaction.

4.2.13 If Commercial Operation of the Facility is achieved based on less than one
hundred percent (100%) of the Expected Nameplate Capacity Rating, then Seller may
inform Idaho Power, by written notice received no later than ten (10) Business Days after
the Commercial Operation Date, that Seller intends to bring the Facility above the
Required Percentage up to but not exceeding one hundred percent (100%) of the
Expected Nameplate Capacity Rating. Such notice from Seller shall include a Final
Completion Schedule. After providing that notice, Seller shall cause the Facility to
achieve Final Completion on or before the ninetieth (90 th) day after the Commercial
Exhibit No. 4
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Operation Date.

4.2.14 If Commercial Operation is achieved at less than one hundred percent (100%) of
the Expected Nameplate Capacity Rating and Seller informs Idaho Power that Seller
intends to bring the Facility to one hundred percent (100%) of the Expected Nameplate
Capacity Rating, Seller shall provide Idaho Power, no later than ten (10) Business Days
after the Commercial Operation Date, with the Final Completion Schedule. All items on
the Final Completion Schedule must be completed on or before the ninetieth (90 th) day
after the Commercial Operation Date. If a Final Completion Schedule is not provided to
Idaho Power within ten (10) Business Days following the Commercial Operation Date,
then the date of Final Completion shall be the same as the Commercial Operation Date.
The conditions set forth in this Section are to be used solely for the purposes of determining
when the Facility has achieved a First Generation Date and are not intended to affect in any way
when the Facility is deemed to have been “placed in service” for tax treatment purposes.
With respect to Sections 4.2.3 through 4.2.6 above, the certificate or opinion provided to Idaho
Power must come from a Licensed Professional Engineer or, in the case of Section 4.2.7 above,
an attorney that is not an employee of Seller (or any Affiliate) and has no financial interest in the
Facility.
Notwithstanding the foregoing, the date for achieving each of the foregoing items shall be
extended on a day for day basis for any delay due solely to Idaho Power’s delay in taking, or
failure to take, any action required of it hereunder in breach of this Agreement.
Without limiting Seller’s obligations under this Agreement, none of the following shall excuse in
any respect Seller’s failure to comply with any and all provisions in this Section 3, no matter
what the source or reason, unless an accepted event of Force Majeure.
These Commercial Operation Date requirements are to be used solely for purposes of
determining when the Facility has achieved its Commercial Operation Date. They are not
intended to affect in any way when the Facility is deemed to have been “placed in service” for
purposes of tax treatment eligibility or purposes.
4.3 Seller covenants and agrees that before it delivers Test Energy to Buyer, it shall ensure
that it has done all of the following, and Buyer shall hold Buyer harmless from and against any
failure of Seller to have done so:
4.3.1 All Facility systems necessary for the stable, safe, reliable and consistent
operation of the installed Facility are substantially complete, any testing of the installed
Facility required pursuant to the Interconnection Agreement(s) and Interconnection
Provider documents and equipment supplier requirements have been successfully
completed, and the Facility is available for operation in all material respects in
accordance with the Requirements of Law.

4.3.2 Seller shall request and obtain written confirmation from the Buyer that all
Exhibit No. 4
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conditions to acceptance of Test Energy have been fulfilled. Such written confirmation
shall be provided within a commercially reasonable time following the Seller’s request
and will not be unreasonably withheld by the Buyer.
4.4 Continuing Obligations. Seller shall provide Buyer with the following during the Term of
this Agreement:
4.4.1 At Buyer’s request, Seller shall provide evidence that it is in compliance with the
insurance requirements set forth in Section 14.

4.4.2 Seller shall maintain compliance and remain in good standing in all requirements
of Sections 3 and 4 of this Agreement.
4.5 Commercial Operation Date Delay, Delay Damages and Deficit Damages.
4.5.1 If Commercial Operation is not achieved on or before the Scheduled Commercial
Operation Date, Seller shall pay to Idaho Power Delay Damages from and after the
Scheduled Commercial Operation Date up to, but not including, the date that the Facility
achieves Commercial Operation. Delay Damages cease to accrue in the event of
termination of this Agreement.

4.5.2 If the Facility does not achieve Commercial Operation by the Guaranteed
Commercial Operation Date, Idaho Power may terminate this Agreement pursuant to
Section 12.

4.5.3 If the Facility achieves Final Completion based on less than one hundred percent
(100%) of the Expected Nameplate Capacity Rating, Seller shall pay to Idaho Power
Deficit Damages.

After the date of Final Completion, any partially completed Solar Array shall not be part of the
Facility, and Seller shall not undertake to add any such partially completed Solar Array or output
from such partially completed Solar Array to the Facility without the prior written consent of
Idaho Power, such consent will not be unreasonably withheld.

4.6 Damages Calculation. Each Party agrees and acknowledges that (a) the damages that
Idaho Power would incur due to Seller’s delay in achieving Commercial Operation or failure to
reach Final Completion based on one hundred percent (100%) of the Expected Nameplate
Capacity Rating would be difficult or impossible to predict with certainty, and (b) it is
impractical and difficult to assess actual damages in the circumstances stated, and therefore the
Delay Damages and Deficit Damages as agreed to by the Parties and set forth herein are a fair
and reasonable calculation of such damages. The Parties agree that Delay Damages and Deficit
Damages shall be Idaho Power’s exclusive remedy for a delay in achieving Commercial
Operation or failure to reach Final Completion based on one hundred percent (100%) of the
Expected Nameplate Capacity Rating and believe that Delay Damages and Deficit Damages
fairly represent actual damages. Subject to the foregoing sentence, this Section 4.5 shall not limit
Seller’s termination rights or the amount of damages payable to Idaho Power if this Agreement is
Exhibit No. 4
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terminated as a result of Seller’s failure to achieve Commercial Operation by the Guaranteed
Commercial Operation Date. Any such termination damages shall be determined in accordance
with Section 12.4.
4.7 Damages Invoicing. By the tenth (10
th) day following the end of the calendar month in
which Delay Damages begin to accrue or Deficit Damages are incurred, as applicable, and
continuing on the tenth (10th) day of each calendar month during the period in which Delay
Damages accrue (and the following months, if applicable), Idaho Power shall deliver to Seller an
invoice showing Idaho Power’s computation of such damages and any amount due Idaho Power
in respect thereof for the preceding calendar month. No later than ten (10) days after receiving
such an invoice and subject to Sections 11.2 and 11.3, Seller shall pay to Idaho Power, by wire
transfer of immediately available funds to an account specified in writing by Idaho Power or by
any other means agreed to by the Parties in writing from time to time, the amount set forth as due
in such invoice.
4.8 Tax Credits. Seller shall notify Idaho Power whether Seller has elected to claim the ITC
within thirty (30) days following the date that Seller (or Seller’s Affiliate, on a consolidated
basis) files its first tax return after the Commercial Operation Date. Seller shall bear all risks,
financial and otherwise throughout the Term, associated with Seller’s or the Facility’s eligibility
to receive the ITC or other Tax Credits, or to qualify for accelerated depreciation for Seller’s
accounting, reporting or tax purposes. The obligations of the Parties hereunder, including those
obligations set forth herein regarding the purchase and price for and Seller’s obligation to deliver
Net Output, shall be effective regardless of whether the sale of Output or Net Output from the
Facility is eligible for, or receives, the ITC or other Tax Credits during the Term.
SECTION 5
DELIVERIES OF NET OUTPUT AND GREEN TAGS

5.1 Purchase and Sale. Except as otherwise expressly provided herein, commencing on the
Commercial Operation Date and continuing through the Term, Seller shall sell and make
available to Idaho Power, and Idaho Power shall purchase and receive (a) the entire Net Output
from the Facility at the Point of Delivery, and (b) all Green Tags associated with the Output or
otherwise resulting from the generation of energy by the Facility. Idaho Power shall be under no
obligation to make any purchase hereunder other than Net Output and all Green Tags, as
described above. Idaho Power shall not be obligated to purchase, receive or pay for Output (or
Green Tags associated with such Output) that is not delivered to the Point of Delivery. In
addition, during the period between the Effective Date and the Commercial Operation Date,
Seller shall sell and make available to Idaho Power, and Idaho Power shall purchase and receive,
all Net Output and Green Tags from the Facility as Test Energy at the price specified in Section
6.1.1.
5.2 No Sales to Third Parties. During the Term, Seller shall not sell any Net Output, energy,
Green Tags or Capacity Rights from the Facility to any party other than Idaho Power; provided,
however, that this restriction shall not apply during periods when Idaho Power is in default
hereof because it has failed to accept the Net Output or Green Tags delivered by Seller to Buyer
as required hereunder .
Exhibit No. 4
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5.3 Title and Risk of Loss of Net Output. Seller shall deliver Net Output, Green Tags and
Capacity Rights to Idaho Power free and clear of all liens, claims and encumbrances. Title to and
risk of loss of all Net Output shall transfer from Seller to Idaho Power upon its delivery to Idaho
Power at the Point of Delivery. Seller shall be deemed to be in exclusive control of, and
responsible for, any damage or injury caused by, all Output up to and at the Point of Delivery.
Idaho Power shall be deemed to be in exclusive control of, and responsible for, any damages or
injury caused by, Net Output after the Point of Delivery.
5.4 Curtailment.
5.4.1 Non-Compensable Curtailment. Except for Compensable Curtailment Energy in
accordance with Section 6.1.3, Idaho Power shall not be obligated to purchase, receive,
pay for, or pay any damages associated with, Net Output if such Net Output is not
delivered to the System or Point of Delivery for any of the following reasons: (a) the
interconnection between the Facility and the System is disconnected, suspended or
interrupted, in whole or in part, consistent with the terms of the Generation
Interconnection Agreement, (b) the Market Operator, Transmission Provider or Network
Service Provider directs a general curtailment, reduction, or redispatch of generation in
the area, (which would include the Net Output) for any reason (excluding curtailment of
purchases for general economic reasons unilaterally directed by the Market Operator or
Idaho Power acting solely in its merchant function capacity), even if and no matter how
such curtailment or redispatch directive is carried out by Idaho Power, which may fulfill
such directive by acting in its sole discretion; or if Idaho Power curtails or otherwise
reduces the Net Output in any way in order to meet its obligations to the Market
Operator, Transmission Provider or Network Service Provider to operate within system
limitations or otherwise, (c) the Facility’s Output is not received because the Facility is
not fully integrated or synchronized with the System, or (d) an event of Force Majeure
prevents either Party from delivering or receiving Net Output (each of the foregoing a
“Non-Compensable Curtailment”).
5.4.2 Curtailed Amount. The quantity of Non-Compensable Curtailment will be
calculated by determining the quantity of Net Output that would have been produced by
the Facility and delivered to the Point of Delivery had its generation not been so curtailed
under this Section 5.4. The quantity of such curtailed electric energy shall be determined
based on (a) the time and duration of the Non-Compensable Curtailment and (b) solar
conditions recorded at the Facility during the period of Non-Compensable Curtailment
and the production estimate based on the Solar Panels and Inverter performance
guaranties provided by Seller to Idaho Power in accordance with Exhibits 2 and 15.
Seller shall promptly provide Idaho Power with access to such information and data as
Idaho Power may reasonably require to confirm to its reasonable satisfaction the amount
of electric energy that was not generated or delivered because of a Non-Compensable
Curtailment.

5.4.3 Compensable Curtailment. Idaho Power shall pay Seller for Compensable
Curtailment Energy as set forth in Section 6.1.3.
Exhibit No. 4
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5.5 Idaho Power as Merchant. Seller acknowledges that Idaho Power, acting in its merchant
capacity function as purchaser under this Agreement, has no responsibility for or control
over Idaho Power Transmission or any successor Transmission Provider.

5.6 Green Tags.
5.6.1 Title. Idaho Power will be granted ownership of 100% of the Green Tags and
Environmental Attributes associated with the Facility. Title to 100% of the Green Tags
and Environmental Attributes shall pass from Seller to Idaho Power immediately upon
the generation of the Output at the Facility that gives rise to such Green Tags or
Environmental Attributes. Idaho Power’s title to 100% of the Environmental Attributes
and Green Tags shall expire at the end of the term of this Agreement with respect to
Output generated after the end of the term of this Agreement, unless the Parties agree to
extend in future agreements. If after the Effective Date and during the term of this
Agreement any additional Green Tags, Environmental Attributes or similar
environmental value is created by legislation, regulation, or any other action, including
but not limited to, carbon credits and carbon offsets, Idaho Power shall be granted
ownership of 100% of these additional Green Tags and Environmental Attributes and
environmental values that are associated with the Net Output delivered by the Seller to
Idaho Power. Seller shall use prudent and commercially reasonable efforts to ensure that
any operations of the Facility do not jeopardize the current or future Green Tags or
Environmental Attribute status of this solar generation Facility. Seller will deliver all of
the Green Tags and Environmental Attributes generated by the Facility during the Term,
without substitution of Green Tags or Environmental Attributes from any other source.

5.6.2 Documentation. At least sixty (60) days prior to the First Generation Date, the
Parties shall mutually cooperate to enable Idaho Power’s Green Tags and Environmental
Attributes from this Facility to be placed into the WREGIS account designated by Idaho
Power’s or any other Green Tag or Environment Attribute accounting and tracking
system selected by the Idaho Power. The Seller at the Seller’s sole expense will be
responsible to establish and maintain the Seller’s WREGIS or other Green Tag and
Environmental Attribute account and/or system that enables the creation of the
Environmental Attribute certificates associated with this Facility and the transfer of 100%
of the Green Tags and Environmental Attributes to Idaho Power for the Term of this
Agreement. If the Green Tag or Environmental Attribute accounting and tracking system
initially selected by Idaho Power is materially altered or discontinued during the Term of
this Agreement, the Parties shall cooperate to identify an appropriate alternative Green
Tag or Environmental Attribute accounting and tracking process and enable the Green
Tag or Environmental Attributes be processed through this alternative method.

5.6.3 Seller, at its own cost and expense, shall register with, pay all fees required by,
and comply with, all reporting and other requirements of WREGIS relating to the Facility
or Green Tags. Seller shall ensure that the Facility will participate in and comply with,
during the Term, all aspects of WREGIS. Seller shall, at its sole expense, effectuate the
transfer of WREGIS Certificates to Idaho Power’s WREGIS account in accordance with
Exhibit No. 4
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WREGIS Operating Rules. Seller may either elect to enter into a Qualified Reporting
Entity Services Agreement with Idaho Power in a form similar to that in Exhibit 20 or
elect to retain a third-party or act as its own WREGIS-defined Qualified Reporting
Entity; provided, however, that if the Facility is in Idaho Power’s balancing authority
area, Seller must enter into a Qualified Reporting Entity Services Agreement with Idaho
Power in the form of Exhibit 20 and not do so with any third party. Unless the failure to
deliver WREGIS Certificates was caused by action of Idaho Power not acting in its
capacity as Qualified Reporting Entity under the Qualified Reporting Entity Services
Agreement, Idaho Power shall be entitled to a refund of the Green Tags Price Component
of Green Tags associated with any Net Output for which WREGIS Certificates are not
delivered, and shall not transfer the affected Green Tags back to Seller, provided that
Seller shall have thirty (30) days after the conclusion of any applicable WREGIS dispute
resolution process to correct any error and deliver such WREGIS Certificates to Idaho
Power or provide such refund payment. Seller shall promptly provide Idaho Power
copies of all documentation it submits to WREGIS. If WREGIS changes the WREGIS
Operating Rules after the execution of this Agreement or applies the WREGIS Operating
Rules in a manner inconsistent with this Agreement after the execution of this
Agreement, the Parties will promptly cooperate as reasonably required to cause and
enable Seller to deliver WREGIS Certificates associated with the Output to Idaho
Power’s WREGIS account. Further, in the event of the promulgation of a scheme
involving Green Tags administered by a Governmental Authority, upon notification by
such Governmental Authority that any transfers contemplated by this Agreement will not
be recorded, the Parties shall promptly cooperate in taking all reasonable actions
necessary so that such transfers can be recorded.

5.6.4 If Idaho Power requests additional Environmental Attribute certifications beyond
what is provided by the WREGIS process the Seller shall use its best efforts to obtain any
Environmental Attribute certifications required by Idaho Power for those Environmental
Attributes delivered to Idaho Power from the Seller. If the Seller incurs cost, as a result of
Idaho Power’s request, and if the additional certification provides benefits to both Parties,
the Parties shall share the costs in proportion to the additional benefits obtained. If Idaho
Power elects to obtain its own certifications, then Seller shall fully cooperate with Idaho
Power in obtaining such certification.
5.6.5 Publicity. Seller shall not make any public statement or report under any program
that any of the Green Tags purchased by Idaho Power hereunder belong to any person
other than Idaho Power. Seller shall reasonably cooperate in any registration by Idaho
Power of the Facility in the renewable portfolio standard or equivalent program in all
such further states and programs in which Idaho Power may wish to register or
maintained registered the Facility by providing copies of all such information as Idaho
Power reasonably requires for such registration.
5.6.6 Renewable Claims. Seller shall not report in any public communication, or under
any program, that any of the Environmental Attributes or part thereof provided to Buyer
hereunder belong to any Person other than Buyer or Customer. Seller hereby irrevocably
assigns to Buyer all rights, title and interest in the Environmental Attributes for Buyer to
Exhibit No. 4
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own, hold and transfer to Customer, including any rights associated with any renewable
energy information or tracking system that exists or may be established (including
participation in any applicable Environmental Attribute registration or tracking program)
with regard to monitoring, registering, tracking, certifying, or trading such Environmental
Attributes. Seller will not claim the Green Tags, Environmental Attributes or other
“renewable energy,” “green energy,” “clean energy” or similar attributes of the Output or
the Facility as belonging to the Seller or any Seller Affiliate or to any person or entity
other than Idaho Power or Customer. Seller shall promptly report to Buyer any such
claims made by third parties of which Seller becomes aware. To the extent that any such
public communication is allowed under this Agreement, in any public communication
concerning the Facility, Facility Energy or the Environmental Attributes, Seller must at
all times be fully compliant with the Federal Trade Commission’s “Green Guides,” 77
Federal Register 62122, including 16 Code of Federal Regulations §260.15. The Parties
agree to work together in good faith to cause the correction of any confusing or
misleading claim or public communications made by a Party or a third party concerning
any relationship with each other or each other’s Affiliates, the Environmental Attributes,
or the Facility. Seller covenants not to collect for its own benefit any cryptocurrency,
blockchain, and similar or related commodities, tokens, or anything of actual, potential,
or theoretical value related to, measured by, or associated with Facility Energy or based
upon or relating to Facility Energy.

5.7 Purchase and Sale of Capacity Rights. For and in consideration of Idaho Power’s
agreement to purchase from Seller the Facility’s Net Output and Green Tags on the terms and
conditions set forth herein, Seller transfers to Idaho Power, and Idaho Power accepts from Seller,
all right, title, and interest that Seller may have in and to Capacity Rights, if any, existing during
the Term.
5.8 Representation Regarding Ownership of Capacity Rights. Seller represents that it has not
sold, and covenants that during the Term it will not sell or attempt to sell to any other person or
entity the Capacity Rights, if any. During the Term, Seller shall not report to any person or entity
that the Capacity Rights, if any, belong to anyone other than Idaho Power. Idaho Power may at
its own risk and expense report to any person or entity that Capacity Rights exclusively belong to
it.
5.9 Authority to Make Sales. Seller covenants that during the Term it will maintain all
required regulatory authority to make wholesale sales from the Facility to Idaho Power.
5.10 Further Assurances. At Idaho Power’s request, the Parties shall execute such documents
and instruments as may be reasonably required to effect recognition and transfer of the Net
Output or Capacity Rights, if any, to Idaho Power or Green Tags to Customer.
SECTION 6
CONTRACT PRICE; COSTS
6.1 Contract Price includes Green Tags and Capacity Rights. Idaho Power shall pay Seller
the prices stated below for all deliveries of Net Output, Green Tags and Capacity Rights, up to
Exhibit No. 4
Case No. IPC-E-24-16
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the Maximum Delivery Rate. The price provided for Test Energy in Section 6.1.1 and the
Contract Price provided for in Section 6.1.2, and the Compensable Curtailment Price provided
for in Section 6.1.3 include the consideration to be paid by Idaho Power to Seller for all Net
Output, Green Tags, Capacity Rights and Test Energy, respectively, and Seller shall not be
entitled to any compensation over and above the Contract Price or the Test Energy price, as the
case may be, for the Green Tags and Capacity Rights associated therewith.

6.1.1 Test Energy and Net Output Before Commercial Operation Date. Between the
Effective Date and the Commercial Operation Date, Seller shall sell and deliver to Idaho
Power all Test Energy and Net Output. Idaho Power shall pay Seller for such Test Energy
and Net Output delivered at the Point of Delivery, an amount per MWh equal to eighty-
five percent (85%) of the Market Price Index for the applicable hour on the applicable
day in the applicable month, provided, however, that Seller’s right to receive payment for
such Test Energy and Net Output is subject to Idaho Power’s right of offset under Section
11.2 for, among other things, payment by Seller of any Delay Damages owed to Idaho
Power by Seller pursuant to Section 4.4 and Section 9.1.2.

6.1.2 Net Output After Commercial Operation Date. For the period beginning on the
Commercial Operation Date and thereafter during the Term, Idaho Power shall pay to
Seller the Contract Price per MWh of Net Output delivered to the Point of Delivery, as
specified in Exhibit 4.

6.1.3 Compensable Curtailment. If, during the period beginning on the Commercial
Operation Date and thereafter during the Term, Net Output is curtailed by Idaho Power
and such curtailment is not included as a Non-Compensable Curtailment (“Compensable
Curtailment Energy”), then Idaho Power shall pay to Seller the Compensable Curtailment
Price for the Compensable Curtailment Energy, as determined below.
6.1.3.1 The Parties will calculate the quantity of Compensable Curtailment
Energy by determining the Potential Net Output (A) during those periods of time
when the Facility is on GOLC and the GOLC Set-Point is set at a level that will
not allow the entire Nameplate Capacity Rating to be deliverable by determining
the difference between Potential Net Output and the delivered Net Output, and
(B) during those periods of time when the Facility is not on GOLC or the GOLC
Set-Point is set at a level that will allow the Nameplate Capacity Rating to be
deliverable by determining the amount that would have been available for
delivery had its generation not been so curtailed. Compensable Curtailment
Energy shall equal the number of kWh represented by the Potential Net Output
less the Net Output actually delivered to the Point of Delivery.

6.1.3.2 Idaho Power will pay Seller the Contract Price for each kWh of
Compensable Curtailment Energy, net of any Non-Compensable Curtailments
(the “Compensable Curtailment Price”).
Exhibit No. 4
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6.1.3.3 For purposes of determining Compensable Curtailment Energy, the amount of Potential
Net Output at any given time will be calculated using Idaho Power’s solar forecasting
vendor/tool. 6.2 Costs and Charges. Seller shall be responsible for paying or satisfying
when due all costs or charges imposed in connection with the scheduling and delivery of Net
Output up to and at the Point of Delivery, including transmission costs, Transmission Service,
and transmission line losses, and any operation and maintenance charges imposed by
Interconnection Provider and Transmission Provider for the Interconnection Facilities. Idaho
Power shall be responsible for all costs or charges, if any, imposed in connection with the
delivery of Net Output at and from the Point of Delivery, including transmission costs and
transmission line losses and imbalance charges or penalties. Without limiting the generality of
the foregoing, Seller, in accordance with the Generation Interconnection Agreement, shall bear
all costs associated with the modifications to Interconnection Facilities or the System (including
system upgrades) caused by or related to (a) the interconnection of the Facility with the System
and (b) any increase in generating capacity of the Facility.
6.3 Station Service. Seller shall be responsible for arranging and obtaining, at its sole risk and
expense, any station service required by the Facility that is not provided by the Facility itself.
6.4 Taxes. Seller shall pay or cause to be paid when due, or reimburse Idaho Power for, all
existing and any new sales, use, excise, severance, ad valorem, and any other similar taxes,
imposed or levied by any Governmental Authority on the Net Output, Capacity Rights or Green
Tags up to and including, but not beyond, the Point of Delivery, regardless of whether such taxes
are imposed on Idaho Power or Seller under Requirements of Law. Idaho Power shall pay or
cause to be paid when due all such taxes imposed or levied by any Governmental Authority on
the Net Output, Capacity Rights or Green Tags beyond the Point of Delivery, regardless of
whether such taxes are imposed on Idaho Power or Seller under Requirements of Law. The
Contract Price shall not be adjusted on the basis of any action of any Governmental Authority
with respect to changes to or revocations of sales and use tax benefits, rebates, exception or give
back. In the event any taxes are imposed on a Party for which the other Party is responsible
hereunder, the Party on which the taxes are imposed shall promptly provide the other Party
written notice thereof and such other information as such Party may reasonably request with
respect to any such taxes. Seller shall be responsible for any and all sun and light severance
taxes.
6.5 Costs of Ownership and Operation. Without limiting the generality of any other provision
hereof and subject to Section 6.4, Seller shall be solely responsible for paying when due (a) all
costs of owning and operating the Facility in compliance with existing and future Requirements
of Law and the terms and conditions hereof, and (b) all taxes and charges (however
characterized) now existing or hereinafter imposed on or with respect to the Facility, its
operation, or on or with respect to emissions or other environmental impacts of the Facility,
including any such tax or charge (however characterized) to the extent payable by a generator of
such energy or Environmental Attributes.
Exhibit No. 4
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6.6 Rates Not Subject to Review. The rates for service specified herein shall remain in effect
until expiration of the Term, and shall not be subject to change for any reason, including
regulatory review, absent agreement of the Parties. Neither Party shall petition FERC pursuant to
the provisions of Sections 205 or 206 of the Federal Power Act (16 U.S.C. § 792 et seq.) to
amend such prices or terms, or support a petition by any other person or entity seeking to amend
such prices or terms, absent the agreement in writing of the other Party. Further, absent the
agreement in writing by both Parties, the standard of review for changes hereto proposed by a
Party, a non-party or the FERC acting sua sponte shall be the “public interest” application of the
“just and reasonable” standard of review set forth in United Gas Pipe Line Co. v. Mobile Gas
Service Corp., 350 U.S. 332 (1956) and Federal Power Commission v. Sierra Pacific Power Co.,
350 U.S. 348 (1956) and clarified by Morgan Stanley Capital Group. Inc. v. Public Util. Dist.
No. 1 of Snohomish, 554 U.S. 527, 128 S. Ct. 2733 (2008).
SECTION 7
OPERATION AND CONTROL
7.1 As-Built Supplement. Within thirty (30) days of completion of construction of the
Facility, Seller shall provide Idaho Power the As-built Supplement. The As-built Supplement
shall be deemed effective and shall be added to Exhibit 16 when it has been reviewed and
approved by Idaho Power, which approval shall not be unreasonably withheld or delayed. If the
proposed As-built Supplement does not accurately describe the Facility as actually built or is
otherwise defective as to form in any material respect, Idaho Power may within fifteen (15) days
after receiving the proposed As-built Supplement give Seller a notice describing what Idaho
Power wishes to correct. If Idaho Power does not give Seller such a notice within the fifteen (15)
day period, the As-built Supplement shall be deemed approved. If Idaho Power provides a timely
notice requiring corrections, Seller shall in good faith cooperate with Idaho Power to revise the
As-built Supplement to address Idaho Power’s concerns. Notwithstanding the foregoing, Idaho
Power shall have no right to require Seller to relocate, modify or otherwise change in any respect
any aspect of the Facility as actually built.
7.2 Standard of Facility Operation.
7.2.1 General. At Seller’s sole cost and expense, Seller shall build, operate, maintain
and repair the Facility and the Interconnection Facilities in accordance with (a) the
applicable and mandatory standards, criteria and formal guidelines of FERC, NERC, any
RTO, and any other Electric System Authority and any successors to the functions
thereof; (b) the Permits and Required Facility Documents; (c) the Generation
Interconnection Agreement; (d) all Requirements of Law; (e) the requirements hereof;
and (f) Prudent Electrical Practice. Seller will have no claims against Idaho Power under
this Agreement with respect to the provision of station service.
7.2.2 Qualified Operator. From and after the Commercial Operation Date, Seller will
cause the Project to be operated and maintained by a Qualified Operator. Seller shall
provide Idaho Power thirty (30) days prior written notice of any proposed change in the
Qualified Operator of the Facility.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 370 of 1056
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7.2.3 Fines and Penalties.
7.2.3.1 Without limiting a Party’s rights under Section 7.2.3.2, each Party shall
pay all fines and penalties incurred by such Party on account of noncompliance by
such Party with Requirements of Law in respect to this Agreement, except where
such fines and penalties are being contested in good faith through appropriate
proceedings.
7.2.3.2 If fines, penalties, or legal costs are assessed against or incurred by either
Party (the “Indemnified Party”) on account of any action by any Governmental
Authority due to noncompliance by the other Party (the “Indemnifying Party”)
with any Requirements of Law or the provisions hereof, or if the performance of
the Indemnifying Party is delayed or stopped by order of any Governmental
Authority due to the Indemnifying Party’s noncompliance with any Requirements
of Law, the Indemnifying Party shall indemnify and hold harmless the
Indemnified Party against any and all losses, liabilities, damages, and claims
suffered or incurred by the Indemnified Party as a result thereof. Without limiting
the generality of the foregoing, the Indemnifying Party shall reimburse the
Indemnified Party for all fees, damages, or penalties imposed on the Indemnified
Party by any Governmental Authority, other person or entity or to other utilities
for violations to the extent caused by a default by the Indemnifying Party or a
failure of performance by the Indemnifying Party hereunder.

7.3 Interconnection. Seller shall be responsible for the costs and expenses associated with
obtaining from the Transmission Provider Network Resource interconnection service for the
Facility at its Nameplate Capacity Rating at the Point of Delivery. Seller shall have no claims
hereunder against Idaho Power, acting in its merchant function capacity, with respect to any
requirements imposed by or damages caused by (or allegedly caused by) acts or omissions of the
Transmission Provider or Interconnection Provider, in connection with the Generation
Interconnection Agreement or otherwise.
7.4 Coordination with System. Seller shall be responsible for the coordination and
synchronization of the Facility and the Interconnection Facilities with the System.
7.5 Outages.
7.5.1 Planned Outages. Except as otherwise provided herein, Seller shall not schedule a
Planned Outage during daylight hours (sun up to sunset) during any portion of the months
of November, December, January, February, June, July, and August, except to the extent
a Planned Outage is reasonably required to enable a vendor to satisfy a guarantee
requirement. Seller shall provide Idaho Power with an annual forecast of Planned
Outages for each Contract Year at least one (1) month, but no more than three (3)
months, before the first day of that Contract Year, and shall promptly update such
schedule, or otherwise change it, only to the extent that Seller is reasonably required to
change it in order to comply with Prudent Electrical Practices. Seller shall not schedule
any maintenance of Interconnection Facilities during such months, without the prior
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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36
written approval of Idaho Power, which approval shall not be unreasonably withheld or
delayed.
7.5.2 Maintenance Outages. If Seller reasonably determines that it is necessary to
schedule a Maintenance Outage, Seller shall notify Idaho Power in writing of the
proposed Maintenance Outage as soon as practicable but in any event at least five (5)
days before the outage begins (or such shorter period to which Idaho Power may
reasonably consent in light of then-existing solar conditions). Upon such notice, the
Parties shall plan the Maintenance Outage to mutually accommodate the reasonable
requirements of Seller and the service obligations of Idaho Power; provided, however,
that Seller shall take all reasonable measures consistent with Prudent Electrical Practices
to not schedule any Maintenance Outage during the daylight hours of the following
periods: November, December, January, February, June 15 through June 30, July,
August, and September 1 through September 15. Notice of a proposed Maintenance
Outage shall include the expected start date and time of the outage, the amount of
generation capacity of the Facility that will not be available, and the expected completion
date and time of the outage. Seller shall give Idaho Power notice of the Maintenance
Outage as soon as practicable after Seller determines that the Maintenance Outage is
necessary. Idaho Power shall promptly respond to such notice and may request
reasonable modifications in the schedule for the outage. Seller shall use all reasonable
efforts to comply with any request to modify the schedule for a Maintenance Outage
provided that such change has no substantial impact on Seller. Seller shall notify Idaho
Power of any subsequent changes in generation capacity available to Idaho Power as a
result of such Maintenance Outage or any changes in the Maintenance Outage completion
date and time. As soon as practicable, any notifications given orally shall be confirmed in
writing. Seller shall take all reasonable measures consistent with Prudent Electrical
Practices to minimize the frequency and duration of Maintenance Outages.
Notwithstanding anything in this Section 7.5.2 to the contrary, Seller may schedule a
Maintenance Outage at any time and without the requirement to notify Idaho Power five
(5) days in advance during conditions of low solar insolation, but shall notify Idaho
Power promptly after Seller decides to schedule such Maintenance Outage.
7.5.3 Forced Outages. Seller shall promptly provide to Idaho Power an oral report, via
telephone to a number specified by Idaho Power (or other method approved by Idaho
Power), of any Forced Outage resulting in more than ten percent (10%) of the Nameplate
Capacity Rating of the Facility being unavailable. This report shall include the amount of
the generation capacity of the Facility that will not be available because of the Forced
Outage and the expected return date of such generation capacity. Seller shall promptly
update the report as necessary to advise Idaho Power of changed circumstances. As soon
as practicable, the oral report shall be confirmed in writing by notice to Idaho Power.
Seller shall take all reasonable measures consistent with Prudent Electrical Practices to
avoid Forced Outages and to minimize their duration.
7.5.4 Notice of Deratings and Outages. Without limiting the foregoing, Seller will
inform Idaho Power, via telephone to a number specified by Idaho Power (or other
method approved by Idaho Power), of any major limitations, restrictions, deratings or
Exhibit No. 4
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Page 372 of 1056
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outages known to Seller affecting the Facility for the following day (except curtailments
of Net Output at the direction of Idaho Power) and will promptly update Seller’s notice to
the extent of any material changes in this information, with “major” defined as affecting
more than five percent (5%) of the Nameplate Capacity Rating of the Facility.

7.5.5 Effect of Outages on Estimated Output. Seller represents and warrants that the
estimated monthly net output set forth on Exhibit 4 takes into account the Planned
Outages, Maintenance Outages, and Forced Outages that Seller reasonably expects to
encounter in the ordinary course of operating the Facility.
7.6 Scheduling.
7.6.1 Cooperation and Standards. With respect to any and all scheduling requirements
hereunder, (a) Seller shall cooperate with Idaho Power with respect to scheduling Net
Output, and (b) each Party shall designate authorized representatives to communicate
with regard to scheduling and related matters arising hereunder. Each Party shall comply
with the applicable variable resource standards and criteria of any applicable Electric
System Authority.
7.6.2 Schedule Coordination. If, as a result hereof, Idaho Power is deemed by an RTO
to be financially responsible for Seller’s performance under the Generation
Interconnection Agreement, due to Seller’s lack of standing as a “scheduling coordinator”
or other RTO recognized designation, qualification or otherwise, then Seller shall acquire
such RTO recognized standing (or shall contract with a third party who has such RTO
recognized standing) such that Idaho Power is no longer responsible for Seller’s
performance under the Generation Interconnection Agreement or RTO requirement.
7.7 Forecasting.
7.7.1 Solar Energy Production Forecast. “Solar Energy Production Forecast” means the
Idaho Power administered solar forecasting model for all solar projects that are under
contract to provide energy to Idaho Power. The Seller shall be responsible for an
allocated portion of the total costs of the forecasting model and to provide solar
irradiation and weather data specified in Section 7.7.2.
7.7.2 Solar Energy Production Forecast Cost and Data. Seller shall contribute to the
cost of the Solar Energy Production Forecasting. The Facility’s share of Solar Energy
Production Forecasting is determined as specified below. Seller’s payments for the cost
of the Solar Energy Production Forecasting in any Contract Year will not be greater than
0.1% of the total energy payments made to Seller by Idaho Power hereunder during the
previous Contract Year.
a. For every month of this Agreement beginning with the first full month after the
First Energy Date as specified in this Agreement, the Solar Energy Production
Forecasting Monthly Cost Allocation (MCA) will be due and payable by the
Seller. Any Solar Energy Production Forecasting Monthly Cost Allocations
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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(MCA) that are not reimbursed to Idaho Power shall be deducted from energy
payments to the Seller.
b. During the first Contract Year, as the value of the 0.1% cap of the total energy
payments to be made to Seller by Idaho Power hereunder will not be known until
the first Contract Year is complete, Idaho Power will deduct the Facility’s
calculated share of the Solar Energy Production Forecasting costs specified in
item d each month during the first Contract Year and subsequently refund any
overpayment (payments that exceed the cap) in equal monthly amounts over the
ensuing Contract Year.

c. The cost allocation formula described below will be reviewed and revised if
necessary on the last day of any month in which the cumulative MW nameplate of
Solar projects having IPUC approved agreements to deliver energy to Idaho
Power has been revised by an action of the IPUC.

d. The monthly cost allocation will be based upon the following formula:

Where: Total MW (TMW) is equal to the total Nameplate Capacity rating of all solar
projects that are under contract to provide energy to Idaho Power Company.

Facility MW (FMW) is equal to the Expected Nameplate Capacity rating of this Facility
as specified within this Agreement.

Annual Solar Energy Production Forecasting Cost (AFCost) is equal to the total
annual cost Idaho Power incurs to provide Solar Energy Production Forecasting. Idaho
Power will estimate the AFCost for the current year based upon the previous year’s cost
and expected costs for the current year. At year-end, Idaho Power will compare the actual
costs to the estimated costs and any differences between the estimated AFCost and the
actual AFCost will be included in the next year’s AFCost.
Annual Cost Allocation (ACA) = AFCost X (FMW/TMW)

And

Monthly Cost Allocation (MCA) = ACA / 12

e. The Solar Energy Production Forecasting Monthly Cost Allocation (MCA) is due
and payable to Idaho Power. The MCA will first be netted against any monthly
energy payments owed to the Seller. If the netting of the MCA against the
monthly energy payments results in a balance being due Idaho Power, the Facility
shall pay this amount within fifteen (15) days of the date of the payment invoice.
7.7.2.1 The Seller shall also provide solar irradiation and weather data specific to the
Facility’s physical location to Idaho Power via real time telemetry in a form
acceptable to Idaho Power. The specific equipment and location of this equipment
Exhibit No. 4
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E. Hackett, IPC
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shall be specified in the GIA. This data will provided at 10 second intervals and will
consist of:
a.) Global Horizontal Irradiance
b.) Plane of Array
c.) Temperature
d.) Wind Speed and Direction

7.8 No Increase in Nameplate Capacity Rating. Without limiting Section 8 or any restrictions
herein on Nameplate Capacity Rating, Seller may not increase the ability of the Facility to
deliver Net Output in quantities in excess of the Maximum Delivery Rate through any means,
including replacement or modification of Facility equipment or related infrastructure, without
consent of Idaho Power, which Idaho Power may grant or withhold in its sole and absolute
discretion.
7.9 Electronic Communications.
7.9.1 GOLC.
7.9.1.1 Beginning on the Commercial Operation Date, Idaho Power will dispatch
Facility through its GOLC system installed by Seller.
Idaho Power may notify Seller, by telephonic communication or through use of
the GOLC Set-Point, to curtail the delivery of Net Output to Idaho Power from
the Facility and to the Point of Delivery, pursuant to Section 5.4, and Seller shall
promptly comply with such notification.

The GOLC Set-Point is calculated by the Transmission Provider and
communicated electronically through the SCADA system. Seller shall ensure
that, throughout the Term, the SCADA signal is capable of functioning on all
GOLC Set-Points within the margin of error specified in the Facility control
system manufacturer’s set point margin of error.

Unless otherwise directed by Idaho Power, Seller shall ensure that the Facility
GOLC is in “Remote” set-point control during normal operations.

7.9.2 Telemetering. Seller shall during the Term provide telemetering equipment and
facilities capable of transmitting the following information concerning the Facility
pursuant to the Generation Interconnection Agreement and to Idaho Power on a real-time
basis, and will operate such equipment when requested by Idaho Power to indicate
instantaneous MW output at the Point of Delivery.

Commencing on the date of initial delivery of Test Energy, Seller shall also transmit or
cause to be transmitted to or make accessible to Idaho Power any other data from the
Facility that Seller receives on a real time basis, including meteorological data, solar
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 375 of 1056
40
insolation data and Net Output data. Such real time data shall be provided to or be made
accessible to Idaho Power and Customer on the same basis on which Seller receives the
data (e.g., if Seller receives the data in four second intervals, Idaho Power shall also
receive the data in four second intervals). Seller must provide Idaho Power and Customer
access to Seller’s web-based performance monitoring system.

7.9.3 Transmission Provider Consent. Seller shall execute a consent, in the form
required by Transmission Provider, to provide that Idaho Power can read the meter and
receive any and all data from the Transmission Provider relating to transmission of Net
Output or other matters relating to the Facility without the need for further consent from
Seller.
7.9.4 Dedicated Communication Circuit. Seller shall install a dedicated direct
communication circuit (which may be by common carrier telephone) between Idaho
Power and the control center in the Facility’s control room or such other communication
equipment as the Parties may agree.
7.10 Reports and Records.
7.10.1 Monthly Reports. Commencing on the Commercial Operation Date, within thirty
(30) days after the end of each calendar month during the Term (each, a “Reporting
Month”), Seller shall provide to Idaho Power a report in electronic format, which report
shall include (a) summaries of the Facility’s solar insolation and actual and predicted
output data for the Reporting Month in intervals not to exceed one hour (or such shorter
period as is reasonably possible with commercially available technology), including
information from the Facility’s computer monitoring system; (b) summaries of any other
significant events related to the construction or operation of the Facility for the Reporting
Month; and (c) any supporting information that Idaho Power may from time to time
reasonably request (including historical solar insolation data for the Facility).
7.10.2 Electronic Fault Log. Seller shall maintain an electronic fault log of operations of
the Facility during each hour of the Term commencing on the Commercial Operation
Date. Seller shall provide Idaho Power with a copy of the electronic fault log within thirty
(30) days after the end of the calendar month to which the fault log applies.
7.10.3 Other Information to be Provided to Idaho Power. Seller shall provide to Idaho
Power and Customer the following information concerning the Facility:
7.10.3.1 Upon the request of Idaho Power, the manufacturers’ guidelines
and recommendations for maintenance of the Facility equipment;
7.10.3.2 A report summarizing the results of maintenance performed during
each Maintenance Outage, Planned Outage, and any Forced Outage, and upon
request of Idaho Power any of the technical data obtained in connection with such
maintenance;

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 376 of 1056
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7.10.3.3 Before Final Completion, a monthly progress report stating the
percentage completion of the Facility and a brief summary of construction activity
during the prior month;
7.10.3.4 Before Final Completion, a monthly report containing a brief
summary of construction activity contemplated for the next calendar month;

7.10.3.5 From and after the Commercial Operation Date, a monthly report
detailing the availability of the Facility; and
7.10.3.6 At any time from the Effective Date, one year’s advance notice of
the termination or expiration of any material agreement, including Leases,
pursuant to which the Facility or any material equipment relating thereto is upon
the Premises; provided that the foregoing does not authorize any early termination
of any land lease. In the event Seller has less than one year’s advance notice of
such termination or expiration, Seller shall provide the notice contemplated by
this Section to Idaho Power within fifteen (15) Business Days of Seller obtaining
knowledge of the termination or expiration.

7.10.4 Information to Governmental Authorities. Seller shall, promptly upon written
request from Idaho Power, provide Idaho Power with all data collected by Seller related
to the construction, operation or maintenance of the Facility reasonably required by Idaho
Power or an Affiliate thereof for reports to, and information requests from, any
Governmental Authority or Electric System Authority. Along with this information,
Seller shall provide to Idaho Power copies of all submittals to Governmental Authorities
or Electric System Authorities directed by Idaho Power and related to the operation of the
Facility with a certificate that the contents of the submittals are true and accurate to the
best of Seller’s knowledge. Seller shall use best efforts to provide this information to
Idaho Power with sufficient advance written notice to enable Idaho Power to review such
information and meet any submission deadlines imposed by the requesting organization
or entity. Idaho Power shall reimburse Seller for all of Seller’s reasonable actual costs
and expenses in excess of $10,000 per year, if any, incurred in connection with Idaho
Power’s requests for information under this Section 7.10.4.
7.10.5 Data Request. Seller shall, promptly upon written request from Idaho Power,
provide Idaho Power with data collected by Seller related to the construction, operation
or maintenance of the Facility reasonably required for information requests from any
Governmental Authorities, state or federal agency intervener or any other party achieving
intervenor status in any Idaho Power rate proceeding or other proceeding before any
Governmental Authority. Seller shall use best efforts to provide this information to Idaho
Power sufficiently in advance to enable Idaho Power to review it and meet any
submission deadlines. Idaho Power shall reimburse Seller for all of Seller’s reasonable
actual costs and expenses in excess of $10,000 per year, if any, incurred in connection
with Idaho Power’s requests for information under this Section 7.10.5.
7.10.6 Documents to Governmental Authorities. After sending or filing any statement,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
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application, and report or any document with any Governmental Authority or Electric
System Authority relating to operation and maintenance of the Facility, Seller shall,
within five (5) Business Days of such submission or filing, provide to Idaho Power a
copy of the same.
7.10.7 Environmental Information. Seller shall, promptly upon written request from
Idaho Power, provide Idaho Power with all data reasonably requested by Idaho Power
relating to environmental information under the Required Facility Documents. Seller
shall further provide Idaho Power with information relating to environmental impact
mitigation measures it is taking in connection with the Facility’s construction or
operation that are required by any Governmental Authority. Idaho Power shall reimburse
Seller for all of Seller’s reasonable actual costs and expenses in excess of $10,000 per
year, if any, incurred in connection with Idaho Power’s requests for the foregoing
information under this Section 7.10.7. As soon as it is known to Seller, Seller shall
disclose to Idaho Power, the extent of any material violation of any environmental laws
or regulations arising out of the construction, operation, or maintenance of the Facility, or
the presence of Environmental Contamination at the Facility or on the Premises, alleged
to exist by any Governmental Authority having jurisdiction over the Premises, or the
present existence of, or the occurrence during Seller’s occupancy of the Premises of, any
enforcement, legal, or regulatory action or proceeding relating to such alleged violation
or alleged presence of Environmental Contamination presently occurring or having
occurred during the period of time that Seller has occupied the Premises.
7.10.8 Operational Reports. Seller shall provide Idaho Power monthly operational
reports in a form and substance reasonably acceptable to Idaho Power, and Seller shall,
promptly upon written request from Idaho Power, provide Idaho Power with all
operational data requested by Idaho Power with respect to the performance of the Facility
and delivery of Net Output, Green Tags or Capacity Rights therefrom.
7.10.9 Notice of Material Adverse Events. Seller shall promptly notify Idaho Power of
receipt of written notice or actual knowledge by Seller or its Affiliates of the occurrence
of any event of default under any material agreement to which Seller is a party and of any
other development, financial or otherwise, which would have a material adverse effect on
Seller, the Facility or Seller’s ability to develop, construct, operate, maintain or own the
Facility as provided herein. Seller shall promptly disclose to Buyer and Customer (but in
no case later than two (2) Business Days after Seller obtains actual knowledge) any
violation of any Applicable Laws arising out of the construction or operation of the
Facility by Seller, its Affiliates or any contractor of any of them, including any Qualified
Operator, or the existence of any past or present enforcement, legal, or regulatory action
or proceeding relating to the Facility, if such violation, action or proceeding adversely
affects or could reasonably be expected to adversely affect the construction or operation
of the Facility or the commercial reputation of Buyer, Customer or any of their respective
Affiliates.
7.10.10 Notice of Litigation. Following its receipt of written notice or actual
knowledge of the commencement of any action, suit, or proceeding before any court or
Exhibit No. 4
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Governmental Authority against Seller or its members with respect to this Agreement or
the transactions contemplated hereunder, Seller shall, within ten (10) days of such notice
or knowledge, give written notice to Idaho Power of the same. Following its receipt of
written notice or actual knowledge of the commencement of any action, suit or
proceeding before any court or Governmental Authority against Seller, its members or
any Affiliate, the effect of which would materially and adversely affect Seller’s
performance of its obligations hereunder, Seller shall, within ten (10) days of such notice
or knowledge, give notice to Idaho Power of the same.
7.10.11 Additional Information. Seller shall provide to Idaho Power and Customer
such other information respecting the condition or operations of Seller, as such pertains to
Seller’s performance of its obligations hereunder, or the Facility as Idaho Power or
Customer may, from time to time, reasonably request.
7.10.12 Confidential Treatment. The monthly reports and other information
provided to Idaho Power under this Section 7.10 shall be treated as Confidential Business
Information if such treatment is requested in writing by Seller at the time the information
is provided to Idaho Power, subject to Idaho Power’s rights to disclose such information
pursuant to Sections 7.10.4, 7.10.5, 7.10.7, 11.5, 25.2 and 25.3, and pursuant to any
applicable Requirements of Law. Seller shall have the right to seek confidential treatment
of any such information from the Governmental Authority entitled to receive such
information.
7.11 Financial and Accounting Information. If Idaho Power or one of its Affiliates determines
that, under (i) the Accounting Standards Codification (ASC) 810, Consolidation of Variable
Interest Entities, and (ii) Requirements of Law that it may hold a variable interest in Seller, but it
lacks the information necessary to make a definitive conclusion, Seller hereby agrees to provide,
upon Idaho Power’s written request, sufficient financial and ownership information so that Idaho
Power or its Affiliate may confirm whether a variable interest does exist under ASC 810 and
Requirements of Law. If Idaho Power or its Affiliate determines that, under ASC 810, it holds a
variable interest in Seller, Seller hereby agrees to provide, upon Idaho Power’s written request,
sufficient financial and other information to Idaho Power or its Affiliate so that Idaho Power may
properly consolidate the entity in which it holds the variable interest or present the disclosures
required by ASC 810 and Requirements of Law. Idaho Power shall reimburse Seller for Seller’s
reasonable costs and expenses, if any, incurred in connection with Idaho Power’s requests for
information under this Section 7.11.
7.12 Output Guarantee.
7.12.1 Output Guarantee. Seller is obligated to deliver a quantity of Net Output during
each month which is equal to the Output Guarantee. For purposes of this Agreement,
“Output Guarantee” for any month means the sum of (i) 90% of the Expected Energy of
the Facility for such month, less (ii) any quantities of Output that were not delivered to
the Point of Delivery (or accepted by Idaho Power) in such month during periods
constituting Seller Uncontrollable Minutes (such quantity calculated on the basis of the
Net Output capable of being delivered in an hour at an average rate equivalent to the
Exhibit No. 4
Case No. IPC-E-24-16
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44
actual Nameplate Capacity Rating).
7.12.1.2 Seller’s Adjustment of Estimated Monthly Net Output Amounts in
Exhibit 4 After the Commercial Operation Date. After the Commercial Operation
Date, the Seller may revise any future estimated monthly Net Output amounts in
Exhibit 4 by providing written notice no later than 5 PM Mountain Time on the 25 th
day of the month that is prior to the month to be revised. If the 25 th day of the month
falls on a weekend or holiday, then written notice must be received on the last
Business Day prior to the 25th day of the month. For example, if the Seller would
like to revise the Estimated Net Output Amount for October, they would need to
submit a revised schedule no later than September 25th or the last Business Day prior
to September 25th.
a.) This written notice must be provided to Idaho Power in
accordance with Section 24.1 or by electronic notice as agreed to
by both Parties.
b.) Failure to provide timely written notice of changes to the
Estimated Net Output Amounts will be deemed to be an election
of no change from the most recently provided monthly Estimated
Net Output Amounts.

7.12.2 Liquidated Damages for Output Shortfall.
7.12.2.1 If the quantity of Net Output delivered by the Facility during any
month is equal to or greater than the Output Guarantee for such month, Seller’s
delivery obligation for such month shall be deemed satisfied for that month.

7.12.2.2 If the quantity of Net Output delivered by the Facility during any
month is less than the Output Guarantee for such month, the resulting shortfall, if
any, shall be determined for that month (the “Output Shortfall”). The Output
Shortfall shall be expressed in MWh and calculated in accordance with the
following formula:

Output Shortfall = (90% of the Expected Energy for the month).

less

Any quantities of Output that were not delivered to the Point of Delivery (or
accepted by Idaho Power) in such month during periods constituting Seller
Uncontrollable Minutes (such quantity calculated on the basis of the Net Output
capable of being delivered in an hour at an average rate equivalent to the actual
Nameplate Capacity Rating),

less

The Net Output for the month.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 380 of 1056
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7.12.2.3 If the product of the Output Shortfall calculation set forth in
Section 7.12.2.1 is a positive number, Seller shall pay Idaho Power liquidated
damages equal to the product of (i) the Output Shortfall for that month, multiplied
by (ii) Idaho Power’s Cost to Cover for that month. If the product of the Output
Shortfall calculation set forth in Section 7.12.2.1 is a negative number, Seller shall
not be obligated to pay Idaho Power liquidated damages for such month.

7.12.2.4 Each Party agrees and acknowledges that (i) the damages that
Idaho Power would incur due to the Facility’s failure to achieve the Output
Guarantee would be difficult or impossible to predict with certainty and (ii) the
liquidated damages contemplated by this provision are a fair and reasonable
calculation of such damages.

7.13 Access Rights. Upon reasonable prior notice and subject to the prudent safety
requirements of Seller, and Requirements of Law relating to workplace health and safety, Seller
shall provide Idaho Power and its authorized agents, employees and inspectors (“Idaho Power
Representatives”) with reasonable access to the Facility: (a) for the purpose of reading or testing
metering equipment, (b) as necessary to witness any acceptance tests, (c) to provide tours of the
Facility to customers and other guests of Idaho Power (not more than twelve (12) times per
year), (d) for purposes of implementing Sections 2.7 or 10.5, and (e) for other reasonable
purposes at the reasonable request of Idaho Power. Idaho Power shall release Seller from any and
all Liabilities resulting from actions or omissions by any of the Idaho Power Representatives in
connection with their access to the Facility, except to the extent that such Liabilities are caused
by the intentional or negligent act or omission of Seller or its agents or Affiliates.
7.14 Facility Images. Idaho Power shall be free to use any and all images from or of the
Facility for promotional purposes, subject to Seller’s consent (not to be unreasonably withheld or
delayed, and which consent may consider Requirements of Law relating to Premises security,
obligations to outside vendors (including any confidentiality obligations), and the corporate
policies of Seller’s Affiliates). Upon Idaho Power’s request and at Idaho Power’s expense, Seller
shall install imaging equipment at the Facility as Idaho Power may request, including video and
or web-based imaging equipment subject to the prudent safety requirements of Seller, and
Requirements of Law relating to workplace health and safety. Idaho Power shall retain full
discretion on how such images are presented including associating images of the Facility with a
Idaho Power-designated corporate logo.
SECTION 8
RIGHT OF FIRST OFFER AND OWNERSHIP OR PURCHASE OPTION

8.1 For purposes of this Section 8, any reference to “Buyer” or “Idaho Power” shall also
mean Buyer’s or Idaho Power’s “Affiliate” as that term is defined in this Agreement.
8.2 Right of First Offer. If this Agreement is terminated for any reason prior to the
Commercial Operation Date, then during the Restricted Period, neither Seller nor any of Seller’s
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Affiliates may enter into any agreement to sell, or hedge the quantity of, Energy or Green Tags
generated by equipment installed at the Premises to any party other than Buyer, without first
offering the same material price and terms of such agreement to Buyer by written notice (“Offer
Notice”). “Restricted Period” means a period that ends eighteen (18) months after the effective
date of a termination. If Buyer rejects or fails to respond to the Offer Notice within fifteen (15)
Business Days, or the Parties negotiate to enter into an agreement but are unable to execute a
definitive agreement within sixty (60) days after Buyer accepts such offer from Seller, then
Seller shall have the right to enter into an agreement with a third party on terms and conditions in
the aggregate not more favorable than the terms and conditions contained in the Offer Notice. If
either Seller or any of its Affiliates wish to enter into an agreement with a third party on terms in
the aggregate more favorable to such third party than those offered to Buyer in the Offer Notice,
or if Seller or such Affiliate fails to close the transaction which gave rise to Seller’s obligation to
provide an Offer Notice within nine (9) months following the issuance of the Offer Notice, then
any subsequent agreement during the Restricted Period shall again be subject to this Section 8.2.
This Section 8.2 shall be specifically enforceable by Buyer without bond and without the need to
prove irreparable harm. Neither Seller nor Seller’s Affiliates may sell or transfer the Facility, or
any part thereof, or land rights or interests in the Site (including the Interconnection Agreement)
during the Restricted Period, except by a transfer permitted by Section 8.2. Upon termination of
this Agreement prior to the Commercial Operation Date, Seller shall deliver a notice of Buyer’s
rights in respect of the Site, in an executed, recordable form reasonably acceptable to Buyer, that
Buyer may record in the real estate records giving notice of Buyer’s rights under this Section 8.2.
Seller enters into this Section 8.2 as authorized agent for all of its present and future Affiliates.
This Section 8.2 shall apply until the earlier of the expiration of the Restricted Period and the
consummation of the first bona fide transfer in accordance with its terms.
8.3 Termination of Duty to Buy. If this Agreement is terminated because of a default by
Seller, neither Seller, nor any successor to Seller with respect to the ownership of the Facility
(for whom Seller acts herein as agent), may thereafter require or seek to require Buyer to
purchase Output from the Facility under Public Utility Regulatory policy Act on account of its
status as a Qualifying Facility, or any other Requirements of Law, for any periods that would
have been within the Term had this Agreement remained in effect. Seller, on behalf of itself and
on behalf of any other entity on whose behalf it may act, hereby waives its rights to require
Buyer to do so.
8.4 Right of First Offer on Ownership.
8.4.1 At any time subsequent to the Effective Date of this Agreement, except in
accordance with this Section 8.4.1, Seller: (a) shall not sell, transfer or offer to sell or
transfer, the Facility; and (b) shall cause its immediately upstream owner(s) (together
with Seller, each a “ROFO Seller”) not to sell, transfer or offer to sell or transfer, any
ownership interest in Seller (the Facility and ownership interests in Seller, as applicable,
each the “Offered Interests”) other than to an Affiliate in accordance with the provisions
of Section 22.2 (each a “Restricted Transaction”). If a ROFO Seller intends to enter into a
Restricted Transaction, Seller shall provide Buyer with written notice of same (a “Seller
ROFO Notice”), and Buyer shall have a right of first offer with respect to the purchase of
such Offered Interests. Within thirty (30) days after receipt of the Seller ROFO Notice,
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Buyer shall notify Seller in writing of its decision whether or not to negotiate with ROFO
Seller for the purchase of the Offered Interests (the “Buyer ROFO Notice”). If Buyer
elects to negotiate with ROFO Seller for the purchase of the Offered Interests, Seller shall
cause ROFO Seller to negotiate in good faith and exclusively with Buyer, for a period of
not less than ninety (90) days following ROFO Seller’s receipt of the Buyer ROFO
Notice. (“ROFO Period”).
8.4.2 In the event that Buyer does not elect to negotiate with ROFO Seller for the
purchase of the Offered Interests pursuant to Section 8.4.1, ROFO Seller shall be free to
sell, transfer or offer or negotiate to sell or transfer the Offered Interests in ROFO Seller’s
sole discretion. In the event that Buyer elects to negotiate with ROFO Seller for the
purchase of the Offered Interests pursuant to Section 8.4.1, and if definitive transaction
documents between ROFO Seller and Buyer or its designee have not been executed with
respect to the Offered Interests within the ROFO Period, ROFO Seller may negotiate a
Restricted Transaction with any other Person, subject, in all cases, to the terms and
conditions of this Agreement, including Section 8.4.1 and the provisions of Section 22. In
no event may ROFO Seller enter into a Restricted Transaction with any other Person on
economic terms (such as purchase price, payment terms and overall revenue streams
associated with such transaction) or other material terms less favorable to ROFO Seller
than such economic terms, if any, as were negotiated by Buyer and ROFO Seller. As used
in this Section 8.4.2, “other material terms” means any terms identified by the Parties
acting in good faith within five (5) Business Days following expiration of the ROFO
Period that the Parties have not agreed to during their negotiation.

8.4.3 If ROFO Seller and such other Person do not agree upon the terms, conditions and
pricing for the Offered Interests within one hundred eighty (180) days following the
expiration of the ROFO Period, ROFO Seller and any Offered Interests shall again be
subject to this Section 8.2 with respect to any Restricted Transaction.

8.5 [Reserved]
8.6 Efforts Required to Transfer Facility and Offered Interests. If Buyer exercises any right to
purchase or agrees to purchase the Facility (or Offered Interests) pursuant to any of the means
specified in this Section 8, then such purchase shall occur pursuant to a form of purchase and
sale agreement prepared by Buyer which shall contain customary representations, warranties and
covenants and otherwise be in form reasonably acceptable to Buyer. It shall be a condition of any
such purchase that Buyer obtains all necessary Governmental Approvals, and notwithstanding
any language to the contrary in this Agreement, Buyer shall be given sufficient time to obtain
such approvals in accordance with applicable statutes and regulations. Pursuant to the purchase
and sale agreement, Seller will take all actions necessary to transfer by deed, bill of sale, or both,
the Facility or Offered Interests to Buyer, as well as all other improvements placed on the
Premises by Seller that are required for the continued and uninterrupted use, maintenance and
operation of the Facility, free and clear from any lien or monetary encumbrance created by or on
behalf of Seller or its Affiliates. In addition, Seller will assign to Buyer all transferrable
Governmental Approvals applicable to the Facility and Required Facility Documents, and all
transferrable warranties for the Facility. Seller shall cooperate with Buyer to assign and enforce
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any and all warranties that apply to the Facility or any of its component parts, which obligation
shall survive the termination of this Agreement.
8.7 Due Diligence; Cooperation; Governmental Approvals; Notice of Rights. Seller will
provide, in a timely manner, information regarding the Facility and Offered Interests which is
reasonably requested by Buyer to allow Buyer to perform due diligence for the purchase of the
Facility and Offered Interests pursuant to this Section 8. Seller shall further provide
commercially reasonable cooperation and assistance to Buyer, without further compensation,
throughout Buyer’s efforts to properly account for and obtain any necessary Governmental
Approvals with respect to the purchase of the Facility and Offered Interests pursuant to this
Section 8. Notwithstanding anything in this Agreement or any definitive transaction
documentation, Buyer shall not be obligated to proceed with the purchase of the Facility or any
Offered Interests pursuant to this Section 8 if Buyer does not receive all necessary Governmental
Approvals in connection with such transaction. Seller shall put any Person with which it enters
into discussions or negotiations regarding a Restricted Transaction on notice of the rights of
Buyer set forth in this Section 8. Buyer shall be permitted to file a notice of the rights contained
in this Section 8 with respect to the Premises.
8.8 Termination of Agreement. Upon the acquisition of the Facility or Offered Interests by
Buyer pursuant to this Section 8, this Agreement shall terminate and neither Party shall have any
obligation to the other under this Agreement, except with respect to the terms and provisions
hereof that expressly survive the termination of this Agreement.
SECTION 9
SECURITY AND CREDIT SUPPORT
9.1 Project Development Security. Seller shall provide within five (5) Business Days from
receipt of a written request from Idaho Power all reasonable financial records necessary for
Idaho Power to confirm Seller satisfies the Credit Requirements.
9.1.1 Form and Amount of Project Development Security. On or before thirty (30) days
of the date of the Effective Date, Seller shall post and maintain in favor of Idaho Power
(a) a guaranty from a party that satisfies the Credit Requirements, in substantially the
form attached hereto as Exhibit 8, (b) a Letter of Credit in favor of Idaho Power, in a
form acceptable to Idaho Power in its reasonable discretion, or (c) cash collateral equal in
each case to ninety thousand dollars ([$90,000]) per MW of Nameplate Capacity Rating
(the “Project Development Security”). Seller and any person or entity providing a
guaranty shall provide within five (5) Business Days from receipt of a written request
from Idaho Power all reasonable financial records necessary for Idaho Power to confirm
the guarantor satisfies the Credit Requirements.
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9.1.2 Use of Project Development Security to Pay Delay Damages. If the Commercial
Operation Date occurs after the Scheduled Commercial Operation Date and Seller has
failed to pay any Delay Damages when due under Section 4.4, Idaho Power shall be
entitled to and shall draw upon the Project Development Security an amount equal to the
Delay Damages. Idaho Power shall also be entitled to draw upon the Project
Development Security for other damages if this Agreement is terminated under Section
12 because of Seller’s default.
9.1.3 Termination of Project Development Security. Seller shall no longer be required
to maintain the Project Development Security after the Commercial Operation Date, if at
such time no damages are owed to Idaho Power under this Agreement. However, as of
the Commercial Operation Date, Seller may elect to apply the Project Development
Security toward the Default Security required by Section 9.2, including by the automatic
continuation (as opposed to the replacement) thereof.

9.2 Default Security.
9.2.1 Duty to Post Default Security. On the date specified in Section 4.2.1, Seller shall
post and maintain in favor of Idaho Power (a) a guaranty from an entity that satisfies the
Credit Requirements, in substantially the form attached hereto as Exhibit 8, or (b) a Letter
of Credit, each in the amount specified in Section 9.2.2 (the “Default Security”), as
provided in this Section 9.2. Seller and any person or entity providing a guaranty shall
provide within five (5) Business Days from receipt of a written request from Idaho Power
all reasonable financial records necessary for Idaho Power to confirm the guarantor
satisfies the Credit Requirements.

9.2.2 Amount of Default Security. The amount of the Default Security required by
Section 9.2.1 shall be forty five thousand dollars ([$45,000]) per MW of Nameplate
Capacity Rating and will be held until this Agreement expires. The amount of Default
Security required shall be thirty-five thousand dollars ([$35,000]) per MW of Nameplate
Capacity Rating beginning with Contract Year eleven (11).

9.2.3 Use of Default Security to Pay Deficit Damages. If the Seller has failed to pay any
Deficit Damages when due under Section 4.4, Idaho Power shall be entitled to and shall
draw upon the Default Security an amount equal to the Deficit Damages until such time
as the Default Security is exhausted. Idaho Power shall also be entitled to draw upon the
Default Security for other damages if this Agreement is terminated under Section 12
because of Seller’s default.

9.3 Senior Lenders. If Seller collaterally assigns this Agreement to Seller’s Lenders in a
manner permitted under this Agreement, Buyer, at Seller’s sole cost and expense, if requested
shall enter into a Lender Consent with Seller’s Lenders substantially in the form of Exhibit 21. If
Seller enters into a Tax Equity Financing, Buyer, at Seller’s sole cost and expense, if requested
shall provide an Estoppel Certificate to Seller’s Tax Equity Investors substantially in the form of
Exhibit 22. Seller will within five (5) Business Days of written demand reimburse Buyer all
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Buyer’s costs and expenses, including legal fees and costs of due diligence, incurred in
connection with any action or exercise of rights or remedies by any of Seller’s Lenders against
Seller, including any proceeding or foreclosure against Seller or this Agreement.

9.4 Change of Control. Seller may not suffer any Change of Control, whether voluntary or
by operation of law, without Buyer’s prior written consent, granted or withheld in Buyer’s
reasonable discretion. Seller may not suffer a Change of Control or any other change of
ownership or control, whether direct or indirect, voluntary or by operation of law, such that
Seller becomes a Sanctioned Person. Seller shall give Buyer notice of any Change of Control
within ten (10) Business Days following the effectiveness thereof
9.5 Security is Not a Limit on Seller’s Liability. The security contemplated by this Section 9
(a) constitutes security for, but is not a limitation of, Seller’s obligations hereunder and (b) shall
not be Idaho Power’s exclusive remedy for Seller’s failure to perform in accordance with this
Agreement. Seller shall maintain security as required by Sections 9.1 and 9.2, as applicable per
this Agreement. To the extent that Idaho Power draws on any security, Seller shall, within five
(5) Business Days following such draw, replenish or reinstate the security to the full amount then
required under this Section 9. If at any time the Seller or Seller’s credit support provider(s) fails
to meet the Credit Requirements, then Seller shall provide replacement security meeting the
requirements set forth in Section 9 within ten (10) Business Days after the earlier of (x) Seller’s
receipt of notice from any source that Seller or the credit support provider(s), as applicable, no
longer meets the Credit Requirements or (y) Seller’s receipt of written notice from Idaho Power
requesting the posting of alternate security.
SECTION 10
METERING, METERING COMMUNICATIONS AND SCADA TELEMETRY

10.1 Metering. Idaho Power shall, provide, install, and maintain metering equipment needed
for metering the electrical energy production from the Facility. The metering equipment will be
capable of measuring, recording, retrieving and reporting the Facility’s hourly gross electrical
energy production, station use, maximum energy deliveries (MW) and any other energy
measurements at the Point of Delivery that Idaho Power needs to administer this Agreement and
integrate this Facility’s energy production into the Idaho Power electrical system. Specific
equipment, installation details and requirements for this metering equipment will be established
in the GIA process and documented in the GIA. Seller shall be responsible for all initial and
ongoing costs of this equipment as specified in Schedule 72 of the Tariff and the GIA. Seller
shall cause the Facility to implement all necessary generation information communications in
WREGIS, and report generation information to WREGIS pursuant to a WREGIS-approved
meter that is dedicated to the Facility and only the Facility.
10.2 Metering Communications. Seller shall, at the Seller’s sole initial and ongoing expense,
arrange for, provide, install, and maintain dedicated metering communications equipment
capable of transmitting the metering data specified in Section10.1 to Idaho Power in a frequency,
manner and form acceptable to Idaho Power. Seller shall grant Idaho Power sole control and use
of this dedicated metering communications equipment. Specific details and requirements for this
metering communications equipment will be established in the GIA process and documented in
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the GIA.
10.3 Supervisory Control and Data Acquisition (SCADA) Telemetry. If the Facility’s
Nameplate Capacity exceeds 3 MW, in addition to the requirements of Section 10.1 and 10.2,
Idaho Power may require telemetry equipment and telecommunications which will be capable of
providing Idaho Power with continuous instantaneous SCADA telemetry of the Seller’s Net
Output and Inadvertent Energy production in a form acceptable to Idaho Power. Seller shall
grant Idaho Power sole control and use of this dedicated SCADA and telecommunications
equipment. Specific details and requirements for this SCADA Telemetry and
telecommunications equipment will be established in the GIA process and documented in the
GIA. Seller shall be responsible for all initial and ongoing costs of this equipment as specified in
Schedule 72 of the Tariff and the GIA.
10.4 Metering Costs. To the extent not otherwise provided in the Generation Interconnection
Agreement, Seller shall bear all costs (including Idaho Power’s costs) relating to all metering
equipment installed to accommodate Seller’s Facility.
10.5 Losses. If the Idaho Power Metering equipment is capable of measuring the exact energy
deliveries by the Seller to the Idaho Power electrical system at the Point of Delivery, no Losses
will be calculated for this Facility. If the Idaho Power Metering Equipment is unable to measure
the exact electric energy deliveries by the Seller to the Idaho Power electrical system at the Point
of Delivery, a Losses calculation will be established to measure the energy losses (MWh)
between the Seller’s Facility and the Idaho Power Point of Delivery. This loss calculation will be
initially set at two percent (2%) of the MWh energy production recorded on the Facility
generation metering equipment. At such time as Seller provides Idaho Power with the electrical
equipment specifications (transformer loss specifications, conductor sizes, etc.) of all of the
electrical equipment between the Facility and the Idaho Power electrical system, Idaho Power
will configure a revised loss calculation formula to be agreed to by both parties and used to
calculate the MWh Losses for the remaining term of the Agreement. If at any time during the
term of this Agreement, Idaho Power determines that the loss calculation does not correctly
reflect the actual MWh losses attributed to the electrical equipment between the Facility and the
Idaho Power electrical system, Idaho Power may adjust the calculation and retroactively adjust
the previous month’s MWh loss calculations.
SECTION 11
BILLINGS, COMPUTATIONS AND PAYMENTS
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11.1 Monthly Invoices. On or before the tenth (10
th) day following the end of each calendar
month, Seller shall deliver to Idaho Power a proper invoice showing Seller’s computation of Net
Output delivered to the Point of Delivery during such month in the form of Exhibit 1. When
calculating the invoice, Seller shall provide computations showing the portion of Net Output that
was delivered during On-Peak Hours and the portion of Net Output that was delivered during
Off-Peak Hours. If such invoice is delivered by Seller to Idaho Power, then Idaho Power shall
send to Seller, on or before the later of the twentieth (20 th) day following receipt of such invoice
or the thirtieth (30th) day following the end of each month, payment for Seller’s deliveries of Net
Output and associated Green Tags to Idaho Power.
11.2 Offsets. Either Party may offset any payment due hereunder against amounts owed by the
other Party pursuant hereto. Either Party’s exercise of recoupment and set off rights shall not
limit the other remedies available to such Party hereunder.
11.3 Interest on Late Payments. Any amounts that are not paid when due hereunder shall bear
interest at the Contract Interest Rate from the date due until paid.
11.4 Disputed Amounts. If either Party, in good faith, disputes any amount due pursuant to an
invoice rendered hereunder, such Party shall notify the other Party of the specific basis for the
dispute and, if the invoice shows an amount due, shall pay that portion of the statement that is
undisputed, on or before the due date. Except with respect to invoices provided under Section
11.1, any such notice shall be provided within two (2) years of the date of the invoice in which
the error first occurred. If any amount disputed by such Party is determined to be due the other
Party, or if the Parties resolve the payment dispute, the amount due shall be paid within five (5)
Business Days after such determination or resolution, along with interest at the Contract Interest
Rate from the date due until the date paid.
11.5 Audit Rights. Each Party, through its authorized representatives, shall have the right, at
its sole expense upon reasonable written notice and during normal business hours, to examine
and copy the records of the other Party to the extent reasonably necessary to verify the accuracy
of any statement, charge or computation made hereunder or to verify the other Party’s
performance of its obligations hereunder. Upon request, each Party shall provide to the other
Party statements evidencing the quantities of Net Output delivered at the Point of Delivery. If
any statement is found to be inaccurate, a corrected statement shall be issued and any amount
due thereunder will be promptly paid and shall bear interest at the Contract Interest Rate from the
date of the overpayment or underpayment to the date of receipt of the reconciling payment.
Notwithstanding the foregoing, no adjustment shall be made with respect to any statement or
payment hereunder unless a Party questions the accuracy of such payment or statement within
two (2) years after the date of such statement or payment.
SECTION 12
DEFAULTS AND REMEDIES
12.1 Defaults. The following events are defaults (each a “default” before the passing of
applicable notice and cure periods, and an “Event of Default” thereafter) hereunder:
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12.1.1 Defaults by Either Party:
12.1.1.1 A Party fails to make a payment when due hereunder if the failure
is not cured within ten (10) Business Days after the non-defaulting Party gives the
defaulting Party a notice of the default.
12.1.1.2 A Party (i) makes a general assignment for the benefit of its
creditors; (ii) files a petition or otherwise commences, authorizes or acquiesces in
the commencement of a proceeding or cause of action under any bankruptcy or
similar law for the protection of creditors, or has such a petition filed against it
and such petition is not withdrawn or dismissed within sixty (60) days after such
filing; (iii) becomes insolvent; or (iv) is unable to pay its debts when due.
12.1.1.3 A Party breaches a representation or warranty made by it herein if
the breach is not cured within thirty (30) days after the non-defaulting Party gives
the defaulting Party a written notice of the default; provided that if such default is
not reasonably capable of being cured within the thirty (30) day cure period but is
reasonably capable of being cured within a ninety (90) day cure period, the
defaulting Party will have such additional time (not exceeding an additional sixty
(60) days) as is reasonably necessary to cure, if, prior to the end of the thirty (30)
day cure period the defaulting Party provides the non-defaulting Party a
remediation plan, the non-defaulting Party approves such remediation plan, and
the defaulting Party promptly commences and diligently pursues the remediation
plan.

12.1.1.4 A Party otherwise fails to perform any material obligation
hereunder for which an exclusive remedy is not provided hereunder and which is
not addressed in any other default described in Section 12.1, if the failure is not
cured within thirty (30) days after the non-defaulting Party gives the defaulting
Party written notice of the default; provided that if such default is not reasonably
capable of being cured within the thirty (30) day cure period but is reasonably
capable of being cured within a ninety (90) day cure period, the defaulting Party
will have such additional time (not exceeding an additional sixty (60) days) as is
reasonably necessary to cure, if, prior to the end of the thirty (30) day cure period
the defaulting Party provides the non-defaulting Party a remediation plan, the
non-defaulting Party approves such remediation plan, and the defaulting Party
promptly commences and diligently pursues the remediation plan.

12.1.2 Defaults by Seller.
12.1.2.1 Seller fails to post, increase, or maintain the Project Development
Security or Default Security as required under, and by the applicable dates set
forth in, Section 9.1 and Section 9.2 and such failure is not cured within ten (10)
Business Days after Idaho Power gives Seller notice of default.
12.1.2.2 Seller fails to (i) cause the Facility to achieve Commercial
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Operation on or before the Guaranteed Commercial Operation Date, or (ii)
complete all items included on the Final Completion Schedule within ninety (90)
days after the Commercial Operation Date.

12.1.2.3 Seller sells Output, Green Tags or Capacity Rights from the
Facility to a party other than Idaho Power in breach of Section 5.2, Seller diverts
any Environmental Attributes for any use other than sale to Buyer, or Seller
makes a public statement or otherwise takes an action that any Governmental
Authority or the Center for Resource Solutions determines is a retirement, double
counting, double sale, double use or double claim of Green Tags.

12.1.2.4 Idaho Power receives notice of foreclosure of the Facility or any
part thereof by a Lender, mechanic or materialman, or any other holder, of an
unpaid lien or other charge or encumbrance, if the same has not been stayed, paid,
or bonded around within ten (10) days of the date of the notice received by Idaho
Power.

12.1.2.5 After the Commercial Operation Date, Seller fails to maintain any
Required Facility Documents or Permits necessary to own, operate, or maintain
the Facility and such failure continues for thirty (30) days after Seller’s receipt of
written notice thereof from Idaho Power; provided, however, that, upon written
notice from Seller, the thirty (30) day period shall be extended by an additional
sixty (60) days if (i) the failure cannot reasonably be cured within the thirty (30)
day period despite diligent efforts, (ii) the default is capable of being cured within
the additional sixty (60) day period, and (iii) Seller commences the cure within
the original thirty (30) day period and is at all times thereafter diligently and
continuously proceeding to cure the failure.

12.1.2.6 Seller’s Abandonment of construction or operation of the Facility
and such failure continues for thirty (30) days after Seller’s receipt of written
notice thereof from Idaho Power.

12.1.2.7 Seller fails to maintain insurance as required by the Agreement and
such failure continues for fifteen (15) days after Seller’s receipt of written notice
thereof from Idaho Power.

12.1.2.8 Seller fails to meet the Output Guarantee for two (2) consecutive
years.

12.1.2.9 Every three (3) years after the Commercial Operation Date, Seller
will supply Idaho Power with a Certification of Ongoing Operations and
Maintenance (O&M) from a Registered Professional Engineer licensed in the
State of Idaho, which Certification of Ongoing O&M shall be in the form
specified in Exhibit 11. Seller’s failure to supply the required certificate will be an
event of default. Such a default may only be cured by Seller providing the
required certificate; and
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12.1.2.10 During the full Term of this Agreement, Seller shall maintain
compliance with all Required Facility Documents and determinations described in
Exhibit 9 of this Agreement. In addition, Seller will supply Idaho Power with
copies of any new or additional Required Facility Documents or determinations.
At least every fifth (5th) Contract Year, Seller will update the documentation
described in Exhibit 9. If at any time Seller fails to maintain compliance with the
Required Facility Documents and determinations described in Section 2.2.3 or to
provide the documentation required by this paragraph, such failure will be a
default of Seller and may only be cured by Seller submitting to Idaho Power
evidence of compliance from the permitting agency.
12.1.2.11 Seller is or becomes a Sanctioned Person.
12.1.2.12 Seller breaches any obligation in Section 27.2, or any
representation or warranty made by Seller in Section 27.2 is or becomes false or
misleading in any material respect (provided that if the falsity or misleading
nature of the representation or breach of the obligation is capable of being cured,
an Event of Default will be deemed to occur only if the falsity or misleading
nature of the representation or breach of obligation is not remedied within five (5)
days after notice);

12.2 Remedies for Failure to Deliver/Receive.
12.2.1 Remedy for Seller’s Failure to Deliver. Upon the occurrence and during the
continuation of a default of Seller under Section 12.1.3, Seller shall pay Idaho Power
within five (5) Business Days after invoice receipt, an amount equal to the sum of (a)
Idaho Power’s Cost to Cover multiplied by the Net Output delivered to a party other than
Idaho Power, (b) additional transmission charges, if any, reasonably incurred by Idaho
Power in moving replacement energy to the Point of Delivery or if not there, to such
points in Idaho Power’s control area as are determined by Idaho Power, and (c) any
additional cost or expense incurred as a result of Seller’s default under Section 12.1.3, as
determined by Idaho Power in a commercially reasonable manner. The invoice for such
amount shall include a written statement explaining in reasonable detail the calculation of
such amount.
12.2.2 Remedy for Idaho Power’s Failure to Purchase. If Idaho Power fails to receive or
purchase all or part of the Net Output and Green Tags required to be purchased pursuant
hereto and such failure is not excused under the terms hereof or by Seller’s failure to
perform, then Seller shall first satisfy its obligations under Section 12.7 and then Idaho
Power shall pay Seller, on the earlier of the date payment would otherwise be due in
respect of the month in which the failure occurred or within five (5) Business Days after
invoice receipt, an amount equal to Seller’s Cost to Cover multiplied by the amount of
Net Output so not purchased, less amounts received by Seller pursuant to Section 12.7.
The invoice for such amount shall include a written statement explaining in reasonable
detail the calculation thereof.
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12.2.3 Remedy for Seller’s Failure to Sell/Deliver Capacity Rights. Seller shall be liable
for Idaho Power’s actual damages in the event Seller fails to sell or deliver all or any
portion of the Capacity Rights to Idaho Power.
12.3 Termination and Remedies. From and during the continuance of an Event of Default, the
non-defaulting Party shall be entitled to all remedies available at law or in equity, and may
terminate this Agreement by written notice to the other Party designating the date of termination
and delivered to the defaulting Party no less than one (1) Business Day before such termination
date. The notice required by this Section 12.3 may be provided in the notice of default (and does
not have to be a separate notice) so long as it complies with all other terms of this Section 12.3.
As a precondition to Seller’s exercise of this termination right, Seller must also provide copies of
such notice to the notice addresses of the then-current President and General Counsel of Idaho
Power. Such copies shall be sent by registered overnight delivery service or by certified or
registered mail, return receipt requested. In addition, Seller’s termination notice shall state
prominently therein in type font no smaller than 14-point all-capital letters that “THIS IS A
TERMINATION NOTICE UNDER A PPA. YOU MUST CURE A DEFAULT, OR THE PPA
WILL BE TERMINATED,” and shall state therein any amount purported to be owed and wiring
instructions. Notwithstanding any other provision of this Agreement to the contrary, Seller will
not have any right to terminate this Agreement if the default that gave rise to the termination
right is cured within fifteen (15) Business Days of Idaho Power’s receipt of such notice. Further,
from and after the date upon which Seller fails to remedy a default within the time periods
provided in Section 12.1, and until Idaho Power has recovered all damages incurred on account
of such default by Seller, without exercising its termination right, Idaho Power may offset its
damages against any payment due Seller. Except in circumstances in which a remedy provided
for in this Agreement is described as a Party’s sole or exclusive remedy, upon termination, the
non-defaulting Party may pursue any and all legal or equitable remedies provided by law, equity
or this Agreement. The rights contemplated by this Section 12 are cumulative such that the
exercise of one or more rights shall not constitute a waiver of any other rights. In the event of a
termination hereof:
12.3.1 Each Party shall pay to the other all amounts due the other hereunder for all
periods prior to termination, subject to offset by the non-defaulting Party against damages
incurred by such Party.
12.3.2 The amounts due pursuant to Section 12.3.1 shall be calculated and paid within
thirty (30) days after the billing date for such charges and shall bear interest thereon at the
Contract Interest Rate from the date of termination until the date paid. The foregoing
does not extend the due date of, or provide an interest holiday for any payments
otherwise due hereunder.
12.3.3 Before and after the effective date of termination, the non-defaulting Party may
pursue, to the extent permitted by this Agreement, any and all legal or equitable remedies
provided by law, equity or this Agreement.
12.3.4 Without limiting the generality of the foregoing, the provisions of Sections 6.4,
Exhibit No. 4
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6.5, 7.10.4, 7.10.5, 7.10.7, 11.3, 11.4, 11.5, and Section 12, Section 13, Section 14.1,
Section 17, Section 23, Section 24, Section 25, and Section 26 shall survive the
termination hereof.
12.4 Termination Damages. If this Agreement is terminated as a result of an Event of Default
by one of the Parties, termination damages shall be determined. The amount of termination
damages shall be calculated by the non-defaulting Party within a reasonable period after
termination of the Agreement. In the event of a default by Seller before the Commercial
Operation Date, the termination payment shall be the Pre-COD Damages Payment. In the event
of default by Seller on or after the Commercial Operation Date, or any default by Buyer, the
termination payment shall be the Forward Settlement Amount. Amounts owed pursuant to this
section shall be due within five (5) Business Days after the non-defaulting Party gives the
defaulting Party written notice of the amount due. The non-defaulting Party shall under no
circumstances be required to account for or otherwise credit or pay the defaulting Party for
economic benefits accruing to the non-defaulting Party as a result of the defaulting Party’s
default.
12.5 [Omitted]
12.6 Duty/Right to Mitigate. Each Party agrees that it has a duty to mitigate damages and
covenants that it will use commercially reasonable efforts to minimize any damages it may incur
as a result of the other Party’s performance or non-performance hereof; provided, however, that
this duty to mitigate shall not limit the amounts payable by the defaulting Party to the non-
defaulting Party pursuant to Section 12.4. “Commercially reasonable efforts” (a) by Seller shall
include requiring Seller to use commercially reasonable efforts to maximize the price for Net
Output and associated Green Tags received by Seller from third parties, including entering into
an enabling agreement with, or being affiliated with, one or more power marketers of nationally
recognized standing to market such Net Output and associated Green Tags not purchased or
accepted by Idaho Power (only during a period Idaho Power is in default), in each case only to
the extent any of the foregoing actions are permitted under Requirements of Law and the
Interconnection Agreement; and (b) by Idaho Power shall include requiring Idaho Power to use
commercially reasonable efforts to minimize the price paid to third parties for energy and Green
Tags purchased to replace Net Output and Green Tags not delivered by Seller as required
hereunder.
12.7 Security. If this Agreement is terminated because of Seller’s default, Idaho Power may, in
addition to pursuing any and all other remedies available at law or in equity, proceed against any
Seller security held by Idaho Power in whatever form to reduce any amounts that Seller owes
Idaho Power arising from such default.
12.8 Cumulative Remedies. Except in circumstances in which a remedy provided for in this
Agreement is described as a sole or exclusive remedy, the rights and remedies provided to Idaho
Power hereunder are cumulative and not exclusive of any rights or remedies of Idaho Power.
SECTION 13
INDEMNIFICATION AND LIABILITY
Exhibit No. 4
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13.1 Indemnities.
13.1.1 Indemnity by Seller. To the extent permitted by Requirements of Law and subject
to Section 13.1.5, Seller shall release, indemnify and hold harmless Idaho Power and
Customer, and each of its divisions, Affiliates, and each of its and their respective
directors, officers, employees, agents, and representatives (collectively, the “Idaho Power
Indemnitees”) against and from any and all losses, fines, penalties, claims, demands,
damages, liabilities, actions or suits of any nature whatsoever (including legal costs and
attorneys’ fees, both at trial and on appeal, whether or not suit is brought) (collectively,
“Liabilities”) actually or allegedly resulting from, or arising out of, or in any way
connected with, the performance by Seller of its obligations hereunder, or relating to the
Facility or Premises, for or on account of injury, bodily or otherwise, to, or death of, or
damage to or destruction of property of, any person or entity, or for or on account of
violation of environmental or criminal law, excepting only to the extent such Liabilities
as may be caused by the gross negligence or willful misconduct of any person or entity
within the Idaho Power Indemnitees. Seller shall be solely responsible for (and shall
defend and hold Idaho Power harmless against) any damage that may occur as a direct
result of Seller’s breach of the Generation Interconnection Agreement.
13.1.2 Indemnity by Idaho Power. To the extent permitted by Requirements of Law and
subject to Section 13.1.5, Idaho Power shall release, indemnify and hold harmless Seller,
its Affiliates, and each of its and their respective directors, officers, employees, agents,
and representatives (collectively, the “Seller Indemnitees”) against and from any and all
Liabilities actually or allegedly resulting from, or arising out of, or in any way connected
with, the performance by Idaho Power of its obligations hereunder for or on account of
(a) injury, bodily or otherwise, to, or death of, or (b) for damage to, or destruction of
property of, any person or entity within the Seller Indemnitees, excepting only to the
extent such Liabilities as may be caused by the negligence or willful misconduct of any
person or entity within the Seller Indemnitees.
13.1.3 Additional Cross Indemnity. Without limiting Sections 13.1.1 and 13.1.2, Seller
shall release, indemnify and hold harmless the Idaho Power indemnitees from and against
all Liabilities related to Net Output prior to its delivery by Seller at the Point of Delivery,
and Idaho Power shall release, indemnify and hold harmless the Seller Indemnitees from
and against all Liabilities related to Net Output once delivered to Idaho Power at the
Point of Delivery as provided herein, except in each case to the extent such Liabilities are
attributable to the gross negligence or willful misconduct or a breach of this Agreement
by any member of the Idaho Power Indemnitees or the Seller Indemnitees, respectively,
seeking indemnification hereunder.
13.1.4 No Dedication. Nothing herein shall be construed to create any duty to, any
standard of care with reference to, or any liability to any person not a Party. No
undertaking by one Party to the other under any provision hereof shall constitute the
dedication of Idaho Power’s facilities or any portion thereof to Seller or to the public, nor
affect the status of Idaho Power as an independent public utility corporation or Seller as
Exhibit No. 4
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an independent individual or entity.
13.1.5 Consequential Damages. NEITHER PARTY SHALL BE LIABLE TO THE
OTHER PARTY FOR SPECIAL, PUNITIVE, INDIRECT, EXEMPLARY OR
CONSEQUENTIAL DAMAGES, WHETHER SUCH DAMAGES ARE
ALLOWED OR PROVIDED BY CONTRACT, TORT (INCLUDING
NEGLIGENCE), STRICT LIABILITY, STATUTE OR OTHERWISE. THE
PARTIES AGREE THAT ANY LIQUIDATED DAMAGES, SECURITY,
INDEMNIFIED CLAIMS OR DAMAGES, DELAY DAMAGES, IDAHO POWER
AND SELLER COST TO COVER DAMAGES, SECTION 12.2.3 CAPACITY
RIGHTS LOSS DAMAGES, OR OTHER SPECIFIED MEASURE OF DAMAGES
EXPRESSLY PROVIDED FOR HEREIN, ARE NOT INTENDED BY THEM TO
REPRESENT AND WILL NOT BE DEEMED SPECIAL, PUNITIVE, INDIRECT,
EXEMPLARY OR CONSEQUENTIAL DAMAGES AND SHALL NOT BE
LIMITED IN AMOUNT BY THIS SECTION 13.1.5.

SECTION 14
INSURANCE
14.1 Required Policies and Coverages. Without limiting any liabilities or any other obligations
of Seller hereunder, Seller shall secure and continuously carry the insurance coverage specified
on Exhibit 13 during the Term or longer period if specified in Exhibit 13.

14.2 Certificates of insurance. Seller shall provide Idaho Power with certificates of insurance
within ten (10) days after the date by which such policies are required to be obtained (as set forth
in Exhibit 13). Seller shall provide a certificate of insurance (in ACORD or similar industry
form) to Idaho Power within ten (10) days of the effective date of any insurance policy required
under this Agreement.
SECTION 15
FORCE MAJEURE
15.1 Definition of Force Majeure. “Force Majeure” or “an event of Force Majeure” means an
event that (a) is not reasonably anticipated as of the Effective Date hereof, (b) is not within the
reasonable control of the Party affected by the event, (c) is not the result of such Party’s
negligence or failure to act, and (d) could not be overcome by the affected Party’s use of due
diligence in the circumstances. Force Majeure includes, but is not restricted to, events of the
following types (but only to the extent that such an event, in consideration of the circumstances,
satisfies the tests set forth in the preceding sentence): acts of God; civil disturbance; sabotage;
strikes; lock-outs; work stoppages; and action or restraint by court order or public or
Governmental Authority (as long as the affected Party has not applied for or assisted in the
application for, and has opposed to the extent reasonable, such court or government action).
Notwithstanding the foregoing, none of the following constitute Force Majeure: (i) Seller’s
ability to sell, or Idaho Power’s ability to purchase energy, capacity or Green Tags at a more
advantageous price than is provided hereunder; (ii) the cost or availability of fuel or motive force
to operate the Facility; (iii) economic hardship, including lack of money; (iv) any breakdown or
Exhibit No. 4
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malfunction of the Facility’s equipment (including any serial equipment defect) that is not
caused by an independent event of Force Majeure, (v) the imposition upon a Party of costs or
taxes allocated to such Party under Section 6.4, (vi) delay or failure of Seller to obtain or perform
any Required Facility Document unless due to a Force Majeure event, (vii) maintenance upgrade
or repair of any facilities or right of way corridors constituting part of or involving the
Interconnection Facilities, whether performed by or for Seller, or other third parties (except for
repairs made necessary as a result of an event of Force Majeure); (viii) Seller’s failure to obtain,
or perform under, the Generation Interconnection Agreement, or its other contracts and
obligations to transmission owner, Transmission Provider or Interconnection Provider, unless
due to a Force Majeure event; (ix) Seller’s inability to obtain any supply of any good or service,
unless due to an independent event of Force Majeure; or (x) any event attributable to the use of
Interconnection Facilities for deliveries of Net Output to any party other than Idaho Power.
Notwithstanding anything to the contrary herein, in no event will the increased cost of electricity,
steel, labor, or transportation constitute an event of Force Majeure.

15.2 Suspension of Performance. Neither Party shall be liable for any delay or failure in its
performance under this Agreement, nor shall any delay, failure, or other occurrence or event
become a default, to the extent such delay, failure, occurrence or event is substantially caused by
conditions or events of Force Majeure during the continuation of the event of Force Majeure, for
the same number of days that the event of Force Majeure has prevailed, provided that:
15.2.1 the Party affected by the Force Majeure, shall, within five (5) days after the
occurrence of the event of Force Majeure, give the other Party written notice describing
the particulars of the event; and

15.2.2 the suspension of performance shall be of no greater scope and of no longer
duration than is required to remedy the effect of the Force Majeure; and

15.2.3 the affected Party shall use diligent efforts to remedy its inability to perform and
shall provide prompt notice to the other Party of the cessation of the event or condition
giving rise to its excuse from performance.

15.3 Force Majeure Does Not Affect Other Obligations. No obligations of either Party that
arose before the Force Majeure causing the suspension of performance or that arise after the
cessation of the Force Majeure shall be excused by the Force Majeure. No obligation of Seller
arising before the Commercial Operation Date may be excused by Force Majeure.
15.4 Strikes. Notwithstanding any other provision hereof, neither Party shall be required to
settle any strike, walkout, lockout or other labor dispute on terms which, in the sole judgment of
the Party involved in the dispute, are contrary to the Party’s best interests.
15.5 Right to Terminate. If a Force Majeure event prevents a Party from substantially
performing its obligations hereunder for a period exceeding one hundred and eighty (180)
consecutive days (despite the affected Party’s effort to take all reasonable steps to remedy the
effects of the Force Majeure with all reasonable dispatch), then the Party not affected by the
Force Majeure event, with respect to its obligations hereunder, may terminate this Agreement by
Exhibit No. 4
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giving ten (10) days prior written notice to the other Party. Upon such termination, neither Party
will have any liability to the other with respect to the period following the effective date of such
termination; provided, however, that this Agreement will remain in effect to the extent necessary
to facilitate the settlement of all liabilities and obligations arising hereunder before the effective
date of such termination.
SECTION 16
SEVERAL OBLIGATIONS; THIRD PARTY BENEFICIARIES

Nothing contained herein shall be construed to create an association, trust, partnership or joint
venture or to impose a trust, partnership or fiduciary duty, obligation or liability on or between
the Parties. Nothing in this Agreement shall be construed to create any duty, obligation or
liability of Seller or Buyer to any Person not a Party to this Agreement. Notwithstanding the
foregoing sentence, Customer is an intended third party beneficiary of this Agreement and
entitled to indemnification hereunder under the terms of this Agreement.
SECTION 17
CHOICE OF LAW

This Agreement shall be interpreted and enforced in accordance with the laws of the State of
Idaho, applying any choice of law rules that may direct the application of the laws of another
jurisdiction.
SECTION 18
PARTIAL INVALIDITY

The Parties do not intend to violate any laws governing the subject matter hereof. If any of the
terms hereof are finally held or determined to be invalid, illegal or void as being contrary to any
Requirements of Law or public policy, all other terms hereof shall remain in effect. The Parties
shall use best efforts to amend this Agreement to reform or replace any terms determined to be
invalid, illegal or void, such that the amended terms (a) comply with and are enforceable under
Requirements of Law, (b) give effect to the intent of the Parties under this Agreement, and (c)
preserve the balance of the economics and equities contemplated by this Agreement in all
material respects.
SECTION 19
NON-WAIVER

No waiver of any provision hereof shall be effective unless the waiver is set forth in a writing
that (a) expressly identifies the provision being waived, and (b) is executed by the Party waiving
the provision. A Party’s waiver of one or more failures by the other Party in the performance of
any of the provisions hereof shall not be construed as a waiver of any other failure or failures,
whether of a like kind or different nature.
SECTION 20
GOVERNMENTAL JURISDICTION
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AND AUTHORIZATIONS
This Agreement is subject to the jurisdiction of those Governmental Authorities having control
over either Party, the Facility, or this Agreement. During the Term, Seller shall maintain all
Permits required, as applicable, for the construction, operation, or ownership of the Facility.
SECTION 21
[INTENTIONALLY OMITTED]
SECTION 22
SUCCESSORS AND ASSIGNS
22.1 Restriction on Assignments. Except as expressly provided in this Section 20, neither
Party may assign this Agreement or any of its rights or obligations hereunder without the prior
written consent of the other Party, which consent shall not be unreasonably withheld.

22.2 Permitted Assignments. Notwithstanding Section 22.1, either Party may, without the need
for consent from the other Party (but with written notice to the other Party, including the names
of the assignees): (a) transfer, sell, pledge, encumber or assign this Agreement or the accounts,
revenues or proceeds therefrom in connection with project financing for the Facility; or (b)
transfer or assign this Agreement to an Affiliate meeting the requirements of this Agreement;
provided, however, that Seller shall not transfer, sell, encumber or assign this Agreement or any
interest herein to any Affiliate of Idaho Power without the prior written consent of Idaho Power
and Buyer may, without the consent of Seller, assign this Agreement and its obligations
hereunder to [Customer’s ultimate parent entity] or Customer. Except with respect to collateral
assignments for financing purposes in every assignment permitted under this Section 22.2, the
assignee must not be a Sanctioned Person, must agree in writing to be bound by the terms and
conditions hereof and must possess the same or similar experience, and possess the same or
better creditworthiness, as the assignor. Idaho Power may assign this Agreement in whole or in
part without the consent of Seller to any person or entity in the event that Idaho Power ceases to
be a load-serving entity, in which event Idaho Power shall be released from liability hereunder
upon approval of Idaho Power ceasing to be a load-serving entity by the IPUC and OPUC. The
Party seeking to assign or transfer this Agreement shall be solely responsible for paying all costs
of assignment.
SECTION 23
ENTIRE AGREEMENT
This Agreement supersedes all prior agreements, proposals, representations, negotiations,
discussions or letters, whether oral or in writing, regarding the subject matter hereof. No
modification hereof shall be effective unless it is in writing and executed by both Parties.
SECTION 24
NOTICES
Exhibit No. 4
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24.1 Addresses and Delivery Methods. All notices, requests, statements or payments shall be
made to the addresses set out below. In addition, copies of a notice of termination of this
Agreement under Section 12.3 shall contain the information required by Section 12.3 and shall
be sent to the then-current President and General Counsel of Idaho Power. Notices required to be
in writing shall be delivered by letter, facsimile or other tangible documentary form. Notice by
overnight mail or courier shall be deemed to have been given on the date and time evidenced by
the delivery receipt. Notice by hand delivery shall be deemed to have been given when received
or hand delivered. Notice by facsimile is effective as of transmission to each and all of the
telefacsimile numbers provided below for a Party, but must be followed up by notice by
registered mail or overnight carrier to be effective. Notice by overnight mail shall be deemed to
have been given the Business Day after it is sent, if sent for next day delivery to a domestic
address by a recognized overnight delivery service (e.g., Federal Express or UPS). Notice by
certified or registered mail, return receipt requested, shall be deemed to have been given upon
receipt.
To Seller:

To Idaho Power: Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Vice President, Power Supply
Email: [e-mail]
with a copy to: Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Energy Contracts
Email: [e-mail]
and termination notices to Idaho Power: Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Vice President, Power Supply
Email: [e-mail]
and to:Idaho Power
1221 W Idaho St
Boise, ID 83702
Attn: Energy Contracts
Email: [e-mail]
[Notice address for Customer to be added.]
24.2 Changes of Address. The Parties may change any of the persons to whom notices are
Exhibit No. 4
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addressed, or their addresses, by providing written notice in accordance with this section.
SECTION 25
CONFIDENTIALITY
25.1 Confidential Business Information. The following constitutes “Confidential Business
Information,” whether oral or written: (a) the Parties’ proposals and negotiations concerning this
Agreement, made or conducted prior to the Effective Date, (b) the actual charges billed to Idaho
Power hereunder, and (c) any information delivered by Idaho Power to Seller prior to the
Effective Date relating to the market prices of energy or Green Tags and methodologies for their
determination or estimation. Seller and Idaho Power each agree to hold such Confidential
Business Information wholly confidential, except as otherwise expressly provided in this
Agreement. “Confidential Business Information” shall not include information that (x) is in or
enters the public domain through no fault of the Party receiving such information, or (y) was in
the possession of a Party prior to the Effective Date, other than through delivery thereof as
specified in subsections (a) and (c) above. A Party providing any written Confidential Business
Information under this Agreement shall clearly mark all pages of all documents and materials to
be treated as Confidential Business information with the term “Confidential” on the front of each
page, document or material. If the Confidential Business Information is transmitted by electronic
means the title or subject line shall indicate the information is Confidential Business Information.
All Confidential Business Information shall be maintained as confidential, pursuant to the terms
of this Section 25.1, for a period of two (2) years from the date it is received by the receiving
Party unless otherwise agreed to in writing by the Parties.

25.2 Duty to Maintain Confidentiality. Each Party agrees not to disclose Confidential Business
Information to any other person (other than its Affiliates, accountants, auditors, counsel,
consultants, lenders, prospective lenders, employees, officers and directors, and Customer),
without the prior written consent of the other Party, provided that: (a) either Party may disclose
Confidential Business Information, if and to the extent such disclosure is required (i) by
Requirements of Law, (ii) in order for Idaho Power to receive regulatory approval and recovery
of expenses related to this Agreement, (iii) pursuant to an order of a court or regulatory agency,
or (iv) in order to enforce this Agreement or to seek approval hereof, and (b) notwithstanding
any other provision hereof, Idaho Power may in its sole discretion disclose or otherwise use for
any purpose in its sole discretion the Confidential Business Information described in Sections
25.1(b) or 25.1(c). In the event a Party is required by Requirements of Law to disclose
Confidential Business Information, such Party shall to the extent possible promptly notify the
other Party of the obligation to disclose such information.

25.3 Idaho Power Regulatory Compliance. The Parties acknowledge that Idaho Power is
required by Requirements of Law to report certain information that is or could otherwise embody
Confidential Business Information from time to time. Such reports include models, filings,
reports of Idaho Power’s net power costs, general rate case filings, power cost adjustment
mechanisms, FERC-required reporting such as those made on FERC Form 1 or Form 714,
market power and market monitoring reports, annual state reports that include resources and
loads, integrated resource planning reports, reports to entities such as NERC, WECC, Pacific
Northwest Utility Coordinating Committee, WREGIS, or similar or successor organizations,
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forms, filings, or reports, the specific names of which may vary by jurisdiction, along with
supporting documentation. Additionally, in regulatory proceedings in all state and federal
jurisdictions in which it does business, Idaho Power will from time to time be required to
produce Confidential Business Information. Idaho Power may use its business judgment in its
compliance with all of the foregoing and the appropriate level of confidentiality it seeks for such
disclosures. Idaho Power may submit Confidential Business Information in regulatory
proceedings without notice to Seller.

25.4 Irreparable Injury; Remedies. Each Party agrees that violation of the terms of this Section
25 constitutes irreparable harm to the other, and that the harmed Party may seek any and all
remedies available to it at law or in equity, including injunctive relief.
25.5 News Releases and Publicity. Except as otherwise provided in Section 7.14, before either
Party issues any news release or publicly distributed promotional material regarding the Facility
that mentions the Facility, such Party shall first provide a copy thereof to the other Party for its
review and approval. Any use of either Party’s name in such news release or promotional
material must adhere to such Party’s publicity guidelines then in effect; any use of Idaho Power’s
name requires Idaho Power’s prior written consent.
SECTION 26
DISAGREEMENTS
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26.1 Negotiations. Prior to proceeding with formal dispute resolution procedures as provided
below in this Section 26, the Parties must first attempt in good faith to resolve all disputes arising
out of, related to or in connection with this Agreement promptly by negotiation, as follows. Any
Party may give the other Party written notice of any dispute not resolved in the normal course of
business. Executives of both Parties at levels one level above those employees who have
previously been involved in the dispute must meet at a mutually acceptable time and place within
ten (10) days after delivery of such notice, and thereafter as often as they reasonably deem
necessary, to exchange relevant information and to attempt to resolve the dispute. If the matter
has not been resolved within thirty (30) days after the referral of the dispute to such senior
executives, or if no meeting of such senior executives has taken place within fifteen (15) days
after such referral, either Party may initiate any legal remedies available to the Party. All
negotiations pursuant to this clause are confidential.
26.2 Choice of Forum. Each Party irrevocably consents and agrees that any legal action or
proceeding arising out of this Agreement or the actions of the Parties leading up to this
Agreement shall be brought exclusively in the United States District Court for the District of
Idaho in Boise, Idaho, or if such court does not have jurisdiction, in the 4 th Judicial District (Ada
County) Court of the State of Idaho. By execution and delivery hereof, each Party (a) accepts
the exclusive jurisdiction of such court and waives any objection that it may now or hereafter
have to the exercise of personal jurisdiction by such court over each Party for the purpose of any
proceeding related to this Agreement, (b) irrevocably agrees to be bound by any final judgment
(after any and all appeals) of any such court arising out of such documents or actions, (c)
irrevocably waives, to the fullest extent permitted by law, any objection that it may now or
hereafter have to the laying of venue of any suit, action or proceedings arising out of such
documents brought in such court (including any claim that any such suit, action or proceeding
has been brought in an inconvenient forum) in connection herewith, (d) agrees that service of
process in any such action may be effected by mailing a copy thereof by registered or certified
mail, postage prepaid, to such Party at its address as set forth herein, and (e) agrees that nothing
herein shall affect the right to effect service of process in any other manner permitted by law.
26.3 Settlement Discussions. No statements of position or offers of settlement made in the
course of the dispute process described in this Section 26 will be offered into evidence for any
purpose in any litigation between the Parties, nor will any such statements or offers of settlement
be used in any manner against either Party in any such litigation. Further, no such statements or
offers of settlement shall constitute an admission or waiver of rights by either Party in
connection with any such litigation. At the request of either Party, any such statements and offers
of settlement, and all copies thereof, shall be promptly returned to the Party providing the same.
Exhibit No. 4
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26.4 Waiver of Jury Trial. EACH PARTY KNOWINGLY, VOLUNTARILY,
INTENTIONALLY AND IRREVOCABLY WAIVES THE RIGHT TO A TRIAL BY JURY IN
RESPECT OF ANY LITIGATION BASED ON THIS AGREEMENT, OR ARISING OUT OF,
UNDER OR IN CONNECTION WITH THIS AGREEMENT AND ANY AGREEMENT
EXECUTED OR CONTEMPLATED TO BE EXECUTED IN CONJUNCTION WITH THIS
AGREEMENT, OR ANY COURSE OF CONDUCT, COURSE OF DEALING, STATEMENTS
(WHETHER VERBAL OR WRITTEN) OR ACTIONS OF ANY PARTY HERETO. THIS
PROVISION IS A MATERIAL INDUCEMENT TO EACH OF THE PARTIES FOR
ENTERING HEREINTO. EACH PARTY HEREBY WAIVES ANY RIGHT TO
CONSOLIDATE ANY ACTION, PROCEEDING OR COUNTERCLAIM ARISING OUT OF
OR IN CONNECTION WITH THIS AGREEMENT OR ANY OTHER AGREEMENT
EXECUTED OR CONTEMPLATED TO BE EXECUTED IN CONJUNCTION WITH THIS
AGREEMENT, OR ANY MATTER ARISING HEREUNDER OR THEREUNDER, WITH
ANY PROCEEDING IN WHICH A JURY TRIAL HAS NOT OR CANNOT BE WAIVED.
THIS SECTION WILL SURVIVE THE EXPIRATION OR TERMINATION OF THIS
AGREEMENT.
SECTION 27
COMPLIANCE
27.1 Nondiscrimination. Customer or its Affiliates is a federal contractor and maintains an
equal opportunity/affirmative action program in accordance with Applicable Law. As a result,
Seller must, to the extent required by Applicable Law, afford equal employment opportunity to
all of its applicants and employees, regardless of their race, color, national origin, sex, age,
religion, marital status, sexual orientation, gender identity and gender expression, protected
veteran status, disability, or other basis protected by law. Also as a result, but only if required by
Applicable Law, Seller shall abide by the requirements of 41 CFR 60-1.4(a), 60-300.5(a) and 60-
741.5(a). These regulations prohibit discrimination against qualified individuals based on their
status as protected veterans or individuals with disabilities and prohibit discrimination against all
individuals based on their race, color, religion, sex, sexual orientation, gender identity, or
national origin. Moreover, these regulations require that covered prime contractors and
subcontractors take affirmative action to employ and advance in employment individuals without
regard to race, color, religion, sex, sexual orientation, gender identity, national origin, disability,
or veteran status. In connection with this Agreement and the Facility, Seller will comply with,
and cause all of its direct and indirect contractors and subcontractors to expressly agree to
comply with, all laws and regulations relating to forced, bonded (including debt bondage) or
indentured labor, involuntary or exploitative prison labor, slavery or trafficking of persons.
27.2 Anti-Corruption. In connection with the negotiation and performance of this Agreement
and the development, construction, and operation of the Facility or the Premises, Seller, on
behalf of itself, Seller’s Parent Entity and any other direct or indirect upstream equity owners
that, notwithstanding percentage of equity ownership interest, have the voting power or
otherwise have the power to control the day-to-day management, operations and policies of
Seller, and such Affiliates that Seller contractually or otherwise controls or directs in the
management or operation of the Facility, and in each case, including the officers, directors,
employees and agents of such entities, represents and warrants that it has not engaged in, and that
Exhibit No. 4
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68
it shall refrain from, offering, promising, paying, giving, authorizing the paying or giving of,
soliciting, or accepting money or Anything of Value, directly or indirectly, to or from (a) any
Government Official to (i) influence any act or decision of a Government Official in his or her
official capacity, (ii) induce a Government Official to act in violation of his or her lawful duty,
(iii) induce a Government Official to use his or her influence with a government or
instrumentality thereof, or (iv) otherwise secure any improper advantage, in each case to the
extent prohibited by applicable anti-corruption laws; or (b) any person in any manner that would
constitute bribery or an illegal kickback, or would otherwise violate applicable anti-corruption
laws. If Seller fails to comply with this Section 27.2 then Buyer may terminate this Agreement
in accordance with Section 12.1.2.12 . In connection with the performance of this Agreement
and all fees charged Buyer, Seller shall maintain books and records practices and internal
controls to ensure (a) that receipts and expenses are accurately recorded with reasonable detail
and are based on accurate and sufficient supporting documentation and (b) that no “off the
books” accounts are created or maintained. Unless otherwise required by law, such books and
records will be maintained for five (5) years after termination or expiration of this Agreement.
Seller will immediately report to Buyer any breach of this Section 27.2 by Seller or its
representatives. Seller will ensure that the contractors and subcontractors it retains in connection
with this Agreement expressly agree to anti-corruption undertakings, representations, and
warranties substantially similar to the provisions herein. If Buyer has reason to believe that a
breach of this Section 27.2 has occurred or will occur, Buyer shall have the right to audit Seller’s
books and records insofar as they relate to performance of this Agreement and to withhold
further payments without any liability to Seller until reasonably satisfied that no breach has
occurred. If the Agreement is terminated pursuant to an Event of Default under Section
12.1.2.12, Buyer shall have no obligation to make further payments hereunder. Buyer’s rights
and Seller’s obligations under this Section 27.2 shall survive the termination or expiration of the
Agreement.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed
in their respective names as of the date last written below.

By:
Name:
Title:
Date: ______________________________
By:
Name:
Title: ______________________________
Date: _______________________________
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 404 of 1056
EXHIBIT 1
MONTHLY POWER PRODUCTION AND SWITCHING REPORT
Month Year
Project Name Project Number:
Address Phone Number:
City State Zip State
Facility Station Metered
Output Usage Maximum Generation
Meter Number:
End of Month MWh Meter Reading: MW
Beginning of Month MWh Meter:
Difference:
Times Meter Constant: Net Generation
MWh for the Month:- =
Metered Demand:
Breaker Opening Record Breaker Closing Record
Date Time Meter * Reason Date Time Meter
* Breaker Opening Reason Codes
1 Lack of Adequate Prime Mover I hereby certify that the above meter readings are
true and correct as of Midnight on the last day of the
above month and that the switching record is accurate
and complete as required by the Energy Sales
Agreement to which I am a Party.
2 Forced Outage of Facility
3 Disturbance of IPCo System
4 Scheduled Maintenance
5 Testing of Protection Systems
6 Cause Unknown
7 Other (Explain)

Signature Date
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 405 of 1056
70
A-2 AUTOMATED METER READING COLLECTION PROCESS
Monthly, Idaho Power will use the provided Metering and Telemetry equipment and processes to collect
the meter reading information from the Idaho Power provided Metering Equipment that measures the Net
Energy and energy delivered to supply Station Use for the Facility recorded at 12:00 AM (Midnight) of the
last day of the month.

The meter information collected will include but not be limited to energy production, Station Use, the
maximum generated power (MW) and any other required energy measurements to adequately administer
this Agreement.
A-3 SELLER CONTACT INFORMATION

Seller’s Contact Information
Name:
Telephone Number:
Cell Phone:
E-Mail:

24-Hour Project Operational Contact

Name:
Telephone Number:
Cell Phone:
E-Mail:

Project On-site Contact information

Name:
Telephone Number:
Cell Phone:
E-Mail:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 406 of 1056
EXHIBIT 2
DESCRIPTION OF FACILITY
Project Name: ______________
Project Number: ______________

B-1 DESCRIPTION OF FACILITY

(Must include the Nameplate Capacity rating and VAR capability (both leading and lagging) of
all Generation Units to be included in the Facility.)

______________________________________________________________________________
______________________________________________________________________________
______________________________________________________________________________
______________________________________________________________________________
______________________________________________________________________________
Var Capability (Both leading and lagging) Leading is _______Lagging is ________.
B-2 LOCATION OF FACILITY
Near: ______________
Actual or nearest physical street address: ______________
GPS Coordinates: Latitude Decimal Degrees: ______________
Longitude Decimal Degrees: ____________
State: ______________ County: ______________
Exhibit No. 4
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EXHIBIT 3
POINT OF DELIVERY/INTERCONNECTION FACILITIES
Instructions to Seller:
1. Include description of point of metering, and Point of Interconnection
2. Include description of Point of Delivery
3. Provide interconnection single line drawing of Facility including any transmission
facilities on Seller’s side of the Point of Interconnection.
5. Describe Seller’s arrangements for station service to the Facility and show on one-line
diagram how station service will be provided and metered.
6. Specify the maximum hourly rate (MW) at which Seller is permitted to deliver energy to
the Point of Delivery and in compliance with Seller’s transmission rights between the Point of
Interconnection and the Point of Delivery (“Maximum Transmission Rate”):
__________MW.
Seller to provide to Buyer with a copy of the final Generator Interconnection Agreement

Exhibit No. 4
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E. Hackett, IPC
Page 408 of 1056
EXHIBIT 4
ESTIMATED MONTHLY NET OUTPUT
EXPECTED ENERGY - FIRST FULL CONTRACT YEAR
PERIOD ON-PEAK (MWh) OFF-PEAK (MWh) TOTAL (MWh)
January
February
March
April
May
June
July
August
September
October
November
December
First Year Total
Exhibit No. 4
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Page 409 of 1056
74
Under separate cover, Seller will also provide Idaho Power one (1) electronic and hard copy of
the solar plant performance estimation report using a Solar Performance Modeling Program no
later than ninety (90) days prior to the start of construction. This report will include, at a
minimum, estimated hourly MW generation output in MWh/h for the Premises and Facility, and
shall set forth additional losses related to availability, AC-side collection, transformers,
substation and no-load/overnight losses. On or prior to the Commercial Operation Date, Seller
shall provide an updated Exhibit A and solar plant performance estimation report based on
completed construction.
Upon the date of Final Completion, if different than the Commercial Operation Date, Seller shall
provide an updated Exhibit A and solar plant performance estimation report based on the final
completed construction.

EXPECTED ENERGY - ANNUAL REDUCTION
PERIOD EXPECTED ENERGY (MWh)
Year 0-1
Year 1-2
Year 2-3
Year 3-4
Year 4-5
Year 5-6
Year 6-7
Year 7-8
Year 8-9
Year 9-10
Year 10-11
Year 11-12
Year 12-13
Year 13-14
Year 14-15
Year 15-16
Year 16-17
Year 17-18
Year 18-19
Year 19-20
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 410 of 1056
EXHIBIT 5
CONTRACT PRICE
Contract Price
Contract Year $/MWh
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 411 of 1056
76
EXHIBIT 6
NERC EVENT TYPES
Event
Type
Description of Outages
U1
Unplanned (Forced) Outage—Immediate – An outage that requires immediate
removal of a unit from service, another outage state or a Reserve Shutdown state.
This type of outage results from immediate mechanical/electrical/hydraulic
control systems trips and operator-initiated trips in response to unit alarms.
U2
Unplanned (Forced) Outage—Delayed – An outage that does not require
immediate removal of a unit from the in-service state but requires removal within
six (6) hours. This type of outage can only occur while the unit is in service.
U3
Unplanned (Forced) Outage—Postponed – An outage that can be postponed
beyond six hours but requires that a unit be removed from the in-service state
before the end of the next weekend. This type of outage can only occur while the
unit is in service.
SF
Startup Failure – An outage that results from the inability to synchronize a unit
within a specified startup time period following an outage or Reserve Shutdown.
A startup period begins with the command to start and ends when the unit is
synchronized. An SF begins when the problem preventing the unit from
synchronizing occurs. The SF ends when the unit is synchronized or another SF
occurs.
MO
Maintenance Outage – An outage that can be deferred beyond the end of the next
weekend, but requires that the unit be removed from service before the next
planned outage. (Characteristically, a MO can occur any time during the year, has
a flexible start date, may or may not have a predetermined duration and is usually
much shorter than a PO.)
ME
Maintenance Outage Extension – An extension of a maintenance outage (MO)
beyond its estimated completion date. This is typically used where the original
scope of work requires more time to complete than originally scheduled. Do not
use this where unexpected problems or delays render the unit out of service
beyond the estimated end date of the MO.
PO
Planned Outage – An outage that is scheduled well in advance and is of a
predetermined duration, lasts for several weeks and occurs only once or twice a
year. (Boiler overhauls, turbine replacement or inspections are typical planned
outages.)
PE
Planned Outage Extension – An extension of a planned outage (PO) beyond its
estimated completion date. This is typically used where the original scope of work
requires more time to complete than originally scheduled. Do not use this where
unexpected problems or delays render the unit out of service beyond the estimated
end date of the PO.
Exhibit No. 4
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Page 412 of 1056
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EXHIBIT 7
START-UP TESTING
(Seller to provide to Buyer before the First Generation Date)

Exhibit No. 4
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Page 413 of 1056
78
EXHIBIT 8
FORM OF GUARANTY — CREDIT SUPPORT OBLIGATION
FORMS OF LIQUID SECURITY
The Seller shall provide Idaho Power with commercially reasonable security instruments
such as Cash, Cash Escrow Security, Guarantee or Letter of Credit as those terms are
defined below or other forms of liquid financial security that would provide readily
available cash to Idaho Power to satisfy the security requirements within this Agreement.

For the purpose of this Appendix D, the term “Credit Requirements” shall mean acceptable
financial creditworthiness of the entity providing the security instrument in relation to the
term of the obligation in the reasonable judgment of Idaho Power, provided that any
guarantee and/or Letter of Credit issued by any other entity with a short-term or long-term
investment grade credit rating by Standard & Poor’s Corporation or Moody’s Investor
Services, Inc. or any successors shall be deemed to have acceptable financial
creditworthiness.

1. Cash – Seller shall deposit cash in the amount of the required security with Idaho
Power. Idaho Power will not be responsible to calculate or pay any interest on these
funds deposited with Idaho Power.

2. Cash Escrow Security – Seller shall deposit funds in an escrow account established by
the Seller in a banking institution acceptable to both Parties equal to the required
security. The Seller shall be responsible for all costs, and receive any interest earned
associated with establishing and maintaining the escrow account(s).

3. Guarantee or Letter of Credit Security – Seller shall post and maintain in an amount
equal to the required security: (a) a guaranty from a party that satisfies the Credit
Requirements, in a form acceptable to Idaho Power at its discretion, or (b) an
irrevocable Letter of Credit in a form acceptable to Idaho Power, in favor of Idaho
Power. The Letter of Credit will be issued by a financial institution acceptable to both
parties. The Seller shall be responsible for all costs associated with establishing and
maintaining the Guarantee(s) or Letter(s) of Credit.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 414 of 1056
EXHIBIT 9
REQUIRED FACILITY DOCUMENTS
1. Obtained Required Facility Documents:
Permits:
Conditional Use Permits from Twin Falls County for the construction and
operation of the Facility
Land Rights:
Solar Park Lease Agreement for the land, access, and interconnection of the
Facility.
2. To Be Obtained (Prior to Commercial Operation) Required Facility Documents:
Licenses, Permits and Authorizations:
Evidence of market-based rate authority under Section 205 of the Federal Power Act or evidence
of qualifying facility certification under the Public Utility Regulatory Policies Act
Access road easement
Electrical Permit
Building Permit
Interconnection approval
Utility easement
Crossing Agreement
Construction and Operations and Maintenance:
Contract for the Sale of Power Generation Equipment and Related Services between vendors and
engineering, procurement, and construction contractor and Seller
Generator Interconnection Agreement
Retail Electric Service Agreement
Proof of Insurance
Construction Agreements:
Balance of Plant/Construction Services Agreement
Operations and Maintenance Agreements:
Exhibit No. 4
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Warranty, Service and Maintenance Agreement
SUCH LIST MAY BE UPDATED PURSUANT TO SECTION 2.2.3
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 416 of 1056
EXHIBIT 10
LEASES

(Seller to provide to Buyer before the Commercial Operation Date)

Memorandum of Solar Park Lease Agreement 1
Memorandum of Solar Park Lease Agreement 2

Exhibit No. 4
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EXHIBIT 11
ENGINEER’S CERTIFICATIONS
ENGINEER’S CERTIFICATION
OF
OPERATIONS & MAINTENANCE POLICY

The undersigned _____________________________________, on behalf of himself/herself and
___________ , hereinafter collectively referred to as “Engineer,” hereby states and certifies to the Seller as
follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter referred to as the
“Agreement,” between Idaho Power as Buyer, and ________________as Seller, dated
_________________________.
3. That the cogeneration or small power production project which is the subject of the Agreement and
this Statement is identified as Idaho Power Company Facility No. ________________ and is hereinafter
referred to as the “Project.”
4. That the Project, which is commonly known as the ____________________Project, is located in
Section _____ Township ________ Range ________, Boise Meridian, __________ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical energy
to Idaho Power for a ________ year period.
6. That Engineer has substantial experience in the design, construction and operation of electric power
plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
Exhibit No. 4
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8. That Engineer has reviewed and/or supervised the review of the Policy for Operation and
Maintenance (“O&M”) for this Project and it is his professional opinion that, said Project has been
designed and built to appropriate standards, and adherence to said O&M Policy will result in the Project’s
producing at or near the design electrical output, efficiency and plant factor for the full Contact Term of
_____________ years.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement, is
relying on Engineer’s representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to the best of
his/her knowledge and therefore sets his/her hand and seal below.
By ______________________________

(P.E. Stamp)

Date ______________________________

Exhibit No. 4
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Page 419 of 1056
84
ENGINEER’S CERTIFICATION
OF
ONGOING OPERATIONS AND MAINTENANCE
The undersigned ____________________________________, on behalf of himself/herself
and _______________________hereinafter collectively referred to as “Engineer,” hereby states and
certifies to the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter referred to as the
“Agreement,” between Idaho Power as Buyer, and ___________________ as Seller, dated
_________________________.
3. That the cogeneration or small power production project which is the subject of the Agreement and
this Statement is identified as Idaho Power Company Facility No. _____________ and hereinafter referred
to as the “Project”.
4. That the Project, which is commonly known as the ____________________Project, is located in
Section _____ Township ________ Range ________, Boise Meridian, __________ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical energy
to Idaho Power for a _________ year period.
6. That Engineer has substantial experience in the design, construction and operation of electric power
plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.

Exhibit No. 4
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E. Hackett, IPC
Page 420 of 1056
85
8. That Engineer has made a physical inspection of said Project, its operations and maintenance
records since the last previous certified inspection. The Engineer certifies, based on the Project’s
appearance and the information provided by the Project, that the Project’s ongoing O&M has been
completed in accordance with said O&M Policy; that it is in reasonably good operating condition; and it is
in the Engineer’s professional opinion that if adherence to said O&M Policy continues, the Project will
continue producing at or near its design electrical output, efficiency and plant factor for the remaining
______ years of the Agreement.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement,
is relying on Engineer’s representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to the best of
his/her knowledge and therefore sets his/her hand and seal below.

By ____________________________

(P.E. Stamp)

Date ______________________________

Exhibit No. 4
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Page 421 of 1056
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ENGINEER’S CERTIFICATION

OF

DESIGN & CONSTRUCTION ADEQUACY

The undersigned _____________________________________, on behalf of himself/herself and
_________________________ hereinafter collectively referred to as “Engineer”, hereby states and certifies
to Idaho Power as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter referred to as the
“Agreement”, between Idaho Power as Buyer, and _____________________________as Seller, dated
__________, _____________________________.
3. That the cogeneration or small power production project, which is the subject of the
Agreement and this Statement, is identified as Idaho Power Company Facility No ________________ and
is hereinafter referred to as the “Project”.
4. That the Project, which is commonly known as the ____________________Project is located in
Section _____ Township ________ Range ________, Boise Meridian, __________ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical
energy to Idaho Power for a _____________ year period.
6. That Engineer has substantial experience in the design, construction and operation of
electric power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project and has
made the analysis of the plans and specifications independently.
8. That Engineer has reviewed the engineering design and construction of the Project,
including the civil work, electrical work, generating equipment, prime mover conveyance system, Seller
furnished Interconnection Facilities and other Project facilities and equipment.
9. That the Project has been constructed in accordance with said plans and specifications, all
Exhibit No. 4
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Page 422 of 1056
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applicable codes and consistent with Prudent Electrical Practices as that term is described in the Agreement.
10.That the design and construction of the Project is such that with reasonable and prudent
operation and maintenance practices by Seller, the Project is capable of performing in accordance with the
terms of the Agreement and with Prudent Electrical Practices for a ________ year period.
11. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the
Agreement, in interconnecting the Project with its system, is relying on Engineer’s representations and
opinions contained in this Statement.
12. That Engineer certifies that the above statements are complete, true and accurate to the best
of his/her knowledge and therefore sets his/her hand and seal below.

By ____________________________

(P.E. Stamp)

Date ______________________________

Exhibit No. 4
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EXHIBIT 12
[RESERVED]

Exhibit No. 4
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EXHIBIT 13
REQUIRED INSURANCE
The Seller shall secure and continuously carry insurance as specified within this Appendix for the
term of the Agreement.

Insurance Requirements:

1. All insurance required by this Agreement shall be placed with an insurance company
with an A.M. Best Company rating of A- or better.

2. If the insurance coverage required in this Appendix is cancelled, materially changed or
lapses for any reason, the Seller will immediately notify Idaho Power in writing. This
notice will advise Idaho Power of the specific reason for cancellation, material change
or lapse and the steps being taken to comply with these Insurance Requirements.
Failure to provide this notice and to comply with these Insurance Requirements within
5 days of the cancellation, material change or lapse will constitute a material breach
and Idaho Power may terminate this Agreement.

3. Prior to the First Energy date and subsequently within 10 days of the annual anniversary
of the Operation Date, the Seller shall provide a Certificate of Insurance in the name of
Idaho Power Company and list Idaho Power Company as an Additional Insured
Endorsement and Waiver of Subrogation Endorsement.

4. The Certificate of Insurance shall evidence the appropriate insurance coverage of
Comprehensive General Liability Insurance for both bodily injury and property damage
with limits equal to[$1,000,000,] each occurrence, combined single limit. The
deductible for such insurance shall be consistent with current Insurance Industry Utility
practices for similar property.
Seller shall be entitled to self-insure these coverages with approval of Idaho Power, which shall
not be unreasonable withheld, delayed or conditioned.
1.5 Periodic Review. Idaho Power may review this schedule of insurance as often as once
every two (2) years. Idaho Power may in its discretion require Seller to make reasonable
changes to the policies and coverages described in this Exhibit to the extent reasonably necessary
to cause such policies and coverages to conform to the insurance policies and coverages typically
obtained or required for power generation facilities comparable to the Facility at the time Idaho
Power’s review takes place.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 425 of 1056
-90-
EXHIBIT 14
SELLER AUTHORIZATION TO RELEASE GENERATION DATA TO IDAHO
POWER
[DATE]
Idaho Power
1221 W Idaho St
Boise, ID 83702
Email: [e-mail]
To Whom it May Concern:
_______________________ (“Seller”) hereby voluntarily authorizes Idaho Power’s
Transmission business unit to share Seller’s interconnection information with marketing function
employees of Idaho Power, including but not limited to those in Power Supply. Seller
acknowledges that Idaho Power did not provide it any preferences, either operational or rate-
related, in exchange for this voluntary consent.

_______________________

Exhibit No. 4
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Page 426 of 1056
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EXHIBIT 15
ATTACHMENTS
(Seller to provide to Buyer before the First Generation Date)

1. Site Map
2. As-Builts
3. Manufacturer’s performance warranties
5. [Other]

Exhibit No. 4
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Page 427 of 1056
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EXHIBIT 16
AS-BUILT SUPPLEMENT
Exhibit No. 4
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EXHIBIT 17
MARKETING COMMUNICATIONS AGREEMENT
This MARKETING COMMUNICATIONS AGREEMENT (this “Agreement”) is made
and entered into as of the date of the last to be made signature below (the “Effective Date”), by
and among [_________] (“Customer”), Idaho Power Company (“Idaho Power”), and
[_________] (“Developer”). Customer, Idaho Power and Developer are together sometimes
hereinafter referred to as the “Parties” and individually as a “Party.”
WHEREAS, in furtherance of the Retail Agreement entered into by Idaho Power and
Customer in order to support Customer’s renewable energy goals, Idaho Power and Developer
have entered into the PPA (as “PPA” and the initially capitalized terms in these Recitals are
hereinafter defined);
WHEREAS, the Parties intend to hereinafter engage in public communications
concerning RECs and electrical output from the Facility; and
WHEREAS, the Parties wish to comport with best practices for communications
concerning RECs, and to comply with the REC Communication Rules.
NOW, THEREFORE, in consideration of the mutual promises herein contained and for
other good and valuable consideration, the receipt and sufficiency of which are hereby
acknowledged, the Parties agree as follows:
1. Definitions.

“Applicable Law” means, in relation to any person, entity, transaction or event, all
federal, state, provincial, local or municipal laws, statutes, codes, acts, treaties, ordinances,
orders, judgments, writs, decrees, injunctions, rules, regulations, governmental approvals,
licenses, permits, directives, and requirements of all regulatory and other Governmental
Authorities, by which such person or entity is bound or having application to the transaction or
event in question.
“Idaho REC Communication Rules” means any laws, rules or regulations promulgated in
the future by the State of Idaho or agency or department thereof with respect to the public
communications concerning RECs, as the same may change from time to time.
“Business Day” means any day other than a Saturday, Sunday or federal holiday.

“Facility” means the solar photovoltaic electrical generating facility and other related
electrical equipment, defined in the PPA as the “[Project].”
“Federal REC Communication Rules” means those portions of the Federal Trade
Commission rules, regulations and guidances relating to communications concerning RECs,
including 16 Code of Federal Regulations § 260.15, 77 Federal Register 62131-32, and the
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Federal Trade Commission Feb. 5, 2015, staff letter,1 as the same may change from time to time.
“Governmental Authority” means any national, state, provincial, local, tribal or
municipal government, any political subdivision thereof or any other governmental, regulatory,
quasi-governmental, judicial, public or statutory instrumentality, authority, body, agency,
department, bureau, or entity with authority to bind a Party at law; however, “Governmental
Authority” shall not in any event include any Party.
“PPA” means that Power Purchase Agreement between Idaho Power and Developer
dated xxxx.

“REC” means the Environmental Attributes, as defined in the Renewable Resource PPA.
“REC Claims” means any claims or public communications concerning RECs or
otherwise covered by REC Communication Standards.
“REC Communication Standards” means the Federal REC Communications Rules and
the Idaho REC Communication Rules.
“Retail Agreement” means that certain Special Contract dated _____, 2021 between
Idaho Power and Customer.

2. Term. The term of this Agreement will commence on the Effective Date and,
unless sooner terminated, will continue until the earlier of (a) the expiration or termination date
of the PPA, or (b) the expiration or termination date of the Retail Agreement. [This Agreement
will automatically terminate if the Retail Agreement is not fully executed by [xxxx]].
3. Marketing Rights; News Releases and Publicity.
(a) Customer will have a unilateral right to determine the timing of any press release
in which the execution of this Agreement or the PPA is initially disclosed. The Parties must
mutually agree upon the content of any initial press release or other initial public disclosure with
respect to the existence or execution of this Agreement or the PPA and of the terms, conditions
or other content herein or therein. No Party will unreasonably withhold, delay or condition its
consent and agreement to the content of such press releases or public disclosures.
(b) Without limiting the effect of Section 3(a), or any agreement concerning public
communications between Idaho Power and Customer in the Retail Agreement, Idaho Power and
Developer each hereby grant to Customer the right to advertise, market, and promote to the
general public the existence, implications and benefits of this Agreement, the PPA and the RECs
associated with the PPA, and the exclusive right to associate Customer with any claimed or
actual environmental or sociological benefits arising from this Agreement or the PPA and the
creation, sale or retirement of RECs,
(c) This Agreement implements and supersedes any provisions to the contrary
concerning public communications in the PPA. As between Idaho Power and Customer (and not
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Developer), in the event of any contradiction between this Agreement and the Retail Agreement,
the Retail Agreement controls. As between Idaho Power and Developer (and not Customer), in
the event of any contradiction between this Agreement and the PPA, this Agreement controls.
Notwithstanding anything in this Agreement to the contrary, this Agreement does not limit or
otherwise modify Idaho Power’s rights to disclose any information that Idaho Power is expressly
permitted to disclose to its Board of Directors, or in response to a public records request, under
and in accordance with the PPA or the Retail Agreement.
(d) Except as otherwise provided above in this Section 3, no Party shall issue any
press or publicity release or otherwise release, distribute or disseminate any information to the
public, or respond to any inquiry from the media, or publicly confirm or comment on any
information, public or otherwise, concerning the Retail Agreement, this Agreement or the PPA
or the participation of the other Party in the transactions contemplated hereby without the prior
written approval of Customer, which approval shall not be unreasonably withheld, delayed or
conditioned. This provision shall not prevent the Parties from releasing information (i) which is
required to be disclosed in order to obtain permits, licenses, releases and other approvals; (ii) as
necessary to fulfill such Party’s obligations under this Agreement, the PPA, the Retail
Agreement or as otherwise required by Applicable Laws; or (iii) if the Party seeking approval
makes prompt and commercially reasonable efforts to obtain such approval but the other Party
fails to give a definitive response within ten (10) Business Days.
(e) The Parties shall work together in good faith to (i) cause the correction of any
claim or public communications that conflicts with this Agreement or that, in a Party’s
reasonable judgment, is otherwise likely to mislead any third party acting reasonably under the
circumstances and (ii) respond to, and mitigate the effects of, any claim on RECs made by a third
party.
(f) Except as expressly set forth herein, nothing in this Agreement grants to any Party
the right to use any names or logos or other intellectual property of any other Party or its
affiliates.
(g) This Section 3 will survive any termination of this Agreement for a period of
three years.
(h) Idaho Power and Developer acknowledge and agree that Customer has no
obligations of payment or performance to the Developer under, pursuant to, in connection with,
or due to the PPA, for any reason, including on account of this Agreement, the Retail Agreement,
or otherwise.
4. REC Claims.
(a) During and after the term of this Agreement, each Party will comply with the
REC Communication Standards, with respect to the each of the PPA and the Facility, and the
RECs associated therewith.
(b) This Section 4 will survive any termination of this Agreement for a period of
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three (3) years.
5. Compliance. Notwithstanding anything to the contrary in this Agreement, a Party
may make such filings, reports, and public statements that it believes are required to comply with
Applicable Law.
6. Facility Images. Upon request from Customer, Developer shall promptly provide
to Customer copies of digital images of the Facility showing the Facility during construction and
as constructed. The promotional rights granted to Customer herein include the right to use and
distribute Facility images.

7. Authority. Each Party represents and warrants to the other that it has full power
and authority to enter into and perform this Agreement.
8. Governing Law; Venue. The validity, interpretation and effect of this Agreement
are governed by and will be construed in accordance with the laws of the State of Idaho.

9. Waiver of Right to Jury Trial. TO THE FULLEST EXTENT PERMITTED BY
LAW, EACH OF THE PARTIES HERETO WAIVES ANY RIGHT IT MAY HAVE TO A
TRIAL BY JURY IN RESPECT OF LITIGATION DIRECTLY OR INDIRECTLY ARISING
OUT OF, UNDER OR IN CONNECTION WITH THIS AGREEMENT. EACH PARTY
FURTHER WAIVES ANY RIGHT TO CONSOLIDATE ANY ACTION IN WHICH A JURY
TRIAL HAS BEEN WAIVED WITH ANY OTHER ACTION IN WHICH A JURY TRIAL
CANNOT BE OR HAS NOT BEEN WAIVED.
10. Further Assurances. The Parties agree to cooperate in good faith, take additional
actions, and execute documents as may be reasonably required to implement this Agreement.
Notwithstanding the foregoing sentence, each Party’s obligations and liability hereunder is
separate, the obligations of the Parties are not joint and several, and no Party shall be liable for
any other Party’s breach or performance hereof.
11. Limitations on Damages. NO PARTY WILL BE LIABLE TO ANY OTHER
PARTY UNDER THIS AGREEMENT FOR SPECIAL, PUNITIVE, INDIRECT,
EXEMPLARY OR CONSEQUENTIAL DAMAGES, WHETHER SUCH DAMAGES ARE
ALLOWED OR PROVIDED BY CONTRACT, TORT (INCLUDING NEGLIGENCE),
STRICT LIABILITY, STATUTE OR OTHERWISE.
12. Notices. All notices, demands, requests, or other communications required or
permitted under this Agreement shall be delivered to the addresses set forth beneath the parties’
signatures below. Notices required to be in writing shall be delivered by hand delivery, U.S.
Mail, or express courier, and in all cases also by email (on the same day as delivery to the courier
or deposit in the U.S. Mail) at the email address provided on the signature line or as updated by
giving notice. Except as may otherwise be specified in this Agreement, all notices, requests,
statements and other communications shall be deemed to have been duly given (a) on the date of
delivery if delivered by hand or by express courier, or (b) five days after deposit in the U.S. Mail.
A Party may change its respective notice information upon giving the other Parties at least 10
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days’ prior notice thereof.
13. Miscellaneous. This Agreement may only be amended by a writing signed by all
Parties. This Agreement is not assignable by a Party without the prior written consent of the
non-assigning Parties, which consent shall not be unreasonably withheld; provided, however,
that any Party may assign this Agreement to any permitted assignee of the Retail Agreement or
PPA, as applicable. The assigning Party must provide notice of the assignment to the non-
assigning Parties within 10 days following such assignment. This Agreement will be binding
upon and inure to the benefit of the Parties’ successors and permitted assigns. Nothing contained
in this Agreement creates a joint venture or partnership between the Parties. There are no
intended third-party beneficiaries hereof, and the Parties do not intend to create or confer any
right or interest in or to, or to grant any remedies to, any third party as a beneficiary hereof or of
any duty, obligation, or undertaking established herein.
14. Counterpart; Signatures. This Agreement may be executed in one or more
counterparts, each of which is an original, but all of which together constitute one and the same
instrument. Delivery of a PDF copy of an original signature, or executing using a digital or
electronic signature, shall have the same force and effect as execution of an original.
IN WITNESS WHEREOF the Parties hereto have executed this Agreement as of the
Effective Date.
[_________]

By __________________
Name __________________
Title __________________
Date __________________
Address for Notices:

Attn:
Email Address:
Idaho Power

By __________________
Name __________________
Title __________________
Date __________________
Address for Notices:
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Attn:
Email Address:
[Developer]

By __________________
Name __________________
Title __________________
Date __________________
Address for Notices:

Attn:
Email Address:

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EXHIBIT 18
FORM OF CONSTRUCTION PROGRESS REPORT

Construction Progress Report
of
_________________________
(“Seller”)
provided to
[BUYER ENTITY]
(“Buyer”)
[Date]

Instructions.
Any capitalized terms used in this report which are not defined herein are defined in the Power
Purchase Agreement by and between , (“Seller”) and [BUYER ENTITY] dated
____________, (the “Agreement”).
Seller shall review the status of each milestone of the construction schedule for the Facility and
Seller shall identify such matters referenced in clauses (i)-(v) below as known to Seller and
which in Seller’s reasonable judgment are expected to adversely affect the schedule, and with
respect to any such matters, shall state the actions which Seller intends to take to ensure that the
milestones will be attained by their required dates. Such matters may include:
(i) Any material matter or issue arising in connection with a Permit, or compliance
therewith, with respect to which there is an actual or threatened dispute over the interpretation of
an Applicable Law, actual or threatened opposition to the granting of a necessary Permit, any
organized public opposition, any action or expenditure required for compliance or obtaining
approval that Seller is unwilling to take or make, or in each case which could reasonably be
expected to materially threaten or prevent financing of the Facility, attaining any milestone, or
obtaining any contemplated agreements with other parties which are necessary for attaining any
milestone or which otherwise reasonably could be expected to materially threaten Seller’s ability
to attain any milestone.

(ii) Any development or event in the financial markets or the independent power industry,
any change in taxation or accounting standards or practices or in Seller’s business or prospects
which reasonably could be expected to materially threaten financing of the Facility, attainment of
any milestone or materially threaten any contemplated agreements with other parties which are
necessary for attaining any Milestone or could otherwise reasonably be expected to materially
threaten Seller’s ability to attain any milestone;
(iii) A change in, or discovery by Seller of, any legal or regulatory requirement which would
reasonably be expected to materially threaten Seller’s ability to attain any milestone;
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(iv) Any material change in Seller’s schedule for initiating or completing any material aspect
of Facility;
(v) The status of any matter or issue identified as outstanding in any prior Construction
Progress Report and any material change in Seller’s proposed actions to remedy or overcome
such matter or issue.
For guidance, each “overview” subsection shall include a summary of the status and progress of
major activities associated with that section, whether planned, in progress, or completed,
including relevant dates. Each “recent activities” subsection shall include details of activities
during the previous month. Each “expected activities” subsection shall include a brief list of
major activities planned for the current month.
Seller shall complete, certify, and deliver this form of Construction Progress Report to
[____________], together with all attachments and exhibits, with copies of this report delivered
to [____________].
1. Executive Summary
Please provide an overview of the Facility, including technology, size, location, and ownership.
Please provide a brief chronological cumulative summary of the major activities completed for
each of the following aspects of the Facility. Include the date each item was added to the
summary:
1.1 Milestones

1.2 Permits

1.3 Financing
1.4 Property Acquisition
1.5 Design and Engineering
1.6 Major Equipment procurement
1.7 Construction
1.8 Interconnection
1.9 Startup
2. Milestones

In this section, please include information on each significant milestone related to the Facility.
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2.1 Milestone schedule
Please state the status and progress of each milestone. Provide the date of completion of
completed milestone(s) and the expected date of completion of uncompleted milestone(s). The
expected date is the current best estimate, and may change from time to time as better
information becomes available.
2.2 Remedial Action Plan (applicable if Seller fails to achieve a milestone by the anticipated
milestone date)

Please describe in detail any delays (actual or anticipated) beyond the scheduled milestone dates.
Describe the cause of the delay (e.g., governmental approvals, financing, property acquisition,
design activities, equipment procurement, Facility construction, interconnection, or any other
factor). Describe Seller’s remedial action plan which shall include detailed plans to achieve the
missed milestone and subsequent milestones.
3. Permits
In this section, please include information on each of the Permits required for the construction of
the Facility and the status thereof. List the applicable government agency, the type of
application/approval requested, and the dates (expected or actual) of significant activity.
Significant activity includes application submission, notice of complete application, notice of
preparation, public hearing or comment period, draft documents or approvals, final documents or
approvals, notice of determination, or issuance of permit. If the government agency maintains a
website with information on the approval process for the Facility, please provide a link.
3.1 Environmental Impact Report/Statement (EIR/EIS) of Conditional Use Permit (CUP)

Please describe the environmental review process and each of the Permit(s) to be obtained for the
Facility. Provide the status and completion date (expected or actual) of each significant activity
in the process.

3.2 Other Permits

Please describe each of the other Permits to be obtained for the Facility. Provide the status and
completion date (expected or actual) of each significant activity.

3.3 Recent Permit activities

Please describe in detail the Permit activities that occurred during the previous calendar month.

3.4 Expected Permit activities

Please list all Permit activities that are expected to be performed during the current calendar
month.

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4. Financing Activities
In this section, please include information on each separate phase of financing for the Facility.
Include information on debt, equity, or federal or state loans or grants.
4.1 Overview of financing activities
Please provide a summary of the status and progress of each major financing activity, including
the date of execution of significant documents, and information on the expected timing of future
significant activities.

4.2 Recent financing activities
Please describe in detail the financing activities that occurred during the previous calendar
month.
4.3 Expected financing activities
Please list the financing activities that are expected to be performed during the current calendar
month.
5. Property Acquisition Activities
In this section, please include information on property acquisition or site control activities for the
Facility.
5.1 Overview of property acquisition activities

Please provide a summary of the status and progress of each major property acquisition activity,
including the date of execution of significant documents, and information on the expected timing
of future significant activities.

5.2 Recent property acquisition activities

Please describe in detail the property acquisition activities that occurred during the previous
calendar month.

5.3 Expected property acquisition activities
Please list the property acquisition activities that are expected to be performed during the current
calendar month.
6. Design and Engineering Activities
In this section, please include information on the status of design and engineering for the
Facility.
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6.1 Overview of design activities
Please provide a summary of the status and progress of each major design or engineering
activity, including dates of completion of significant activities and expected timing of future
activities.
6.2 Recent design activities
Please describe in detail the design activities that occurred during the previous calendar month.
6.3 Expected design activities
Please list the design activities that are expected to be performed during the current calendar
month.
7. Major Equipment Procurement
In this section, please include information on all major equipment to be procured for all portions
of the Facility to be completed by Seller, including switchyards, substations and any other
interconnection equipment, in addition to generating and auxiliary equipment.
7.1 Overview of major equipment procurement activities
For each type of equipment, list the number of each major item to be procured, the manufacturer,
model number (if applicable), and rating. List the delivery schedule (expected or actual as
applicable), breaking out the number of each item (to be) procured or delivered in each month.

7.2 Recent major equipment procurement activities
Please describe in detail the major equipment procurement activities that occurred during the
previous calendar month.
7.3 Expected major equipment procurement activities
Please list the major equipment procurement activities that are expected to be performed during
the current calendar month.
8. Construction Activities
In this section, please include information on the status of any construction-related factors that
may affect the ability of the Facility to deliver the Facility Energy. Include information on the
Facility infrastructure, generating equipment, and major auxiliary equipment. Also include
information on the substations, switchyards, gen-ties, telecommunications equipment or other
interconnection facilities that are the direct responsibility of the Facility.
8.1 Overview of major construction activities
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Please provide a summary of the status and progress of each major construction activity for all
portions of the Facility, including a schedule showing expected or actual dates as applicable.
Provide the name of the EPC Contractor, the date of execution of the EPC Contract, and the date
of issuance of a Notice to Proceed (or equivalent). For each major type of equipment, break out
the number of each item (to be) installed or commissioned in each month.
8.2 Recent construction activities
Please describe in detail the construction activities that occurred during the previous calendar
month.
8.3 Expected construction activities
Please list the interconnection activities that are expected to be performed during the current
calendar month.
8.4 EPC Contractor Progress Report
Please attach a copy of the progress reports received during the previous calendar month from
the EPC Contractor pursuant to the construction contract between Seller and EPC Contractor,
certified by the EPC Contractor as being true and correct as of the date issued.
8.5 Look-ahead construction schedule
Please provide a look-ahead construction schedule covering at least three months.
8.6 OSHA Recordables

Please list all OSHA recordables from the previous calendar month.
8.7 Work stoppages
Please describe any work stoppage from the previous calendar month and its effect on the
construction schedule.
9. Interconnection Activities
In this section, please include information on interconnection-related factors that may affect the
ability of the Facility to deliver Facility Energy. Include information on the status of
interconnection studies, Interconnection Agreements, design and construction of interconnection
facilities (e.g., substations, switchyards, gen-ties, system protection schemes,
telecommunications equipment to the extent not already covered in the Facility construction
information in Section 8), network upgrades, and grid outage or interconnection schedules.
9.1 Overview of interconnection activities
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Please provide a summary of the status and progress of each major interconnection activity
including dates of completion of significant activities and expected timing of future activities.
9.2 Recent interconnection activities
Please describe in detail the interconnection activities that occurred during the previous calendar
month.
9.3 Expected interconnection activities
Please list the interconnection activities that are expected to be performed during the current
calendar month.
10. Startup
In this section, please include information on the status of activities related to preparation for
Commercial Operation, including equipment testing, commissioning, release to operations,
requirements of the grid operator, and any other activities that must be conducted before the
Facility may deliver Energy to the grid or declare Commercial Operation.
10.1 Overview of startup activities
Please provide a summary of the status and progress of each major startup activity including
dates of completion of significant activities and expected timing of future activities.
10.2 Recent startup activities
Please describe in detail the startup activities that occurred during the previous calendar month.
10.3 Expected startup activities
Please list the startup activities that are expected to be performed during the current calendar
month.
11. Other Information Reasonably Requested by Buyer
11.1 Litigation
Please list any communication received directly or indirectly from any third party that is in the
nature of a threat of litigation, a litigation hold notice, a summons and complaint, or a
commencement of a judicial, regulatory, or arbitration proceeding or investigation against Seller
or concerning the Facility
11.2 [_________________]
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I, ________________, on behalf of and as an authorized representative of ________________,
do hereby certify that any and all information contained in this Seller’s Construction Progress
Report is true and accurate, and reflects, to the best of my knowledge, the current status of the
construction of the Facility as of the date specified below.
By:_______________________________
Name:_____________________________
Title:______________________________
Date:______________________________

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EXHIBIT 19
FORM OF OPERATIONS REPORT

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EXHBIT 20
[IDAHO POWER FORM OF WREGIS QRE AGREEMENT]

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EXHIBIT 21
FORM OF LENDER CONSENT
CONSENT AND AGREEMENT

This Consent and Agreement (this “Consent”) is made and entered into as of ___ _, 20__, by and
between Idaho Power Corporation (“Buyer”), and _______ (“Lender”).

RECITALS

A. ________ (“Seller”), has entered into that certain Loan Agreement, dated as of ___ __,
20__ (as amended, restated, supplemented, or otherwise modified from time to time, the “Loan
Agreement”), with Lender in order to finance construction of a photovoltaic solar electric energy
generating facility owned by Seller and located at ____ (the “Solar Project”).

B. Seller and Buyer have entered into that certain Power Purchase Agreement, dated as of
____ (as amended, restated, supplemented or otherwise modified from time to time, the “PPA”),
relating to the energy generated by the Solar Project to supply the needs of Buyer’s customer
under a Special Contract, [_________] (“Customer”).

C. As part of the transactions contemplated by the Loan Agreement, Lender has received a
pledge of all the limited liability company interests in Seller (the “Pledged Equity”), and Seller
has collaterally assigned all of its rights, title and interests in, to and under the PPA (the “Pledged
PPA”, collectively with the Pledged Equity, the “Assigned Interest”) to Lender.

AGREEMENTS

NOW, THEREFORE, for and in consideration of the premises and the mutual covenants
contained herein, and for other good and valuable consideration, the receipt, adequacy and legal
sufficiency of which are hereby acknowledged, and intending to be legally bound hereby, the
parties hereby agree as follows:

1. Consent to Assignment. Buyer hereby consents to the collateral assignment by
Seller to Lender of the Pledged PPA and the pledge to Lender of the Pledged Equity and
acknowledges the right of Lender to exercise Lender’s rights and remedies as a secured creditor
with respect to the Assigned Interest.

2. Pledged PPA Step-In. “Subsequent Seller Requirements” means an entity that (a)
is acceptable to Buyer; (b) is not involved, and has no Affiliate involved, in any state or federal
litigation or regulatory proceeding adverse to Buyer or any Affiliate of Buyer, or Customer or
any Affiliate of Customer; (c) has, or has retained, a reputable entity acceptable to Buyer that
has, at least five (5) years’ experience in the operation and maintenance of solar energy facilities
of comparable size to the Facility and the ability perform all aspects of the PPA; (d) has agreed
in writing to be bound by the PPA and to assume all of Seller’s obligations under the PPA; and
(e) is not a Sanctioned Person. Buyer agrees that, if Lender has elected to exercise its rights and
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remedies to proceed against the Pledged PPA, and has so notified Buyer, then, if and only if (i)
the hereinafter-defined Subsequent Seller meets all of the Subsequent Seller Requirements, (ii)
Buyer is holding, and will be holding as of and after the date of assignment, the Project
Development Security or Default Security, as applicable, and (iii) Buyer has not terminated this
PPA pursuant to the terms thereof and of this Consent, then Lender or any assignee or designee
of Lender, including Lender or any purchaser in a foreclosure sale or in lieu of foreclosure of the
Pledged PPA (a “Subsequent Seller”), may be substituted for Seller under the PPA and Buyer
shall recognize such Subsequent Seller as its counterparty under the PPA and, subject to all
rights and remedies of Buyer under the PPA, continue to perform its obligations under the PPA
in favor of such Subsequent Seller. Lender shall have no liability or obligation under the PPA as
a result of this Consent except if Lender becomes a Subsequent Seller. Any Subsequent Seller
succeeds to the interests and obligations of Seller and must comply with the PPA. The transfer
of the PPA from Seller to a Subsequent Seller does not relieve or discharge Seller of its
obligations and liabilities to Buyer which accrued prior to the date of such transfer.
3. Change of Control. Buyer hereby consents to both (i) the pledge of the Pledged
Equity to Lender as part of the transactions contemplated by the Loan Agreement, and (ii) the
transfer of such Pledged Equity, in connection with such an exercise of Lender’s remedies
against the Pledged Equity, to a Subsequent Seller that meets the Subsequent Seller
Requirements, provided that Lender provides written notice to Buyer in advance of any such
transfer.

4. Notice of Default. If Seller defaults in the performance of any of its obligations
under the PPA, Lender may cure such default by the deadline provided therefor in the PPA.
Buyer will not terminate the PPA before providing notice to Lender and giving Lender the
opportunity to cure such default as follows: (a) with respect to payment defaults, or a default
under Section 11.1(l) of the PPA, before the later of (i) ten (10) business days after Buyer’s
delivery of notice to Lender of such default or (ii) five (5) business days plus the number of days
in the applicable cure period provided Seller in the PPA, and (b) with respect to other defaults
(except those set forth in Section 11.1(e)-(j) of the PPA, for which no notice or extension is
promised by Buyer herein), within the greater of (i) ninety (90) days or (ii) thirty (30) days plus
the number of days in the applicable cure period provided Seller in the PPA following delivery
of such notice from Buyer to Lender; provided, however, that such cure period in clause (b) may
be extended by a reasonable period of time, not to exceed an additional ninety (90) days (or, with
respect to an Event of Default under Section 11.1(c) of the PPA, to a date that is no greater than
ninety (90) days after Buyer’s delivery of notice to Lender of such default), if Lender has
commenced and is diligently pursuing appropriate action to cure such non-monetary default;
provided further, that to the extent that such default permits Lender to foreclose on its security
interests in the Assigned Interest and Lender needs to gain possession of the Solar Project in
order to perform such cure, Buyer will allow an additional reasonable amount of time, not to
exceed sixty (60) days, to permit Lender to do so.
5. PPA Termination. Buyer agrees that it shall not, without Lender’s prior written
consent, mutually agree with Seller to a voluntary termination of the PPA; provided that
notwithstanding the foregoing, Buyer may terminate the PPA without Lender consent due to an
uncured Event of Default under the PPA after the expiration of Lender’s rights to cure under
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Section 4 hereof.
6. No Setoff. Notwithstanding any provision to the contrary set forth in this
Consent, Lender may not use the Consent or any other setoff or other right set forth in the PPA
as a basis for any action under, or nonperformance of, its obligations under any letter of credit
naming Buyer or any affiliate as beneficiary, with respect to which the terms of such letter of
credit shall control.
7. Certifications of Buyer. Buyer hereby certifies to Lender, as of the date hereof,
that (i) the execution, delivery and performance by Buyer of this Consent and the PPA have been
duly authorized by all necessary corporate action on the part of Buyer, (ii) each of this Consent
and the PPA is in full force and effect and constitutes the legal, valid and binding obligation of
Buyer, enforceable against Buyer in accordance with its terms, except as the enforceability
thereof may be limited by bankruptcy, insolvency, reorganization or other similar laws affecting
the enforcement of creditors’ rights generally and general equitable principles, (iii) the PPA and
the Acknowledgment of Consent and Agreement (attached hereto) with respect to this Consent
are the only agreements between Seller and Buyer, (iv) a true and correct copy of the PPA is
attached hereto as Exhibit A and the PPA has not been further amended, (v) Buyer is not in
default of any of its obligations under the PPA, (vi) solely to the best of the actual knowledge of
its employees with responsibility for administering the PPA, Seller is not in default of any of its
obligations under the PPA, (vii) solely to the best of the actual knowledge of its employees with
responsibility for administering the PPA, there are no material disputes between Buyer and Seller
under the PPA, (viii) Buyer has not assigned any interest it has in the PPA, and Buyer has no
notice of, and has not consented to, any previous assignment by Seller of all or any part of its
rights under the PPA, (ix) there are no actions pending against Buyer as a debtor under any
federal or state bankruptcy or insolvency laws, (x) there are no proceedings pending or, to
Buyer’s knowledge, threatened against or affecting Buyer before any court, governmental
authority, or arbitration board or tribunal which could reasonably be expected to have a material
adverse effect on the ability of Buyer to perform its obligations under the PPA, (xi) solely to the
best of the actual knowledge of its employees with responsibility for administering the PPA, no
event of Force Majeure has occurred, and (xii) subject to Seller’s obligation to declare the
Commercial Operation Date on or before the Guaranteed Commercial Operation date, solely to
the best of the actual knowledge of Buyer’s employees with responsibility for administering the
PPA, no event or condition exists that would either immediately or with the passage of any
applicable grace period or giving of notice, or both, enable either Buyer or Seller to terminate or
suspend its obligations under the PPA.

8. Replacement Agreement. If the PPA is rejected or terminated as a result of any
bankruptcy, insolvency, reorganization or similar proceeding affecting Seller, Buyer will, at the
option of Lender exercised by providing written notice thereof to Buyer within forty-five (45)
days after such rejection or termination, enter into a new agreement with Lender (or its designee
or assignee) having identical terms as the PPA (subject to any conforming changes (none of
which may include limitation of Buyer’s remedies) necessitated by the substitution of the seller
entity); provided that the following conditions shall apply: (i) the seller under the new agreement
must meet the Subsequent Seller Requirements; (ii) the term under such new agreement shall be
equal to the remaining balance of the term specified in the PPA and (iii) Lender (or its designee
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 447 of 1056
112
or assignee) shall have cured any then-existing payment or performance defaults by Seller under
the PPA (other than the bankruptcy of Seller or a transfer of the Facility to Lender, or of Seller to
Lender, that was in connection with Lender’s foreclosure thereupon and in compliance with this
Consent but that was not in compliance with Section 9.2 of the PPA).

9. Notices. All notices given under this Consent shall be in writing and shall be
deemed effectively given: (a) upon personal delivery to the party to be notified; (b) one business
day after deposit with a reputable overnight courier, prepaid for overnight delivery and addressed
as set forth below, with a copy of the notice simultaneously emailed to each applicable recipient
at the email address shown below; provided that the sending party receives a confirmation of
delivery from the overnight courier service; or (c) three (3) business days after deposit with the
U.S. Post Office, postage prepaid, certified with return receipt requested and addressed to the
party to be notified at the address indicated for such party below with a copy of the notice
simultaneously emailed to each applicable recipient at the email address shown below. The
parties may designate alternative notice addresses upon ten (10) days’ advance written notice to
the other parties:
If to Seller:
With a copy to:
If to Buyer:

With copies to all of:

If to Lender:
With a copy to:
10. Successors and Assigns. This Consent shall be binding upon Buyer and Seller
and their permitted successors and assigns.
11. Termination. Upon the satisfaction in full of Seller’s obligations under the Loan
Agreement (other than contingent indemnification and reimbursement obligations that survive
repayment of the loans and advances, interest fees and other amounts owed under the Loan
Documents): (a) Lender shall notify Buyer of such fact and (b) this Consent shall terminate
without further action of the parties hereto. Additionally, upon Lender’s consummation of all of
its remedies available under this Consent, this Consent shall terminate without further action of
the parties hereto.
12. Waiver of Right to Jury Trial. TO THE FULLEST EXTENT PERMITTED BY
LAW, EACH OF THE PARTIES HERETO WAIVES ANY RIGHT IT MAY HAVE TO A
Exhibit No. 4
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Page 448 of 1056
113
TRIAL BY JURY IN RESPECT OF LITIGATION DIRECTLY OR INDIRECTLY ARISING
OUT OF, UNDER OR IN CONNECTION WITH THIS CONSENT. EACH PARTY
FURTHER WAIVES ANY RIGHT TO CONSOLIDATE ANY ACTION IN WHICH A JURY
TRIAL HAS BEEN WAIVED WITH ANY OTHER ACTION IN WHICH A JURY TRIAL
CANNOT BE OR HAS NOT BEEN WAIVED.

13. Governing Law. This Consent will be governed by and construed in accordance
with the laws of the State of New York, without giving effect to principles of conflicts of law.
14. Severability. If any provision of this Consent or the application thereof is
determined by a court of competent jurisdiction to be invalid, void or unenforceable, the
remaining provisions hereof, or the application of such provision to the parties hereto or
circumstances other than those as to which it has been held invalid or unenforceable, shall
remain in full force and effect and shall in no way be affected, impaired or invalidated thereby,
so long as the economic or legal substance of the transactions contemplated hereby is not
affected in any manner materially adverse to any party by the invalidity, unenforceability or
nullification of the offensive provisions.
15. Amendment. This Consent may not be amended, modified, or changed in any
respect except by an agreement in writing signed by Lender and Buyer. Nothing in this Consent
amends or modifies the PPA.
16. Counterparts; Rules of Construction; Definitions. This Consent may be executed
in one or more counterparts, each of which will be an original and all of which, when taken
together, will constitute one and the same original agreement. All references made (a) in the
neuter, masculine, or feminine gender are made in all such genders, and (b) in the singular or
plural includes the plural or singular number as well. Any capitalized term used but not defined
herein is defined in the PPA.
17. Third Party Rights. Nothing in this Consent, expressed or implied, is intended or
shall be construed to confer upon, or give to any Person, other than Buyer and Lender,
respectively, rights, remedies or claims, legal or equitable, under or by reason hereof, or any
covenant or condition hereof; and this Consent and the covenants and agreements, here contained
are and shall be held for the sole and exclusive benefit of Buyer and Lender.
18. Seller Acknowledgement of Consent and Agreement. Buyer’s obligations under
this Consent are conditioned upon the execution and delivery by Seller to Buyer of the
Acknowledgment of Consent and Agreement attached hereto.
[REMAINDER OF PAGE LEFT INTENTIONALLY BLANK]

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 449 of 1056
114
IN WITNESS WHEREOF, the parties hereto have caused this Consent to be duly executed and
delivered by their duly authorized signatories as of the date first above written.
IDAHO POWER COPRPORATION
By: ______________________________________
Name:_________________________________
Title:__________________________________
[LENDER]
By _______________________
Its _______________________

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 450 of 1056
115
ACKNOWLEDGEMENT OF CONSENT AND AGREEMENT

Reference is made to the Consent and Agreement dated as of ______ (the “Consent and
Agreement”) between Idaho Power Corporation (as “Buyer”), and ______ (as “Lender”). _____
as “Seller” under the PPA (as defined in the Consent and Agreement) hereby directs Buyer to
pay any amounts payable by Buyer under the PPA, as and when required under the PPA,
pursuant to the payment instructions delivered and effective as of or proximate to the date hereof,
from Seller to Buyer, or as may otherwise be specified from time to time by Lender or Seller to
Buyer in writing. Any payment made to Seller or as Buyer in good faith believes to have been
directed by Seller or Lender shall discharge any obligation of Buyer to Seller with respect to the
making of such payment. Seller, by its execution of this Acknowledgment of Consent and
Agreement, acknowledges and agrees that, notwithstanding any term to the contrary in the PPA,
Buyer and Lender may perform all acts or obligations as set forth in the Consent and Agreement,
and Buyer may perform as set forth herein or as otherwise purportedly instructed by Lender,
including, without limitation, the manner and place of any payments to be made by Buyer that
would otherwise be required pursuant to the PPA, and further agrees and consents to the various
agreements made by Buyer in the Consent and Agreement, issues or confirms the instructions
contained in the Consent and Agreement or herein or as hereafter issued by Seller or Lender,
agrees to indemnify Buyer for any damages or liabilities suffered in the performance of the
Consent and Agreement or such instruction; and further agrees that none of the execution of the
Consent and Agreement, the performance by Buyer or Lender of any of their respective
obligations thereunder, the exercise of any of the rights of Buyer or Lender thereunder, or the
acceptance by Buyer of performance of the PPA by any party acting at the direction of Seller,
Lender, or a Subsequent Seller shall subject Buyer to liability to Seller or release Seller from any
obligation of Seller under the PPA. Seller acknowledges that Buyer need not enter into any
agreement in the nature of the Consent and Agreement with any of Seller’s other lenders prior to
the termination of the Consent and Agreement. Nothing in this Acknowledgment of Consent and
Agreement or in the Consent and Agreement amends or modifies the PPA. Seller shall have no
rights against Buyer, under the PPA or otherwise, arising out of or on account of the Consent and
Agreement or Buyer’s performance (or nonperformance) thereunder or of the instruction.

Agreed to and Accepted:

By:
Its:
Date:

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 451 of 1056
116
EXHIBIT 22
FORM OF ESTOPPEL CERTIFICATE
ESTOPPEL CERTIFICATE
This Estoppel Certificate (“Estoppel”) is dated _____ __, 20__. Reference is made to that
certain Renewable Energy Purchase Agreement, dated as of ______ (the “PPA”), by and
between Idaho Power Corporation (“Buyer”), and _________ (“Seller”) concerning output of a
[wind/solar] energy generating facility owned by Seller and located in ____ (the “Project”).
This certificate is delivered by Buyer to __________ (“Investor”) and _______ as Administrative
Agent (as defined in the Consent defined below) (“Administrative Agent”). Capitalized terms
used but not defined herein are defined in the PPA.
Buyer certifies that, as of the date hereof, that (i) the execution, delivery and performance by
Buyer of this Estoppel and the PPA have been duly authorized by all necessary action on the part
of Buyer, (ii) each of this Estoppel and the PPA is in full force and effect and constitutes the
legal, valid and binding obligation of Buyer, enforceable against Buyer in accordance with its
terms, except as the enforceability thereof may be limited by bankruptcy, insolvency,
reorganization or other similar laws affecting the enforcement of creditors’ rights generally and
general equitable principles, (iii) the PPA and the Acknowledgment of Consent and Agreement
dated _____ are the only agreements between Seller and Buyer, (iv) a true and correct copy of
the PPA is attached hereto as Exhibit A and the PPA has not been further amended, (v) solely to
the best of the actual knowledge of its employees responsible for administering the PPA, Buyer
is not in default of any of its obligations under the PPA, (vi) solely to the best of the actual
knowledge of its employees with responsibility for administering the PPA, Seller is not in default
of any of its obligations under the PPA, (vii) solely to the best of the actual knowledge of its
employees with responsibility for administering the PPA, there are no material disputes between
Buyer and Seller under the PPA, (viii) Buyer has not assigned any interest it has in the PPA, and
Buyer has no notice of, and has not consented to, any previous assignment by Seller of all or any
part of its rights under the PPA, (ix) there are no actions pending against Buyer as a debtor under
any federal or state bankruptcy or any other similar laws, (x) there are no proceedings pending
or, to Buyer’s knowledge, threatened against or affecting Buyer before any court, governmental
authority, or arbitration board or tribunal which could reasonably be expected to have a material
adverse effect on the ability of Buyer to perform its obligations under the PPA, (xi) solely to the
best of the actual knowledge of its employees with responsibility for administering the PPA, no
event of Force Majeure has occurred, and [(xii) subject to Seller’s obligation to declare the
Commercial Operation Date on or before the Guaranteed Commercial Operation Date, solely to
the best of the actual knowledge of Buyer’s employees with responsibility for administering the
PPA][omit if estoppel delivered after COD], no event or condition exists that would either
immediately or with the passage of any applicable grace period or giving of notice, or both,
enable either Buyer or Seller to terminate or suspend its obligations under the PPA. Buyer
disclaims any obligation to advise Investor or Administrative Agent of any changes to the
foregoing.

IN WITNESS WHEREOF, the undersigned has caused this Estoppel to be signed by its
Exhibit No. 4
Case No. IPC-E-24-16
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117
authorized signatory as of the date first set forth above.
IDAHO POWER CORPORATION
By: ______________________________________
Name:_________________________________
Title:__________________________________
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 453 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements
{00325040.DOCX; 1}Active 103483969.1 1
Bidder shall review and redline the following draft agreement into the submitted proposal for the specific
product type and ownership structure as defined in this RFP.
For purposes of clarity, bidder shall redline these terms and conditions, and understands that the
following will be incorporated into a materially similar power purchase agreement for other products as
additionally included in this Exhibit H.
This draft Exhibit H is not comprehensive and does not constitute a binding offer, shall not form the bases
for an agreement by estoppel nor otherwise, and is not conditions upon each party’s receipt of all
requirement management approvals (including final credit and legal approval) and all regulatory
approvals. Any actions taken by a party in reliance on the terms set forth in this working draft or on
statements made during negotiations pursuant to this working draft shall be at that party’s own risk. Until
this agreement is negotiated, approved by management, executed, delivered, and approved by all required
regulatory bodies, no party shall have any other legal obligations, expressed or implied, or arising in any
other manner under this working draft or in the course of negotiations.
WIND PERFORMANCE GUARANTEES

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 454 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements
{00325040.DOCX; 1}Active 103483969.1 2
1. Definitions.
Capitalized terms used in this Exhibit [ ] and not defined in this Exhibit will have the
meaning assigned in the Agreement.
“Annual Report” is defined in Section 2.4 of this Exhibit.
“Available Resource” means the wind speed, wind direction, air pressure, air temperature,
precipitation, and relativity humidity to be used to determine Lost Metered Energy, calculated in
accordance with Section 2.3 of this Exhibit.
“Availability Damages” is defined in Section 2.2 of this Exhibit.
“Availability Factor” means a percentage calculated as (a) 100, multiplied by (b) the result
of (i) the sum of all Metered Energy and Lost Metered Energy in the relevant Contract Year,
divided by (ii) the Expected Energy in the relevant Contract Year.
“Availability Shortfall” means, for any Contract Year where the Guaranteed Availability
is not met, an amount of Energy, expressed in MWh, equal to (a) the Guaranteed Availability
Factor minus the Availability Factor during such Contract Year, multiplied by (b) the Expected
Energy for such Contract Year.
“Average Energy Value” means, for any Contract Year, [insert description of appropriate
pricing] for the applicable Contract Year weighted based on the Expected Energy for such Contract
Year.
“Average Environmental Attribute Value” means the fair market price (expressed in
$/MWh or $/MW, as applicable) of Attributes of the same vintage and quality as the RECs to be
transferred under this Agreement, determined by averaging the price quotes from two independent
third party brokerage services, reasonably selected by Purchaser.
“Damages Rate” means, for any Contract Year, an amount equal to the Average Energy
Value for such period, plus the Average Environmental Attribute Value for such Contract Year,
minus the Contract Rate for such period, provided that the Damages Rate will never be less than
$0/MWh.
“Expected Energy” means an amount for any given measurement period calculated by
applying the Available Resource to the Reference Power Curve. The calculation shall assume that
(i) the Project is one hundred percent (100%) available and (ii) the turbines perform as designed
by the manufacturer, specifically relative to the Reference Power Curve. Losses as reported in the
Wind Resource Assessment shall be applied to the calculation. The calculation of the Expected
Energy shall include a correction for air density.
“Guaranteed Availability” is defined in Section 2.1 of this Exhibit.
Exhibit No. 4
Case No. IPC-E-24-16
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Page 455 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements
{00325040.DOCX; 1}Active 103483969.1 3
“Guaranteed Availability Factor” means [ percent ([ ]%)], except that for the first
Contract Year the Guaranteed Availability factor shall mean [ percent ([ ]%)].
“Lost Metered Energy” means, for any measurement period, the amount of Energy (based
on actual wind and availability data during such measurement period) equal to the difference
between the amount of Metered Energy in such measurement period and the aggregate amount of
Energy that would have been Metered Energy in such measurement period, but for (i) voluntary
curtailments directed by Purchaser, (ii) a system curtailment order, (iii) an event of Force Majeure,
(iv) a Purchaser Event of Default, (v) Weather Events, and (vi) planned outages up to [__] hours
in a given Contract Year.
“Reference Power Curve” means the turbine manufacturer’s reference power curve used
in the Wind Resource Assessment. The Reference Power Curve shall not be subject to adjustment
for any reason.
“Weather Event” shall mean any condition causing a turbine to not generate or deliver
Energy as a result of icing on turbine blades, lightning strikes, wind speeds in excess of, or below,
the cut in/out speed for the turbines (as specified in the manufacturers’ recommendations for such
turbines), and any period during which a hail or tornado warning exists, provided that (i) such
Weather Event is not attributable to fault or negligence on the part of Seller, (ii) such Weather
Event is caused by factors beyond Seller's reasonable control, and (iii) despite taking all reasonable
technical and commercial precautions and measures to prevent, avoid, mitigate or overcome such
event and the consequences thereof, Seller has been unable to prevent, avoid, mitigate or overcome
such event or consequences.
“Wind Resource Assessment” means the wind resource assessment report prepared by
Seller after the Major Equipment Commitment Date, a complete and unredacted copy of which
shall be provided to Purchaser no later than sixty (60) days prior to the Commercial Operation
Date.
2. Availability Guarantee.
2.1 Availability Guarantee. Seller guarantees that the Project will achieve an
Availability Factor during each Contract Year equal to or greater than the
Guaranteed Availability Factor (the “Guaranteed Availability”).
2.2 Availability Damages. For any Contract Year during which Seller fails to achieve
the Guaranteed Availability, Seller will pay Purchaser liquidated damages in the
amount equal to the product of (a) the Availability Shortfall, times (b) the Damages
Rate (“Availability Damages”). Except as provided in [insert cross reference to
applicable default tied to poor availability], the payment of Availability Damages
shall be Purchaser’s sole and exclusive remedy, and Seller’s sole and exclusive
liability, for any Availability Shortfall. If a payment is due from Seller, Seller shall
include on the next invoice issued pursuant to Section [ ] after the delivery of the
Annual Report, or as soon as reasonably practicable thereafter, a credit for such
Availability Damages. Purchaser shall be permitted to net the amount of any
Availability Damages against any amounts due and owing from Purchaser to Seller,
Exhibit No. 4
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E. Hackett, IPC
Page 456 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements
{00325040.DOCX; 1}Active 103483969.1 4
regardless of whether or not Seller has yet to include such amounts on the next
invoice to be issued.
2.3 Calculation of Available Resource and Lost Metered Energy.
a. Calculation of Lost Metered Energy. Lost Metered Energy shall be
calculated on a unit-by-unit basis on ten (10) minute intervals as follows:
i. First, if the nearest comparable unit is producing energy without
curtailment or error, the amount of energy produced by such unit
(less any energy produced by the unit for which Lost Metered
Energy is being calculated) shall be used for the applicable
measurement period.
ii. If the nearest comparable unit is not producing energy without
curtailment or error during such measurement period, the next most
comparable unit that is producing energy without curtailment or
error shall be used for determining the Lost Metered Energy.
iii. If neither of the foregoing comparable units is producing energy
without curtailment or error during such measurement period, then
Lost Metered Energy shall be calculated by applying the Available
Resource in such measurement period to the Project Power Curve.
The Available Resource shall be calculated on a unit-by-unit basis
on ten (10) minute intervals as follows:
A. First, if the unit-mounted anemometer or other industry-
approved remote sensing technology for the unit in question
is operating without error, the Available Resource as
measured by such equipment.
B. If the unit-mounted anemometer or other industry-approved
remote sensing technology for the unit in question is not
available, then the closest comparable unit-mounted
anemometer or other industry-approved remote sensing
technology that is operating without error shall apply.
C. If the closest comparable unit-mounted anemometer or other
industry-approved remote sensing technology is not
available, then the Available Resource shall be determined
by averaging the available unit-mounted anemometers then
available, or by other industry-approved remote sensing
technology then available, across the Project.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 457 of 1056
Idaho Power 2026 All Source RFP
Exhibit H – Draft Form Agreements
{00325040.DOCX; 1}Active 103483969.1 5
2.4 Reporting.
a. From and after the Commercial Operation Date, Seller shall calculate the
Metered Energy, Lost Metered Energy and Expected Energy on an hourly basis and, on a
quarterly basis no later than the tenth (10th) day after the end of each quarterly period during
a Contract Year, Seller shall furnish Purchaser with a report detailing the foregoing for the
prior quarter. If requested by Purchaser, Seller shall also furnish detailed backup data
supporting the calculations in such report, including the hour counters and event code
reporting on a turbine-by-turbine basis as returned by the turbine controllers and SCADA
system for the Project and any adjustments made to such hour counter and event code
reporting by Seller. If requested by Purchaser, the Parties shall meet to discuss and use
commercially reasonable efforts to agree upon any reasonably proposed adjustments to the
various hour counters and event codes returned by the turbine controllers and the SCADA
system, with any disputes arising therefrom being subject to Section [ ].
b. No later than the thirty (30) days after each Contract Year, Seller shall
deliver to Purchaser a report detailing the Metered Energy, Lost Metered Energy and
Expected Energy on an hourly basis during such Contract Year and calculating the
Availability Factor for such Contract Year and the amount of any Availability Damages, if
any, due to Purchaser (the “Annual Report”). If requested by Purchaser, Seller shall also
furnish detailed backup data supporting the calculations in the Annual Report, including
the hour counters and event code reporting on a turbine-by-turbine basis as returned by the
turbine controllers and SCADA system for the Project and any adjustments made to such
hour counter and event code reporting by Seller. If requested by Purchaser, the Parties shall
meet to discuss and use commercially reasonable efforts to agree upon any reasonably
proposed adjustments to the various hour counters and event codes returned by the turbine
controllers and the SCADA system, and Seller’s calculation of the Availability Factor for
such Contract Year, with any disputes arising therefrom being subject to Section [ ].
c. All reports and data contemplated by this Section 2.4 shall be furnished in
their native readable format (e.g., while providing a pdf is permissible, it shall be
accompanied by the original report and data in its native software format such that it is
capable of being read electronically by Purchaser).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 458 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Internal Use Only
Minimum Requirements for Battery Energy Storage System (BESS)
Engineering, Procurement, and Construction
Technical Specification
409298.65.7500
THIS GENERIC SPECIFICATION IS DESIGNED TO PROVIDE A BASIS FOR A VARIETY OF BATTERY ENERGY STORAGE
SYSTEMS (BESS) APPLICATIONS AND MUST BE CUSTOMIZED FOR THE SPECIFIC PROJECT REQUIREMENTS AND
SITE CONDITIONS BY THE ENGINEER OF RECORD PRIOR TO FINALIZING THEIR DESIGN.

Rev. A

28 June 2021
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 459 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 1
Table of Contents
GENERAL.....................................................................................................................................................5
1.1 General Description ................................................................................................................................. 5
1.2 Work Included in Contractors Scope ................................................................................................ 5
1.3 Work Not in Contractor’s scope .......................................................................................................... 6
1.4 Permits and Agreements........................................................................................................................ 6
1.5 Equipment .................................................................................................................................................... 6
1.6 Use and Operation .................................................................................................................................... 6
...........................................................................................................8
2.1 Site Location / Interconnecting Provisions.................................................................................... 8
2.2 Site Conditions ........................................................................................................................................... 8
2.3 Site Arrangement ...................................................................................................................................... 8
2.4 Seismic ........................................................................................................................................................... 8
2.5 Dead Loads .................................................................................................................................................. 8
2.6 Live Loads .................................................................................................................................................... 9
2.7 Soil and Hydrostatic Loads ................................................................................................................... 9
2.8 Wind Loads .................................................................................................................................................. 9
2.9 Snow Loads .................................................................................................................................................. 9
2.10 Rain Loads .................................................................................................................................................... 9
2.11 Construction Loads .................................................................................................................................. 9
......................................................................11
3.1 General Description .............................................................................................................................. 11
3.2 Items Provided by Others ................................................................................................................... 11
3.3 Safety Requirements ............................................................................................................................. 11
3.4 Electrical and Control ........................................................................................................................... 11
3.5 Civil / Structural ..................................................................................................................................... 11
3.6 Engineering .............................................................................................................................................. 12
3.7 Procurement ............................................................................................................................................ 12
3.8 Construction ............................................................................................................................................. 12
3.9 Special Inspections ................................................................................................................................ 13
3.10 Commissioning and Startup .............................................................................................................. 13
3.11 Training ...................................................................................................................................................... 14
3.12 Specifications and Standards ............................................................................................................ 14
...............................................................................................................................................15
4.1 General ....................................................................................................................................................... 15
4.2 Codes and Standards ............................................................................................................................ 15
4.3 Fencing ....................................................................................................................................................... 15
4.4 Dewatering ............................................................................................................................................... 15
4.5 Grading and Drainage .......................................................................................................................... 15
4.6 Heavy Loads ............................................................................................................................................. 16
4.7 Compaction ............................................................................................................................................... 16
4.8 Roads ........................................................................................................................................................... 16
4.9 Landscaping and Restoration ........................................................................................................... 17
4.10 Existing Conditions ............................................................................................................................... 17
....................................................................................................18
5.1 General ....................................................................................................................................................... 18
5.2 Considerations ........................................................................................................................................ 18
5.3 Analysis ...................................................................................................................................................... 18
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 460 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 2
5.4 Slab-on-Grade..........................................................................................................................................18
5.5 Foundations.............................................................................................................................................. 18
5.6 Equipment Bases .................................................................................................................................... 19
NON-OCCUPI .......................................................................20
6.1 General ....................................................................................................................................................... 20
6.2 Materials .................................................................................................................................................... 20
6.3 Occupancy Class ..................................................................................................................................... 20
6.4 Partition Walls......................................................................................................................................... 20
6.5 Windows .................................................................................................................................................... 20
6.6 Doors ........................................................................................................................................................... 20
6.7 Floor Coverings ....................................................................................................................................... 21
6.8 Fire Detection and Suppression ....................................................................................................... 21
6.9 HVAC ........................................................................................................................................................... 21
6.10 Security System ...................................................................................................................................... 21
CONCRETE................................................................................................................................................22
7.1 General ....................................................................................................................................................... 22
7.2 Codes and Standards ............................................................................................................................ 22
7.3 Design Criteria......................................................................................................................................... 22
7.4 Materials .................................................................................................................................................... 22
7.5 Reinforced Applications ...................................................................................................................... 23
7.6 Finishes ...................................................................................................................................................... 24
7.7 Air-Entraining.......................................................................................................................................... 24
7.8 Grout ............................................................................................................................................................ 24
............................................................................................................................25
8.1 General ....................................................................................................................................................... 25
8.2 Codes and Standards ............................................................................................................................ 25
8.3 Design Criteria......................................................................................................................................... 25
8.4 Deflection Guidelines............................................................................................................................ 26
8.5 Lateral Drift Guidelines ....................................................................................................................... 26
8.6 Materials .................................................................................................................................................... 26
8.7 Grating, Guards, Handrails, and Toe Plates ................................................................................. 27
8.8 Stairs, Ladders, and Deck .................................................................................................................... 27
8.9 Stenciling and Marking ........................................................................................................................ 28
.............................................................................................29
9.1 General ....................................................................................................................................................... 29
9.2 Codes and Standards ............................................................................................................................ 29
9.3 Water-Based Systems........................................................................................................................... 30
9.4 Clean Agent System ............................................................................................................................... 31
9.5 Valves .......................................................................................................................................................... 32
9.6 Local Addressable Fire Alarm Control Panel .............................................................................. 32
9.7 Fire Detection and Alarm .................................................................................................................... 34
9.8 Fire Equipment ....................................................................................................................................... 35
9.9 Materials .................................................................................................................................................... 35
9.10 Testing ........................................................................................................................................................ 36
........................................................................................38
10.1 General ....................................................................................................................................................... 38
10.2 Codes and Standards ............................................................................................................................ 38
10.3 Design Requirements ........................................................................................................................... 38
10.4 Transformer Spill Containment ....................................................................................................... 38
10.5 Transformer Fire Walls ....................................................................................................................... 38
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 461 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 3
..................................................................40
11.1 General ....................................................................................................................................................... 40
11.2 Codes and Standards ............................................................................................................................ 40
11.3 Design Requirements ........................................................................................................................... 40
11.4 Testing ........................................................................................................................................................ 41
.........................................................................................................................42
12.1 General ....................................................................................................................................................... 42
12.2 Codes and Standards ............................................................................................................................ 42
12.3 Cable Basic Requirements .................................................................................................................. 42
12.4 Power Cable.............................................................................................................................................. 43
12.5 Control and Instrumentation Cable ................................................................................................ 43
12.6 Lighting and General Use Conductors ........................................................................................... 43
12.7 Cable Connectors and Terminations .............................................................................................. 44
12.8 Earthing and Bonding Requirements ............................................................................................ 44
12.9 Lightning Protection Criteria ............................................................................................................ 44
12.10 Conduit and Raceway ........................................................................................................................... 44
12.11 Lighting, Convenience Receptacles, and Wiring Devices ....................................................... 45
12.12 Emergency Stop Switches (E-Stop) ................................................................................................ 45
12.13 Earthing and Bonding Installation and Testing ......................................................................... 45
12.14 Arc Flash Mitigation .............................................................................................................................. 46
......................................................................................................47
13.1 General ....................................................................................................................................................... 47
13.2 Applicable Standards ............................................................................................................................ 47
13.3 Design Requirements ........................................................................................................................... 47
13.4 Testing ........................................................................................................................................................ 47
13.5 Loss Evaluation ....................................................................................................................................... 48
13.6 Transformer Data Sheets .................................................................................................................... 48
..........................................................................................................49
14.1 General ....................................................................................................................................................... 49
14.2 Codes and Standards ............................................................................................................................ 49
14.3 Overall System Protection .................................................................................................................. 49
14.4 Metering ..................................................................................................................................................... 50
...............................................................................51
15.1 General ....................................................................................................................................................... 51
15.2 Codes and Standards ............................................................................................................................ 51
15.3 Design Requirements ........................................................................................................................... 51
15.4 Low Voltage Panelboards ................................................................................................................... 51
...............................52
16.1 General ....................................................................................................................................................... 52
16.2 Codes and Standards ............................................................................................................................ 52
16.3 Submittals ................................................................................................................................................. 53
16.4 Site Work ................................................................................................................................................... 53
16.5 Grounding ................................................................................................................................................. 53
16.6 SF6 Circuit Breakers ............................................................................................................................. 53
16.7 Islanding Switchgear ............................................................................................................................ 54
16.8 Instrument Transformers ................................................................................................................... 54
16.9 Underground Raceway ........................................................................................................................ 54
16.10 Foundations.............................................................................................................................................. 54
...........................................................................................................55
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 462 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 4
17.1 General.......................................................................................................................................................55
17.2 Batteries ..................................................................................................................................................... 55
17.3 Racks ........................................................................................................................................................... 56
17.4 Battery Management System............................................................................................................56
..........................................................................................................58
18.1 General ....................................................................................................................................................... 58
18.2 Codes and Standards ............................................................................................................................ 58
18.3 Inverters .................................................................................................................................................... 58
18.4 PCS Specifications .................................................................................................................................. 58
Bi--...............................................................................60
19.1 General ....................................................................................................................................................... 60
ER................................................................................................................................61
20.1 General ....................................................................................................................................................... 61
20.2 Operating Modes .................................................................................................................................... 61
20.3 SCADA Interface ..................................................................................................................................... 63
.....................................................................................64
21.1 General ....................................................................................................................................................... 64
SUBMITTALS...........................................................................................................................................65
22.1 General ....................................................................................................................................................... 65
22.2 Drawings .................................................................................................................................................... 65
22.3 Catalog Pages / Manufacturer Cut Sheets .................................................................................... 65
22.4 Formats and Quantities ....................................................................................................................... 65
22.5 Operation and Maintenance Manuals ............................................................................................ 66
22.6 Equipment Lists ...................................................................................................................................... 66
22.7 Design Calculations ............................................................................................................................... 66
22.8 Bid Submittal List ................................................................................................................................... 66

Attachment A Supplied Equipment and Contractor Fill-In Data
Attachment B Approved Supplier List

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 463 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 5
GENERAL
1.1 General Description
A. The Scope of Work of this project is for the Engineering, Procurement, and
Construction (EPC) of a 80 MW / 320 MWhr grid connected, battery energy storage
project including (MV / HV) interconnect to an adjacent (Distribution /
Transmission) switchyard or interconnection point.
B. Contractor shall implement the project using a non-occupiable, containerized
solution specified in 6.0 Non-.
C. Contractor shall provide pricing options to implement the project based upon the
following:
1. Contractor to furnish all project equipment
1.2 Work Included in Contractors Scope
Contractor’s scope shall include but not be limited to the following:
A. Site Preparation and Utility tie-ins
B. All required foundations & civil work
C. Design, Furnish and install Battery Energy Storage System (BESS) non-occupiable
equipment enclosures including:
1. Lighting, raceway, and auxiliary systems
2. HVAC/Cooling system
3. Off-gas detection, Fire detection & suppression system as applicable
D.Design, Furnish and install Battery Energy Storage System (BESS) equipment
including:
1. Batteries, Racks, and BMS equipment
2. DC main disconnects
3. DC bus / cable interconnections between racks and disconnect
4. Bi-directional inverters
5. Metering, Relaying and Protection Panels, as required
6. Auxiliary electrical distribution system and cabling
7. Grounding Transformers (As Required)
E. Design, Furnish, and Install an AC collection system including cable, raceway and
transformers.
F. Design, Furnish and Install a new utility switchyard/substation or the modifications
that are required to interconnect the BESS to an existing switchyard/substation
including [but not limited to] MV or HV breakers and disconnects, surge arresters,
grounding transformers, CTs and VTs, etc.
G. Design, Furnish and Install all required metering, telemetry, and Site Controller
equipment including any required modifications to the existing telemetry hardware
and software.
H. Perform start-up checks utilizing OEM factory representatives as required and
commission the facility.
I.Complete, perform & provide all applicable NERC testing and compliance reports for
review by Owner. Reports shall provide NERC related support documentation in a
manner that is thorough, well organized, complete, and include explanations that
support the conclusions reached. Reports shall be suitable for use in presenting to
NERC audit personnel.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 464 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 6

J.Complying with all requirements of the local Utilities’ interconnection requirements.
1.3 Work Not in Contractor’s scope
The basis of Contractor’s bid shall be to provide a turnkey installation including main power
transformers, batteries, racks, and the Battery Management System (BMS).
Contractor shall also provide pricing to implement the project incorporating Owner-furnished main
power transformers, batteries, racks, and BMS.
1.4 Permits and Agreements
A. Owner will obtain --
1. Operating permits
B. Contractor shall obtain and pay for –
1. Building Permits
2. Construction Permits
3. Local Permits
4. Licenses as required for engineering and construction activities
5. Utility Interconnection Agreement
6. Land Use and Rights-of-Way
7. Environmental permits
1.5 Equipment
A. Design equipment in accordance with generally accepted industry standards for
energy storage facilities.
B. Systems and operations shall be designed in compliance with equipment OEM’s
requirements and applicable industry standards.
C. Equipment shall be of proven design. Experimental, prototype, or one of a kind
designs are not acceptable.
D. Permanent equipment shall be new and unused.
E. OEM shall be able to demonstrate at least 5 installations of comparable size within
the Continental United States of America which have achieved commercial
operation as defined by the owning utility or Power Purchase Agreement (PPA) off-
taker.
F. Contractor shall verify that all equipment procured as part of this contract shall
comply with Department of Energy regulations.
1.6 Use and Operation
A. Method of usage to be one full charge/discharge cycle per day, proposal to outline
number of full cycles per year. Up to two and a half (2.5) times as many
recommended cycles can be expected in any 48-hour period, i.e. two full cycles in
one day with rest to finish out 48-hour period.
B. Project to be designed for full nameplate capacity at Commercial Operation Date.
Contractor shall provide the OEM’s annual battery life degradation schedule and
curves for expected use scenario and an additional schedule and curves based on
10% over cycling per year, and 20 periods of 10% over cycling per 48-hour period
over a year (396 cycles per year).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 465 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
1.0 GENERAL

Page 7

C. Project to maintain a minimum rating of 80 / 320 MWh throughout the life of the
project. Contractor to initially size the system to account for any expected derating
and degradation that can be expected in order to maintain this minimum rating.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 466 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
2.0 PROJECT DESIGN CONDITIONS

Page 8
PROJECT DESIGN CONDITIONS
2.1 Site Location / Interconnecting Provisions
To be identified through RFP process
Owner
Elevation
Voltage
2.2 Site Conditions
Parameter Data
Nearest ASHRAE weather data location
To be identified through RFP process
Temperature Range (10yr Extreme, Max/Min)
Relative Humidity Range
Heating Dry Bulb Temperature Design, 99% occurrence
Cooling Temperature Design, 1% occurrence, DB/WB
Design Wind Speed
Rainfall
Seismic
2.3 Site Arrangement
2.4 Seismic Loads
Seismic loads and element design criteria shall be in accordance with applicable sections of the IBC,
ASCE 7, AISC, and related or referenced documents for equipment, buildings, and structures.
2.5 Dead Loads
A. Dead loads shall be considered as being the weight of the structure and supported
equipment of a permanent or semi-permanent nature including tanks, wall panels,
partitions, roofing, piping, drains, electrical trays, and the contents of tanks
measured at full capacity. However, the contents of tanks shall not be considered
effective in resisting uplift.
B. Dead loads shall be determined using the minimum design dead loads and unit
weights from the International Building Code (IBC and ASCE 7)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 467 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
2.0 PROJECT DESIGN CONDITIONS

Page 9

2.6 Live Loads
A. Live loads are produced by the use and occupancy of the building or structure
including movable and transitory loads such as the weight of people, portable
equipment, and tools; and mobile equipment or parts which may be moved over or
placed on floors during maintenance operations.
B. The live loads used in the design of buildings and structures shall be the maximum
loads likely to be imposed by the intended use or occupancy but shall not be less
than the minimum live loads prescribed in the IBC and ASCE 7.
2.7 Soil and Hydrostatic Loads
A. The design of below-grade structures shall consider the effects of lateral soil
pressures considering also appropriate allowances for possible surcharges due to
adjacent fixed or moving loads.
B. Structures below the water table shall also be designed to resist the effects of
hydrostatic pressure and buoyancy based on expected extreme groundwater
conditions.
2.8 Wind Loads
A. Wind loads shall be computed in accordance with International Building Code (IBC
and ASCE 7. A step function of pressure with height shall be used.
B. Design wind pressures shall be determined by applying velocity pressures for the
design wind speed to the appropriate design equations for, respectively, the
building or structure's main wind-force resisting system, other buildings,
components and cladding, and for other construction considering the appropriate
design coefficients and factors.
2.9 Snow Loads
A. The effects of drifting sliding, partial, and imbalanced snow loads shall be
considered as set forth in IBC and ASCE 7.
B. Rain-on-snow surcharge shall also be considered as set forth herein except where
locally adopted requirements are more stringent.
2.10 Rain Loads
A. Roofs and similar nearly horizontal surfaces shall be designed considering the
potential ponding instability according to IBC and ASCE 7.
2.11 Construction Loads
A. The integrity of structures shall be maintained during construction without use of
temporary framing struts, ties, or cable bracing insofar as possible.
B. Should construction or crane access considerations dictate the use of temporary
structural systems; identify such situations and provide criteria that it intends to
use to determine requirements for the temporary system.
C. Special consideration shall be given to ensure the stability and integrity of
structures during any periods involving temporary bracing systems.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 468 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
2.0 PROJECT DESIGN CONDITIONS

Page 10

D. Assumed construction loads shall not be less stringent than those recommended in
ASCE 7, International Building Code (IBC) or other generally recognized structure
design agencies.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 469 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
3.0 SCOPE OF WORK/DIVISION OF RESPONSIBILITY

Page 11
SCOPE OF WORK/DIVISION OF RESPONSIBILITY
3.1 General Description
A. Contractor’s Scope of Work includes design, engineering, procurement,
construction, construction management, commissioning, startup, testing,
demonstration testing and operator training.
B. For any Owner furnished equipment, the Contractor shall be responsible for
receiving, unloading, storing, installing, checkout, commissioning, startup, and
testing unless expressly stated otherwise.
C. For the avoidance of doubt, Contractor’s scope includes all work necessary to
provide a fully operational BESS facility except where explicitly noted otherwise.
3.2 Items Provided by Others
Items furnished by others and not in this scope of supply include the following:
A. Conceptual/Basic Layout
B. Option price for Owner to directly purchase equipment stated in Section 1.1.
.
C. Permits as described in Section 1.0.
3.3 Safety Requirements
A. The Contractor shall comply with the Owner’s site safety requirements.
B. Contractor shall be responsible for site control as well as site safety training for any
personnel that come onto the work site.
C. Report weekly on safety statistics including the number of safety walks, job safety
assessments, and any incidents.
3.4 Electrical and Control
A. The electric system should be configured in a manner similar to the conceptual One-
Line Diagram. The one-line should be considered conceptual in nature and is not
intended to show all details required. The conceptual One-Line diagram is not
intended to limit Contractor’s flexibility in design.
B. Contractor’s scope includes engineering, procurement, installation, and
commissioning of the BESS scope including (MV or HV) interconnect to an adjacent
switchyard or interconnection point.
3.5 Civil / Structural
A. Contractor shall contract a 3rd party to perform a geotechnical investigation of the
site. The design and installation of the facility shall be pursuant to the geotechnical
report findings. A copy of the geotechnical report shall be made available to the
Owner.
B. Contractor is responsible to prepare the site as required. Contractor shall clear,
grub, and perform earthwork activities as necessary to create a site that is suitable
for construction.
C. Contractor is responsible to develop a site-specific storm water runoff plan and to
protect the site against erosion during construction. The Contractor shall be
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 470 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
3.0 SCOPE OF WORK/DIVISION OF RESPONSIBILITY

Page 12

responsible for final grading of site, maintaining the storm water drainage system,
and completion of storm water drainage system in accordance with the site permits.
Contractor shall obtain the stormwater permit and is responsible for closure of the
stormwater permit.
D. Costs for the handling and disposal of any existing contaminated soils or other
materials not identified in the soils report shall not be included in the Contract Price.
Unforeseen conditions shall be treated as additional scope of work in accordance
with the Contract documents.
E. Contractor is responsible to survey the site and establish site control geometry as
necessary to perform the work. The survey data shall be provided as on-ground
(surface) values with an equation to convert from ellipsoidal heights (State Plane
Ground) to orthometric heights (State Plane Grid). Horizontal and vertical accuracy
shall be Second Order Class II per the National Map Accuracy Standards (NMAS).
F. Dewatering and shoring of excavation works shall be the responsibility of the
Contractor.
3.6 Engineering
A. Perform all engineering and design work required for a complete and operating
facility, unless noted otherwise. Construction design documents shall be sealed by
registered Professional Engineers licensed in the state where the project is located.
B. Contractor shall provide a complete list of design deliverables with delivery dates to
the Owner.
3.7 Procurement
A. Except for equipment specifically listed as Owner furnished, Contractor shall be
responsible for the procurement of non-engineered equipment and engineered
equipment, including freight to the site, unloading, and storage that is required to
complete the project. Contractor shall also be responsible for unloading and onsite
storage of any Owner-furnished equipment.
B. Contractor shall procure all bulk materials whether intended for permanent
installation or temporary installation that is needed for the erection of the systems
and components.
C. The Contractor shall be responsible for performing the vendor shop inspections for
the Contractor-furnished equipment. The Contractor's standard shop inspection
reports shall be utilized and distributed to the Owner. Notify Owner of Factory
Acceptance Tests (FAT) for equipment at least two weeks in advance of start of the
FAT tests. The Owner may elect to attend such tests at their cost and sole discretion,
unless stipulated otherwise.
D. Submit to Owner a binder and corresponding electronic files containing
recommended operating spare parts lists including pricing, lead times, and contact
information for equipment supplied by the Contractor. Owner shall be able to
purchase these spare parts from the Contractor or suppliers for the prices noted
during the first year of operation.
3.8 Construction
A. Perform construction and erection work required for a complete operating facility,
including management and responsibility for quality and time of performance for
subcontracted work.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 471 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
3.0 SCOPE OF WORK/DIVISION OF RESPONSIBILITY

Page 13

B. The Contractor shall be responsible for all indirect construction costs such as
supervision, equipment, taxes, utilities, facilities, and other indirect items needed.
This includes costs for personnel, construction equipment, including mobilization
and demobilization, temporary buildings, temporary utilities, scaffolding, project job
office expenses, employee travel and per diem expenses, and quality control testing,
such as for concrete and welding.
C. Temporary construction office facilities, furnishings, janitorial services, and supplies
shall be furnished by the Contractor.
D. Contractor shall provide temporary office space for two persons for use by Owner
and/or Owner’s representative during the period of site construction.
3.9 Special Inspections
A. The Owner may engage one or more qualified Special Inspectors to verify
compliance with requirements specified or indicated. These services do not relieve
the Contractor of responsibility for compliance with other document requirements.
B. Requirements for the Contractor to provide quality-assurance and quality-control
services are not limited by provisions of this Section.
C. The Contractor shall coordinate the inspection and testing services with the
progress of the work. The Contractor shall provide notice to the testing agency to
allow scheduling of personnel such that it does not create delays in work.
D. The Contractor shall be responsible for scheduling and coordinating the review and
acceptance by the Authority Having Jurisdiction (AHJ).
E. The Contractor shall be responsible for providing a BESS Hazard Mitigation analysis
in accordance with NFPA-855 requirements for installations that meet Hazard
Mitigation analysis criteria as described but not limited to NFPA-855 section 4.1.4.1.
F. The Contractor shall be responsible for costs of:
1. Re-testing and re-inspection of materials, work, or products that do
not meet the requirements of the Contract Documents and shop
drawings / submittal data.
2. Review of proposed repair and / or replacement procedures by the
inspectors and testing agencies.
3. Repair or replacement of work that does not meet the requirements
of the Contract Documents, Special Inspector’s, or AHJ’s
requirements.
3.10 Commissioning and Startup
A. Startup shall include activities, procedures, and tests required to bring installed
systems and equipment to a state of readiness for Owner acceptance and
commercial operation. It is the Contractor’s responsibility to comply with the
battery manufacturer’s requirements as well as any applicable NERC/FERC
requirements.
B. Contractor shall prepare written commissioning and testing procedures and submit
for Owner review and acceptance a minimum of 30 days prior to commencement of
pre-commissioning tests.
C. Contractor shall comply with all interconnecting Utility requirements and/or
system conditions that may be present.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 472 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
3.0 SCOPE OF WORK/DIVISION OF RESPONSIBILITY

Page 14

3.11 Training
A. Contractor is responsible for training plant staff on the operation, maintenance, and
repair of equipment furnished as part of the Works.
B. Training shall include both classroom and hands-on training for at least ten (10)
persons.
C. Contractor shall allow Owner representatives to shadow Contractor’s startup
personnel during commissioning activities. Participation by Owner’s trainees is at
Owner’s option and does not relieve Contractor of responsibility to properly
commission the facility.
3.12 Specifications and Standards
A. Reference to standards or manuals of any society, organization, or association,
whether such reference be specific or by implication, shall mean the latest standard,
manual, or code in effect as of the time of the Contractor's performance of the Work,
unless specifically stated otherwise.
B. References to any standard or code and specifically to the International Building
Code (IBC) shall mean the version of that code or standards adopted and modified
by the local Authority Having Jurisdiction (AHJ).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 473 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
4.0 SITE WORK

Page 15
SITE WORK
4.1 General
A. This section covers initial site work, maintenance of drainage systems during
construction, and final site work.
B. The site grading and drainage plan shall conform to the requirements of the permits.
C. Site drainage facilities shall be designed to convey the runoff from a 4 percent
probability (25 year) 24-hour storm event unless specific federal, state, or local
regulations are more stringent.
4.2 Codes and Standards
Erosion and sediment control, grading, drainage, and storm water management; design,
construction, and maintenance shall be in accordance with requirements set forth by state and local
environmental management agencies and Environmental Protection Agency (EPA).
4.3 Fencing
A. A security fence at least 6 ft high with suitable gates shall be provided around the
project site boundary during construction. Temporary or permanent fencing may
be provided at Contractor’s option.
B. Fencing shall be isolated or grounded at Contractor’s option to ensure safety with
respect to touch potentials. Special precautions shall be taken where fence abuts an
existing electrical substation fence and near overhead transmission lines.
C. The permanent security fence shall have an overall height of approximately 8 feet
including 3 strands of barbed wire mounted on 45-degree extension arms at top
extending outward.
D. Other Applicable Owner Standards
4.4 Dewatering
A. Contractor shall provide temporary dewatering if required for any work requiring
excavation below the groundwater table.
B. The dewatering plan must be approved by the reviewing agencies prior to any
dewatering activities being undertaken.
4.5 Grading and Drainage
A. The site shall be graded to convey storm water runoff away from permanent
facilities. Minimum slopes shall be based on surface type. Provide a minimum
1 percent overall slope.
B. Areas that do not lend themselves to grading for surface drainage shall be provided
with catch basins and underground piping. Maximum earth slopes shall be set
based on slope stability and maintainability requirements. The steepest
unimproved slope shall be limited to 3:1 height to vertical ratio.
C. Channels and ditches shall be designed and shown on the drawings.
D. Culverts shall generally be reinforced concrete, corrugated metal, or smooth-lined
corrugated HDPE pipes.
E. Grating and guards shall be provided for fall protection at channels and ditches.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 474 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
4.0 SITE WORK

Page 16

4.6 Heavy Loads
A. Roadway sub grades, pavements, and structures shall be designed for HS20 loads.
B. Contractor shall be responsible for repair of damage to any existing roads caused by
hauling of battery containers, mobilization / demobilization of cranes, or other
heavy loads.
4.7 Compaction
Unless the Contractor’s geotechnical report allows for lower compaction requirements, the
following minimums shall be adhered to. Submit for Owner review any requests for alternative
values.
Proctor
(%)
Unauthorized excavation 95
Fills and embankments 90
Trench subgrades 90
Trench subgrades beneath roads 95
Subgrades beneath roads 95
Structure backfill (around walls and structures) 95
Compacted sand fill 95
Trench backfill (crushed rock) 75 (relative density)
Trench backfill (cohesive and sand material) 90
Trench backfill (traversing paved areas) 95
Compacted rock fill 75 (relative density)
Structural fill (beneath structures) 98
4.8 Roads
A. Contractor shall be responsible for the cost, construction, maintenance, and
improvement of all facilities and improvements necessary for access to and from the
Facility Site and for performance of the work. Contractor shall be responsible for
providing Buyer sufficient access to the site for the performance of routine
maintenance and sufficient space within the facility during such times as not to
interfere with Owner activities.
B. Road construction shall be similar to existing access road unless greater load
carrying capability is required due to battery / container loads.
C. Horizontal and vertical alignment shall be based on anticipated traffic and design
speed for each road.
D. The minimum road design criteria to be considered are as follows:
1. Intersection Radius: 40 ft (12 m) from radius to inside edge or trafficked
surface
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 475 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
4.0 SITE WORK

Page 17

2. Maximum Grade: 3% primary access routes; 6% for limited length
secondary routes
4.9 Landscaping and Restoration
A. Provide finish landscaping for the site according to local ordinances and practices
applicable to typical industrial facilities.
B. Areas of the site, including lay-down areas not specifically addressed by a
landscaping plan or other requirements shall be restored to a condition acceptable
to the Owner as part of the demobilization from the site. This condition should also
allow for closure of the Stormwater Permit.
4.10 Existing Conditions
A. This project may have below grade pre-existing conditions not indicated on any
drawings, maps or other documents, or in locations different than where indicated.
B. Prior to any excavation activities, all known underground utilities shall be positively
located using “soft dig” techniques to minimize the likelihood of a utility strike.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 476 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
5.0 SUBSTRUCTURE REQUIREMENTS

Page 18
SUBSTRUCTURE REQUIREMENTS
5.1 General
Design and construct of reinforced concrete or other acceptable method to resist the loadings
imposed by the building, structure, or equipment being supported.
5.2 Considerations
Foundation design shall consider the following:
1. Soil bearing capacities
2. Pile or pier capacities
3. Active, at-rest, and passive lateral earth pressures
4. Allowable settlements
5. Building, structure, equipment, and environmental loading
6. Equipment operating characteristics and performance criteria
7. Access and maintenance
8. Temporary construction loading
5.3 Analysis
A. Minimum factors of safety against overturning and sliding shall be 1.5 and 1.25,
respectively, but in no case less than those prescribed by the International Building
Code (IBC).
B. Geotechnical exploration, testing, and analysis information shall be used to
determine the most suitable foundation system. Elastic (short-term) and
consolidation (long-term) foundation settlements shall be calculated and limited to
the following design values:
1. Total settlement: 1.5 in
2. Differential settlement: 0.1 percent slope between column support points
5.4 Slab-on-Grade
A. Care shall be taken to provide suitable base construction and to align and locate
expansion and control joints as recommended in these references to minimize
uncontrolled cracking.
B. Slabs-on-grade that are open or generally exposed to the environment shall be
sloped to prevent the accumulation of standing water. Interior slabs do not require
sloping.
5.5 Foundations
A. Prepare detailed foundation design criteria for each foundation type on the basis of
on an independent geotechnical exploration program, performed by Contractor.
B. Interpretation or use of any preliminary boring information is solely the
responsibility of the Contractor.
C. Foundations may be either cast in place or precast. All foundations shall be
reinforced at a minimum to the temperature and shrinkage requirements of ACI
318.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 477 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
5.0 SUBSTRUCTURE REQUIREMENTS

Page 19

D. Pile, post, or earth screw type equipment base foundations typically found in the
renewable energy industry are acceptable alternatives to concrete foundations.
Contactor shall provide safe access provisions to any equipment bases elevated
above grade by more than the height of the equipment base.
5.6 Equipment Bases
A. Equipment bases may be site constructed of concrete, pre-fabricated concrete, or
may be a structural metal skid furnished as part of the equipment.
B. Equipment bases shall consider all additional loads encountered during transport to
the site and placement into final position.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 478 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
6.0 NON-OCCUPIABLE CONTAINER REQUIREMENTS

Page 20
NON-OCCUPIABLE CONTAINER REQUIREMENTS
6.1 General
A. This section covers the minimum requirements for containerized Battery Energy
Storage Systems.
B. Containers should be shipped fully assembled to the extent practical, except for
loading of the battery modules in the field.
C. Air conditioning units may be removed for shipment if required.
6.2 Materials
A. Container foundations may be formed in place concrete, pre-cast concrete, piers, or
earth augers at the engineer of records option.
B. Foundations shall meet local building codes with respect to frost depth. Placement
of containers directly on compacted fill is not allowed.
C. Container structural base may be pre-cast concrete or a structural steel system with
steel decking.
D. Container walls and roof may be pre-cast concrete, steel, or hybrid construction.
E. All materials shall be non-flammable
F. Materials shall be suitable for a minimum 20-year lifetime.
6.3 Occupancy Class
A. It is the intent that containerized systems be classified as equipment enclosures
rather than occupiable buildings.
B. The layout of equipment in containerized systems shall be such that personnel cannot
occupy the enclosure. Containerized systems arranged to provide interior working
space are strongly discouraged. If central aisle containers are provided, aisle width
shall meet NEC required working space.
C. Access to battery modules and other equipment should be via doors arranged along
the length of the container such that personnel are not required to enter the container
to perform maintenance.
6.4 Partition Walls
A. If a skid assembly includes “central inverter” power conversion equipment and
battery racks on a single skid, designs which include a fire-rated partition wall
between batteries and power conversion equipment are preferred.
6.5 Windows
A. Windows are not required. Arrangements that allow the main DC disconnect
position to be viewed or operated without opening doors are preferred.
6.6 Doors
A. Doors are not required for personnel ingress/egress.
B. Doors for equipment access should be provided along the long sides of the
container. Doors arranged in “French Door” fashion are preferred.
C. Door opening width shall be as required to provide access to battery racks for
module installation and removal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 479 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
6.0 NON-OCCUPIABLE CONTAINER REQUIREMENTS

Page 21

D. Doors shall be lockable and keyed alike.
E. Exterior hardware shall be stainless steel.
6.7 Floor Coverings
A. Floors shall be non-combustible.
6.8 Fire Detection and Suppression
A. Containerized BESS systems shall be provided with fire detection systems as
specified in 9.0 Fire Detection and Suppression.
B. Containerized BESS systems shall be provided with clean agent fire suppression
systems as specified in 9.0 Fire Detection and Suppression.
C. Fire detection schemes incorporating early off-gas detection and interlock to shut
down affected BESS equipment prior to fire or smoke detection are encouraged.
6.9 HVAC
A. HVAC systems shall be in accordance with 11.0 HVAC.
6.10 Security System
A. Security cameras shall be provided and located such that the entire site area is
visible.
B. Security cameras shall be able to be monitored remotely at Owner’s operations
center
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 480 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
7.0 CONCRETE

Page 22
CONCRETE
7.1 General
Design and construct concrete structures in accordance with Building Code Requirements for
Structural Concrete.
7.2 Codes and Standards
A. Specifications for materials shall generally conform to the standard specifications of
the American Society for Testing and Materials (ASTM) and American Concrete
Institute (ACI).
B. Field and laboratory testing procedures for materials shall follow standard ASTM
specifications and the American Society for Nondestructive Testing (ASNT)
procedures and practices.
C. Design loadings shall be in accordance with the loading criteria as stipulated in
International Building Code (IBC).
D. Design and placement of structural concrete shall follow the recommended
practices and the latest specifications and standards of the International Building
Code (IBC).
E. Other recognized standards shall be followed where required to serve as guidelines
for design, fabrication, and construction when not in conflict with the listed
standards.
F. Other Applicable Owner Standards
7.3 Design Criteria
A. Controlled Low-Strength Material (CLSM) can be used in nonstructural applications
where limited strength is acceptable, its use would not be detrimental to the
finished or adjacent construction and involves materials and placement methods
commonly used and accepted in the region where the project is located.
B. Design concrete structures based on the following mix class:
Mix
Class Usage
-
Strength
psi (bar)
Coarse
in. (mm)
A-1 Lean concrete for work slabs (mud
mats), fill, duct banks
2,000 (138) 3/8 (9.5) 0.55
B-1 General usage 4,000 1(276) 3/4 (19.1) 0.48
Grout 5,000 (345)--
CLSM Selected nonstructural applications 300 max (21) - -
Note 1 – Strength shall be greater if required for durability per Chapter 4 of ACI 318
7.4 Materials
A. Refer to table for the material, application, and requirements that must be met:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 481 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
7.0 CONCRETE

Page 23

Material Application Requirements
Cement In accordance with mix design, local
supply
ASTM C150, (Type as
required by soil condition and
exposure conditions).
Water In accordance with mix design, local
supply
Potable or Non-potable
Aggregate In accordance with mix design, local
supply
ASTM C33.
Fly Ash In accordance with mix design, local
supply
ASTM C618.
Reinforcing steel, main
reinforcing
No. 4 through No. 10 ASTM A615, Grade 60.
Reinforcing steel, ties and
stirrups
No. 4 ASTM A615, Grade 60.
Forms For exposed concrete surfaces except
flatwork
Plywood or modular steel
dimensions to nearest inch.
B. Ready-mixed concrete shall conform to ASTM C94.
C. Hot and cold weather concreting shall be in accordance with the recommendations
of ACI.
7.5 Reinforced Applications
A. Suspended slabs shall be two-way reinforced; 0.75 in (19 mm) minimum cover; 6 in
(150 mm) minimum thickness; steel trowel finish; sprayed with curing compound.
B. Structural Beams shall be singly or doubly reinforced; 0.75 in (19 mm) minimum
cover for interior locations, 1.5 in (38 mm) cover for exterior locations; beam width
in 2 in (50 mm) increments, minimum 8 in (200 mm); beam depth in 2 in (50 mm)
increments, minimum 12 in (300 mm); cured at least 72-hours in forms.
C. Grade Beams shall be singly or doubly reinforced; 1.5 in (38 mm) cover; beam width
coordinated with excavator characteristics, minimum 8 in (200 mm); 4 in (100 mm)
minimum thickness void form below elements spanning between piers or piles.
D. Spread footings shall be 6 in (150 mm) increments for footing dimensions less than
9 ft (2.8 m); 3 in (75 mm) cover for sides and bottoms cast against soil; 1.5 in (38
mm) bottom cover when cast against working slab or mud mat.
E. Concrete strength determination shall be in accordance with ASTM C39.
F. Use Type V cement when high-sulfate resistance concrete is required. If not
available provide written documentation of the unavailability, and then use of
concrete Type I or Type II cement with a maximum tricalcium aluminate (C 3A)
content of 6 percent or less will be acceptable.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 482 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
7.0 CONCRETE

Page 24

7.6 Finishes
A. Exposed Concrete Pads – Float Finish
B. Door Landing Stoops – Medium Broom Finish
C. Equipment Bases – Steel Trowel Finish
D. Steel troweled, surface hardened concrete shall be provided for exposed concrete
construction in such areas as battery equipment areas, storage rooms, switchgear
rooms, and mechanical rooms. Surface shall be non-slip; wet or dry.
7.7 Air-Entraining
A. Air-entraining agent shall be in accordance with ASTM C260.
B. Outdoor concrete shall include entrained air.
7.8 Grout
A. Use Portland, non-shrink cement for grout.
B. Metal shims shall be stainless steel.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 483 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
8.0 METAL STRUCTURES

Page 25
METAL STRUCTURES
8.1 General
This section covers the minimum requirements for the design of metal framed structures and
systems.
8.2 Codes and Standards
A. Design, fabrication, and erection of structural steel shall be in accordance with the
recommended practices and specifications of:
1. American National Standards Institute (ANSI)
2. American Iron and Steel Institute (AISI)
3. American Welding Society (AWS)
4. American Society for Testing and Materials (ASTM)
5. National Association of Corrosion Engineers (NACE)
6. International Building Code (IBC)
7. Occupational Safety and Health Association (OSHA)
8. Other Applicable Owner Standards
B. Other recognized standards shall be followed where required to serve as guidelines
for design, fabrication, and construction when not in conflict with the listed
standards.
C. The standards listed shall mean the latest version adopted by the state or local
authorities including any amendments to, or modifications of the original document.
8.3 Design Criteria
A. Limit use of rigid frames to less critical applications such as pre-engineered metal
buildings used primarily for enclosure purposes.
B. Utilize simple framing for such things as framed structures supporting equipment
and utilities, either alone or in conjunction with enclosure materials.
C. Lateral forces imposed on buildings and structures shall be resisted through a
system of horizontal and vertical bracing or horizontal diaphragms, and vertical
bracing, shear walls or rigid frames.
D. Design member end connections for the forces and moments determined by
engineering analysis.
E. Bolted connections shall be designed as bearing type with threads included in the
shear plane except where slip-critical connections are required.
F. Bolted connections shall use 3/4 in (19 mm), 7/8 in (22 mm), or 1 in (25 mm) ASTM
A325 (ISO R898 Class 8.8, or higher) bolts.
G. Large diameter or ASTM A490 (ISO R898 Class 10.9 or 12.9) bolts may be
considered only when necessary to resist unusually large forces or reduce
connection size.
H. Wedge anchors and epoxy or polymer mortared anchors shall be zinc plated or
galvanized anchors are acceptable for interior applications; and stainless steel for
exterior.
I. Anchor bolts installed during concrete placement shall be galvanized for their full
length. Other materials may be used only as specifically approved by the Owner.
J. Diagonal bracing that may impede equipment/material access is unacceptable.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 484 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
8.0 METAL STRUCTURES

Page 26

8.4 Deflection Guidelines
A. Floor or roof members supporting plaster ceilings or masonry walls; 1/360 times
the span considering live load only.
B. Isolated structural members supporting masonry walls; the lesser of 1/600 times
the span or 0.3 in (8 mm) considering dead plus live load.
C. For other members; 1/240 times the span, considering live load only.
D. Metal wall panel girts:
1. Vertical; 1/240 times the span except the lesser of 1/960 times the span or
3/8 in (9.5 mm) where located under or over glass or masonry walls where
clearance and load bearing capabilities are a consideration.
2. Horizontal; 1/180 times the span except the lesser of 1/360 times the span
or 1.33 in (33 .8 mm) when located under or over glass.
8.5 Lateral Drift Guidelines
A. The following guidelines for lateral drift of major structures shall be followed unless
more stringent criteria are required by local building codes.
B. Braced frames shall be designed to resist the specified lateral environmental loads
while limiting lateral deflection to 1/200 of the story or building height.
C. Moment resisting frames, such as those commonly used in pre-engineered metal
buildings, shall be designed to resist 75 percent (corresponding to a 10 year
recurrence interval) of the specified lateral environmental loads while limiting
lateral deflections to 1/120 of the story or building height.
D. In structures without interior walls or other nonstructural components in contact
with or supported by a building frame, lateral deflection may be increased to 1/50
of the story or building height considering the allowed reduction in lateral
environmental loads.
8.6 Materials
A. Structural steel shapes, plates, and appurtenances for general use shall conform to
the multi-certification requirements for ASTM A36/ASTM A572, Grade 50, or ASTM
A992.
B. High strength connection bolts shall conform to ASTM A325. Other bolts shall
conform to ASTM A307, Grade A.
C. Coat bolts for resistance to rusting for a minimum of 30 years.
D. Bolted connections shall conform to Specification for Structural Joints; ASTM A-325
or A-490 Bolts, current edition.
E. Bolt tightening/pre-tensioning shall be accomplished by use of load indicating
washers or the turn-of-nut method. For bolts tightened by the turn-of-nut method, a
minimum of 10 percent shall be checked using a calibrated torque wrench.
F. Anchor bolts shall conform to ASTM F1554, Grade 36 and shall be galvanized for
their full length. Embedded shapes and plates shall be of ASTM A36 material and
shall be galvanized.
G. Expansion and chemically bonded anchors shall be stainless steel conforming to
ASTM A276 or ASTM A493.
H. Welding electrodes shall have a minimum specified tensile strength of 70,000 psi
(4827 bar).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 485 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
8.0 METAL STRUCTURES

Page 27

I. Outdoor structural steel shall be hot-dip galvanized. Galvanizing shall be in
accordance with the requirements of ASTM A123, ASTM A153, and/or ASTM A525
as applicable.
J. Galvanized steel fabrication or modification performed on site shall be sent out for
re-galvanizing whenever the work process can be revised to permit doing so
without resulting in an unacceptable construction delay.
K. When offsite re-galvanizing is not feasible, field application of galvanizing material
will be acceptable, subject to the Owner acceptance and provided the effective
thickness, adhesion, and durability of the field applied galvanizing method proposed
can be shown to be at least equal to that of undamaged adjacent areas.
L. Field applied galvanizing paint will be acceptable for installation touchup and will
be acceptable for galvanizing of field fabrication repairs or modifications only if
conformance with the above requirements can be demonstrated.
M. Galvanizing of nuts, washers, and bolts shall be in accordance with ASTM B695.
N. Corrosion-resistant steel shall be used where corrosion or abrasion may be
expected, thus requiring the use of special steels. Corrosion-resistant stainless
steels shall conform to ASTM A213, Type 316L, 2.75 percent minimum molybdenum
content; or ASTM 240, Type 304 / 304L as appropriate for the application.
8.7 Grating, Guards, Handrails, and Toe Plates
A. Steel grating shall be welded rectangular steel bar with bearing bars at least 3/16 in
wide by not less than 1-1/4 in (32 mm) deep.
B. Guards, handrails, and toe plates for exterior shall be constructed of galvanized
steel. Interior may be painted steel or galvanized. Steel guards and handrails shall
be fabricated from 1-1/2 in (38 mm) nominal diameter, ASTM A53, round steel pipe
with joints mitered and welded to form a continuous railing system.
C. Grating shall be hot dip galvanized steel except in corrosive environments; which
shall be of fiberglass reinforced plastic construction. Grating ends shall be banded.
D. Guards for non-public locations shall be a two-rail system with the top rail 42 in
(1067 mm) above the walkway surface and the intermediate rail 21 in (533 mm)
below the top rail.
E. Guard post spacing shall be proportional to the length of the protected horizontal
opening and shall consider the specified lateral loading but shall not exceed 6 ft
(1800 mm) center-to-center.
F. Handrail for open sides of stairs in non-public locations shall be a combination
guardrail/handrail system in which the top and intermediate rails are provided in
accordance with the preceding and, in addition, with a handrail, offset from the
plane of the guards toward the center of the stair run by distance required for hand
clearance and with its top 34 in (860 mm) above the nose of the treads.
G. Provide toe-plates for platforms and stairways.
8.8 Stairs, Ladders, and Deck
A. Stair treads shall be galvanized assemblies of steel grating with cast abrasive nosing.
Treads and riser proportions shall be in accordance with the IBC.
B. Exterior ladders shall be galvanized, interior may be painted steel; fabricated from
ASTM A36 bar rails, 2-1/2 in by 1/2 in (64 x 13 mm), with 0.75 in (19 mm) diameter
rungs inserted and plug welded into holes punched or drilled through the ladder
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 486 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
8.0 METAL STRUCTURES

Page 28

rails. Ladder supports shall be spaced not more than 12 in (300 mm) vertically
center-to-center.
C. Metal deck form shall conform to ASTM A446, Grade A or ASTM A611, Grade C.
Metal deck shall be galvanized with a uniform coating having a weight of not less
than 6 oz/sqft (316 g/sqm) on each surface.
8.9 Stenciling and Marking
A. Column identification by row letter and number shall be stenciled on four faces of
exposed steel columns.
B. Letters and numbers shall be a minimum of 12 in (300 mm) tall.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 487 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 29
FIRE DETECTION AND SUPPRESSION
9.1 General
A. Contractor shall be responsible to comply with all applicable fire and building
Codes, including NFPA 855.
B. Contractor is advised that no source of water is available at the project site. If a
water-based fire suppression system is required to meet local AHJ or Owner’s
insurance requirements. Contractor shall design and install tankage and pumps as
requirement
C. This section covers the minimum requirements for the fixed suppression systems,
early warning detection systems, alarm systems, and portable fire protection equip-
ment.
D. Contractor shall provide design, approvals, permits, installation, testing, and
training for a complete, operational, and code compliant fire detection, alarm, and
protection system(s). The design and record documents shall be sealed by a
professional fire protection engineer registered in the jurisdiction in which
construction occurs.
E. The fire protection and alarm systems and design requirements shall be based upon
each BESS area being H3 occupancy per International Building Code (IBC).
Contractor shall confirm with code enforcement that this is the correct design.
9.2 Codes and Standards
A. Unless otherwise specified, the governing edition and addenda used shall be
interpreted as the jurisdictionally approved edition and addenda. If a code or
standard is not jurisdictionally mandated, then the current edition and addenda in
effect at the date of this document shall apply.
B. Any conflict between referenced codes or standards, or between the standards and
these specifications, shall be referred in writing to Purchaser to determine which
standard or specification requirements shall govern.
C. In addition to other codes and standards, design in accordance with Occupational
Safety and Health Association (OSHA) and Americans Disabilities Act (ADA).
D. If not omitted by the local AHJ per allowance in NFPA-855, water-based system shall
be in accordance with NFPA 13; the design occupancy classification shall be Extra
Hazard Group 2 (EH2).
E. Clean Agent systems shall be in accordance with NFPA 2001 2018 and NFPA 855
200.
F. Other Applicable Owner Standards

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 488 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 30

G. The following shall be followed:
Description AH
J
NF
P
A
Overall design X X X X
Fire detection system
equipment components
X X X X
Smoke/gas detection X X X
Heat detection X X X
Manual pull stations X X X
Notification/Indicating devices X X X
Sprinkler system X X X X
Control panel initiating and
indicating devices
X X X
Pipe thread tolerances X X X
Hydrant flow tests X X X X
Extinguishers X X X
Hose systems X X X X
Fire alarm system wiring,
initiating devices, notification
appliances, solenoids, and
signaling line circuits
X X X
Testing of complete fire
suppression and detection
system
X X X X
Portable fire extinguishers X X X
9.3 Water-Based Systems
A. Water-based suppression requirements shall be provided in accordance with AHJ
requirements, as NFPA-855 allows water-based suppression requirements to be
omitted only if approved by the AHJ.
B. The sprinkler system shall be a double-interlock pre-action dry pipe sprinkler
system with a minimum design density of 0.3 gpm/ft2 over 2500 ft2.
C. Piping systems shall be pressurized using air or nitrogen; and shall be constantly
monitored. One of the following methods shall be employed.
1. Method 1: K-factor of K-8.0 fused sprinkler heads with temperature rating
of 135oF for heat detection. Activation of sprinkler head shall result in loss
of pressure in the pipe, thereby providing one of the two signals needed at
the fire alarm panel. Photoelectric smoke detection shall provide the other
needed signal, thus allowing water to flow into the piping system.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 489 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 31

2. Method 2: 135
oF fixed electric temperature heat detectors will provide the
initial signal as well as provide one of the two initiating signals needed to
activate the pre-action sprinkler system. A K-factor of K-8.0 fused sprinkler
heads with temperature rating of 145oF to 155
oF shall provide the other
required signal, thus allowing water to flow into the piping system. Water
shall not be discharged into the area until the fixed heat detector and
sprinkler head have activated. To ensure prompt recognition of a fire
condition, the fixed electric heat detectors shall be spaced at half of their
listed spacing (i.e.: A detector listed for 30ft spacing shall be installed at 15ft
spacing).
3. Method 3: Use of Very Early Warning Air Sampling Smoke Detection
System(i.e.: VESDA) with capability of providing two alarm points; one
would be an initial general warning but it would not initiate the interlock
system, the second alarm would be set equivalent to the set-point of a
photoelectric smoke detector; which would be one of the initiating signals of
the double interlock system. The second initiating signal shall be from K-
factor of K-8.0 fused sprinkler head with a set-point of 135oF. Linear heat
detection may be considered if its use and installation is acceptable to the
Authority Having Jurisdiction (AHJ).
4. Method 4: Use of Off-gas detection system as alternative to smoke detection
as the pre-action signal if acceptable to the Authority Having Jurisdiction.
D. All methods shall be provided with manual pull (MP) stations. MPs shall act as an
alternative for one of the input signals for the pre-action system. MPs shall be
located and spaced per applicable codes, standards, and local requirements.
E. Contractor shall include all wiring necessary to provide a complete system fire
protection system. Wiring shall include power wiring to connect the specified
termination points on the fire protection and detection systems to the plant
electrical power, tie-ins to plant systems, and tie-ins to outside agencies.
F. Contractor shall verify the fire water supply is adequate for the new fire protection
system(s) by performing flow testing.
G. In areas that are not continuously occupied, automatic smoke detection shall be
provided at the location of each fire alarm control unit(s). Where ambient
conditions prohibit installation of automatic smoke detection, automatic heat
detection shall be permitted.
H. Detailed drawings and calculations shall be provided for each system. Drawings and
calculations shall be updated at the completion of the job to show as-built
configuration. All drawing, calculations and submitted documents shall bear the
seal of a registered professional engineer, in the state constructed.
9.4 Clean Agent System
A. Clean agent fire suppression system shall be FM200, NOVEC 1230, or equal. CO2
systems are not acceptable.
B. Non-occupiable container solution specified in Section 6.0 shall include a clean
agent fire suppression system.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 490 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 32

9.5 Valves
A. If valves are required as part of a water-based suppression system, valves installed
between alarm initiating devices intended to signal activation of a system and the
fire suppression system shall be electrically supervised.
B. Contractor shall verify that the design and physical locations of automatic or manual
valves and piping network are acceptable to avoid hydraulic shock when the valves
are actuated.
C. A permanently attached placard shall be provided on each valve indicating the
location and hydraulic information.
9.6 Local Addressable Fire Alarm Control Panel
A. Local control panel(s) shall be furnished and installed to monitor systems. A
minimum of one addressable local control panel shall be provided. A main fire
control panel shall be located near facility main entrance. The main fire control
panel shall monitor and annunciate all fire signals. The main fire control panel shall
include as a minimum a distinctive Alarm, Trouble and Supervisory LED for each
suppression and detection system.
B. Main fire panel shall remotely transmit and annunciate all Fire, Trouble and
Supervisory conditions to a manned location as designated by Owner and as
required per applicable codes, standards, and local requirements
C. Each local control panel shall be tagged and be capable of operation as a stand-alone
system with its own internal secondary power via battery backup. Panel(s) shall
communicate together via OEM’s internal network communication system. Each
initiating device shall be addressable and communicate to local panel via SLC circuit
D. The addressable local control panel(s) shall monitor and annunciate; alarms,
trouble, and supervisory signals for each of the fire protection and detection devices
and systems. The panel shall be of modular construction, front accessible, and wall
mounted. In addition, the panel shall have a minimum of two spare alarm zones
requiring only field wiring for future use.
E. Automatic pre-action valves shall be actuated (opened) electrically upon receipt at
the panel of fire indication from the detection system for the given hazard, and the
control panel shall concurrently produce a fire alarm and initiate any required
auxiliary shutdown functions that may be specified or required per applicable
codes, standards, and local requirements.
F. The panel for each clean agent or pre-action sprinkler system shall also
continuously monitor the off-normal conditions necessary to ensure the availability
and proper operation of each system and to annunciate distinctly supervisory and
trouble alarms as appropriate.
G. The following distinctive alarms, as a minimum, shall be provided as applicable at
the local panel for each pre-action sprinkler system: (Equivalent shall be provided
for Clean Agent system and detection systems)
Source
Fire detected Heat detectors, smoke detectors, Very
Early Air Sampling Smoke Detection, or
Manual Pulls (Style D)
Fire
Solenoid energized (for automatic or remote
manual systems only)
Local panel (Style B) Fire
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 491 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 33

Source
Water flow Water pressure switch (Style B) Fire
System isolation gate valve (or alarm
isolation valve) not fully open
Tamper switches (Style B) Supervisory
Header isolation gate valve not fully open* Tamper switch (Style B) Supervisory
Low air pressure in sprinkler piping Air pressure switch (Style B) Supervisory
High air pressure in sprinkler piping Air pressure switch (Style B) Supervisory
Solenoid trouble
(automatic or remote manual systems only)
Open or ground in wiring to solenoid
(Style B)
Trouble
Strobe or Fire alarm bell/horn circuit
trouble*
Open or ground in wiring to
notification device (Style Y)
Trouble
Water pressure switch circuit trouble Open or ground in wiring to switch
(Style B)
Trouble
Low air pressure switch circuit trouble Open or ground in wiring to switch
(Style B)
Trouble
High air pressure switch circuit trouble Open or ground in wiring to switch
(Style B)
Trouble
Fire detector or MP circuit trouble Open or ground in detector wiring
(Style D)
Trouble
System isolation valve tamper switch circuit
trouble
Open or ground in wiring to switch
(Style B)
Trouble
Header isolation valve tamper switch circuit
trouble
Open or ground in wiring to switch
(Style B)
Trouble
Loss of primary power at panel/battery in
use*
Local panel Trouble
Battery voltage low Low voltage in battery Trouble
Battery short, charger, or wiring trouble Open or ground in circuits Trouble
System normal Local panel N/A
Lamp test N/A Switch
Acknowledge N/A Switch
System reset N/A Switch
*These alarms need not be duplicated when two or more suppression systems are controlled by one panel.

H. Actuating devices and relays shall be furnished to provide annunciation per
applicable codes, standards, and local requirements. Spare capacity shall be
provided and internally wired.
I. Each local control panel shall continuously monitor its associated fire suppression
and/or detection system(s) for fire alarms, supervisory signals, and circuit trouble
signals.
1. Upon receipt of a fire alarm, the given panel shall activate appropriate
system valves, auxiliary relay, strobes and fire alarm bells throughout the
building.
2. Upon receipt of a trouble or supervisory signal, the panel shall activate
individual indicating LEDs on the panel and a trouble horn at or near the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 492 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 34

panel. Trouble and supervisory signals shall be distinctive, i.e., the mixing of
two or more signals on one circuit is not allowed.
J. Auxiliary shutdown functions, where required, shall be designed, furnished, and
installed, as a minimum, per applicable codes, standards, and local requirements.
K. New panels shall include 10 percent spare I/O of each type. Indicated potential
future expansion out cannot be considered as part of the spare capacity to meet this
requirement.
L. Wiring and raceway between local panel(s) and remote relay, where required for
such things as HVAC systems for auxiliary contacts, will be furnished and installed.
Remote shutdown devices shall be located within 3 ft from device/system being
shut down. Fire Contractor shall clearly note termination points and wiring on the
drawings so other Contractors will be able to land wiring on shutdown relays.
M. Fire protection wiring shall include surge protection, per applicable codes,
standards, and local requirements.
N. Upon receipt of any fire alarm signal from a fire detector, suppression system, flow
switch, or pull station, the local alarm panel shall activate interior and exterior fire
alarm horns/strobes.
9.7 Fire Detection and Alarm
A. Each independent fire detection system shall be designed to provide fire detection,
MP and annunciation in each of the areas protected.
B. Each detection control panel shall continuously monitor its detection systems for
fire or trouble condition and activate the appropriate fire or trouble alarm(s). These
detection and alarm functions shall be performed independently of any other plant
equipment or facility. All signals shall be annunciated on main fire control panel.
C. Airflow, ceiling height and slope, and ceiling constructions of the protected area
shall be evaluated when selecting spacing and location of detectors. Refer to NFPA
72 for location criteria.
D. HVAC duct detectors shall be provided in the duct and wired to the local fire
protection panel to initiate the appropriate response per applicable codes,
standards, and local requirements. The fire alarm shutdown contacts shall be
installed in a junction box next to the HVAC controller. Refer to NFPA 90A.
E. All wiring shall be installed in ridged metallic conduit.
F. As a minimum, the following shall be provided:
1. Smoke, heat, and HVAC duct detectors.
2. Manual Pull Stations
3. Early Warning Air Sampling Smoke detectors and sampling pipe network, if
this is the method utilized.
4. Fire detection circuits, wiring, raceway, conduit and supports as required for
a complete system.
5. Local control panel with distinctive alarm, trouble and supervisory LED’s.
6. Remote shutdown relays i and junction boxes.
7. Notification devices (i.e.: Strobes, horns and bells).
8. Connecting wire and raceway for electrical devices.
9. All field devices shall be installed in a junction box.
G. Each fire detection and alarm control panel shall be provided with the capability to
send alarms for remote annunciation of fire and trouble alarms. The following
distinctive alarms shall be provided for remote monitoring purposes from each of
the local panel, as required.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 493 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 35

Source
Fire detected*Area or duct smoke detector (Style B)* Fire
Detector circuit trouble (short, open, or
ground fault)
Panel (Style B)* Trouble
Loss of ac power (battery in use) Local panel Trouble
Low or missing batteries Low voltage in batteries/panel Trouble
Battery short, charger, or wiring trouble Open or ground in circuits Trouble
Notification circuit trouble Open or ground in wiring to indicating
appliance
Trouble
System normal Panel N/A
Lamp test N/A Switch
Acknowledge N/A Switch
System reset N/A Switch
*NFPA Style D circuit, when detection is used as releasing device
9.8 Fire Equipment
A. Fire hose stations shall be provided only if required by local AHJ or applicable codes,
standards, and local requirements.
B. The Contractor shall furnish fire hose stations with fire hose, hose racks, and
accessories per applicable codes, standards, and local requirements
C. Portable fire extinguishers shall be provided. Refer to NFPA 10 for extinguisher
locations and spacing.
D. Submit certified drawings of fire hose stations, as applicable and portable fire
extinguishers including dimensional data.
9.9 Materials
Component Material
PIPING
Sprinkler piping
(downstream of isolation gate valve)
ASTM A53, Grade A or B, galvanized, seamless or welded
(ERW); or ASTM A106, Grade B, galvanized. Minimum
Schedule 40
Pre-action systems
(downstream of isolation gate valve)
ASTM A53, Grade A or B, galvanized; seamless or welded
(ERW); ASTM A106, Grade B, galvanized (no copper or
brass tubing or piping). Minimum Schedule 40
Piping
(upstream of the sprinkler and spray
systems)
Black steel, ASTM A53, Grade B, seamless; or ASTM A106,
Grade B, seamless. Minimum Schedule 40
FLANGES
Flanges Hot-dip galvanized following welding when connected to
galvanized pipe
Piping 2 in (50.8 mm) and smaller Screwed or shop welded.
Piping larger than 2 in (50.8 mm) Welded flanges or shop welded connections
Pipe Accessories
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 494 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 36

Component Material
Sprinkler fittings - threaded or flanged;
tees, couplings, elbows, caps, and
reducers
Malleable iron, Class 150. Mitered fittings are not
acceptable.
Sprinkler fittings Galvanized, ASTM A153; no bushing, slip type, or clamp-
on rubber gasketed fittings
Gaskets Red rubber sheets, 1/16 in (1.6 mm) thick, full face,
ASTM D2000, No. 2AA705A13L14
Thread sealant Teflon ribbon, Optional for gas suppression piping:
Loctite 592 sealant and primer NF-73656
Thread tolerances Local Fire Code and standard pipe threads
Bolts and nuts Steel machine bolts
Plugs Square heads and of a metal dissimilar to fitting to which
they are attached
Piping supports Per State and Local Fire Code
Supplementary support beams (pipe
support)
ASTM A36, fireproof construction
Riser lugs ASME B31.1
Hanger rods Per Fire Code
Water shields Viking model B-1, or equivalent.
Valves
Gate valves OS&Y type, flanged ends
Control panels (local) NEMA 4 or IP56

9.10 Testing
A. Contractor shall be present during testing. Contractor shall be responsible for costs
associated with initial testing as well as costs to correct deficiencies and retest.
B. Contractor shall notify Owner and AHJ (if required) at least 5 days in advance of
beginning of each test. Final acceptance shall be determined by the Owner.
C. Documentation of the inspections and tests shall be maintained by Contractor and
furnished to Owner. Defects found by these inspections and tests shall be re-
inspected following repair by the same method and technique which originally
identified the defect. Acceptance shall be based on identical acceptance criteria.
Inspection and tests shall be in accordance with NFPA as a minimum. All parties
necessary to sign off on test shall be obtained.
D. Testing shall be done by Contractor for:
1. Testing and system acceptance of water-based fire protection systems
2. Testing and system acceptance of fire alarm system
3. Entire System
4. Testing shall be performed on all piping and valves.
E. Piping and valves; each test shall be conducted for 2 hours at 200 psi (13.8 bar) or at
50 psi (3.5 bar) above the maximum static pressure, whichever is greater. The
systems shall be visually inspected during the tests. There shall be no visible
leakage or drop in gauge pressure during the tests.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 495 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
9.0 FIRE DETECTION AND SUPPRESSION

Page 37

F. The valves shall be tested along with the piping. Any blind flanges or removable
plugs required for openings not closed by the valves and piping provided shall be
furnished.
G. The pressurization equipment including water piping from the supply shall be
furnished.
H. In addition to hydrostatic tests, perform air pressure tests on air pressurized piping
and valves. Air pressure of 40 psi shall be established, and the pressure drop shall
be measured. The pressure drop shall not exceed 1.5 psi (0.11 bar) in 24 hr.
I. The time to exhaust air and achieve continuous water flow shall not exceed 60
seconds.
J. Systems shall be tested in accordance with the manufacturer’s recommendations
and to verify proper alarm and annunciation.
K. Each control panel and independent detection system shall be tested in accordance
with NFPA 72 after installation has been completed. Each initiating and notification
device shall be checked for operation. Remote annunciation to main panel and to
remote location shall be tested.
L. Testing of the detectors shall be by manufacturer's recommendations. Upon
detector actuation, visual and audible annunciation of the independent detection
system at the local and main fire control panel shall be verified. Each alarm circuit
at the local and main fire control panel shall be tested to verify proper operation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 496 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
10.0 SPILL CONTAINMENT AND FIRE WALLS

Page 38
SPILL CONTAINMENT AND FIRE WALLS
10.1 General
A. This section covers the requirements for spill containment and transformer fire
walls.
B. At Owner’s option, transformers may be supplied with environmentally friendly
less-flammable fluid (FR3, MIDEL 7131 or engineer approved equal) which may reduce
spill containment and firewall requirements if approved by environmental permit.
Contractor to verify fluid characteristics are appropriate for site environmental
conditions.
10.2 Codes and Standards
A. Equipment, material, design, fabrication, erection, and testing shall conform to
governing codes and standards, and minimum requirements of:
1. International Building Code (IBC)
2. Occupational Safety and Health Association (OSHA)
3. American Society of Mechanical Engineers (ASME)
4. American Society for Testing and Materials (ASTM)
5. American Concrete Institute (ACI)
6. American National Standards Institute (ANSI)
7. State and Local Fire Code
8. Environmental Protection Agency (EPA)
9. Other Applicable Owner Standards
B. The standards listed shall mean the latest version adopted by the state or local
authorities including any amendments to, or modifications of the original document.
10.3 Design Requirements
A. Design shall comply with requirements for civil, structural, piping, and fire
protection systems.
10.4 Transformer Spill Containment
A. Spill containment for transformers shall be based on the number of gallons (liters)
of oil/fluid in the transformer.
B. Design shall comply with requirements for environmental, civil, structural, and fire
protection systems.
C. Containment shall be sized to retain any fluid that may be accidentally spilled from
the transformer plus a specified storm event rainfall depth, plus any applicable fire
water.
D. Containment may be combined to include multiple transformers or transformer
areas; such that the containment meets requirements for the maximum containment
needed for a single event.
10.5 Transformer Fire Walls
A. Refer to NFPA 850 for location and configuration of firewalls.
B. A minimum 2-hour fire barrier of appropriate height shall be provided between any
transformer of sufficient oil volume and any building in accordance with applicable
Codes or insurance requirements.
C. Adequate physical separation distance may be provided in lieu of fire barriers.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 497 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
10.0 SPILL CONTAINMENT AND FIRE WALLS

Page 39

D. Transformers utilizing approved less-flammable fluids (e.g. FR3) shall follow
minimum separation requirements of FM Global Loss Prevention Data Sheet 5-4.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 498 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
11.0 HEATING, VENTILATION, AND AIR CONDITIONING

Page 40
HEATING, VENTILATION, AND AIR CONDITIONING
11.1 General
A. Heating, ventilating, and air conditioning (HVAC) systems shall be provided to
ensure equipment OEMs’ recommended environmental conditions are met at all
times.
B. HVAC equipment and systems shall be heavy-duty, industrial grade design,
construction, and installation designed to provide a minimum 20-year life
expectancy.
C. Design calculations shall include air conditioning load calculations, heating load
calculations, ventilation calculations, psychometric calculations, and pressure drop
calculations.
11.2 Codes and Standards
A. Equipment, material, design, fabrication, erection, startup, and testing shall conform
to governing codes and standards, and minimum requirements of:
1. State Energy Conservation Codes
2. International Building Code (IBC)
3. Occupational Safety and Health Association (OSHA)
4. American Society of Mechanical Engineers (ASME)
5. American Society for Testing and Materials (ASTM)
6. American National Standards Institute (ANSI)
7. State and Local Fire Codes
8. American Society of Heating, Refrigerating and Air-Conditioning Engineers
(ASHRAE)
9. Other Applicable Owner Standards
11.3 Design Requirements
A. Cooling equipment capacity shall be sized based on end-of-life battery state-of-
health (70-80%) heat dissipation coincident with maximum design ambient heat
gain.
B. Building or enclosure areas housing batteries shall be segregated into hot and cold
aisles. Supply air measured at the battery rack cold aisle shall be maintained at 23C
+/- 5C at all times, unless battery OEM specifically requires a different operating
temperature. Each battery cold aisle temperature shall be measured at three
locations equally spaced along the length of the row. Temperature sensors shall be
located approximately 5 feet above the floor. All temperature measurements shall
be recorded in the site data historian at 1-minute resolution. Data shall be stored a
minimum of 6 months.
C. High efficiency filtration (80%, MERV 13) is required for HVAC units that provide a
mixture of outside air and return air. For 100% recirculation style units only 30%,
MERV 7 filters may be provided.
D. HVAC systems should be designed to operate in economizer (free cooling) mode
whenever outdoor air temperature is within specified supply air temperature range.
E. Filter banks shall have differential pressure transmitters to monitor filter loading.
F. Heating calculations shall include a minimum 10% margin on capacity. Cooling
calculations shall include a minimum 15% margin on sensible and latent capacity.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 499 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
11.0 HEATING, VENTILATION, AND AIR CONDITIONING

Page 41

G. HVAC equipment shall be arranged to provide for maximum efficiency of operation
and to provide easy access for performing routine maintenance.
H. System design shall be headered such that each HVAC unit is able to provide
conditioned air to the entire space within a fire partition.
I. Equipment redundancy shall be provided such that failure of a single HVAC unit
does not result in loss of more than 50% cooling capacity.
J. The HVAC control system shall monitor any equipment failures resulting in loss of
cooling capacity. Diminished cooling capacity shall be interlocked with the Site
Controller to limit battery charging/discharging rate as necessary to avoid cooling
system overload. Battery state of health should be taken into consideration when
developing charge/discharge rate limit.
K. The HVAC systems shall interface with fire protection systems in accordance with
NFPA and other applicable codes. HVAC systems shall shut down and fire/smoke
dampers shall close upon fire or smoke detection. Fire-fighting personnel shall be
able to override system shutdown to ventilate the building space if required.
11.4 Testing
A. After installation, HVAC systems shall be functionally tested by NEBB certified
technicians to verify proper operation.
B. Emphasis shall be placed on ensuring that cooling airflow is properly balanced to
maintain cold aisle temperature within specified limits.
C. All temperature data points recorded in site data historian shall be functionally
verified for proper operation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 500 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
12.0 GENERAL ELECTRICAL

Page 42
GENERAL ELECTRICAL
12.1 General
A. This section describes the design criteria which shall be used for general electrical
work related to this project.
B. Equipment and systems covered in this section are:
1. Cable
2. Earthing and Bonding
3. Lightning Protection
4. Conduit and Raceway
5. Lighting and Wiring Devices
12.2 Codes and Standards
A. The Work shall be in accordance with applicable laws and regulations of the federal
government and the state, local utility requirements for interconnection, and
applicable local codes and ordinances. A partial listing of the codes and industry
standards used for design and construction follow:
1. National Electrical Code (NEC)
2. International Building Code (IBC)
3. American National Standards Institute (ANSI)
4. Institute of Electrical and Electronics Engineers (IEEE)
5. American Society for Testing and Materials (ASTM)
6. State Energy Conservation Code
7. Illuminating Engineering Society (IES)
8. State and Local Fire Code
9. Occupational Safety and Health Association (OSHA)
B. Other recognized standards shall be utilized as required to serve as design,
fabrication, and construction guidelines when not in conflict with the above listed
standards.
C. The codes and industry standards used for design, fabrication, and construction
shall be the codes and industry standards in effect at the date of this Contract.
D. The Owner may be exempt from certain NEC requirements. The system electrical
design shall be NEC compliant to the greatest extent possible and in accordance with
all applicable standards. Deviations from the NEC must be approved by Owner.
12.3 Cable Basic Requirements
A. Cable requirements are applicable to general (field) wiring only. Manufacturer's
standard wiring practices are acceptable for equipment wiring .
B. Medium voltage cables shall be fully shielded, and shields shall be grounded in
accordance with IEEE 422.
C. Instrument cable shall be fully shielded to minimize electrical noise attenuation.
Each pair of instrument conductors shall be shielded, and each multi-pair cable
assembly shall include an additional overall shield. Cable shields shall be
electrically continuous. When two lengths of shielded cable are connected together
at a terminal block, a point on the terminal block shall be used for connecting the
shields. Instrument cable shields shall be grounded on one end only.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 501 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
12.0 GENERAL ELECTRICAL

Page 43

D. Medium voltage cable feeders along with their shields and equipment ground
conductors shall be sized so that a short-circuit fault shall not result in cable damage
prior to normal operation of fault interrupting devices.
E. Insulated conductors installed in cable tray shall have non-propagating and self-
extinguishing characteristics. Cables shall meet the vertical cable tray flame test
requirements of IEEE 383.
F. Thermocouple extension cable shall be used for extension leads from
thermocouples to junction boxes and to instruments for measurements of
temperature. Cables may be routed in trays, conduits, or ducts.
G. All cables shall be identified on each end with a unique cable ID and permanent
cable tag.
H. Cable data such as year of manufacturing, manufacturer name, insulation material,
rated voltage, and cross section shall be printed on the cable jacket at even spacing.
I. Cable conductor colors shall be in accordance with Owner standards.
12.4 Power Cable
A. Medium voltage power cable shall be MV-105, 133% insulation, single copper or
aluminum conductor, Class B stranded, shielded power cable. Cable shall meet AEIC
CS8 and ICEA S-97-682 requirements and shall be UL listed for cable tray use. Cable
shall meet the flame test requirements of IEEE 383.
B. Low voltage power cable shall supply power to loads at voltage levels of 480 volts ac
and below and 250 volts dc and below. Power cable shall be Class B stranded
copper conductor. Cable shall meet ICEA S-95-658 and shall meet the flame test
requirements of UL VW-1 (8 AWG and smaller) and IEEE 383 (6 AWG and larger).
C. No MV cable splices are permitted unless explicitly approved by the Owner.
12.5 Control and Instrumentation Cable
A. Control cable shall be used for control, metering, and relaying. Control cable shall
have Class B stranded copper conductor, flame retardant insulation, flame and
ultraviolet retardant overall jacket and shall be UL listed Type TC. Cable shall meet
ICEA S-95-658 and UL 1277. The cable shall meet the flame test requirements of
IEEE 383.
B. Control shall be multi-conductor and shall be UL listed Type TC.
C. Instrumentation cable shall be single or multi twisted pair or triad and shall be UL
listed Type PLTC.
D. Metering and Relaying panel conductors shall be type SIS #14 AWG minimum or
#12 AWG minimum for CT circuits.
12.6 Lighting and General Use Conductors
A. Insulation shall be rated 600 volt. Circuit runs shall be in conduit. Minimum
conductor size shall be #12 AWG (4.0 mm2).
B. Type THHN or THWN single conductor with copper conductor for low voltage
general use circuits indoor or conditioned areas.
C. Lighting conductors in areas not normally accessible after construction may utilize
properly supported type MC cable.
D. Grounding cable shall be Class B or C, Type THWN or THHN insulated and un-
insulated soft drawn copper conductors sized as required.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 502 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
12.0 GENERAL ELECTRICAL

Page 44

12.7 Cable Connectors and Terminations
A. Power cables shall utilize standard two-hole pressure crimped connectors except
when terminating to devices which are provided with clamp type connectors, such
as molded case circuit breakers. Hole spacing shall be NEMA standard.
B. Medium voltage shielded cables shall not be spliced. Medium voltage terminations
shall have stress relief system applied at the termination of the cables. Stress relief
system shall be of the pre-formed cone type, cold shrink type suitable for the cable
to which they are to be applied; Manufacturer shall be 3M.
C. Control and Instrument Terminations may utilize Contractor’s / Manufacturers’
standard.
D. Current Transformer (CT) terminations shall utilize ring lug terminals. Field CT
circuits terminating in control and protection cabinets shall be terminated on
shorting-type terminal blocks prior to continuation to protective devices.
12.8 Earthing and Bonding Requirements
A. The BESS earthing system shall be an interconnected network of bare copper
conductor, copper-clad ground rods, foundation reinforcing steel, and other
grounding electrodes present as defined by the NEC. The BESS facility earthing
system shall be connected to any adjacent grounding grids. (As applicable)
B. Contractor shall perform calculations in accordance with IEEE 80 methods to
demonstrate the BESS facility is safe from the perspective of touch, step, and
transferred potentials. Calculations shall be submitted for Owner review.
12.9 Lightning Protection Criteria
A. The requirement for lightning protection shall be evaluated based on a risk-based
assessment such as that provided in NFPA 780 Annex L. If required, lightning
protection shall be designed and installed in accordance with NFPA 780.
B. Lightning protection equipment shall conform to the requirements of Underwriters
Laboratories Standards 96.
12.10 Conduit and Raceway
A. Cable tray design shall be based on the loads to be carried plus the dead weight of
the tray system. In addition to, and concurrent with the load specified above, the
tray shall be designed to withstand a concentrated load of 200 lbs. (90kg) at the
mid-span, at the center of the rung or on either side rail. The safety factor for this
load condition shall be at least 1.5 based on the ultimate capacity of the tray or any
of its components as determined by test in accordance with NEMA load test
VE-1-Sect 4.
B. Cable trays and fittings shall be the standardized products of a single manufacturer
designed to permit easy assembly in the field.
C. Aluminum cable trays shall be manufactured of heat-treated ASTM B221 6063
aluminum alloy for extruded parts and ASTM B209 5052 alloy for parts fabricated
from sheets. Rungs shall not be movable.
D. Minimum radius for tray bends and fittings shall be eight times the diameter of the
largest non-shielded cable or 12 times the diameter of the largest shielded cable to
be installed, whichever is the larger. Dropout fittings shall be provided where
required to maintain the minimum cable bending radius.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 503 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
12.0 GENERAL ELECTRICAL

Page 45

E. In general, trays for cables of different voltage levels shall be stacked in descending
order with the higher voltage at the highest elevation. Individual tray systems shall
be established for the following services. Trays may be divided into multiple
services by the use of continuous, metallic barriers.
1. Medium voltage power cables
2. Low voltage power cables
3. Low voltage control cable
4. Shielded instrumentation cables
5. Communication cables
F. Fire stops shall be provided where trays penetrate exterior walls or fire separation
areas.
G. Except for indoor lighting and communications circuits, exposed conduit shall be
rigid steel, hot-dipped galvanized.
H. Conduits for lighting, power, and general convenience circuits, and communications
circuits in indoor areas may utilize Electrical Metallic Tubing (EMT), hot-dipped
galvanized inside and outside. EMT shall not be used in hazardous areas or where
subject to physical damage during and after installation.
I. Minimum conduit size shall be 3/4 in (20 mm) nominal diameter except for lighting
fixture stems, which may be 1/2 in (16 mm) nominal diameter.
J. Conduits shall be routed such that they do not create a trip hazard.
K. Liquid tight flexible metallic conduit shall be used for connections to accessory
devices, for connections to vibrating equipment, and across areas where expansion
or movement of the conduit is required. Lengths shall not exceed 3 ft (900 mm).
12.11 Lighting, Convenience Receptacles, and Wiring Devices
A. The lighting system shall provide personnel with illumination for operation under
normal conditions and means of egress under emergency conditions.
B. Interior and exterior luminaries shall be LED type, mounted so they are easily
accessible for maintenance to the maximum extent practical.
C. Emergency lighting shall be self-contained emergency lighting units including
batteries and battery charger.
D. Lighting levels shall be designed in accordance with the Illuminating Engineering
Society (IES) recommendations.
E. Outdoor fixtures shall include photoelectric sensors and motion detectors to keep
lights off when not required.
F. Convenience receptacles shall be spaced in the battery storage area such that there
is a maximum 100 ft (30.0 m) distance to a receptacle outlet, unless codes require
otherwise. An accessible receptacle outlet shall be provided within 25 ft (7.6 m) of
each HVAC unit.
12.12 Emergency Stop Switches (E-Stop)
A. Containerized BESS systems shall incorporate an E-stop function into the inverter
control panel or local HMI. Containerized BESS system E-stops shall shut down only
the affected BESS equipment train.
12.13 Earthing and Bonding Installation and Testing
A. Earthing conductors shall be copper and have a minimum cross-sectional area of
#2/0 AWG.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 504 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
12.0 GENERAL ELECTRICAL

Page 46

B. Cable trays shall include a bare copper earthed conductor installed the entire length
and connected to each section of tray and to station earth grid.
C. Major items of equipment, such as transformers, relay and control panels, and
panelboards, shall contain copper earthed buses connected to the primary earthing
system. Equipment with multiple sections such as low voltage switchboards shall
connect earth bus to station grid at both ends.
D. Each row of battery racks shall be earthed at each end.
E. Metallic structures and equipment housings located on the roof of the building shall
be connected to earthing system.
F. The site perimeter fence may be earthed or isolated at Contractor’s option, subject
to safe touch potential analysis. If the site fence is not earthed, then isolating
sections shall be installed where the BESS site fence abuts the existing substation
fence.
G. BESS container lightning protection system downcomers shall be terminated to the
BESS earthing grid.
H. Earthing system connections shall be made with exothermic welds or non-
reversible compression type fittings. Mechanical bolted connections are not
permitted.
I. Earthing connections at the substation shall be exothermic weld. Earthing connections
on the collection system may be irreversible crimp or exothermic weld.

12.14 Arc Flash Mitigation
A. Contractor shall perform an Arc Flash hazard analysis in accordance with IEEE 1584
for voltages up to 15kV. For voltages above 15kV, Kinectrics ARCPRO software must
be utilized.
B. The system shall be designed such that a PPE level of no higher than Level 4 (40
cal/cm2) is required.
C. All electrical equipment shall be labeled in accordance with NFPA 70E. At a
minimum, the following information shall be shown on equipment labels:
1. Nominal system voltage
2. Arc Flash Boundary
3. Working distance
4. Available incident energy at working distance
D. Methods shall be employed to reduce the arc flash hazards including:
1. Maintenance Mode relay settings and a maintenance mode selector switch
(Normal / Maintenance) with blue indicating light for medium voltage
switchgear breakers.
2. Bus differential relay protection.
3. Transformer differential relay protection on the main power transformer.
4. Provide remote racking systems for medium voltage draw-out circuit
breakers. Remote racking system shall be Safe-T-Rack or Owner approved
equal.
5. Provide actuator to remotely operate pistol grip type breaker Open / Close
switches. CBS Arc Safe Chicken Switch or Owner approved equal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 505 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
13.0 PADMOUNTED TRANSFORMERS

Page 47
PADMOUNTED TRANSFORMERS
13.1 General
A. This document specifies the scope of supply and the major design and performance
parameters for the Step-Up transformers and the facility station service
transformer.
B. Basic design shall be outdoor oil-immersed 3-phase pad mounted distribution
transformers designed for daisy-chain or loop feed on the HV side (As Applicable)
13.2 Applicable Standards
A. Characteristics, definitions, and terminology, except as specifically covered in this
specification, shall be in accordance with the latest revision of ANSI, IEEE, NEMA,
and Department of Energy standards, as applicable.
B. Specifically, but not limited to:
1. IEEE C57.12.00, and associated applicable parts
2. C57.12.28
3. C57.12.34
4. C57.12.90 for standard testing
5. C57.12.91
6. C57.154
7. NEMA TR1
8. NEMA 260
13.3 Design Requirements
A. Inverter step-up transformers shall be naturally cooled. Cooling fans shall not be
required for continuous operation to achieve maximum rating.
B. Transformers shall be suitable for bi-directional operation.
C. Transformers shall be sized to continuously accept inverter rated kVA output
between .9 leading and .9 lagging power factor without overload.
D. Inverter step-up transformers shall be suitable for operation at up to 5% harmonics
on both the HV and LV winding at the transformer full load rating.
E. As applicable, loop feed or daisy chain transformers shall be provided with six high
voltage bushings, 600A minimum. HV connections shall be made via elbow
disconnects.
F. For HV/Substation Interconnections, the Power Conversion System (PCS) step-up
transformer voltage ratio shall be selected to match the substation interconnection
voltage without use of intermediate step-up transformers
G. For intermittent generating sources, during detailed design, Contractor shall
perform an electrical harmonics study to confirm that the proposed PCS system
does not cause harmonic resonance when paralleled with the Owner’s existing
equipment. If required, the addition of air core tuning reactors or other mitigating
measures shall be engineered and provided by Contractor.
13.4 Testing
A. Perform standard factory tests in accordance with IEEE C57.12.90. Furnish tests
reports per submittal requirements.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 506 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
13.0 PADMOUNTED TRANSFORMERS

Page 48

13.5 Loss Evaluation
A. Transformers will be continuously energized when BESS facility is in standby mode.
No-load losses should be minimized to extent practical. Bidders shall include no-
load and load loss data for BESS transformers. Owner will evaluate the transformer
losses using values of $4000/KW for no-load losses and $2000/KW at rated full load
output.
13.6 Transformer Data Sheets
Contractor shall submit information in “Vendor Data” column with Proposal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 507 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
14.0 METERING AND PROTECTION

Page 49
METERING AND PROTECTION
14.1 General
A. This section covers the basic system protection requirements.
B. Contractor shall coordinate with interconnection work to ensure equipment is
provided which meets the overall intent of the project and utility interconnection
requirements.
14.2 Codes and Standards
A. The design and specification of work shall be in accordance with applicable laws
and regulations of the governing bodies, local utility requirements for
interconnection, and applicable local codes and ordinances.
B. A listing of the codes and industry standards to be used in design and construction:
1. American National Standards institute (ANSI)
2. American Society for Testing and Materials (ASTM)
3. Institute of Electrical and Electronic Engineers (IEEE)
4. National Electrical Manufacturers Association (NEMA)
5. National Fire Protection Association (NFPA)
6. State and Local Fire Code
7. National Electrical Safety Code (NESC)
8. Occupational Safety and Health Act (OSHA)
9. Underwriters Laboratories, Inc. (UL)
10. National Electrical Code (NEC)
11. Other Applicable Owner Standards
C. Other recognized standards shall be utilized as required to serve as design,
fabrication, and construction guidelines when not in conflict with the above listed
standards.
D. The Owner may be exempt from certain NEC guidelines. The system electrical
design shall be NEC compliant to the greatest extent possible and in accordance with
all applicable legal requirements.
E. The codes and industry standards used for design, fabrication, and construction
shall be the codes and industry standards in effect at the date of this Contract.
14.3 Overall System Protection
A. Contractor shall perform system analysis from the point of interconnection (POI)
down to the BESS inverters and station auxiliary LV buses. Where system
information is not available, Contractor shall assume an infinite bus at the
Substation high voltage bus. Relay settings shall be based on actual system
interconnection values which will be provided prior to setting relays.
B. Contractor shall perform initial and final electrical system studies. The scope shall
include studies required to design and specify the plant auxiliary electric system
within the site boundaries. Studies include, but are not limited to, load flow, feeder
and equipment sizing duty calculations, short circuit and protective device
coordination, harmonics and arc flash.
C. Contractor shall develop relay settings for protection and control devices within
Contractor’s supply scope. Protection and control settings for the breaker at the POI
shall be coordinated with Owner’s existing protection and control scheme.
Contractor shall implement settings into relays and test all relays prior to operation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 508 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
14.0 METERING AND PROTECTION

Page 50

D. Protective relays shall be solid-state microprocessor type, flush mounted.
E. Each item of the electrical system shall be provided with a back-up protection that is
responsive to electrical faults thus allowing isolation of the faulted item in a timely
manner, before major damage is sustained. This is not required to be a separate
relay and may form part of the transformer or feeder protection, e.g. over-current
and earth fault.
F. Alarm/trouble contacts from each breaker and relay shall be remotely alarmed via
SCADA. All protective devices shall be synchronized to the substation same time
source via IRIG-B signal.
G. Any devices used to isolate electrical equipment for maintenance shall have a visible
airgap or means of visual disconnect.
H. Contractor shall provide a means of detecting a ground fault occurrence either via a
neutral grounding transformer or a Zig-Zag grounding transformer. If a Zig-Zag
grounding transformer is utilized, it shall be provided as required on each Bus to
facilitate ground fault detection. BESS protection shall trip and prevent further
operation of BESS if grounding system is unavailable. Grounding transformers shall
be automatically removed from service when BESS is not in service and shall be
interlocked with any other grounding system to ensure only one grounding system
is active at any given time.
i. KVA Rating as required for effective grounding of AC collection circuits. All
grounding transformers to have the same KVA rating, etc. and be
interchangeable.
ii. KVA Rating as required for effective grounding of AC collection circuits. All
grounding transformers to have the same KVA rating, etc. and be
interchangeable.
iii. Pedestals for padmount transformers shall be fiberglass, pre-cast, or poured
concrete.
iv. Grounding transformers shall be sized to keep the collection feeder voltage
rise during a fault to less than 1.39pu voltage as per IEEE C62.92.1-2000.
14.4 Metering
Contractor shall provide bi-directional, revenue grade metering at each point of interconnection in
the form of a SEL-735 Power Quality and Revenue Meter. Contractor shall also provide provisions
for an Owner supplied revenue meter (Schneider Electric ION-8500) or Owner approved alternate.
BESS facility auxiliary power consumption shall be separately metered, also with an SEL-735
revenue grade meter.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 509 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
15.0 LOW VOLTAGE ELECTRICAL DISTRIBUTION

Page 51
LOW VOLTAGE ELECTRICAL DISTRIBUTION
15.1 General
This section covers the low voltage distribution equipment
15.2 Codes and Standards
A. The design and specification of work shall be in accordance with applicable laws
and regulations of the governing bodies, local utility requirements for
interconnection, and applicable local codes and ordinances.
B. A listing of the codes and industry standards to be used in design and construction:
1. American National Standards institute (ANSI)
2. American Society for Testing and Materials (ASTM)
3. Institute of Electrical and Electronic Engineers (IEEE)
4. National Electrical Manufacturers Association (NEMA)
5. National Fire Protection Association (NFPA)
6. State and Local Fire Codes
7. National Electrical Safety Code (NESC)
8. National Electrical Code (NEC)
9. Occupational Safety and Health Act (OSHA)
10. Underwriters Laboratories, Inc. (UL)
11. Other Applicable Owner Standards
C. Other recognized standards shall be utilized as required to serve as design,
fabrication, and construction guidelines when not in conflict with the above listed
standards.
F. The codes and industry standards used for design, fabrication, and construction
shall be the codes and industry standards in effect at the date of this Contract.
G. The Owner may be exempt from certain NEC requirements. The system electrical
design shall be NEC compliant to the greatest extent possible and in accordance with
all applicable standards. Deviations from the NEC must be approved by Owner.
15.3 Design Requirements
A. The LV distribution system shall be fed from a dedicated station service
transformer. The LV system capacity shall be primarily determined by Contractor’s
BESS HVAC design. See Oneline diagram for additional information.
B. Auxiliary power consumption shall be metered separately.
15.4 Low Voltage Panelboards
A. Panelboards shall be dead-front, fixed mounted circuit breaker type.
B. Breaker operating handles shall be accessible through a door that can latch and lock.
A panel directory shall be placed inside the panelboard door. Circuit breaker
assignments shall be consistent with design drawings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 510 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
16.0 MEDIUM AND HIGH VOLTAGE EQUIPMENT AND
INTERCONNECTION

Page 52
MEDIUM AND HIGH VOLTAGE EQUIPMENT AND INTERCONNECTION
16.1 General
A. This section covers the scope of work associated with the interconnection of the
BESS to the Owner’s substation. The Contractor shall be responsible for ensuring
compliance with the utility and system operator interface requirements.
B. Work shall include Engineering, Procurement, and Construction and shall include:
1. Site Work
2. Grounding
3. Steel Structures
4. MV and HV Equipment
5. Metering and Protection
6. Instrument Transformers
7. Overhead Lines and Underground Lines
8. Foundations
9. Commissioning and Start-up
C. Coordinate ratings and design requirements with interconnection utility.
Equipment shall meet at least the minimum requirements. Single-line diagram (s)
are provided for reference to show the limits of the anticipated work.
D. The codes and industry standards used for the design, fabrication, and construction
shall be the codes and industry standards in effect at the start date of the work.

16.2 Codes and Standards
A. The design and specification of work shall be in accordance with applicable laws
and regulations of the governing bodies, local utility requirements for
interconnection, and applicable local codes and ordinances.
B. A listing of the codes and industry standards to be used in design and construction:
1. American National Standards institute (ANSI)
2. American Society for Testing and Materials (ASTM)
3. Institute of Electrical and Electronic Engineers (IEEE)
4. National Electrical Manufacturers Association (NEMA)
5. National Fire Protection Association (NFPA)
6. State and Local Fire Codes
7. National Electrical Safety Code (NESC)
8. National Electrical Code (NEC)
9. Occupational Safety and Health Act (OSHA)
10. Underwriters Laboratories, Inc. (UL)
11. Other Applicable Owner Standards
C. Other recognized standards shall be utilized as required to serve as design,
fabrication, and construction guidelines when not in conflict with the above listed
standards.
D. The codes and industry standards used for design, fabrication, and construction
shall be the codes and industry standards in effect at the date of this Contract.
E. The Owner may be exempt from certain NEC requirements. The system electrical
design shall be NEC compliant to the greatest extent possible and in accordance with
all applicable standards. Deviations from the NEC must be approved by Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 511 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
16.0 MEDIUM AND HIGH VOLTAGE EQUIPMENT AND
INTERCONNECTION

Page 53

16.3 Submittals
A. Provide submittals in accordance with project submittal requirements.
B. Preliminary and detail design engineering and construction documents, to include:
1. Nameplate data.
2. Schematic design drawings for Owner review.
3. Detailed construction drawings for Owner review.
4. Protection coordination study, selectivity, and settings.
5. Final sealed and signed conform to construction record drawings at the
completion of the project.
6. Test Reports
7. Operation and Maintenance Manuals.
C. Relay protection shall include such things as the study report, time coordination
curves, settings, setting manuals, setting files for downloading into relays, and
programming of protection devices.
D. Documentation for each relay, meter, or programmable controller furnished or
altered under this contract shall include supporting calculations and/or
methodology for each setting that differs from the relay vendor’s factory default
settings. In addition, a logic drawing shall be provided that clearly documents all
custom logic and the logic driving all relay output. Relay output includes; contact
outputs, virtual outputs, LED targets, and LCD display message.
16.4 Site Work
A. Excavate as required for new breaker and takeoff structure foundations.
B. After completion of foundations, structures, ground grid; underground duct
bank/precast cable trench and conduits, and other permanently installed
equipment, the areas shall be backfilled and compacted to 95% modified proctor to
an elevation of 6 in below finished grade.
C. All areas within the substation shall be finished with 6 in of cleaned, crushed rock to
match existing substation surfacing. The rock must have a minimum of 3 fractured
faces and must meet the minimum requirements for appropriate step/touch
potentials.
16.5 Grounding
A. All new above grade structures shall be connected to the grounding grid with #4/0
AWG bare copper conductors.
B. Manual disconnect switch operators shall have a potential equalizing (switching)
mat installed. Switching mats shall be constructed from galvanized 4 ft x 6 ft metal
grating set level on top of the stone yard surface and connected to the ground grid
and to the switch handle / operator ground.
16.6 SF6 Circuit Breakers
A. Provide three phase, freestanding, SF6 dead tank breaker, complete.
B. Install breakers on new concrete foundation.
C. Equip breakers with the number of multi-ratio current transformers (MRCT)
required for use in protective relaying or metering.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 512 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
16.0 MEDIUM AND HIGH VOLTAGE EQUIPMENT AND
INTERCONNECTION

Page 54

16.7 Islanding Switchgear
A. Provide three phase, freestanding, metal clad switchgear lineup.
B. Switchgear shall be outdoor and arc-flash rated.
C. Switchgear shall include vacuum circuit breakers, instrument transformers, and
protective relaying.
16.8 Instrument Transformers
A. Current and voltage transformers are required for protection and metering. High
accuracy CTs shall be required for revenue metering.
B. Current and voltage transformers shall meet the utility interconnection
requirements for both type and accuracy class. Accuracy class shall be maintained
for any tap position on a multi-ratio CT, specifically for metering applications during
lightly loaded conditions.
16.9 Underground Raceway
A. All underground circuits shall be encased in conduit, ductbank, or a cable trench.
B. Duct banks shall be concrete encased. Cable trench shall have covers rated for the
appropriate loads that may be encountered.
C. The AC collection circuits from the BESS to the substation may be direct buried after
exiting the substation.
16.10 Foundations
A. Foundations shall be provided as specified in other Sections of this specification.
B. Substation foundations shall extend at least 12 in (300 mm) above finished grade.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 513 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
17.0 BATTERIES, RACKS, AND BMS

Page 55
BATTERIES, RACKS, AND BMS
17.1 General
A. This section establishes the minimum functional specifications for the Batteries,
Racks, and Battery Management System (BMS).
17.2 Batteries
A. Battery cell/module design shall be of proven technology and shall have been
installed in similar applications for a minimum of one year. It is expected that
battery cells/modules are sourced from recognized “Tier 1” manufacturers. It is
expected that replacement modules of the same design or of a directly compatible
design will be readily available from the manufacturer for a minimum of 10 years
such that rack modifications are not required.
B. Battery racks shall be factory pre-assembled into vertical sections. Rack dimensions
shall be manufacturer’s standard, designed for installation into a building or
environmental enclosure arranged in back-to-back rows. Racks shall include all
bracing required for the site seismic conditions and to ensure racks cannot tip
during module installation. Racks shall be suitable for installation directly onto a
finished concrete floor with tolerances specified in other sections of this
specification. Racks shall be anchored using drilled concrete anchors and leveling
shims as required. Rack design shall include provisions to protect personnel from
inadvertent contact with exposed energized parts, such as ventilated doors or
insulated covers over live parts.
1-
Description Requirements
Intended Use Energy-Shifting
Applications / Use Cases Primary application is energy time-shift and arbitrage (C =
0.25) (See below for description of “C” rating)

Battery is to be 80 MW / 320 MWhr (0.25 C).

(C-rate is a measure of the rate at which a battery is discharged
relative to its maximum capacity. The C rate is calculated as the
inverse of battery discharge rate in hours. i.e. a battery that
discharges in 4 hours would have a C rate of 1/4 = 0.25.)
End of Life Power 80 MW
End of Life Energy 320 MWhr useable depth of discharge (DOD)
Minimum End of Life Energy EPC to provide expected degradation curves based on specified
Duty Cycle with proposal.
Duty Cycle 200 cycles of full depth of charge/discharge per year at 0.25C,
plus
10 cycles per day within +/- 15 percent range DOD (of 50%
nominal SOC) at 0.5C
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 514 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
17.0 BATTERIES, RACKS, AND BMS

Page 56

Charging Method Constant Current / Constant Voltage
Discharging Method Constant Current
Design Life Component life 20 years.
Inverter Nominal Voltage Range 1500 VDC nominal
Warranty requirements Manufacturer Standard
Installation
Design Ambient (battery enclosure) 23C +/- 5C
Design Humidity (battery enclosure) 20 – 100%, non-condensing
Seismic Data Refer to Section 2.4
17.3 Racks
A. Each rack section (or pair of sections for long duration systems) shall include a load-
break disconnecting means to allow isolation of the rack’s modules from the DC bus
by the Battery Management System.
17.4 Battery Management System
A. The Battery Management System (BMS) shall be the battery OEM’s standard
product, providing the following functions at a minimum:
1. Measurement of Battery operating parameters
2. Measurement of battery cell voltages
3. Measurement of battery cell temperatures
4. Measurement of battery string current
5. Measurement of battery string voltage
6. Calculation of battery string State of Charge (SOC)
7. Calculation of battery string State of Health (SOH).
8. Cell Balancing
9. Battery Protection from the following:
a. Cell under voltage
b. Cell over temperature
c. Cell under temperature
d. Cell over current
10. Pre-charge protection
B. At a minimum, the BMS shall monitor the data points listed in Table 2. The BMS
shall monitor all data points required and store data a minimum of 24 hours of pre-
and post- event (or as required by the battery OEM) for root cause / post mortem
analysis and warranty claim disposition. Data points shall also be transmitted to
the Site Controller / Historian for long term data storage and retrieval.
C. Rack BMS to System BMS communication protocol shall be manufacturer standard.
D. System BMS to Site Controller communication protocol shall be Modbus TCP/IP or
alternate as approved by Purchaser.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 515 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
17.0 BATTERIES, RACKS, AND BMS

Page 57

Table 2- Minimum BMS Functional Specifications
Description
System Level
Fault Status
Alarm Status
System Current
System Voltage
Each Rack or String
Rack Voltage
Rack Current
Rack SOC
Rack SOH
Rack Fault Status
Rack Alarm Status
Maximum Cell Voltage Value
Maximum Cell Voltage Position
Minimum Cell Voltage Value
Minimum Cell Voltage Position
Maximum Cell Temperature Value
Maximum Cell Temperature Position
Minimum Cell Temperature Value
Minimum Cell Temperature Position
Rack DC Switch Status
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 516 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
18.0 POWER CONVERSION SYSTEM

Page 58
POWER CONVERSION SYSTEM
18.1 General
A. This section establishes the minimum functional specifications for the BESS Power
Conversion Systems (PCS).
B. The PCS, in conjunction with the BESS Site Controller, shall be capable of automatic,
unattended operation. The PCS shall include all necessary self-protective and self-
diagnostic features to protect itself from damage in the event of component failure
or from operating beyond equipment ratings, whether due to internal or external
causes.
C. The PCS system shall include provisions for isolation on both the AC and DC
terminals. Disconnecting provisions shall be capable of being locked out to
facilitate Owner’s LOTO process for maintenance work. Filter capacitors shall be
provided with bleeder resistors or other means of discharging to less than 50 volts
within approximately one minute of de-energization.
18.2 Codes and Standards
A. UL 1741
B. IEEE 1547
C. IEEE 519
D. NFPA 855
E. Other Applicable Owner Standards
18.3 Inverters
A. Operating in conjunction with the Site Controller, the PCS shall be able to operate in
all modes specified in Section 20.0.
B. Inverters shall be of proven technology and shall have been installed in similar
applications for a minimum of one year. The PCS must be sourced from recognized
“Tier 1” manufacturers such as those provided in the approved supplier list.
C. Inverters shall have a design life of not less than 20 years and shall be suitable for
installation in an outdoor environment. It is expected that replacement components
will be readily available from the manufacturer for the design lifetime.
18.4 PCS Specifications
A. The PCS internal cooling system design may be the manufacturer’s standard,
provided that failure of a single cooling fan does not cause more than 50% derating
of the affected PCS’s power rating.
B. The PCS transformer shall meet the requirements of Section 13.0- Pad Mounted
Transformers.
C. The PCS shall meet the requirements of the following:
Table 3- Minimum PCS Functional Specifications
Description Requirements
Intended use Energy-Shifting
Project Power Rating 80 MW across power factor range of .95 lagging to .95 leading
without active power de-rating
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 517 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
18.0 POWER CONVERSION SYSTEM

Page 59

Reactive Capability Inverters shall be capable of operation between 0.8 lagging to
0.8 leading power factor with active power de-rating
Inverter Form Factor Central or distributed (rack / string) are acceptable.
Charging Method Constant Current / Constant Voltage
Discharging Method Constant Current
Design Life Component life 20 years.
Inverter Nominal Voltage Range, DC To be coordinated with Owner-furnished battery
Inverter Nominal Voltage, AC As selected by EPC
Warranty requirements Manufacturer Standard
Installation
Design Ambient See Section 2.0.
Design Humidity See Section 2.0.
Seismic Data See Section 2.0.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 518 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
19.0 Bi-Directional Inverters/ DC-DC Converters

Page 60
Bi-Directional Inverters/ DC-DC Converters
19.1 General
A. Operating in conjunction with the Site Controller, the PCS shall be able to operate in
all modes specified in Section 20.0.
B. Inverters/converters shall be of proven technology and shall have been installed in
similar applications for a minimum of one year. It is expected that PCS are sourced
from recognized manufacturers as listed in Attachment .
C. Inverters/converters shall have a design life of not less than 20 years and shall be
suitable for installation in an outdoor environment. It is expected that replacement
components will be readily available from the manufacturer for the design lifetime.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 519 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
20.0 SITE CONTROLLER

Page 61
SITE CONTROLLER
20.1 General
A. This section establishes the minimum functional specifications for the BESS Site
Controller.
B. The Site Controller shall coordinate with the PCS and BMS to perform the functions
specified in this section.
C. The Site Controller shall interface with the Owner’s remote dispatch system.
Contractor may coordinate revisions to the Owner’s existing SCADA remote
interface gateway or may furnish a new gateway. The remote interface gateway
shall be a SEL RTAC 3530 or equal. Communication with Owner’s remote dispatch
system shall utilize DNP3 Ethernet protocol.
D. The Site Controller shall aggregate the operation of the individual Power Conversion
Systems such that the BESS may be remotely operated as if a single asset. The Site
Controller shall include a data historian function able to store a minimum of 1
month of required BESS operating data locally. The Site Controller shall include a
local HMI station and shall be located in a separate control enclosure. .
E. The Site Controller hardware and application software shall be of proven technology
and shall have been installed in similar applications for a minimum of one year.
20.2 Operating Modes
A. At a minimum, the Site Controller shall provide the following BESS operating modes:
1. MESA)
. In the Direct Remote Control mode, the BESS responds directly
to signals from a remote dispatch system in the same way a conventional
dispatchable generation asset is controlled. Because a BESS is a bi-
directional generation asset, the remote dispatch system must provide a
real-time “signed” dispatch signal commanding the BESS to charge (negative
value), discharge (positive value), or remain idle (0) as necessary. The rate
of charge/discharge is determined by the magnitude of the dispatch signal.
Both the real power output (MW) and reactive power output (controllable
as power factor) may be adjusted; operating at power factors less than unity
reduce the BESS MW output rating to maintain inverter MVA within its
rating.
In this mode, the BESS relies upon the remote system to determine the
optimum operating mode of the BESS in consideration of real time price
signals, battery state-of-charge, and any upcoming scheduled operating
modes having higher priority.

2. -- Charging and
discharging direction and magnitude is controlled according to a fixed time
schedule. The local site controller shall store at least 20 user-defined
schedules, any of which may be selected locally or via SCADA command. For
each schedule, the user shall have the ability to set the time of day at which
the charge or discharge is to begin and desired charge or discharge rate vs.
time.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 520 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
20.0 SITE CONTROLLER

Page 62

3.-- The local site
controller shall contain a droop control function with adjustable
proportional gain (droop) and dead band settings. When Frequency Bias is
enabled, the present charge or discharge setting is biased by an amount
proportional to measured system frequency. For example, with the droop
controller set at 5%, a 5% drop in system frequency (3 Hz) would cause a
control bias of 100% of discharge rating (80 MW), assuming the battery is at
a sufficient state-of-charge. Frequency fluctuations within an adjustable
dead band range shall have no effect. The Frequency Bias mode can be
enabled or disabled, and when enabled shall operate concurrently with any
other active control mode.

4. --(need to discuss whether
the battery will be controlled directly by the remote dispatch system for this
mode or operate autonomously. If autonomously, the Frequency Bias mode
above would provide the same functionality. Another possibility is to add a
feature such that the amount of power and/or energy that the BESS provides
autonomously to support system frequency is limited (for example, limit
MW to xx% of rating, or limit the amount of discharged energy to xx% DOD.

5. --This function is intended to
decrease the rate of change and smooth the output of intermittent
generation resources. The BESS charges or discharges in proportion to the
error between the moving average generation and the instantaneous
generation at the POI, subject to an adjustable deadband. The degree of
response (gain) is Operator adjustable to allow matching the amount of
smoothing possible given the relative capacity of the battery based upon its
real time state of charge vs. the variation in intermittent generation.

6. – The BESS is used
to limit the rate of change of generation output from intermittent generation
resources. The BESS is operated at a selected nominal state of charge, such
that it can be charged to limit the “ramp up” and discharged to limit “ramp
down” rate of change in intermittent generation respectively. The
intermittent generation ramp rate is continuously calculated by comparing
the current intermittent generation against the previous 1-minute average
generation. If the intermittent generation ramp rate exceeds the setpoint
value, the controller commands the BESS to charge or discharge only as
required to limit the up or down ramp to the setpoint value. No action is
taken for intermittent generation ramp rates less than the setpoint value.
7. - The BESS
operates autonomously to maintain the substation bus voltage at setpoint by
adjusting the BESS power factor setting. Setpoint voltage and high/low
voltage dead band range are adjustable. The Voltage Regulation mode does
not have a direct control on the BESS MW setting and may be operated
simultaneously with other control modes. When the local AVR mode is
disabled, the BESS active and reactive power output are separately
controllable via SCADA dispatch commands within the BESS’s MVA rating
(Direct Remote Control function 9).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 521 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
20.0 SITE CONTROLLER

Page 63

20.3 SCADA Interface
20.3.1 Remote Control Interface
The BESS control system mode selection shall be possible locally via the site controller HMI or via
the remote SCADA system.
The Site Controller shall locally store the data points listed in Section 17.0, 2 at a collection
interval of once per second.
The Site Controller shall aggregate the rack / string level data listed in 2 and transmit to the
remote dispatch system via SCADA RTAC at a two second intervals.
The SCADA interface must be fully capable of communicating with all required Owner energy
management systems.
Full list of required SCADA control points and data points to be transmitted from/to remote
dispatch to be provided during detailed design.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 522 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
21.0 TELECOMMUNICATIONS AND NETWORK

Page 64
TELECOMMUNICATIONS AND NETWORK
21.1 General
A. Contractor’s scope includes design, equipment, and installation of a complete local
area network to allow monitoring of the BESS facility from a remote location.
B. System and subsystems provided by Contractor shall be designed and configured for
unmanned operation of the facility.
C. communication connections to the remote System Operator shall connect serially
via DNP 3.0 or Modbus TCP to the switchgear SEL-3530 (RTAC).
D. Network media internal to equipment enclosures may be implemented via
CAT 6 cables.
E. Terminations to equipment shall be made using pre-fabricated patch cables.
CAT 6 cables exiting equipment shall first terminate on a patch panel.
F. Fiber installed underground on the premises shall be installed in conduit.
Bends and risers extending above ground shall be metallic conduit.
G. Fiber installed in buildings or enclosures may be routed in inner-duct
supported in instrument and control trays.
H. Network communications leaving the project site shall be implemented using fiber
optic cable installed in HDPE or similar underground conduit following regional
practices for telecommunications installations.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 523 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
22.0 SUBMITTALS

Page 65
SUBMITTALS
22.1 General
A. This section defines the requirements for engineering design and vendor submittals.
B. Submittals shall be in English.
C. Contractor has sole responsibility to meet completion date requirements and to
supply material and equipment that conforms to Contract. Owner’s review does not
constitute a waiver of Owner rights with respect to nonconforming Work.
D. Contractor shall furnish expected document submittal list and schedule to Owner
within 60 days of award.
E. All design documents must use Owner drawing templates & follow all Owner
drawing standards.
22.2 Drawings
A. Project-specific drawings shall be submitted including the following information as
applicable:
1. Type
2. Ratings
3. Size
4. Quantities
5. Physical arrangement
6. Weights
7. Shipping breakdown / splits
8. Operation of components and systems
9. Materials and coatings
10. External connections
11. Interconnection with other services
12. Anchorages, supports and fastening
13. Installation and coordination with other equipment and materials.
22.3 Catalog Pages / Manufacturer Cut Sheets
A. Manufacturer catalog pages, i.e. cut sheets, are not an acceptable substitute for
engineering design documents, except for standard non-engineered products.
B. Catalog pages must be submitted with a cover page clearly indicating the tag
number and description of the item(s) covered by the catalog sheet.
C. If multiple components are shown on same page, the applicable line items shall be
clearly identified.
22.4 Formats and Quantities
A. Electronic copies of documents and drawings shall be in .PDF format.
B. Final, record copy of project-specific design drawings shall be submitted in .PDF and
native CAD format.
C. Contractor shall submit electronic copies plus one hard copy of the “
Construction”, drawings to Owner at the same time they are issued to the field.
“ documents and any subsequent revision shall be signed
and sealed by the engineer of record.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 524 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
22.0 SUBMITTALS

Page 66

D. Final “Conformed to Construction Record” (As-built) documents shall be provided to
Owner. These documents shall be sealed by the engineer of record; and shall be
considered the final record set. Each document issued “For Construction”, whether
any changes were made during construction or not; shall be revised and sealed for
the record set.
22.5 Operation and Maintenance Manuals
A. Prior to final acceptance, prepare and submit three hard copies and one editable
electronic file copies of the operations and maintenance manuals that adequately
describe the installed equipment and systems.
B. An initial draft of this manual shall be available for review and acceptance prior to
the start of testing and commissioning, in order that it may be used for that purpose.
C. As a minimum, such manuals shall include recommended procedures for operation,
maintenance, and inspection of the equipment; present pertinent safety
considerations; and provide descriptions of major systems, including major
equipment, normal operating parameters, and significant control logic.
22.6 Equipment Lists
A. Submit one electronic file of equipment lists, piping lists, valve lists, cable, circuit,
and raceway lists, and instrument lists.
B. Resubmit electronic file of any list as revisions are made and issue for construction.
C. Lists shall be electronic sortable data files in either MS-Excel or MS-Access formats.
22.7 Design Calculations
A. Engineering and design calculations prepared during the design are required as
submittals.
B. Such calculations include architectural, structural, civil, electrical, and mechanical.
22.8 Bid Submittal List
The contractor is asked to submit the following items with their bid
A. General outline drawing showing overall estimated size and configuration of the BESS
container
B. Description, manufacturer’s name, and standard descriptive literature for all major
BESS system components
C. List of components with lead times longer than 30 days that will be ordered and
shipped from another manufacturing facility for assembly in the final plant
D. List of origin of major components, factory manufactured or assembled
E. Location of factory providing the BESS container assembly
F. List of recommended spare parts
G. List of special and maintenance tools to be furnished
H. Supplier’s previous experience with proposed equipment
I. List of factory tests
J. Complete description of the extent of shop assembly of components
K. Battery cell data sheet (dimensions, weight, float, and charging voltages etc.)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 525 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
22.0 SUBMITTALS

Page 67

L. Description of any field assembly work required, including sectional shipments and
accessories shipped loose. Include an estimate of man-hours required to complete the
field assembly per container
M. Special storage requirements, if applicable
N. Subcontractor list, if applicable
O. Preliminary milestone schedule
P. Staggered shipping schedule, if applicable
Q. Current projected shop loading and shop capacity curves
R. Description of Owner overview, history, and qualifications
S. Project key team members and org chart
T. Information on bidders Information Security Program
U. Information on the Bidder’s Safety program
V. Information on the Bidder’s QA/QC program
W. Craft labor rate sheets
X. Financial information such as balance sheet, income statement, sales volume, etc.
Y. Itemized EPC budgetary cost estimate
Z. Overall Bill of Materials
AA. Details of continuing service contracts available to support BESS system after
installation
BB. Complete Datasheets provided below

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 526 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications
Exhibit A Attachments
XXX
Page 68

List of Attachments
Attachment A Contractor Data
Attachment B Approved Supplier List

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 527 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 1

Attachment A – Supplied Equipment and Contractor Fill-in Data
Provided for Information Only
Table 1- Vendor Supplied Data
Description Data Units
Aux Power Requirement per rack kW
Beginning of Life Number of Battery Racks each
Rack Dimensions ft, L x W x H each rack
Communication Methodology, BMS to Site
Controller
Provide Description
DC Roundtrip Efficiency @ 0.5C, BOL %, Roundtrip
DC Roundtrip Efficiency @ 0.5C, EOL %, Roundtrip
DC Roundtrip Efficiency @ 0.25C, BOL %, Roundtrip
DC Roundtrip Efficiency @ 0.25C, EOL %, Roundtrip
Cycle Life at 10% useable DOD Cycles
Cycle Life at 50% useable DOD Cycles
Cycle Life at 80% useable DOD Cycles
Cycle Life at 100% useable DOD Cycles
Capacity vs. C-Rate Provide Curve
Operating Temperature Range Deg. C
Storage Temperature Range Deg. C
Self-Discharge Rate %/month

Cell / Module Manufacturer
Model Number
Module / Tray Dimensions W x H x D, in (mm)
Module / Tray Weight Lb (kg)
Nominal Capacity Ah
Nominal Voltage V
Energy Wh
Operating Voltage Range V
Specific Energy Density (@ 1C, 25 deg C) Wh/lbs (Kg)
Chemistry
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 528 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 2

Table 1- Vendor Supplied Data
Description Data Units
Rack Mfg./Part/Configuration Number
Modules per Rack each
Number of Racks supplied each
Dimensions W x H x D, in (mm)
Weight Lbs (kg)
Voltage Operating Range V
Power, nominal W
Energy @ BOL kWhr
DC Short Circuit Current at rack disconnect A
Heat dissipation per rack @ C/2 kW
Heat dissipation per rack @ C/4 kW

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 529 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 3

Table 1- Vendor Supplied Data
Description Data Units
PCS Manufacturer N/A
Model Number N/A
Operating efficiency %
Standby power consumption watts
Auxiliary power supply requirements describe
AC Power @ 40C kVA / kW
Max AC Current Amps
Frequency Hz
Short term Overload capability describe
Short Circuit capability P.U.. Amps / mS
AC Voltage Volts
Current Harmonic Distortion (per IEEE
519)
%
Power Factor operating range Leading / Lagging
Isolating Provisions describe
Method of Connection to Inverter
Transformer
describe

DC Voltage Range Volts
Maximum DC Voltage Volts
Maximum DC continuous current Amps
Battery connection provisions describe
Isolating Provisions describe
Cabinet Dimensions W x D x H inches (mm)
Cabinet Weight Lbs (kg)
Cooling System describe
Cabinet Degree of Protection NEMA / IP
Permissible Ambient Temperature C
Permissible Humidity Range %
Noise Level dBA @ 3 feet
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 530 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 4

Table 1- Vendor Supplied Data
Description Data Units
Local HMI describe
PCS to BMS protocol describe
PCS to Site Controller Describe available options
Physical I/O Describe available options
Certifications
UL 1741 Yes/no
IEEE 1547 Yes/no
Other, list describe
Active / Reactive Power “D” Curve
Temperature De-rating Curve
Outline Drawing
List of Recommended Preventative Maintenance Inspections / schedule

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 531 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 5

-Up
Transformers
DESCRIPTION UNITS
Manufacturer n/a By manufacturer
Catalog/Serial No. n/a By manufacturer

Operating Frequency Hz 60
Capacity KVA XXXX
Cooling Class -KNAN
Design Base Temperature Measured by Thermometer Deg. C XX
Rise Temperature Measured by Thermometer Deg. C XX
Impedance @ nominal Voltage on Base Rating Z% X.XX%
X/R Ratio -By manufacturer
Bi-Directional Power Flow Y/N Y
Design Altitude Ft.Per Section

Guaranteed Efficiency:
@ 100% of Maximum MVA 65oC Rating % By manufacturer
@ 75% of Maximum MVA 65oC Rating % By manufacturer
@ 50% of Maximum MVA 65oC Rating % By manufacturer
Voltage Regulation @ 100% of MVA Rating:
@ Unity Power factor % By manufacturer
@ 80% lagging power factor % By manufacturer
@ 80% leading power factor % By manufacturer
Excitation Current @ 100% Rated Voltage, based on Max.
MVA 65oC Rating
% By manufacturer
Maximum Guaranteed Losses @ 100% Rated Voltage:
No Load Losses KW By Manufacturer
Load Loss Max. MVA 65oC Rating KW By Manufacturer
Auxiliary Losses at Max. MVA, and 65oC Rating KW 0
Total losses at Max. MVA; cannot exceed % 0.8
Loss Evaluation (By Owner) $/kW Proprietary

Winding Data:
Rated Voltage of HV Terminals (Nominal) KV XX.X
Rated Voltage of LV Terminals (At Full Load)V XXX, 3ph/3W
Basic Impulse Level HV Terminals KVBIL XXX KVBIL
Connection HV Terminals (2 cables per phase) Delta/wye XXX
Connection LV Terminals (9 cables per phase) Delta/wye XXX
HV Taps:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 532 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 6

-Up
Transformers
DESCRIPTION UNITS
No. of Steps Above Nominal Qty / % 2 @ + 2.5%
No. of Steps Below Nominal Qty / % 2 @ - 2.5%

Oil/Fluid – FM Approved Type Less Flammable
Fluid or Mineral Oil

Total Gallons of Fluid in System gal By manufacturer
Core and Coil Construction Type - By manufacturer
Type of Material Used in Coils - By manufacturer
Approximate Weights:
Fluid lbs. By manufacturer
Total Transformer With Fluid lbs. By manufacturer
Total Shipping Weight lbs. By manufacturer
Weight of Largest Piece for Handling lbs. By manufacturer
Method of Shipment - By manufacturer

Approximate Dimensions:
Overall Height in By manufacturer
Overall Width in By manufacturer
Overall Depth in By manufacturer

Loop or Radial System Design (Deadfront)- Loop/Deadfront

Standard Features and Accessories:
Nameplate -Y
Dial-type thermometer - Y
Liquid level gauge - Y
Pressure-vacuum gauge - Y
1 in drain valve with sample valve -Y
Pressure relief valve -Y
Non-PCB label - Y
1 in upper fill/filter press connection - Y
Options:
Surge Arrester-MOV Type Y/N N
High Voltage Switch; Under Oil w/ Window Y/N N
Primary Fuse Overcurrent Protection Y/N Y
Shielding Between HV and LV Windings Y/N Y
CTs on LV Bushings – Protection Class Y/N Y
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 533 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 7

-Up
Transformers
DESCRIPTION UNITS
Alarm Contacts for Temp, Liquid Level, and pressure and
vacuum gauges
Y/N Y
List any Special Considerations

System Power Flow will be such that transformer will
charge and discharge Energy Storage Batteries through
IGBT inverters with filters; meeting IEEE 1547
- Watt and Var Bi-
directional power
flow

List parts Requiring Field Assembly - By manufacturer
Required Maintenance Tools Furnished - By manufacturer

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 534 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments A
XXX
Page 8

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 535 of 1056
Idaho Power 2026 All Source RFP
Exhibit I – BESS Technical Specifications

Attachments B
XXX
Page 1

Attachment B - Approved Supplier List
EQUIPMENT MANUFACTURER
HV Circuit Breaker ABB, Alstom, Mitsubishi Electric, Siemens
MV Circuit Breaker ABB, Alstom, Mitsubishi Electric, Siemens
Power Transformers ABB, Ethosenergy, Fortune Elec., GE, Hico, Shihlin
Electric, Siemens
OHL Insulators Hubbell Power, MD Henry Lapp Insulators, Maclean
Power, MD Henry, NGK Locke
T-line Hardware Bekaert, Southeast Power
Steel T-line/Substation pole Trinity, Distran Steel, MD Henry, Meyer Utility,
Nello, Pelco, Southland Grid, Valmont
Electrical Equipment Enclosure Powell, ABB, ESS Metron,
Grounding Transformers GE Prolec, ABB
Lighting Crouse Hinds, Lithonia, Holophane, General Electric
Auxiliary Relays Allen-Bradley, Cutler-Hammer, General Electric
Protective Relays SEL, Basler, General Electric
Relay Panels Kemco, Norhtern Star, Electrical Power, Relay &
Power Systems
600V Cable American Wire Group, Belden, General Cable,
Kerite, Okonite, Southwire
Panelboards Cutler-Hammer, General Electric, Square-D, ABB
Cable Tray B-Line, MP Husky, Summit Elec.
Fiber Optic Cable Aria Tech, Belden, Cable Management, General
Cable, Norhtwire
MV Cable Aethna, American Wire Group, General Cable,
Kerite, Okonite, Southwire, USA Wire & Cable
Junction Boxes City Elec, Westburne Electric
Battery Energy Storage System ABB Inc., BYD, CATL, Sungrow, Dynapower,
Greensmith, Flexgen, LG Chem, Panasonic, Primus,
S&C Elec. Samsung SDI, Schneider, Samsung,
Sumitomo, Tesla, Tesvolt, Toshiba, Younicos
Inverters/ Converters Dynapower, Emerson, GE Energy, Schneider,
Siemens, SMA Solar Tech, Sungrow, Fronius.
Medium Voltage Switchgear ABB, Crown, Siemens, Eaton, Schneider Elec., GE,
ESSMetron, Powell
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 536 of 1056
Idaho Power 2026 All Source RFP
Exhibit J – Solar Technical Specifications

Internal Use Only
IDAHO POWER CO.SOLAR PV TECHNICAL SPECIFICATION

THIS GENERIC SPECIFICATION IS DESIGNED TO PROVIDE A BASIS FOR A VARIETY OF SOLAR PV
SYSTEMS (PV) APPLICATIONS AND MUST BE CUSTOMIZED FOR THE SPECIFIC PROJECT REQUIREMENTS
AND SITE CONDITIONS BY THE ENGINEER OF RECORD PRIOR TO FINALIZING THEIR DESIGN.
PREPARED FOR

Idaho Power Co.
28 JUNE 2021
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 537 of 1056
Idaho Power 2026 All Source RFP
Exhibit J – Solar Technical Specifications

Internal Use Only
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 538 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents i
Internal Use Only
Table of Contents
1.0 General 1-1
1.1 Description ....................................................................................................................................................... 1-1
1.1.1 Defined Terms ............................................................................................................................... 1-1
1.1.2 Description of Facility ................................................................................................................ 1-2
1.2 General Requirements ................................................................................................................................. 1-3
1.2.1 Codes and Standards .................................................................................................................. 1-3
1.2.2 Equipment ....................................................................................................................................... 1-5
1.3 Contractor’s Scope of Work ....................................................................................................................... 1-6
1.3.1 Owner-Furnished Equipment ................................................................................................. 1-8
1.3.2 Permitting ....................................................................................................................................... 1-8
1.3.3 Engineering Drawings and Specifications ......................................................................... 1-8
1.3.4 Project Control Submittals ..................................................................................................... 1-11
1.3.5 Engineering Submittals ........................................................................................................... 1-11
1.3.6 Engineering Completion.......................................................................................................... 1-12
1.3.7 Quality Assurance ...................................................................................................................... 1-14
1.3.8 Delivery Storage and Handling ............................................................................................. 1-14
1.3.9 Required Manufacturer’s Warranties ................................................................................ 1-16
1.3.10 Miscellaneous .............................................................................................................................. 1-16
1.4 General Installation Requirements ...................................................................................................... 1-16
1.4.1 Construction Management ..................................................................................................... 1-17
1.4.2 Project Closeout Procedure ................................................................................................... 1-18
1.4.3 Temporary Utilities ................................................................................................................... 1-18
1.4.4 Site Security and Access .......................................................................................................... 1-19
1.4.5 As-Built Drawings ...................................................................................................................... 1-20
1.4.6 Electrical Equipment Installation ........................................................................................ 1-20
1.5 Interconnection Requirements .............................................................................................................. 1-20
1.6 Acronyms and Abbreviations Reference Technical ....................................................................... 1-21
1.7 Submittals and Documentation ............................................................................................................. 1-24
1.7.1 General Information.................................................................................................................. 1-24
1.7.2 Submittals ..................................................................................................................................... 1-27
1.7.3 Miscellaneous Submittals ....................................................................................................... 1-32
1.7.4 Submittal Drawing and Data Requirements ................................................................... 1-33
1.7.5 Submittal Document Review ................................................................................................. 1-35
1.7.6 Operating Manuals .................................................................................................................... 1-36
1.7.7 Job Books ....................................................................................................................................... 1-37
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 539 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents ii
Internal Use Only
1.7.8 Record Drawings........................................................................................................................1-37
1.8 Environmental Conditions ....................................................................................................................... 1-38
1.9 Schedule, Meetings, and Progress Reports ....................................................................................... 1-39
1.10 Request for Information ........................................................................................................................... 1-41
1.11 Health and Safety Plan ............................................................................................................................... 1-42
1.12 Environmental Plan .................................................................................................................................... 1-42
2.0 ...........................................................................................................................................2-1
2.1 Civil, Structural, and Architectural Design and Equipment Requirements ........................... 2-1
2.1.1 General ............................................................................................................................................. 2-1
2.1.2 Wind Loads ..................................................................................................................................... 2-1
2.1.3 Seismic Loads................................................................................................................................. 2-2
2.1.4 Factors of Safety ........................................................................................................................... 2-2
2.2 Hydrology.......................................................................................................................................................... 2-2
2.2.1 Earthwork ....................................................................................................................................... 2-3
2.2.2 Geotechnical Report .................................................................................................................... 2-3
2.2.3 Roads, Parking Lots, and other Surfacing .......................................................................... 2-5
2.2.4 Solar Field Fencing and Signage............................................................................................. 2-7
2.2.5 Hazard Warning Labels ............................................................................................................ 2-8
2.2.6 Foundation for Equipment and Structures ....................................................................... 2-9
2.2.7 Module Mounting System ....................................................................................................... 2-10
2.2.8 Concrete Work ............................................................................................................................ 2-12
2.2.9 Steel Work ..................................................................................................................................... 2-13
2.2.10 General Structural Welding ................................................................................................... 2-13
2.2.11 Painting and Coatings ............................................................................................................... 2-14
2.3 Civil, Structural and Architectural Installation Requirements ................................................. 2-15
2.3.1 Site Development and Earthwork ....................................................................................... 2-15
2.3.2 Clearing and Grubbing ............................................................................................................. 2-15
2.3.3 Disposal of Unusable Soils ...................................................................................................... 2-15
2.3.4 Erosion Control ........................................................................................................................... 2-16
2.3.5 Dust Control ................................................................................................................................. 2-16
2.3.6 Existing Underground Facilities........................................................................................... 2-16
2.3.7 Excavation ..................................................................................................................................... 2-16
2.3.8 Grading ........................................................................................................................................... 2-17
2.3.9 Fill ..................................................................................................................................................... 2-17
2.3.10 Compaction ................................................................................................................................... 2-18
2.3.11 Site Restoration .......................................................................................................................... 2-19
2.4 Testing and Inspections ............................................................................................................................ 2-19
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 540 of 1056
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IDAHO POWER CO.
| Table of Contents iii
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3.0 ......................................................................................................................................3-1
3.1 General Requirements ................................................................................................................................. 3-1
3.1.1 Facility Operating Noise Level Requirements .................................................................. 3-1
3.1.2 Equipment Certifications .......................................................................................................... 3-1
3.1.3 Solar PV Field ................................................................................................................................. 3-1
3.2 Major Equipment Requirement ............................................................................................................... 3-2
3.2.1 Photovoltaic Modules ................................................................................................................. 3-2
3.2.2 Required Manufacturer’s Warranties .................................................................................. 3-4
3.2.3 Required Spare Parts .................................................................................................................. 3-4
3.2.4 PV Module Mounting System .................................................................................................. 3-4
3.2.5 Required Manufacturer’s Warranties .................................................................................. 3-6
3.2.6 Required Spare Parts .................................................................................................................. 3-6
3.2.7 Combiner Boxes ............................................................................................................................ 3-6
3.2.8 Required Manufacturer’s Warranties .................................................................................. 3-7
3.2.9 Required Spare Parts .................................................................................................................. 3-8
3.2.10 Recombiner Boxes ....................................................................................................................... 3-8
3.2.11 Required Manufacturer’s Warranties .................................................................................. 3-8
3.2.12 Required Spare Parts .................................................................................................................. 3-8
3.2.13 Solar PV Inverters ........................................................................................................................ 3-8
3.2.14 Required Manufacturer’s Warranties ................................................................................ 3-10
3.2.15 Required Spare Parts ................................................................................................................ 3-10
3.3 Installation Requirements........................................................................................................................ 3-11
3.3.1 Photovoltaic Modules ............................................................................................................... 3-11
3.3.2 PV Module Mounting System ................................................................................................ 3-11
3.3.3 Recombiner and Combiner Box ........................................................................................... 3-11
3.3.4 Solar PV Inverters...................................................................................................................... 3-12
4.0 ......................................................................................................................................4-1
4.1 Electrical Design and Equipment Requirements .............................................................................. 4-1
4.1.1 Inverter AC Disconnect Switches .......................................................................................... 4-1
4.1.2 Junction Boxes ............................................................................................................................... 4-1
4.1.3 Concrete Pull Boxes ..................................................................................................................... 4-2
4.1.4 Low Voltage Dry-Type Transformers .................................................................................. 4-2
4.1.5 Low Voltage Panelboards ......................................................................................................... 4-2
4.1.6 Medium Voltage, Pad-Mounted Transformers ................................................................ 4-3
4.1.7 Medium Voltage Switchgear .................................................................................................... 4-6
4.1.8 Lightning Protection ................................................................................................................. 4-12
4.1.9 Raceways ....................................................................................................................................... 4-13
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 541 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents iv
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4.1.10 Conduit...........................................................................................................................................4-13
4.1.11 Grounding Systems ................................................................................................................... 4-14
4.1.12 Power and Control Wiring...................................................................................................... 4-15
4.1.13 GFCI Receptacles ........................................................................................................................ 4-18
4.1.14 Light Switches ............................................................................................................................. 4-19
4.1.15 Site Lighting .................................................................................................................................. 4-19
4.2 Installation Requirements........................................................................................................................ 4-20
4.2.1 Lightning Protection ................................................................................................................. 4-20
4.2.2 Raceways ....................................................................................................................................... 4-20
4.2.3 Grounding Systems ................................................................................................................... 4-21
4.2.4 Power and Control Cabling .................................................................................................... 4-23
4.2.5 Site Lighting .................................................................................................................................. 4-28
4.2.6 Low Voltage Dry-Type Transformer .................................................................................. 4-28
4.2.7 Low Voltage Panelboards ....................................................................................................... 4-29
4.2.8 Medium Voltage Pad-Mounted Transformers ............................................................... 4-29
4.2.9 Medium Voltage Switchgear .................................................................................................. 4-29
4.2.10 GFCI Receptacles ........................................................................................................................ 4-30
4.2.11 Light Switches ............................................................................................................................. 4-30
4.2.12 Disconnect Switches ................................................................................................................. 4-30
4.2.13 Equipment Location Tolerances .......................................................................................... 4-30
4.2.14 Alignment ...................................................................................................................................... 4-31
4.2.15 Bolted Electrical Connections ............................................................................................... 4-31
4.2.16 Equipment Finishes .................................................................................................................. 4-31
4.3 Equipment Testing ...................................................................................................................................... 4-32
4.3.1 Ground System Testing ............................................................................................................ 4-32
4.3.2 Electrical Testing ........................................................................................................................ 4-32
4.3.3 Testing ............................................................................................................................................ 4-33
5.0 ...............................................................................................................5-1
5.1 General ............................................................................................................................................................... 5-1
5.2 Design and Installation Requirements .................................................................................................. 5-1
5.2.1 Codes and Standards .................................................................................................................. 5-1
5.2.2 Arrangement .................................................................................................................................. 5-2
5.2.3 System Voltage .............................................................................................................................. 5-2
5.2.4 Electrical Clearances ................................................................................................................... 5-2
5.2.5 Noise Study ..................................................................................................................................... 5-2
5.3 Equipment and Materials ........................................................................................................................... 5-2
5.3.1 Bus Conductors and Fittings ................................................................................................... 5-2
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 542 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents v
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5.3.2 Main Power Transformer......................................................................................................... 5-2
5.3.3 HV Circuit Breakers ..................................................................................................................... 5-3
5.3.4 HV Disconnect Switches ............................................................................................................ 5-3
5.3.5 High Voltage (HV) and Medium Voltage (MV) Surge Arresters ................................ 5-3
5.3.6 MV Circuit Breakers .................................................................................................................... 5-3
5.3.7 MV Disconnect Switches ........................................................................................................... 5-4
5.3.8 Instrument Transformers ......................................................................................................... 5-4
5.3.9 Switchboards ................................................................................................................................. 5-5
5.3.10 Metering ........................................................................................................................................... 5-5
5.3.11 Reactive Power Compensation and MV Capacitor/Reactor Banks (If Needed) . 5-5
5.4 Auxiliary Power .............................................................................................................................................. 5-5
5.4.1 DC and AC Systems ...................................................................................................................... 5-5
5.4.2 Station Batteries and Charger ................................................................................................. 5-6
5.4.3 Grounding........................................................................................................................................ 5-6
5.4.4 Lightning Protection ................................................................................................................... 5-8
5.4.5 Lighting ............................................................................................................................................ 5-8
5.4.6 Security............................................................................................................................................. 5-8
5.4.7 Operating and Maintenance..................................................................................................... 5-8
5.5 Substation Civil/Structural Design Criteria ........................................................................................ 5-9
5.5.1 General ............................................................................................................................................. 5-9
5.5.2 Civil .................................................................................................................................................... 5-9
5.5.3 Structures ........................................................................................................................................ 5-9
5.5.4 Foundations .................................................................................................................................... 5-9
5.5.5 Substation Fencing .................................................................................................................... 5-10
5.5.6 Raceway ......................................................................................................................................... 5-10
5.5.7 Drainage ......................................................................................................................................... 5-10
5.5.8 Collection System Substation Vehicle Access (Outside Substation Fence) ........ 5-11
5.5.9 Restoration and Landscaping ............................................................................................... 5-11
5.6 Collection System Substation Control Building ............................................................................... 5-11
5.6.1 Design and Construction ......................................................................................................... 5-11
5.7 Collection System Substation Protection and Control .................................................................. 5-12
5.7.1 General ........................................................................................................................................... 5-12
5.7.2 HV Breaker and HV/MV Main Power Transformer Protection .............................. 5-13
5.7.3 MV Bus Protection ..................................................................................................................... 5-13
5.7.4 MV Switchgear Protection ...................................................................................................... 5-13
5.7.5 MV Collector Circuit Protection ........................................................................................... 5-13
5.7.6 MV Capacitor Protection ......................................................................................................... 5-14
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 543 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents vi
Internal Use Only
5.7.7 Capacitor Bank Control............................................................................................................5-14
5.7.8 Interconnection Protection .................................................................................................... 5-14
5.7.9 Wiring ............................................................................................................................................. 5-15
5.7.10 Control Panels ............................................................................................................................. 5-15
5.7.11 Relays .............................................................................................................................................. 5-16
5.7.12 Communications ......................................................................................................................... 5-16
5.8 Collection System Substation Bus, Switch and Equipment Nomenclature System .......... 5-17
5.9 Submittal Requirements ........................................................................................................................... 5-17
5.10 Testing .............................................................................................................................................................. 5-19
5.10.1 General ........................................................................................................................................... 5-19
5.10.2 General Testing and Commissioning ................................................................................. 5-20
5.10.3 Transformers Over 600V ........................................................................................................ 5-20
5.10.4 Circuit Breakers Over 600V ................................................................................................... 5-21
5.10.5 Switches Over 600V .................................................................................................................. 5-21
5.10.6 Station Bus Systems .................................................................................................................. 5-21
5.10.7 Protective Relays ........................................................................................................................ 5-21
5.10.8 Station Control Wiring ............................................................................................................. 5-21
5.10.9 Grounding...................................................................................................................................... 5-22
5.10.10 NERC Protection System Testing ......................................................................................... 5-22
5.10.11 Maintenance and Testing ........................................................................................................ 5-22
6.0 ............................................................................................................................................6-1
6.1 General ............................................................................................................................................................... 6-1
6.1.1 Contractor Scope of Work ........................................................................................................ 6-1
6.1.2 General Design Philosophy ...................................................................................................... 6-1
6.1.3 System Layout............................................................................................................................... 6-1
6.1.4 SCADA Integration ....................................................................................................................... 6-1
6.2 Telephone and Telecommunications System..................................................................................... 6-2
6.2.1 Communications Requirements ............................................................................................ 6-2
6.3 SCADA System Scope .................................................................................................................................... 6-2
6.3.1 PV Module Supplier SCADA System ..................................................................................... 6-2
6.3.2 Telemetry, Disturbance Monitoring and Substation SCADA System ...................... 6-3
6.3.3 Substation Communication System Design ....................................................................... 6-6
6.3.4 SCADA Points Lists ...................................................................................................................... 6-6
6.3.5 Substation Device Configuration ........................................................................................... 6-6
6.3.6 Material Specification ................................................................................................................. 6-7
6.3.7 Procurement, Installation and Implementation .............................................................. 6-7
6.3.8 Commissioning .............................................................................................................................. 6-7
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 544 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents vii
Internal Use Only
6.4 Fiber Optic Network Design...................................................................................................................... 6-7
6.4.1 Design Requirements ................................................................................................................. 6-7
6.4.2 Fiber Optic Splice and Distribution Panel Details........................................................... 6-8
6.5 Fiber Optic Installation ................................................................................................................................ 6-8
6.5.1 General Installation ..................................................................................................................... 6-8
6.5.2 Fiber Terminations ...................................................................................................................... 6-8
7.0 ................................................................................................................................7-1
7.1 General ............................................................................................................................................................... 7-1
7.1.1 Definitions ....................................................................................................................................... 7-1
7.1.2 General Specifications ................................................................................................................ 7-1
7.1.3 Contractor Design Deliverables ............................................................................................. 7-3
7.1.4 Owner Provided Facilities and Services ............................................................................. 7-5
7.1.5 Codes, Regulations, and Standards ....................................................................................... 7-5
7.2 Generator Lead Line Material and Design Criteria .......................................................................... 7-6
7.2.1 General Requirements ............................................................................................................... 7-6
7.2.2 Generator Lead Line Design Criteria .................................................................................... 7-7
7.2.3 Design Requirements ................................................................................................................. 7-7
7.2.4 Structure Types and Configurations .................................................................................... 7-9
7.2.5 Generator Lead Line Foundation Design .......................................................................... 7-10
7.2.6 Material .......................................................................................................................................... 7-10
7.3 Generator Lead Line Site Requirements ............................................................................................ 7-12
7.3.1 Site and Environmental Criteria .......................................................................................... 7-12
7.3.2 Fire Water during Construction/Fire Protection ......................................................... 7-12
7.3.3 Environmental Compliance ................................................................................................... 7-13
7.3.4 Preserved Areas .......................................................................................................................... 7-13
7.3.5 Site Access ..................................................................................................................................... 7-13
7.3.6 Site Management ........................................................................................................................ 7-14
7.3.7 SWPP Plan ..................................................................................................................................... 7-14
7.3.8 Unloading and Staging ............................................................................................................. 7-14
7.3.9 Site Facilities ................................................................................................................................ 7-14
7.3.10 Cleanup ........................................................................................................................................... 7-14
7.3.11 Site Restoration .......................................................................................................................... 7-15
7.3.12 Trenches/Excavations ............................................................................................................. 7-15
7.3.13 Equipment Condition ............................................................................................................... 7-15
7.3.14 Fuel Storage .................................................................................................................................. 7-15
7.3.15 Equipment Leaks and Spills ................................................................................................... 7-16
7.3.16 Work or Travel Violations of Marked Boundaries ....................................................... 7-16
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 545 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents viii
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7.3.17 Recycling........................................................................................................................................7-16
7.3.18 Site Connectivity and Communications ............................................................................ 7-16
7.3.19 Transportation ............................................................................................................................ 7-17
7.3.20 Lighting .......................................................................................................................................... 7-17
7.3.21 Water ............................................................................................................................................... 7-17
7.3.22 Dust Control/Non-Potable Water for Construction ..................................................... 7-17
7.4 Construction................................................................................................................................................... 7-17
7.4.1 General ........................................................................................................................................... 7-17
7.4.2 Surveying ....................................................................................................................................... 7-18
7.4.3 Access .............................................................................................................................................. 7-19
7.4.4 Outages ........................................................................................................................................... 7-19
7.4.5 Temporary Power ...................................................................................................................... 7-19
7.5 Close Out .......................................................................................................................................................... 7-19
8.0 Commissioning..........................................................................................................................................8-1
8.1 Commissioning Requirements ................................................................................................................. 8-1
8.1.1 General Requirements ............................................................................................................... 8-1
8.1.2 Testing Requirements ................................................................................................................ 8-2
8.1.3 Testing Conditions ....................................................................................................................... 8-3
8.1.4 Calculations .................................................................................................................................... 8-3
8.1.5 Required Inspections, Tests and Verifications................................................................. 8-3
8.1.6 Commissioning Report Requirements .............................................................................. 8-16
9.0 ...............................................................................................................................9-1
9.1 Functional Test ............................................................................................................................................... 9-1
9.2 Short Term Performance Ratio Test ...................................................................................................... 9-1
9.2.1 Purpose ............................................................................................................................................ 9-1
9.2.2 Measurement Requirements ................................................................................................... 9-2
9.2.3 Test Period ...................................................................................................................................... 9-3
9.2.4 Calculation of Expected Performance Ratio ...................................................................... 9-4
9.2.5 Calculation of Measured Performance Ratio .................................................................... 9-7
9.2.6 Performance Ratio Test ............................................................................................................. 9-8
9.2.7 Reporting Requirements ........................................................................................................... 9-9
9.3 One Year Adjusted Energy Test ............................................................................................................... 9-9
9.3.1 Purpose ............................................................................................................................................ 9-9
9.3.2 Measurement Requirements ................................................................................................... 9-9
9.3.3 Test Period .................................................................................................................................... 9-12
9.3.4 Adjusted Energy Calculation ................................................................................................. 9-13
9.3.5 Adjusted Energy Test ............................................................................................................... 9-15
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 546 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
IDAHO POWER CO.
| Table of Contents ix
Internal Use Only
9.3.6 Reporting Requirements.........................................................................................................9-15
9.4 Short Term Capacity Test ........................................................................................................................ 9-15
9.4.1 Purpose .......................................................................................................................................... 9-15
9.4.2 Measurement Requirements ................................................................................................. 9-16
9.4.3 Test Period .................................................................................................................................... 9-18
9.4.4 Determination the Reporting Conditions (RC) .............................................................. 9-18
9.4.5 Determination of Expected Capacity.................................................................................. 9-20
9.4.6 Measured Capacity .................................................................................................................... 9-21
9.4.7 Capacity Test ................................................................................................................................ 9-21
9.4.8 Reporting Requirements ......................................................................................................... 9-22
.......................................................................................9-24

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 547 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-1
Internal Use Only
1.0 General
1.1 DESCRIPTION
This Technical Specification (Specification) sets forth Owner technical requirements for the design,
procurement, and construction of a complete, fully functional, and operational solar photovoltaic
(PV) facility that is in full compliance with Owner requirements, project Interconnection
Agreement, project Power Purchase Agreement, applicable codes, standards, laws and regulations;
and when completed can perform in accordance with the requirements to be set forth in the
Contract to which this Specification is attached.
1.1.1 Defined Terms
The terms below used in this Specification shall have the following meanings:
Contractor shall mean – the party with whom Owner executes the Contract.
The Contract shall mean – the Contract between Owner and Contractor for Contractor to
construct the Facility.
shall mean – the date upon the codes or standards considered to take
effect,
The Facility shall mean – the solar PV generating facility and project substation (if
applicable) described in this Specification
shall mean – the State of Idaho Division Electrical Specialty Code
shall mean – Idaho Power Company
Owner shall mean – Idaho Power Company
shall mean – Owner’s designated representatives and affiliates
shall mean – one or more point(s) between the last
transformation and POI
shall mean – the primary side of the interconnection
breaker provided by Idaho Power located at Project Site
Specification shall mean – this Technical Specification document
shall mean – the system impact study performed by the
Transmission Provider for the Facility.
shall mean – Idaho Power Company is the owner of transmission
line that Facility interconnects to.]
shall mean – the latest revision of the local utility
Requirements
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 548 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-2
Internal Use Only
1.1.2 Description of Facility
The Facility shall be a grid interactive solar PV power generating facility located at Owner’s
project Site.
Contractor shall ensure that the execution of the Facility and its Interconnection will be
completed per the terms set forth in Owner’s Project Schedule.
The Facility shall have a nameplate AC Capacity of up to 80 MWac.
The Facility shall interconnect to the grid at the POI.
The Facility shall interconnect to the POI in accordance with all applicable requirements set
forth in the Section 1.5 Interconnection Requirements and approved by Owner.
The interconnection voltage shall be as set forth in Section 1.5 Interconnection Requirements.
The energy production Facility shall be metered at the specified POM.
The Facility shall be designed to operate autonomously and capable of delivering electrical
power to the POI whenever sufficient sunlight is available.
The Facility shall be designed to be controlled and monitored remotely.
The Facility shall include any or all of the following as defined in the project contract:
1. Earthworks, civil engineering structures, and roadways
2. Site lighting and security systems
3. PV modules
4. Tracking PV module mounting system
5. Solar PV inverters
6. Isolation transformers, if required
7. Medium voltage step-up transformer(s)
8. Main step-up transformer(s), if required]
9. Interconnection Package
10. DC cabling, AC cabling, control cabling, conduits, and raceways
11. DC combiners, disconnect switch and recombiners
a. As an option for Owner’s selection, all recombiners shall include electrical
monitoring on each input port]
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 549 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-3
Internal Use Only
b. Recombiner monitoring functions shall be connected to the SCADA System of
the Facility.
12. An interconnection to the POI
13. A Supervisory Control And Data Acquisition (SCADA) system
14. Meteorological Monitoring Station(s)
15. Voice and data connectivity
16. Communications cabling and hardware
17. Storage facility, if applicable
18. Site fence
19. Signage
20. Switchgear/Switchboard
21. All fixtures required for a complete and operational Facility compliant with this
Specification
1.2 GENERAL REQUIREMENTS
Work performed under the Contract shall be performed in accordance with all of the
requirements set forth therein, and:
1. All applicable codes and standards
2. All requirements set forth in this Specification
3. Industry-standard engineering and quality assurance practices
The Facility shall be designed for a 30 year operating life based on normal operation, and the
performance of maintenance, repairs, and the replacement of parts according to
manufacturers’ recommendations and standard industry practices.
1.2.1 Codes and Standards
The codes and standards applicable to the work performed under the Contract shall include
any or all of the following. It is incumbent upon the contractor to be knowledgeable of and
implement all applicable codes and standards:
1. MIOSHA Standards
2. Local building codes and amendments
3. Local energy codes and amendments
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 550 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-4
Internal Use Only
4. Local Electric Utility requirements
5. Transmission Provider interconnection requirements
6. Federal, State, and Local environmental protection agency rules and regulations
7. State and Local soil erosion and sediment control regulations
8. Federal, State, County and Local Authorities Having Jurisdiction (AHJ) requirements.
9. United States Code of Federal Regulations (CFR)
10. Occupational Safety and Health Administration (OSHA)
11. Idaho Building Code (IBC)
12. National Fire Protection Association (NFPA)
13. International Fire Code (IFC)
14. National Electrical Code (NEC)
15. National Electrical Safety Code (NESC)
16. Underwriters Laboratories Inc. (UL)
17. National Electrical Manufacturer's Association (NEMA)
18. InterNational Electrical Testing Association Inc. (NETA)
19. Aluminum Association (AA)
20. American Association of State Highway and Transportation Officials (AASHTO)
21. American Concrete Institute (ACI)
22. American Institute of Steel Construction (AISC)
23. American Society of Mechanical Engineers (ASME)
24. American Society for Nondestructive Testing (ASNT)
25. American Society for Testing and Materials (ASTM)
26. American National Standards Institute (ANSI)
27. American Railway Engineering and Maintenance Association (AREMA)
28. American Society of Civil Engineers (ASCE)
29. American Welding Society (AWS)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 551 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-5
Internal Use Only
30. Association of Iron and Steel Engineers (AISE)
31. Concrete Reinforce Steel Institute (CRSI)
32. Environmental Protection Agency (EPA)
33. Institute of Electrical and Electronics Engineers (IEEE)
34. Insulated Cable Engineers Association (ICEA)
35. International Electrotechnical Commission (IEC)
36. Instrumentation Society of America (ISA)
37. The International Organization for Standardization (ISO)
38. National Association of Corrosion Engineers (NACE)
39. Nation Environmental Balancing Bureau (NEBB)
40. North American Electric Reliability Council (NERC)
41. Structural Steel Painting Council (SSPC)
Unless otherwise specified, the applicable governing edition and addenda to be used for all
references to codes or standards specified herein shall be interpreted to be the
jurisdictionally approved edition and addenda.
If a code or standard is not jurisdictionally mandated, then the current edition and addenda in
effect on the Effective Date shall apply.
The referenced codes and standards shall govern the minimum standards for the work.
If an Owner’s requirement is in conflict with the requirements in the applicable codes and
standards, it shall be brought to the Owner’s attention using request for information (RFI) to
resolve.
Contractor shall provide document and evidence to prove that the design and PV plant facility
is NERC compliance.
1.2.2 Equipment
All equipment shall be new and unused when procured by the Contractor, undamaged at the
time of Substantial Completion, and manufactured by reputable manufacturers with
experience in the manufacture of the particular Equipment supplied by them.
All equipment shall be installed in a neat and workmanlike manner with adequate staying,
bracing, and anchoring.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 552 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-6
Internal Use Only
Original OEM warranty shall be actionable for the owner, following close of development
(COD)
Contractor shall use calibrated and verified equipment. Contractor shall maintain records and
shall provide to Owner upon request.
1.3 CONTRACTOR’S SCOPE OF WORK
Contractor’s scope of work shall include:
1. Project management, including but not limited to:
a. Host daily meetings to discuss status of tasks with subcontractor.
b. Prepare, review and monitor time schedules and milestone dates established by
Contractor. This shall be done on a weekly basis.
c. Host weekly meetings to discuss status of tasks with Owner.
d. Prepare and review shop drawings, documents and reports as appropriate.
e. Prepare and submit Requests for Information and submittals if questions or
conflicts arise.
f. Contactor request to Owner for design changes shall be completed in a timely
manner per the Contract.
g. Witness vendor tests of major equipment.
h. Daily Safety Meeting during construction (JSA)
2. Obtaining topographical surveys of the Site that meets the owner’s requirements
regarding content, layout, and scale.
3. Land acquisition
4. Rights of way
5. Design engineering, engineering calculations and studies, as specified in Section 1.3.4.
6. Site preparation, including grubbing, grading and drainage, which meets owner’s storm
requirement.
7. Obtaining required building, construction and other permits
a. Existing permits may require modification by Contractor to reflect the design
specified by Contractor
8. Procurement of equipment and materials
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 553 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-7
Internal Use Only
a. Inverter, Pad-mount Transformers and Skid 1
b. SCADA System
c. PV Modules
d. PV Mounting Systems
e. Main step-up transformer(s), as required
f. MV switchgear, if required
g. Meteorological Monitoring Station(s)
h. All ancillary equipment necessary to operate the PV facility
9. Construction of the Facility, project management and construction management,
including but not limited to:
a. Receipt and secure storage of all procured equipment and materials
b. Procuring construction consumables, including power and water
c. Machinery and tools
d. Labor and labor management
e. Transportation
f. Removal of construction debris and other rubbish
10. Commissioning of the Facility
11. Acceptance testing of the Facility
12. Project closeout
13. Complete training and instruction of Owner’s personnel in the operation, maintenance
and repair of all equipment and systems in the Facility
14. Warranty service
Contractor shall cooperate with Owner and Owner’s representatives.
Owner and Owner’s representatives shall be provided with unrestrained opportunity to
monitor Contractor’s work.
1 [Reference datasheets or other relevant information pertaining to this equipment.]
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 554 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-8
Internal Use Only
Contractor shall coordinate its actions and cooperate with other contractors, Owner and
Owner's representatives, the Local Electric Utility and local permitting agencies.
Contractor shall include licensed Professional Engineer (State of Idaho) personnel in the
design and installation team.
1.3.1 Owner-Furnished Equipment
Owner responsible for all hardware up to the primary (low voltage side) of the breaker at the
POI
1.3.2 Permitting
Contractor shall be responsible for obtaining and expediting, as necessary, all permits and all
permit modifications, as applicable.
No construction, including disturbing soils or vegetation, shall be allowed on Site without the
issuance of approved permits by the permitting agencies or approval from Owner.
Contractor shall be responsible for submittal of all necessary drawings and calculations to the
AHJ for the purpose of obtaining construction Permit approval.
Prior to or in parallel with such submission, Contractor shall provide Owner with complete
sets of all documents intended for inclusion in the submission.
To the extent required by applicable agencies, Contractor shall provide access to an
archeologist approved by the responsible agency to address any concerns regarding historic
preservation.
1.3.3 Engineering Drawings and Specifications
An up-to-date printable index listing all previously issued Contractor drawings and
specifications by number and title, showing the revision status of each drawing, shall be
maintained and shall be available to Owner at all times.
Contractor shall provide an internet-accessible secure file share service that contains all
drawings and specifications and be made available to Owner at all times.
Contractor shall develop a Design Package with Idaho registered Professional Engineer sealed
drawings for the Project containing the following. The package may be submitted in stages as
agreed to with the Owner:
1. Index
2. General notes and symbols
3. Electrical specifications
4. Circuit and raceway list
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 555 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-9
Internal Use Only
5. Equipment schedule
6. Equipment datasheets
7. Major subcontractor equipment drawings
8. Site arrangement drawings
9. Module, inverter, combiner and recombiner location & identification number maps
10. Inverter plans and details
11. Module mounting system plans, Details, and Structural Calculations
12. Pre-engineered building plans and details, as applicable
13. Substation Control Building plans and details
14. Foundation plans and details
15. Fencing, gate, signage, grounding, and label details
16. Road plans and profiles, as applicable
17. Electrical one-line diagrams, both AC and DC, including all voltage.
18. Switchgear plans and elevations, as applicable
19. Switchgear elementary diagrams, as applicable
20. Protective relay calibration tests
21. One-Line and Three-Line system diagrams
22. Trenching drawings, with both in-plan and cross-section views
23. Grounding plans and details
24. Lighting plans and details
25. Lightning protection plans and details
26. Security infrastructure of electrical equipment, hardware and software
27. Fire alarm & detection drawings, as applicable
28. SCADA communication block diagram
29. SCADA point list and index of vendor drawings
30. Factory test reports on new equipment
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 556 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-10
Internal Use Only
31. Manufacturer field service reports
32. Instrument list
33. Installation details
34. Calculations
a. AC/DC Cable sizing calculations
b. AC/DC Cable total loss calculations
c. Conduit sizing calculations
d. AC/DC Load calculations
e. Voltage drop calculations
f. Short circuit calculations and labels
g. Overcurrent device coordination
h. Grounding study, if applicable
i. HVAC calculations, if applicable
j. Structural calculations
35. Civil Studies (Studies shall be in accordance with AHJ and additionally the Civil &
Structural: Section 2.0, if the study is specified in Section 2.0)
a. Surveys (geotechnical, topographic, recordable easement exhibit, other)
b. Grading plans & hydrology study, if applicable
c. Utility investigation and identify property easements, if applicable
d. Erosion control plans, if applicable
e. Storm Water Pollution Prevention Plan (SWPPP), if applicable
f. Road and railroad crossing plans for underground or overhead transmission line
crossings of public and private Right-of-way, if applicable
g. Offsite road improvement plans, if applicable
h. Utility improvement plans, if applicable
36. Noise-level Study
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 557 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-11
Internal Use Only
37. Glare/FAA study
38. Shading study
39. Engineering drawing checklist
40. Commissioning, normal operation, shutdown and emergency shutdown procedures
41. All drawings, specifications, studies, and calculations shall be sealed by a Professional
Engineer in good standing, licensed in the State of Idaho for the applicable discipline.
42. Subcontractor redlines shall be included in the main contractor redlines and given to
Owner for review. Contractor shall coordinate with Subcontractors the turnover of
redlines on a daily basis throughout the duration of project. Redline drawing turnover
coordination meeting shall be led by the Contractor.
Contractor shall utilize Owner’s drafting standards in the development of engineering
drawings for the Facility as noted in this specification’s Appendices
1.3.4 Project Control Submittals
Contractor shall provide the following submittals within 30 days upon receiving Notice To
Proceed (NTP) or Contract signing.
1. Project Execution Plan
2. Drawing list
3. Specification list
4. Safety, accident, health program
5. Engineering submissions for construction permit
6. Contractor permit applications and permits
7. Project schedule
1.3.5 Engineering Submittals
Engineering submittals shall include the design package described in Section 1.3.4 as well as a
progress report.
Engineering submittals shall be provided by Contractor in electronic form (PDF format) as a
minimum. Contractor shall provide 1 hard copy and 1 PDF format of each revision of each
Approved for Construction design drawing. The final As-Built drawing set shall be provided in
both PDF and DWG format. Owner reserves the right to request additional documents.
Manufacturer field service representative shall be on site during commissioning to provide
accurate commissioning report.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 558 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-12
Internal Use Only
Contractor shall provide drawing and associated document submittals at the following design
stages:
1. 30 percent, within 30 days of the Contract being executed
2. 60 percent, within 45 days of the Contract being executed
3. 90 percent, within 60 days of the Contract being executed
4. 100 percent, within 90 days of the Contract being executed
5. Construction, within 115 days of the Contract being executed
6. As Built, within 30 days of the commercial operation of Project
Refer to Section 1.7 for the list of Constructor’s submittals to Owner.
Owner's review of drawings and other submittals shall cover only general conformity of the
data to the technical specifications, external connections, interfaces with equipment and
materials furnished under separate specifications, and dimensions that affect system
arrangements.
Owner's review will not include a thorough review of all dimensions, quantities, and details of
the equipment, material, device, or item indicated or the accuracy of the information or
calculations submitted.
1. Review and comment by Owner of Contractor's drawings or other submittals shall not
relieve Contractor of its sole responsibility to meet the requirement of the Contract and
to supply work that conforms to the requirements of the Contract.
2. Owner shall be allowed a 14 calendar day review period.
3. Contractor shall provide responses to Owner’s review at least one week prior to
scheduled review meetings.
1.3.6 Engineering Completion
Contractor shall prepare and deliver to Owner, at least one week prior to the start of
commissioning activities:
1. Two electronic copies of all engineering drawings, all engineering submittals, and the
Operations and Maintenance (O&M) manual for the Facility
2. Three hard copies of the O&M manual for the Facility.
Within one week of completion of commissioning and testing, the following submittals shall
be provided to Owner.
1. Protective relay calibration tests
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 559 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-13
Internal Use Only
2. Trial operation of equipment - summary report
3. Manufacturer field service reports
4. Performance test report
5. Flash Test Data
Contractor shall provide [two] closeout binders in hard copy at project completion (with
associated electronic files).
The binder shall also be provided electronically in PDF format.
This binder shall include the following:
1. As-built drawings
2. CAD & PDF versions of all drawings
3. Interconnection approvals
4. Revenue grade meter calibration certificate
5. Functional testing results
6. Transformer completed test reports
7. Commissioning results
8. O&M manual
9. Installation manuals
10. Completed warranty cards
11. Registration cards
12. Operation manuals (manufacturer)
13. Maintenance schedules
14. Spare parts list
15. Letter from manufacturer, if required, – indicating they have inspected the installation,
it conforms to their installation guidelines, and the full warranty is in effect.
16. Point of Contact (POC) list for all subcontractors, vendors, suppliers
17. Municipal permits
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 560 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-14
Internal Use Only
18. Point of contact for warranty service
Contractor-furnished materials shall include bound O&M information and system
descriptions for each system that shall be incorporated in the Facility.
The system descriptions shall include text describing normal and abnormal control for system
components.
1. This manual shall include detailed Facility operating procedures including detailed step-
by-step commissioning/shutdown sequences or troubleshooting procedures.
2. This manual shall also include maintenance schedules.
3. Separate stand-alone O&M manuals shall be provided for the SCADA system and
inverters.
1.3.7 Quality Assurance
Unless specifically named in the Specifications, a manufacturer shall have furnished
equipment of the type and size specified which has been in successful operation for not less
than the past 5 years.
Contractor shall select equipment manufacturers with sufficient capacity to produce and
deliver required materials without causing delay in work.
1.3.8 Delivery Storage and Handling
1.3.8.1 Delivery
Contractor shall bear the responsibility for delivery of equipment, spare parts, special tools,
and materials to the Site and shall comply with the requirements specified herein and shall
provide required information concerning the shipment and delivery of the materials specified
in this Contract.
These requirements also apply to any sub-suppliers making direct shipments to the jobsite.
Contractor shall, either directly or through contractual arrangements with others, accept
responsibility for the safe handling and protection of the equipment and materials furnished
under this Contract before and after receipt at the port of entry.
Acceptance of the equipment shall be made after it is installed, tested, commissioned, placed
in operation and found to comply with all the specified requirements.
All items shall be checked against packing lists immediately on delivery to the Site for damage
and for shortages by contractor.
Damage and shortages shall be remedied with the minimum of delay, at no additional cost to
Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 561 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-15
Internal Use Only
Delivery of portions of the equipment in several individual shipments shall be subject to
review of Contractor before shipment.
When permitted, all such partial shipments shall be plainly marked to identify, to permit easy
accumulation, and to facilitate eventual installation.
1.3.8.2 Storage
Contractor shall bear the responsibility for storage of equipment, spare parts, special tools,
and materials to the Site and shall comply with the requirements specified herein.
Upon delivery, all equipment and materials shall immediately be stored and protected from
damage, theft, vandalism and the elements until installed.
Stacked items shall be suitably protected from damage by spacers or load distributing
supports that are safely arranged.
No metalwork (miscellaneous steel shapes and reinforcing steel) shall be stored directly on
the ground.
Masonry products shall be handled and stored in a manner to hold breakage, chipping,
cracking, and spalling to a minimum.
Cement, lime, and similar products shall be stored off the ground on pallets and shall be
covered and kept completely dry at all times.
Pipe, fittings, and valves may be stored outdoors, but shall be placed on wooden blocking.
PVC pipe, geomembranes, plastic liner, and other plastic materials shall be stored off the
ground on pallets and protected from direct sunlight.
Pumps, motors, electrical equipment, and all equipment with antifriction or sleeve bearings
shall be stored in weather tight structures maintained at a temperature above 60 °F (16 °C).
Electrical equipment insulation shall be protected against moisture and water damage.
All space heaters furnished in equipment shall be connected and operated continuously.
Equipment having moving parts, such as gears, bearings, and seals, shall be stored fully
lubricated with oil, grease, etc., unless otherwise instructed by the manufacturer.
Manufacturer's storage instructions shall be carefully followed by Contractor.
When required by the equipment manufacturer, moving parts shall be rotated a minimum of
twice a month to ensure proper lubrication and to avoid metal to metal "welding." Upon
installation of the equipment, Contractor shall, at the discretion of its engineer, start the
equipment at one-half load for an adequate period of time to ensure that the equipment does
not deteriorate from lack of use.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 562 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-16
Internal Use Only
When required by the equipment manufacturer, lubricants shall be changed upon completion
of installation and as frequently as required thereafter during the period between installation
and acceptance.
New lubricants shall be put into the equipment by Contractor at the time of acceptance.
Equipment and materials shall not show any pitting, rust, decay, soiling, stains, or other
deleterious effects of storage when installed in the work.
In addition to the protection specified for prolonged storage, the packaging of spare units and
spare parts shall be for export packing and shall be suitable for long-term storage in a damp
location.
Each spare item shall be packed separately and shall be completely identified on the outside
of the container.
1.3.8.3 Handling
Stored items shall be laid out to facilitate their retrieval for use in the work.
Care shall be taken when removing the equipment for use to ensure the precise piece of
equipment is removed and that it is handled in a manner that does not damage the
equipment.
1.3.9 Required Manufacturer’s Warranties
Contractor shall submit manufacturers’ warranties for Owner’s acceptance, manufacturer’s
standard/extended warranty document executed by authorized company official.
Manufacturers’ warranties are in addition to, and do not limit, other rights Owner may have
under the Contract.
1.3.10 Miscellaneous
Contractor shall be responsible to any damage to the Site.
Contractor shall be responsible for repair and/or replacement of all damaged equipment and
materials whether provided by Contractor or by others.
1.4 GENERAL INSTALLATION REQUIREMENTS
This Section describes Owner’s requirements for the methods and means of installation for the
Facility.
Contractor is responsible for construction of a fully operational and functional Facility as set
forth in this Specification, unless otherwise approved by Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 563 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-17
Internal Use Only
1.4.1 Construction Management
1.4.1.1 Construction Management
Contractor shall have an onsite Construction Manager when work is being done at the Site.
Contractor’s Construction Manager shall provide oversight to staff and subcontractors.
Contractor shall develop a site specific safety plan that shall be reviewed by Owner.
1. If the maximum emergency personnel response time to the Site is greater than thirty
(30) minutes, the Contractor shall provide an onsite EMT and ambulance during all
working hours or detail plan to have access for Life Flight helicopter access near the
project site.
2. An urgent care facility shall be contracted to set up nonemergency physician referrals.
First aid kits shall be provided around the Site and regularly maintained.
3. At least one person trained in first aid shall be part of the construction crew. In
addition, all foremen and supervisors shall be given first aid training.
Contractor shall ensure that all subcontractors abide by this safety plan.
The safety plan shall include a Contractor assigned point of contact that shall be available
24 hours a day, 7 days a week.
Contractor shall ensure all staff and subcontractors have proper OSHA/IDOSHA training.
Contractor shall ensure that all visitors to the Site are briefed on safety procedures and wear
the proper PPE, as applicable.
Contractor shall maintain a current set of drawings, red-line set of drawings, and a filing
system consisting of meeting minutes, safety training, visitor log, photo log, test reports, RFIs,
shop drawings, change orders, schedules, etc.
All materials, workmanship, and testing shall be in accordance with the appropriate
specifications, standards, and codes of practice.
Methods of Contractor's quality control shall be clearly established and documented.
Working methods shall ensure the construction of stable structures able to withstand all
applied loadings during construction and for the operating life of the Facility without collapse,
failure, or excessive deformation such as to cause any damage, loss of function, or durability
problems.
1.4.1.2 Waste Management
Contractor shall manage construction waste such that it does not disturb surrounding
neighbors or construction progress.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 564 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-18
Internal Use Only
Waste shall be removed from the Site at Contractor’s expense.
Waste disposal shall meet local requirements.
1.4.1.3 Dust Control
Contractor shall implement dust control measures at the Site during construction as required
by local AHJ and site Host.
Dust levels shall be kept at a minimum at all times during construction.
1.4.1.4 Housekeeping
Contractor shall maintain the Site in a neat and orderly manner, including providing street
sweeping, and mud control mat.
Walkways and work areas shall be clear of debris and shall be maintained on a daily basis.
1.4.2 Project Closeout Procedure
Contractor shall perform the following tasks as part of the project closeout procedures:
1. Provide approved submittals specified in Section 1.3.7
2. Respond to all Requests for Information (RFIs)
3. Complete all change orders
4. Provide copies of all required O&M manuals
5. Assign all applicable warranties
6. Provide copies of all punch list inspection records
7. Provide copies of all required construction documents, as compiled
8. Provide form of job books
9. Permit closeout document
1.4.3 Temporary Utilities
1.4.3.1 Trailers
Contractor shall be responsible for required onsite storage.
Storage facilities shall meet AHJ requirements.
Contractor shall provide owner with a trailer at the Site suitable for 6 full time onsite
personnel and furnished with work desks, chairs, electrical power, lighting, air conditioning,
heating, a telephone connection and internet connection.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 565 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-19
Internal Use Only
1.4.3.2 Electric Power
Contractor shall determine the type and amount of power necessary and make arrangements
for obtaining temporary electric service, metering, and shall bear the costs for electric power
used during the construction period.
1.4.3.3 Lighting
Contractor shall provide temporary lighting during construction to meet applicable safety
requirements.
1.4.3.4 Water
Contractor shall provide potable water for construction and drinking by construction
personnel during construction.
1.4.3.5 Sanitary Facilities
Contractor shall provide and maintain sanitary facilities on Site during construction.
Separate male and female facilities with hand wash stations shall be provided on Site during
construction.
1.4.3.6 Phone and Communication Facilities
Contractor shall provide phone lines, or ensure cell phone coverage and contact during the
entire construction process.
1.4.3.7 Parking
Areas within the Site shall be used for construction parking. If necessary, buses shall be used
to transport workers from the parking areas to the construction Site. These areas shall
provide adequate parking space for construction personnel and visitors during construction
and shall be maintained for stability and safety.
1.4.3.8 Offload and Staging Areas
Areas within the Site boundary shall be used as offload and staging areas. If additional lay-
down space is required offsite to temporarily store construction materials and Project
equipment prior to installation, the Contractor shall obtain all permits and approvals for such
offsite areas.
1.4.3.9 Other Utilities
Other necessary utilities for construction shall be provided by Contractor, as applicable.
1.4.4 Site Security and Access
Contractor shall ensure the Site (including any offsite areas specified in section 1.4.3) is
secured, limiting access to construction workers, Owner, and AHJ during construction.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 566 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-20
Internal Use Only
1.4.5 As-Built Drawings
During construction, Contractor shall keep on file one set of current as-built drawings with
green and red lined reflecting all field deviations from the design drawings.
As a condition to Final Acceptance, Contractor shall submit to Owner a set of as-built
drawings which have been fully conformed to the construction records as of the completion of
the work.
1.4.6 Electrical Equipment Installation
Installation work shall include receiving, unloading, inventorying assemblies and all sub-
system assemblies, storage, removal from storage, hauling, cleaning, installation on
foundations, and other work necessary to place all equipment into successful operation.
Factory test reports shall be filed and stored onsite.
In addition, installation work shall include complete assembly of equipment shipped
unassembled; dismantling and reassembly of equipment to make adjustments and provisions
of personnel, equipment, and assistance in testing and placing the equipment into operation.
Contractor shall submit detailed installation procedures, detailed manpower allocation and
an installation schedule for approval by Owner prior to starting installation work.
Equipment shall be checked prior to its installation to ensure that it is in conformance with
the purchase documents and manufacturer’s drawings.
Any discrepancies shall be reported to Owner.
1.5 INTERCONNECTION REQUIREMENTS
As set forth in General Interconnection Agreement which will be obtained by the Owner.
Contractor shall be responsible for the work up to thpoint of interconnection.
The interconnection for the Facility shall comply with all applicable codes, standards and
requirements.
The interconnection for the Facility shall be approved by Owner.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 567 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-21
Internal Use Only
1.6 ACRONYMS AND ABBREVIATIONS REFERENCE TECHNICAL
ACRONYM/ABBREVIATION MEANING
AASHTO American Association of State Highway and Transportation Officials
AC Alternating Current
ACI American Concrete Institute
AHJ Authority(ies) Having Jurisdiction
AISC American Institute of Steel Construction
ALTA American Land Trust Association
ANSI American National Standards Institute
ASCE American Society of Civil Engineers
ASD Allowable strength design
ASTM American Society for Testing and Materials
ATS Acceptance Testing Specifications
AWG American Wire Gauge
AWS American Welding Society
CAD Computer-Aided Drawing
CAT6e Category 6 Cable (enhanced)
CCH Communication and Control House
CCTV Closed-circuit Television
CE Conformité Européenne (European Economic Area Conformity Marking)
CEC California Energy Commission
CFR Code of Federal Regulations (USA)
CSV Comma Separated Value file format
DAQ Data Acquisition
dBA Decibels Acoustic
DC Direct Current
DRW Drawing file format
EIA Electronic Industries Alliance
EMT Electrical Metallic Tubing
EPC Engineering, Procurement and Construction contractor
FC’Minimum specified compressive strength of concrete
FEMA Federal Emergency Management Administration
FF Fill Factor (of an IV curve for a PV cell/module/string/array)
GFCI Ground Fault Circuit Interrupt
GHI Global Horizontal Irradiance
HMI Human-Machine Interface
HVAC Heating, Ventilation and Air Conditioning
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 568 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-22
Internal Use Only
ACRONYM/ABBREVIATION MEANING
IBC International Building Code
ICEA Insulated Cable Engineers Association
IEC International Electrotechnical Commission
IEEE Institute of Electrical and Electronics Engineers
Imp Current at Maximum Power (of an IV curve for a PV
cell/module/string/array)
Isc Short Circuit Current (of an IV curve for a PV cell/module/string/array)
IV Current-Voltage curve for a PV cell/module/string/array
kV kilovolt(s)
kVA kilovolt-ampere(s)
kVAr kilovolt-ampere(s)-reactive
kW kilowatt(s)
kWac kilowatts AC
kWh kilowatthour(s)
LED Light-Emitting Diode
LFMC Liquidtight Flexible Metallic Conduit
LRFD Load and Resistance Factor Design
LV Low Voltage
MHz megahertz
MPPT Maximum Power Point Tracking
MV Medium Voltage
MVAr megavolt-ampere(s)-reactive
MW megawatt(s)
MWac megawatt(s) AC
NEC National Electrical Code (USA)
NEMA National Electrical Manufacturer's Association
NESC National Electrical Safety Code
NETA InterNational Electrical Testing Association Inc.
NFPA National Fire Protection Association
NOCT Normal Operating Cell Temperature (of a PV module)
NTP Notice To Proceed
O&M Operations and Maintenance
OS Operating System (of a computer)
OSHA Occupational Safety and Health Administration
PDF Portable Document Format
PGE Portland General Electric
PLC Programmable Logic Circuit
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 569 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-23
Internal Use Only
ACRONYM/ABBREVIATION MEANING
Pmpp Power at Maximum Power Point (of an IV curve for a PV cell/module/string/
array)
POA Plane-of-Array (of PV modules)
POC Point of Connection
POI Point of Interconnection
POM Point of Metering
PPE Personal Protective Equipment
PSI Pounds per Square Inch
PV Photovoltaic
PVC Poly-vinyl Chloride
RGS Rigid Galvanized Steel
SCADA Supervisory Control and Data Acquisition
SPPWC Standard Plans for Public works Construction
SSPC Society for Protective Coatings
SSPWC Standard Specifications for Public Works Construction
STC Standard Test Conditions (for PV modules)
SWPPP Storm Water Pollution Prevention Plan
TBD To Be Determined
THD Total Harmonic Distortion
THHN Thermoplastic High Heat-resistant Nylon-coated
THWN Thermoplastic Heat and Water-resistant Nylon-coated
TIA Telecommunications Industry Association
TW Thermoplastic Moisture-Resistant Wire
UBC United Building Code
UL Underwriters Laboratories
UPS Uninterruptable Power Supply
VA volt-ampere
Vdc volts DC
Vmp Voltage at Maximum Power (of an IV curve for a PV
cell/module/string/array)
Voc Open-Circuit Voltage (of an IV curve for a PV cell/module/string/array)
XHHW Cross-Linked High Heat Water Resistant Insulated Wire
XLPE Cross-linked polyethylene

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 570 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-24
Internal Use Only
1.7 SUBMITTALS AND DOCUMENTATION
1.7.1 General Information
1.7.1.1 Definition
Submittals are defined below or in other sections of this document:
1. Construction drawings include the documents used to construct the project. These shall
follow the Owner’s standards and be created on the Owner’s standard drawing sizes and
title blocks.
2. Shop drawings include custom-prepared data of all types including drawings, diagrams,
specifications, performance curves, material schedules, weld schedules, templates,
instructions, and similar information.
3. Product data includes standard printed information on materials, products, and
systems; not custom-prepared for this project, other than the designation of selections
from available choices.
4. Samples include both fabricated and unfabricated physical examples of materials,
products, and Work; both as complete units and as smaller portions of units of Work;
either for limited visual inspection or (where indicated) for more detailed testing and
analysis. Mock-ups are a special form of samples which are too large to be handled in
the specified manner for transmittal of sample submittals.
Miscellaneous submittals are those technical reports, administrative submittals, certificates,
and guarantees not defined as shop drawings, product data, or samples.
1. Technical reports include laboratory reports, tests, technical procedures, technical
records, and Contractor's design analysis. Also included are environmental planning
and compliance documents, reports, and other submittals for Idaho Department of
Environmental Quality (MDEQ) or other governing agencies.
2. Administrative submittals are those non-technical submittals required by this document
or deemed necessary for administrative records. These submittals include maintenance
agreements, bonds, Project photographs, physical work records, statements of
applicability, Project record data, schedules, security/protection/safety data, and
similar type submittals.
3. Certificates and guarantees are those submittals on equipment and materials where a
written certificate or guarantee from the Supplier is called for in the specifications.
Refer to the Master Appendix List which lists the minimum required submittals.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 571 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-25
Internal Use Only
1.7.1.2 Quality Requirements
Submittals such as shop drawings and product data shall be of suitable quality for legibility
and reproduction purposes. Every line, character, and letter shall be clearly legible. Drawings
issued by electronic media shall be useable for further reproduction to yield legible hard
copy.
Documents submitted to Owner that do not conform to specified requirements shall be
subject to rejection by Owner, and upon request by Owner, Contractor shall resubmit
conforming documents. If conforming submittals cannot be obtained, such documents shall
be retraced, redrawn, or photographically restored as may be necessary to meet such
requirements. Contractor's (or his Subcontractor's) failure to initially satisfy the legibility
quality requirements will not relieve Contractor (or his Subcontractors) from meeting the
required schedule for submittal of shop drawings and product data.
1.7.1.3 Language and Dimensions
All primary dimensional units shall be shown in the English units, in addition to any other
units.
All words shall be in the English language in addition to any other language, for use at the
construction site.
1.7.1.4 Submittal Completeness
Submittals shall be complete with respect to dimensions, design criteria, materials of
construction, and other information specified to enable Owner to review the information
effectively.
Where standard drawings are furnished which cover a number of variations of the general
class of equipment, each such drawing shall be individually annotated to describe exactly
which parts of the drawing apply to the equipment being furnished. Use hatch marks to
indicate variations that do not apply to the submittal. The use of "highlighting markers" is not
an acceptable means of annotating submittals. Such annotation shall also include proper
identification of the Submittal permanently attached to the drawing.
Reproductions or copies of drawings or portions thereof will not be accepted as complete
fabrication or erection drawings.
1.7.1.5 Form of Submittals
Submittals and other Project documents shall be transmitted in electronic format as specified.
1. Selected submittals may be provided in paper ("hardcopy") copies with advance
approval of Owner, and using the procedures specified herein.
2. Equipment instruction books and operating manuals shall be provided in paper copies
in addition to specified electronic format.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 572 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-26
Internal Use Only
Electronic Format
1. When practicable, scanned submittals and documents shall not be used. Transmit
submittals and Project documents in:
Nonproprietary, native electronic format incorporating any necessary reference
files, or
Adobe Portable Document Format (PDF) files created directly from native electronic
format, or
TIFF file format, or
Owner-approved equal.
For any given submittal, the filename and format shall be consistent for initial
submission and subsequent revisions of the same. Use consistent naming
convention throughout.
Nonconforming Submittals are subject to rejection by Owner.
Provide "Construction Record" submittals, including drawings, documents, equipment
instruction books and operating manuals, and other documents to the Owner.
Construction Record drawings shall be submitted in formats specified in Section 1.7.8
below.
Digital delivery media may be transferred through Owner established file structure via the
FTP site Box.com unless Contractor and Owner agree upon an alternative means.
Contractor shall provide and support a hosted submittal management system and facilitate
access by all Owner reviewers. Software platform (Contract Management, Expedition, etc.) to
be coordinated with and approved by Owner.
1.7.1.6 Conforming to Construction Records or As-Built Requirements
Submittals and Owner-supplied Project documentation including submittals and drawings
shall be conformed to construction record conditions. Delivery format is detailed above.
Construction Record drawings shall be submitted for Owner approval following completion of
the construction and no later than at time of Final Completion.
1.7.1.7 Engineering Change Notice
Contractor shall use the Owner’s engineering change notice process, GA-304 for changes to
approved drawings, unless Contractor has existing engineering change process which is accepted
by Owner. GA-304 can be found in the Master Appendix List, Generation Design Drawing
Standards.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 573 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-27
Internal Use Only
1.7.2 Submittals
Submittals shall be broken down into two categories: “Approval Required Submittals” and “Other
Submittals.”
Approval Required Submittals:
1. Shall be approved by the Owner prior to Contractor proceeding with design or release
for fabrication or manufacture.
2. Shall be resubmitted on each revision for the number of times required to obtain
approval. However, any need for re-submittals in excess of the number set forth in the
accepted schedule, or any other delay under Contractor’s responsibility, will not be
grounds for extension of the Project Schedule.
3. Shall be as defined in the Deliverables List.
4. Shall be so marked on the transmittal to the Owner.
The approval of submittals by Owner does not relieve the Contractor or Supplier of the
responsibility to meet requirements of the EPC Agreement or any legal responsibility for such
designs.
Work relative to Approval Required Submittals, if commenced or shipped prior to the
submittal having been stamped “AAS” (or “Approved as Submitted”) or “AAN” (or “Approved
as Noted”) by Owner shall be performed at Contractor’s risk. A copy or sample of each
submittal shall be kept in good order by Contractor at the Site.
The remaining submittals, the Other Submittals, shall include the data included in Sections
1.7.4 and 1.7.5 and information as applicable to the particular equipment and materials and in
accordance with applicable codes and standards.
1.7.2.1 Schedule of Submittals
Prepare for Owner’s concurrence, a schedule for submission of all submittals specified or
necessary for Owner’s approval of the use of equipment and materials proposed for
incorporation in the Work or needed for proper installation, operation, or maintenance.
Submit the schedule with the procurement schedule and Work progress schedule. Schedule
submission of all submittals to permit review, fabrication, and delivery in time to not cause a
delay in the Work of Contractor or his Subcontractors or any other contractors as described
herein.
In establishing schedule for submittals, allow fifteen (15) working days in Owner’s office for
reviewing original submittals and ten (10) working days in Owner’s office for reviewing re-
submittals. In the event a submittal contains an abnormally large amount of documents or a
rapid sequence of submittals amounts to an abnormally large amount of documents, more
than fifteen (15) working days should be allowed for Owner review.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 574 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-28
Internal Use Only
Submittals requiring revision shall be resubmitted within ten (10) working days after receipt
of Owner’s review notations.
The schedule shall indicate the anticipated dates of original submission for each item and
Owner’s approval thereof, and shall be based upon at least one resubmission of each item. A
list of submittals (Submittal Schedule) with the schedule to be submitted shall also be
submitted to Owner thirty (30) days after Limited Notice to Proceed.
Schedule all Approval Required Submittals required prior to fabrication or manufacture.
Schedule submittals pertaining to storage, installation and operation at the site for Owner’s
acceptance prior to delivery of the equipment and materials.
Resubmit submittals the number of times required for Owner’s "AAS" or “AAN.” However,
any need for re-submittals in excess of the number set forth in the accepted schedule, or any
other delay in obtaining approval of Submittals, will not be grounds for extension of the
schedule, provided Owner completes its reviews within the times specified.
Where a submittal is required by the EPC Agreement or the accepted Deliverable Schedule,
any related Work performed prior to Owner’s review and approval of the pertaining
submittal will be at the sole expense and responsibility of Contractor.
1.7.2.2 Transmittal of Submittals
Submittals of equipment and materials furnished by Subcontractors, manufacturers, and
suppliers shall be submitted to Owner by Contractor.
Owner shall supply submittal naming conventions prior to beginning the submittal process.
Contractor shall utilize Owner’s electronic document management system (ProjectWise) to
facilitate all drawings, submittal reviews, RFI, PCN etc. Contractor shall procure any
necessary software.
All submittals shall be in an electronic format (PDF is preferred). The file name and type shall
be the same for all revisions and shall include the revision number at the end of the title.
All submittals shall be accompanied with a transmittal with the following information:
1. Contractor’s file name/drawing number.
2. Contractor’s revision number/letter.
3. Description of file/drawing title. (individual for each drawing)
4. Supplier/Sub-Supplier’s name (if applicable).
5. Supplier/Sub-Supplier’s drawing number (if applicable).
6. Supplier/Sub-Supplier’s revision number (if applicable).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 575 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-29
Internal Use Only
Each drawing sheet to be reviewed shall be in separate files to align with ProjectWise setup.
After checking and verifying, Contractor shall transmit submittals to Owner for acceptance as
follows:
Identify each submittal by Project name and number, EPC Agreement title and number, and
the specification section or drawing and article number attached to the file and in the letter of
transmittal file. Unidentifiable submittals will be returned for proper identification.
Each submittal shall have its own cover sheet. Unidentifiable submittals will be returned for
proper identification.
Check and annotate submittals of Subcontractors, suppliers, and manufacturers with
Contractor’s approval prior to transmitting them to Owner. Contractor’s stamp of approval
shall constitute a representation to Owner that Contractor has both determined and verified
all quantities, dimensions, field construction criteria, materials, catalog numbers, and similar
data, or Contractor assumes full responsibility for doing so, and that Contractor has
coordinated each submittal with the requirements of the Work and the EPC Agreement.
Any deviations from the requirements of the EPC Agreement shall be called to the attention of
Owner in the letter of transmittal document file.
Make all modifications noted or indicated by Owner and reissue revised document, copies, or
samples until accepted. Direct specific attention in the document file, or on revised
submittals, to changes other than the modifications called for by Owner on previous
submittals. After submittals have been accepted, issue copies thereof for record. Files of
accepted drawings transmitted for final distribution will not be further reviewed and are not
to be revised. If errors are discovered during manufacture or fabrication, correct the
submittal and resubmit for review.
Following completion of the Work and prior to final payment, furnish record documents and
approved samples and shop drawings revised as necessary to indicate “conformed to
construction record” conditions, updated to include all field modifications.
Keep a copy of each submittal or sample in good order at the Site.
Quantity Requirements:
1. Except as otherwise specified, transmit all Contractor’s, Subcontractor’s,
manufacturer’s, or fabricator’s shop drawing submittals in the quantity as follows:
Initial submittal: One electronic file plus one hard copy to Owner. Comments will be
returned to Contractor in PDF format.
Re-submittals: One electronic file to Owner. Comments will be returned to
Contractor in PDF format.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 576 of 1056
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CO.| General 1-30
Internal Use Only
Submittal for Final Distribution: Electronic media plus one hard copy to Owner
unless otherwise approved in writing by Owner.
As-Constructed Prints: Electronic file plus one hard copy unless otherwise approved
in writing by Owner.
2. Transmit Submittals of product data as follows:
Initial Submittal: Electronic file plus one hard copy to Owner. Comments will be
returned to Contractor in PDF format.
Re-submittals: Electronic file plus one hard copy to Owner. Comments will be
returned to Contractor in PDF format.
Submittal for Final Distribution: Electronic file plus one hard copy to Owner.
Comments will be returned to Contractor in PDF format.
3. Transmit Submittals of material samples, color charts, and similar items as follows:
Initial Submittal: three (3) to Owner.
Re-submittals: three (3) to Owner.
Upon approval, one (1) Sample will be returned to Contractor.
4. Transmit submittals of equipment instruction books and operating manuals as follows:
Initial submittal: One (1) hard copy plus electronic file copies to Owner. Comments
will be returned to Contractor in PDF format.
Re-submittals: One (1) hard copy plus electronic file copies to Owner. Comments
will be returned to Contractor in PDF format.
5. Submittal for final distribution:
One (1) electronic media copy to Owner unless otherwise approved in writing by
Owner.
6. Submittals for Reference Only
One (1) electronic copy and one hard copy to Owner.
Owner may copy and use for internal operations and staff training purposes any and all
document submittals required by this document, whether or not such documents are
copyrighted, at no additional cost to Owner.
Copies of the equipment erection drawings and other submittals required for the installation
of equipment furnished by others under separate Agreement for installation under this
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 577 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-31
Internal Use Only
document, if any, will be transmitted to Contractor by Owner’ in the final distribution of such
Submittals.
1.7.2.3 Owner’s Review
Owner will review and take appropriate action on Submittals in accordance with the accepted
schedule of submittals. Owner’s review and approval will be only to determine if the items of
equipment and materials covered by the submittals will, after installation or incorporation in
the Work, conform to the EPC Agreement and be compatible with the design concept of the
completed Project as a functioning whole as indicated by the Agreement.
Owner’s review and approval will not extend to design data reflected in submittals which is
peculiarly within the special expertise of Contractor or Contractor's Subcontractors or
Suppliers. Review and approval of a component item as such will not indicate approval of the
assembly in which the item functions.
Owner’s review and approval of shop drawings, product data, or samples will not relieve
Contractor of responsibility for any deviation from requirements of the EPC Agreement
unless Contractor has in writing called Owner’s attention to such deviation at the time of
submission, and Owner has given written concurrence in and approval of the specific
deviation. Approval by Owner shall not relieve Contractor from responsibility for errors or
omissions in submittals.
1.7.2.4 Submittal Action Stamp
Owner’s review action stamp, appropriately completed, will appear on all Submittals of
Contractor when returned by Owner. Review status designations listed on Owner action
stamp are defined as follows:
AAS – APPROVED AS SUBMITTED: Signifies that equipment or material represented by the
submittal conforms to the design concept and complies with the intent of the EPC Agreement
and is approved for incorporation in the Work. Contractor is to proceed with fabrication or
procurement of the items and with related Work. All submittals shall be resubmitted until an
Approved as Submitted status is achieved.
AAN – APPROVED AS NOTED: Signifies that equipment and material represented by the
submittal conforms to the design concept and complies with the intent of the EPC Agreement
and is approved for incorporation in the Work in accordance with Owner’s notations.
Contractor is to proceed with fabrication or procurement of the items and with related Work
in accordance with Owner’s notations and is to submit a revised submittal responsive to
notations marked on the returned submittal or written in the letter of transmittal.
R&R – REVISE AND RESUBMIT (RESUBMIT): Signifies that equipment and material
represented by the submittal does not conform to the design concept or comply with the
intent of the EPC Agreement and is disapproved for use in the Work. R&R may also signify
information is either insufficient in detail or contains discrepancies which prevent Owner
from completing his review. Contractor is to resubmit revised information responsive to
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 578 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-32
Internal Use Only
Owner’s annotations on the returned submittal or written in the letter of transmittal.
Fabrication or procurement of items represented by the submittal and related Work is not to
proceed until the submittal is approved. IFI – ISSUED FOR INFORMATION – (For Reference,
No Approval Required): Signifies submittals which are for supplementary information only;
pamphlets, general information sheets, catalog cuts, standard sheets, bulletins and similar
data, all of which are useful to Owner in design, operation, or maintenance, but which by their
nature do not constitute a basis for determining that items represented thereby conform with
the design concept or comply with the intent of the EPC Agreement. Owner reviews such
submittals for general content but not for basic details.
PRELIMINARY - PRELIMINARY SUBMITTAL: Signifies submittals of such preliminary nature
that a determination of conformance with the design concept or compliance with the intent of
the EPC Agreement shall be deferred until additional information is furnished. Contractor is
to submit such additional information to permit layout and related activities to proceed.
Submittals may have data missing which is required to complete the review. Further
submittal(s) to Owner once the submittal is complete is required by Contractor to fulfill
Contractual obligations.
1.7.3 Miscellaneous Submittals
“Miscellaneous Submittals” are comprised of technical reports, administrative submittals, and
guarantees which relate to the Work, but do not require Owner approval prior to proceeding with
the Work. Miscellaneous submittals will be submitted in electronic media and one hard copy.
1.7.3.1 Transmittal of Miscellaneous Submittals
All Miscellaneous Submittals furnished by Subcontractors, manufacturers, and Suppliers shall
be submitted to Owner by Contractor in electronic media with one hard copy unless
otherwise specified.
1. Complete the Consumers Energy Submittal Form for each initial submittal issue and
each submittal re-issue. Each submittal shall have its own cover sheet. Unidentifiable
submittals will be returned for proper identification.
2. At the time of each submission, call to the attention of Owner in the transmittal files any
deviations from requirements of this document
Quantity Requirements:
Technical reports and administrative submittals except as otherwise specified:
Owner: One (1) electronic file and one (1) hard copy.
Written certificates and guarantees:
Owner: One (1) electronic file and one (1) hard copy.
Test Reports:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 579 of 1056
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CO.| General 1-33
Internal Use Only
1. Responsibilities of Contractor and Owner regarding tests and inspections of equipment
and materials and completed Work are set forth elsewhere in this Scope of Work
document.
2. The party specified responsible for testing or inspection shall in each case, unless
otherwise specified, arrange for the testing laboratory or reporting agency to distribute
test reports by electronic media and in addition as follows:
Owner: One (1) electronic copy plus one (1) hard copy.
Resident Project Representative: One (1) copy.
Contractor: As Required.
Manufacturer or supplier: As Required.
1.7.3.2 Owner’s Review
Owner will review Miscellaneous Submittals for indications of Work or material deficiencies.
Owner will respond to Contractor on those Miscellaneous Submittals which indicate Work or
material deficiency.
1.7.4 Submittal Drawing and Data Requirements
The following documents, as a minimum unless additional documents are specified by the Owner,
shall be submitted to the Owner in accordance with the Submittal Schedule.
1. Technical Submittals/Equipment Data Sheets for all engineered equipment items to be
provided as part of the Project. Data sheets shall include a concise description of
performance rating, materials, and design data.
2. Test Procedures (functional and acceptance test procedures) including but not limited to
concrete testing, subgrade testing, access road and crane pad suitability tests, substation
power and control testing, and collection system PD testing.;
3. Operation and Maintenance Manuals for all Contractor supplied equipment;
4. Major equipment specifications;
5. Outline drawings with dimensions, weights, and foundation loading information,
performance data, seating and bolting arrangement, and clearance for maintenance;
6. Sectional drawings showing materials and construction;
7. Characteristic equipment curves as available;
8. Electrical one-line and three line diagrams, control schematic diagrams, control wiring
diagrams and cable schedule;
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 580 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-34
Internal Use Only
9. Calculated total unit weights of large components of items of machinery and equipment as
provided by equipment vendors (weights on drawings shall reflect dry and full weights).
10. Manufacturers’ recommendations on types and quantities of lubricants to be used for each
piece of equipment and list of consumables used during normal operation, such as filter
elements, chemicals, oil, and other items as applicable. This data shall be compiled into a
plant lubrication schedule, which shall summarize all lubricants required for ordering,
indicating frequency of lubrication required;
11. Layout of custom fabricated panels and switchboards sufficient to review for human
engineering features;
12. Minimum clearances for maintenance capability;
13. Lists of special tools furnished with the equipment (all special tools, except those supplied
by PV Module supplier, for erection and maintenance are to be provided by the Contractor);
14. Requirements for storage and protection of equipment upon receipt and following
installation, but prior to start-up.
15. System descriptions suitable for operations and maintenance training;
16. Short circuit calculations;
17. Load flow and equipment ratings calculations, including substation bus design calculations;
18. Grounding calculations;
19. Cable ampacity calculations;
20. Power loss calculations;
21. Other calculations as required by the Owner (including geotechnical and foundation
calculations)
22. Spare parts list
23. Schematic drawings and detailed wiring drawings of control, protection, monitoring, and
data acquisition schemes.
24. Communications block diagram and nameplate list for all systems and equipment utilizing
any communications protocols and/or networks.
25. Process and Instrument Diagrams (P&ID’s)
26. PV Module Installation Check Lists
27. PV Module Installation Inspection Procedure
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 581 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-35
Internal Use Only
28. Programmable device programs, configuration data, source code and settings, including that
for SCADA, PV Module control and generator and system protection
29. Protection and Relay Coordination Study
30. Foundation designs, public road improvement designs, access road design including prism,
cross section and profiles and other such civil designs for items in Contractor scope of work.
1.7.5 Submittal Document Review
The following classes of documents, as a minimum unless additional documents are requested by
the Owner, shall be submitted for review.
1. Geotechnical Engineering Reports
2. Access road layout design and detail
3. Route Improvement design and detail
4. Erosion and sediment control plan
5. Storm Water Pollution Prevention Plan
6. Foundation design and details
7. Civil infrastructure design and details
8. Concrete specifications
9. Structural steel specifications
10. High Voltage equipment specifications and layout drawings
11. Medium Voltage equipment specifications and layout drawings
12. High Voltage cable plans and specifications
13. Medium Voltage cable plans and specifications
14. Low voltage (e.g. less than 1,000 V) cable specifications
15. Fiber optic cable design and specifications
16. Engineered equipment specifications
17. All electrical one-line, three line and schematic diagrams
18. Electrical grounding system calculations and details (PV Module sites and substation)
19. Site Plan
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 582 of 1056
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CO.| General 1-36
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20. General arrangement drawings
21. Test procedures
22. Rigging plans
23. Crane Management Plan
24. Job Book Table of Contents
1.7.6 Operating Manuals
Contractor shall submit a draft of the Operating Manual for the Owner’s approval. The Operating
Manual shall include manufacturers’ instruction books for all electrical, mechanical, hydraulic,
pneumatic, and electronic equipment incorporated into the Work. The Operating Manual to be
supplied by Contractor will not include PV Module operating instructions. All manufacturers
manuals shall be incorporated into the project Operating Manual with multiple volumes, indexed
and placed in three ring binders, with volume and content clearly identified on the spine.
Commercial manuals are acceptable for inclusion in Operating Manuals. Contractor shall request
the following information to be included in vendors’ commercial manuals:
1. Installation, start-up and initial test instructions;
2. Operating instructions, including safety precautions; Maintenance procedures and routine
adjustments; including detailed maintenance plans;
3. Parts illustrations, including parts lists adequate for the purpose of identifying and ordering
replacement parts with designation of the number required per component, and lists of
recommended spare parts for three (3) years of operation of any component;
4. Wiring diagrams for electrical equipment;
5. Hydraulic diagrams for hydraulic equipment;
6. Detailed descriptions of the functions of each principal component of a system;
7. Performance and nameplate data;
8. Alignment instructions;
9. Safety precautions;
10. Maintenance instructions, which shall include detailed assembly drawings with part
numbers, parts lists, instructions for ordering spare parts, and complete preventative
maintenance instructions required to ensure satisfactory performance and longevity of the
equipment involved;
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 583 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-37
Internal Use Only
11. Lubrication instructions, which shall list points to be greased or oiled, shall recommend
type, grade, and temperature range of lubricants, and shall recommend frequency of
lubrication; and
12. Lists of electrical relay settings and control and alarm contact settings.
1.7.7 Job Books
Job Books shall be supplied by the Contractor in the form specified in the Master Appendix List.
Minimum expectations for the Job Books include the following items.
1. Completed Contractor’s QA/QC Exhibits
2. Completed PV Module Supplier QA/QC checklists
3. Material certifications and testing information (mill certs, concrete compressive strength
results, equipment factory test reports, etc.)
1.7.8 Record Drawings
Contractor shall provide to Owner, a complete set of “Record” drawings consisting, as a
minimum, instrument lists, electrical schematics, one-line and three line electrical drawings,
control logic diagrams, schematics, wiring diagrams, cable and conduit, underground or
embedded conduit drawings, civil design drawings, and electrical studies at the completion of
the project. Contractor shall also modify existing drawings that are affected by the Scope of
Work.
1. Contractor shall provide Record drawings locating all underground utilities dimensioned
from permanent identifiable benchmarks or GIS location-controlled information may be
substituted. Record drawings shall be provided using English customary units and the
English language.
2. All Record drawings shall be sealed by the Contractor’s engineer registered in the State
of Idaho. The Record drawings shall be provided to the Owner within eight (8) weeks
after Substantial Completion.
3. All record drawings shall be submitted in electronic format via ProjectWise.
4. Record drawings shall also be submitted in CAD format for use in AutoCAD using Owner
provided AutoCAD .dwg borders. CAD files and their associated PDF viewing files shall
bear the same name with the exception of the file extension. These shall be issued as
independent, stand-alone files which use only AutoCAD default fonts with no more than
one reference file. Reference files shall be a single TIFF file unless determined necessary
for the integrity of the drawing and is agreed upon by Owner and its Record Center
representatives.
In addition, as-built collector system routing, junction box locations, bore locations, drain tile
repair locations, and permanent civil infrastructure locations shall be provided in GIS format.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 584 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-38
Internal Use Only
Contractor shall provide coordinates Idaho State Plane Coordinates NAD83 of the project
site(s), installed collector line at a minimum frequency of every one hundred (100) feet along
tangents and every twenty-five (25) feet along the curves. Data shall be collected with GPS
equipment capable of achieving an accuracy of 10 cm +/- (horizontal). Contractor shall
provide make and model of GPS equipment to be used to Owner. A known survey control
point shall be surveyed and checked against prior to each day’s survey. Survey control points
shall be provided by Owner or Owner’s surveyor. Contractor deliverables shall include:
1. A shape file (.shp) with line work connecting the survey points.
2. A shape file (.shp)with survey points for all collection system splice locations, grounding
locations and drain tile repairs locations.
1.8 ENVIRONMENTAL CONDITIONS
The BOP shall be designed by the Contractor to operate satisfactorily throughout the range of
temperature and climatological conditions expected at the site. See section 2.0 Civil Structural for
additional requirements. Approximate environmental design conditions for the site include the
following:
1. Minimum low ambient temperature: Normal and extreme for Project Location per IEC
61400-1
2. Maximum high ambient temperature: Normal and extreme for Project Location per IEC
61400-1
3. Normal Humidity: Range of up to 95% relative humidity (IEC 61400-1).
4. Ice Accumulation – 0.75-inches at 10 meters shall be scaled up to the appropriate
dimensions using the height, importance and topographic factors detailed in ASCE 7-10
section 10.4.
5. Combination wind load on ice covered structure – (50-year mean recurrence interval
uniform ice thickness due to freezing rain with concurrent 3-second gust speed) gust speed
of 40 mph, shall be scaled up to the appropriate dimensions using the height, importance
and topographic factors detailed in ASCE 7-05 section 10.5
6. Lightning – Up to four (4) flashes per square kilometer per year (Vaisala-GAI, Inc. 1996-
2000 Flash Density map). Lightning frequency estimates for each PV Module in the wind
farm and component design to prevent lightening damage shall be in accordance the
methods recommended in the current versions of NFPA 780 and IEC 61400-24.
7. NCDC Climate Records
a) Average annual temperature: Per NDC Climate Normals for Project Location closest
weather station
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 585 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-39
Internal Use Only
b) Extreme low temperature (30 year dataset): Per NDC Climate Normals for Project
Location closest weather station
c) Average days per year below -20° C (-4° F): Per NDC Climate Normals for Project
Location closest weather station
d) Extreme high temperature (30 year dataset): Per NDC Climate Normals for Project
Location closest weather station
1.9 SCHEDULE, MEETINGS, AND PROGRESS REPORTS
The Contractor, prior to commencement of work, shall furnish to the Owner for review and
approval, an integrated Detailed Critical Path Method (“CPM”) Network Diagram conforming to the
dates specified in EPC Agreement Exhibit E and in accordance with EPC Agreement Exhibit DD, with
a supporting CPM printout covering all Work. Allowances shall be made in this Detailed CPM
Schedule for occurrences such as holidays, possible strikes, and inclement weather. The “by area”
report shall have activities for engineering work (including submittal of preliminary and final
documents and drawings), fabrication and delivery of equipment/material, installation, and shop
testing. The “by start-up system” aspect of the report shall have activities for installation,
inspection, examination, testing, and turnover on a system basis. The Contractor shall use
Primavera 6 in the Owner’s LoadSpring environment. Access to Primavera 6 will be provided upon
approval of the Detailed CPM Network Diagram and Owner receipt of the native version of the
schedule to uploaded into the database.
The Contractor’s Detailed CPM Schedule shall be the basis for planning, scheduling, and executing
the Work in accordance with the following guidelines:
Each activity item shall be identified by a work activity description and number.
Each activity shall indicate Contractor engineering and design document submittal dates, if
applicable.
Each activity shall indicate Contractor release for fabrication dates, if applicable.
Each activity shall indicate Contractor’s fabrication sequences, if applicable.
Each activity shall indicate material and/or equipment on Jobsite dates for both Owner-
furnished items and Contractor-furnished items. Delivery dates for Contractor stored material
for which Contractor expects payment prior to installation shall also be identified on
Contractor’s detailed schedule.
Each activity shall indicate any outage requirements for tie-in to existing systems as applicable.
Each activity shall indicate any restraint placed upon its starting and/or, completion whether it
is Contractor or Owner furnished and/or controlled.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 586 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-40
Internal Use Only
Each activity shall provide information concerning labor-hours, bulk quantities such that this
information can be cross referenced and balanced with the information provided on the SOV.
Activities for periodic testing and hold points for inspections.
Schedules in support of outages or other specified projects will require further levels of detail
as described in the Contract documents.
Include Owner review period for all submittals pertaining to activities such as engineering,
design, shop fabrication, construction, testing, or other submittals as noted in section 1.3.6.
Depending on the scope of the Contract, Contractor may be required to furnish two schedules,
one for pre-outage Work and one for outage Work.
Each Activity shall roll-up to the SOV and the man-hours/cost shall equal that of the original bid
(unless otherwise approved by Owner).
The critical paths for the Work shall be identified and highlighted.
The Detailed CPM Schedule shall show the work activity descriptions and logic as a minimum. The
requirements of this section shall be shown on the Detailed CPM Schedule or, at the Contractor’s
option, on supporting CPM printouts.
The Detailed CPM Schedule indicating the construction “by area”, including supporting CPM
printouts, shall be revised and provided to the Owner by the Contractor weekly to reflect the status
of Work through the end of the previous calendar week. The start-up activities report output of the
Detailed CPM Schedule will be issued weekly after a date specified by the Owner. Weekly updates
shall be in tabular report format and shall provide the following information by activity:
Activity Number
Activity Number Description
Original Duration
Remaining Duration
Current Early Start (Actual Start)
Current Early Finish (Actual Finish)
Total Float
Percent Complete
Productivity Rates
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 587 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-41
Internal Use Only
The critical paths for the Work shall be updated, as required. Any changes shall be subject to
approval by Owner. Updates for certain portions of the Work (such as start-up activities or
complex construction activities) and outage support will be required more frequently and may be a
detailed frag-net or a detailed system or subsystem schedule. Such updates may be required on a
daily basis during intense construction and start-up periods.
Changes in the Work that affect existing activities, schedule or milestone dates, or duration of
activities of the detailed CPM schedules or changes as specifically requested by Owner shall be
added by Contractor to the detailed CPM schedule, including the CPM printout, within ten (10)
calendar days after notification by Owner that such change shall be implemented. Any revision to
Owner approved Baseline Schedule shall only occur after Owner issues the corresponding PCN.
Once Work has started on an activity, it shall not be modified into additional activities unless
reviewed and approved by the Owner.
Changes or modifications to activities not started shall be submitted no less than one (1) month
prior to starting Work on the activity.
Should Contractor complete a milestone prior to the scheduled date, the “float” shall be credited to
Owner. Any such “float” may, at Owner’s sole discretion, be used by Owner to accelerate other
areas of the Project schedule. It is understood Owner and Contractor will work together to apply
any “float” gained over the course of the Project whether through the efforts of Owner, Contractor,
or other Contractors to the area that best fits the Project’s needs.
The Contractor shall provide to the Owner for review, when requested, its daily/weekly Work
activity or planning schedule which supports the Detailed CPM Schedules. The two week work plan
CPM Schedule float reports, updates, and any special requested reports shall be submitted on a
weekly basis.
Contractor shall participate in regular meeting and submit progress reports to Owner, including
Plan of the Day (POD) reports, monthly status reports, and schedule progress reports, in
accordance with the Master Appendix List.
1.10 REQUEST FOR INFORMATION
The Contractor shall follow Owner’s Request for Information (RFI) Procedure and use Owner’s RFI
Form for any and all information requests. The RFI Form is included as the Master Appendix List.
Owner shall supply Contractor with the required forms in electronic format. The Contractor shall
provide sufficient detail in RFIs such that the Owner can respond to the request appropriately and
timely.
Contractor shall provide Owner sufficient time to review and respond to RFIs. Contractor shall
provide and support a hosted submittal/RFI management system and facilitate access by all Owner
reviewers. Software platform (Contract Manager, Expedition, etc.) shall be coordinated with and
approved by Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 588 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| General 1-42
Internal Use Only
1.11 HEALTH AND SAFETY PLAN
The Contractor shall prepare and deliver to Owner the Safety Plan and erect and maintain all
necessary safeguards for the safety and protection of life and property at the Project Site, as
required by the condition and progress of the Work and in accordance with the Safety Plan,
Contractor shall ensure Contractor and Subcontractor compliance with the Safety Plan and any
other Owner issued regulations and rules delivered to Contractor with respect to the Project Site.
1.12 ENVIRONMENTAL PLAN
The Contractor shall comply with all environmental requirements as set forth for the Project and
included in different Project Permits. The Contractor shall not discharge any toxic, poisonous or
polluted effluents onto the Project Site or into any running or stagnant water at any time.
The Contractor shall develop and submit to Owner for review an Environmental Plan for the
construction phase of the Project. The Environmental Plan shall to reflect the terms of all permits,
the land lease agreement, and Prudent Wind Industry Practices. Aspects of the plan should include,
but not be limited to:
Storm water control and erosion protection
Waste management (including hazardous wastes)
Spill prevention, control, and countermeasure
Wetland protection
Dust control
The Environmental Plan shall be completed by the Contractor and approved by the Owner prior to
the start of any work at the Site.
Contractor shall utilize dust suppression procedures per the project Dust Control Plan to reduce the
impact of dust at the Project Site.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 589 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-1
Internal Use Only
2.0 Civil Structural
2.1 CIVIL, STRUCTURAL, AND ARCHITECTURAL DESIGN AND EQUIPMENT REQUIREMENTS
2.1.1 General
The design shall consider all applied loads including dead, live, impact, thermal, dynamic,
settlement, movement, wind, seismic, and other loading conditions where appropriate.
Temporary loads during maintenance and erection shall be considered.
All structures and structural elements, including array structures, shall be designed in
accordance with all applicable local Building Codes and standards pertaining to the erection
of such structures.
All structural components, including array structures shall be designed in a manner
commensurate with attaining a minimum 30 year design life.
The design shall mitigate corrosion issues at the connections between dissimilar metals,
especially at grounding points.
The design shall mitigate issues of corrosion of the racking and foundation at the ground
interface level.
All design drawings and specifications produced shall be sealed by a Professional or
Structural Engineer licensed to practice in the State of Idaho
Steel structures shall be designed by either the allowable strength design (ASD) method or
load and resistance factor design (LRFD) method.
Reinforced concrete structures shall be designed by the strength design (SD) method.
2.1.2 Wind Loads
The design wind speed for the Facility shall be as required by the local Authorities Having
Jurisdiction (AHJ).
All structures shall be designed per the design codes and standards listed in Section 1.2.1 with
local amendments, or as required by the AHJ based on Contractor’s overall system design
components, at no additional cost to Owner, but in all cases, Contractor is ultimately
responsible for system survivability.
PV Module support frames and foundation support systems shall be designed to allow the
modules to function normally after a design wind event as indicated above.
Calculations documenting the design, deflection, and functionality shall be submitted for
review and approval prior to construction of any systems in the field.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 590 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-2
Internal Use Only
For PV module support structure design only, Risk Category II shall be utilized to determine
Basic Wind Speed and related importance factors, unless specified otherwise by the AHJ.
2.1.3 Seismic Loads
Structures shall be seismically designed in accordance with the design codes and standards
listed in Section 1.2.1 with local amendments.
Contractor shall determine the appropriate Seismic Zone for the Site based on design codes
and standards listed in Section 1.2.1 and design the structures accordingly.
For PV module support structure design only, Risk Category II shall be utilized to determine
seismic importance factors, unless specified otherwise by the AHJ.
2.1.4 Factors of Safety
Minimum factors of safety for all structures, tanks, and equipment supports shall be as shown
in Table 2.1.
Table 2.1. Factors of Safety
PARAMETER FACTOR OF SAFETY
Overturning 1.50
Sliding 1.10 for seismic loads
1.50 for wind loads
Buoyancy at Design Water-Level 1.25
Uplift due to wind
Frost Heave
1.50
2.50 or as specified by the Geotechnical
Engineer
2.2 HYDROLOGY
The Site shall be designed to handle runoff from a 25-year storm and mitigate flood risks from
a 25-year storm event, or as required by the AHJ, whichever is more stringent.
Contractor shall prepare a hydrology study for the pre- and post-development conditions of
the Site in accordance with the requirements of the local jurisdiction.
The hydrology study shall evaluate any potential flooding for various storm events and make
recommendations for flood mitigation and permitting if necessary.
The hydrology study shall identify any existing drainages within the Site and provide
information on incoming storm water flows for various storm water events.
Increased imperviousness, diversion of existing drainage, and concentrating of storm water
flows resulting from the development shall be studied for any potential impacts on the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 591 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-3
Internal Use Only
downstream properties and mitigated as necessary. Such mitigation measures shall include
the construction of storm water retention/infiltration basins, perforated pipes, dry wells,
energy dissipator structures, etc.
Contractor shall be responsible for identifying and obtaining all permits as a result of water
retention, detention, alteration within jurisdictional waters or discharge to surface waters.
2.2.1 Earthwork
Contractor shall prepare a grading and drainage plan for the proposed development in
accordance with the hydrology study and pertinent recommendations in the Geotechnical
Report.
The grading design for the Site shall follow the existing topographical features of the Site as
much as possible to minimize the drainage impact.
The Contractor shall design and construct drainage mitigation measures, such as retention
basin, detention basin, or similar structures to mitigate any increased drainage runoffs due to
the post-development condition
Contractor shall design and construct compacted soil pads for the proposed control house
building as applicable, and for various electrical equipment, including inverters, transformers,
and switchgears. Pads shall be constructed in conformance with recommendations of the
project geotechnical report.
The pads shall be designed to allow storm water to drain away from the structures and
provide a finished surface elevation raised a minimum 12 inches above 100-year flood
elevations, or as required by the AHJ.
Contractor shall consider soil budgeting during the grading design.
Contractor shall submit the grading and drainage plan to the Owner for review prior to
construction activities.
2.2.2 Geotechnical Report
The results of a detailed subsurface investigation shall be documented in a geotechnical
engineering report certified by a qualified Geotechnical Engineer.
The Geotechnical Engineer shall be familiar with the various types of soil that exist in the area
of the development, including the geologic and seismic conditions.
The geotechnical report shall outline the following:
1. General subsurface conditions, including:
a. Subsoil description
b. Soil classification
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 592 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-4
Internal Use Only
c. Physical/engineering properties of soil
d. Ground surface and groundwater elevations
e. Infiltration rates for drainage retention facilities, where applicable
f. Representative soil profiles (cross sections)
2. Geological hazards and considerations, including:
a. Fault surface rupture
b. Seismic shaking
c. Seismic zone site class and related seismic parameters
d. Liquefaction potential and related impacts
e. Lateral spreading
f. Erosion
g. Expansive soil
h. Subsidence
i. Bearing capacities
j. Settlement – gross and differential
k. Corrosion – corrosivity and resistivity
l. Scouring
m. Frost heave
n. Soil’s resistivity and thermal conductivity
3. Earthwork recommendations, including:
a. Clearing and site preparation
b. Subgrade preparation
c. Material for structural and non-structural fill
d. Compaction requirements
e. Wet/cold weather construction conditions and considerations
f. Trench backfill
g. Trench excavations
h. Surface drainage considerations – temporary (during construction) and
permanent
4. Conclusions and recommendations, including:
a. Seismic design
b. Foundation design recommendations including, but not limited to, allowable
bearing pressure, settlement, friction coefficient, soil friction, soil passive
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 593 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-5
Internal Use Only
pressure, depths, uplift and lateral loads and recommended in-situ field tests for
verification of design parameters
c. Limitations
d. Soil resistivity and corrosion potential of anticipated foundation systems and
underground utility materials used on Project
e. Paving and road section recommendations
5. Exhibits, including:
a. Site location map
b. Boring location map
c. Soil classification chart
d. Rock classification chart
e. Boring logs
6. The soils investigation shall also determine whether the soils are corrosive to buried
concrete and ferrous metals, to support materials selection for foundations,
underground piping and/or design of corrosion protection systems, as applicable.
7. The Contractor shall perform pile load tests for driven steel piles, where applicable. The
pile load tests shall be in performed in accordance with ASTM D3966 and D3689.
8. The Contractor is responsible for furnishing all materials, products, accessories, tools,
equipment, services, transportation, labor and supervision, and manufacturing
techniques required for installation and testing of piles for this project.
9. The Contractor shall install piles that will develop the load (compression, uplift, and
lateral) capacities specified by the racking system manufacturer.
10. The pile load capacities shall be verified by performance lateral load testing as required
and must meet the test acceptance criteria specified by the racking system
manufacturer.
2.2.3 Roads, Parking Lots, and other Surfacing
Contractor shall design and construct access roads connecting the Site to existing public
roadways.
When applicable, access roads and interior roads shall also be provided for the substation,
control building, along the perimeter of the Site (if required by the AHJ), and to all equipment
pads in order to provide vehicular access for operation and maintenance of the system.
Access road and interior road width, turning radius and turn-around design requirements
shall be verified with the Owner and AHJ, and shall be sufficient to allow access for
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 594 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-6
Internal Use Only
anticipated deliveries, construction and maintenance vehicles and emergency personnel per
applicable codes and regulations.
Aggregate roads shall be designed and constructed to provide year-round access for Facilities
Operation and Maintenance.
Roads shall be designed to withstand loading from anticipated delivery, construction, and
maintenance vehicles. Structural section of the access road shall conform to the Geotechnical
Engineer recommendations.
All road surfaces shall be designed to allow for proper drainage (ponding of water is not
acceptable) and to allow transportation of normal maintenance equipment and materials
throughout the Site.
All roads shall be designed to meet Owner's insurance requirements.
Bollards shall be placed to provide protection to people and equipment. Contractor to verify
placement of bollards with the Owner prior to installation.
Contractor-provided temporary roads within the Site as required for construction activities
shall be removed as required or upgraded to meet the final Site requirements.
Hammerhead turn-around or Owner-approved alternate turn-around facility shall be
provided at the terminus of a dead-end access road.
Road locations shall minimize the risk of materials entering public waters and minimize
disturbance to stream channels, lakes, wetlands, and floodplains. Where viable alternatives
exist, roads shall not be located on steep slopes, slide areas, or high-risk sites, or in wetlands,
riparian management areas, channels, and floodplains.
When possible, locations of roads parallel to and in close proximity to streams shall be
avoided because such locations have a higher than normal potential to deliver sediments
directly into the channel. Stream and ditch crossings shall be as close to a right angle with the
stream as possible in order to enter and exit the stream with minimal intrusion.
Alternative road locations shall be considered where natural resources are impacted. The
most favorable road locations are those that provide the best combination of meeting
objectives and minimizing economic and environmental costs.
Prior to the start of construction, the condition of the public roads to be used for hauling
equipment and delivery of materials shall be documented by the Contractor with the AHJ, if
required by the AHJ.
Unimproved public roads within the Project may require improvements to carry the vehicles
likely to be used during construction and throughout the life of the Project. These
improvements shall be coordinated with the AHJ. Any design and construction of these public
roads by the Contractor shall be in accordance with local codes and regulations.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 595 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-7
Internal Use Only
2.2.4 Solar Field Fencing and Signage
Security fencing shall be provided around the entire Site. Perimeter fence shall follow as close
as possible the property boundary of the Project Site.
A separate security fence shall be provided around the substation (if applicable).
Contractor shall furnish and install a permanent fence around the entire Site and substation
(if applicable) to provide for public safety in accordance with AHJ and Good Utility Industry
Practices.
Fencing shall be chain-link with a minimum total height of 6 feet, unless specified otherwise
by the AHJ.
Chain link fence member sizes and materials shall conform to Standard Specifications for
Public Works Construction (SSPWC or the "Green Book"), latest edition.
Fence design shall also comply with the specifications from the latest version of the National
Electric Code.
At a minimum, one personnel gate and one vehicle gate shall be provided at each project
entrance, with an additional personnel gate at the control house, if applicable.
All gates shall have tamper proof gate hinges and hardware.
Gates along the perimeter shall have heavy duty bolt cutter resistant padlocks, except for
gates with motorized access.
Gates shall be equipped with knox box, or as required by the local Fire Department.
Signage shall meet Owner’s insurance requirements and any local regulations.
Signage shall be per code requirements and provide adequate safety and property protection
information.
At minimum every 100-foot interval on the perimeter shall have “Danger / High Voltage /
Keep Out” warning signs, as shown in Figure 2.1, posted on the fence.
The sign should also indicate that trespassers will be prosecuted and cite applicable
ordinance/laws and penalties that will be imposed on violators.
Text shall read in English.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 596 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-8
Internal Use Only
Figure 2.1. Example Warning Sign

Owner signage shall be provided at all gate entrances.
2.2.5 Hazard Warning Labels
The labels shall be in accordance with the NFPA, IEEE, the NEC, and the National Electric
Safety Code.
Flash hazard markings shall be furnished for all medium voltage (MV) and low voltage (LV)
switchgear, panel boards, control panels, and motor control centers.
The labels shall be located in a clearly visible area at each point of access to the equipment.
Equipment access includes but is not limited to breaker, starter, rear access, panel board, and
auxiliary compartment doors.
Labels provided shall be in accordance with applicable ANSI codes and standards, and either
one of the examples shown in Figure 2.2.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 597 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-9
Internal Use Only
Figure 2.2. Example Arc Flash Hazard Warning Labels

Signs shall use black lettering and border on white background.
The top banner background shall be orange for Warning signs and red for Danger signs, in
accordance with safety colors defined in applicable ANSI codes and standards.
2.2.6 Foundation for Equipment and Structures
Foundations for equipment and structures shall as applicable comply with the following:
1. All concrete foundations and reinforcing steel shall be designed in accordance with
applicable ACI and ASTM standards.
2. All concrete foundations for Owner-supplied equipment must meet Owner’s
requirements and specifications, as applicable.
3. All foundations shall be designed and built in accordance with the equipment to be
mounted on the foundation considering design loads, dimensions, weight distribution,
height, seismic, etc.
4. Contractor shall provide a detailed structural analysis of the foundations and
demonstrate that the design conforms to the applicable standards and codes.
5. Foundations shall be designed per the geotechnical report.
6. Contractor shall drill enough borings to determine the existing subsurface conditions.
7. Change orders related to unforeseen subsurface conditions shall be negotiated by the
terms and conditions of the EPC Agreement. Contractor shall provide unit price for
anticipated change order items related to unforeseen subsurface conditions.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 598 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-10
Internal Use Only
8. For ground-mounted systems, Contractor is responsible for designing foundations and
supports as appropriate to withstand the 100-year storm conditions and associated
scour and/or frost heave, as applicable.
9. Grade floor elevations of buildings and the tops of foundations for major outdoor
equipment at grade shall be at a minimum six inches above the high point of the finished
grade elevation.
10. Minimum strength of concrete shall conform to the requirements shown in Table 2.2.
11. Concrete finish shall be broom swept with a ¾" chamfered edge
12. Reinforcing steel shall be ASTM A 615/A 615M Grade 60 (420) deformed billet-steel
bar, unfinished.
13. Steel welded wire reinforcement shall be ASTM A 185/A 185M, plain type, flat sheets
with 6x6 minimum mesh size and W5xW5 minimum wire gage, unless otherwise
indicated in the construction documents.
14. Tie wire shall be annealed, minimum 18 gage.
15. Chairs, bolsters, bar supports, and spacers for the reinforcing steel shall be sized and
shaped for adequate support of reinforcement during concrete placement.
16. Mechanical couplers shall be capable of developing 160 percent of the specified yield
strength of the bar and shall develop a minimum of 10 times the yield point strain in the
connected reinforcing bars.
17. All oil-filled step-up transformer and medium voltage pad-mount transformer
foundations shall be reinforced concrete and shall have an integral spill containment
area as per IEEE 980, or alternative spill remediation measures as set out by 40CFR 112.
Containment area shall contain a sump for removal of liquids by portable pump.
18. Ground wires shall be embedded in foundations and stubbed up at their final location to
prevent a tripping hazard.
2.2.7 Module Mounting System
The design specifications for the foundations of the module mounting system ("mounting
system") shall be provided by Contractor as part of the mounting system design
specifications.
The mounting system foundation shall be designed to withstand the soil chemistry of the Site
location for a minimum of years without replacement
The mounting system including foundation design and support design shall be in compliance
with the recommendations of the Geotechnical Report
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 599 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-11
Internal Use Only
The foundation shall be designed to comply with all of the environmental conditions of the
Site, including, but not limited to, corrosion and frost heave.
The mounting system shall be certified by UL or another approved testing agency to meet the
requirements of UL Subject 2703.
Contractor shall provide detailed information on the material and design of the mounting
system.
Contractor shall provide a detailed structural analysis of the foundations and demonstrate
that the design conforms to the applicable standards and codes.
Contractor shall demonstrate that the modules will stay attached to the mounting structure
under all environmental conditions specified by applicable codes, by providing wind load
tests (either wind tunnel tests or computational fluid dynamics tests) and structural finite
element analysis tests.
As part of the design review process (50%, 90%), the contractor shall submit all structural
designs and calculations for the mounting system to Owner for review and approval prior to
purchase of any mounting system equipment.
Contractor shall prepare a design to mitigate the effects of corrosive soils on the structural
support system, which includes adding a sacrificial layer to the structural steel members,
galvanizing and/or coating the structural steel members with additional epoxy coating.
The mounting system and modules shall have provisions to be continuously bonded and
grounded to the ground grid system of the array.
Contractor shall install PV modules that comply with all requirements set forth in these
Technical Specifications.
The mounting system shall be able to support a ground coverage ratio between 0.30 and 0.50.
Contractor shall warrant the following:
1. The PV module mounting system, with the PV modules attached thereto, shall be
capable of withstanding all wind and weather conditions defined by the local building
code without damage over its required 25-year operating lifetime.
2. The PV modules shall be installed and attached to the PV module mounting system
according to the specifications and requirements defined by the PV module
manufacturer.
3. The PV modules as installed and attached to the PV module mounting system shall not
be exposed to a loading pressure in excess of the maximum loading pressure rating
specified by the PV module manufacturer, when subjected to any wind and weather
conditions over the entire range defined by the local building code.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 600 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-12
Internal Use Only
2.2.8 Concrete Work
Reinforced concrete structures shall be designed and constructed in accordance with ACI 318,
Building Code Requirements for Reinforced concrete.
Concrete work shall conform to the requirements of ACI 301, Specifications for Structural
Concrete.
Concrete production, proportioning, and placing as well as the formwork, reinforcing, joints
and embedded items, repair, curing, and protection shall all be in accordance with the
applicable ACI standards and specifications.
The testing and frequency of testing shall be provided by Contractor in accordance with the
requirements of the ACI and applicable ASTM standards.
Grout shall be prepackaged, non-shrinking grout requiring water only, suitable for the
service.
Proportioning, mixing, placing temperature, surface preparation, and curing of grout shall be
in accordance with manufacturer’s requirements.
Contractor shall provide the required quality assurance testing.
Minimum concrete strength classes for the various structures shall be as shown in Table 2.2.
Table 2.2. Minimum Concrete Strength Classes
ITEM
MINIMUM ULTIMATE COMPRESSIVE
STRENGTH FC’ (PSI) (AT 28 DAYS)
Sub-grade leveling slab 2,000
Electrical duct bank encasement 2,000
Paving concrete 4,000
Foundations and structural concrete 4,000
Reinforcing bars shall be deformed bars conforming to ASTM A615, Grade 60.
Welded wire fabric shall conform to ASTM A185.
Cement shall be Portland cement conforming to ASTM C150, type as required by soil
conditions.
Aggregates for normal weight concrete shall conform to ASTM C33.
Exposed concrete floors shall have a trowel or broom finish as appropriate for intended use
and be sealed to provide chemical resistance where such exposure is possible.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 601 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-13
Internal Use Only
Concrete mix proportioning shall meet minimum ACI requirements based on exposure and
class.
2.2.9 Steel Work
Steel structures for buildings and equipment support shall be designed, fabricated, and
erected in accordance with ANSI/AISC 360 Specification for Structural Steel Building and
ANSI/AISC 341, Seismic Provisions for Structural Steel Buildings.
Steel structures shall also conform to the applicable ASTM standards, the AWS codes, and the
Research Council on Structural Connections’ Specification for Structural Joints Using ASTM
A325 or A490 bolts.
Materials for structural steel and miscellaneous steel shall conform to the requirements of the
ASTM’s Standard Specification for Structural Steel.
W-shapes and WT-shapes shall conform to ASTM A992 Grade 50.
M-shapes, S-shapes, HP-shapes, L-shapes, and C-shapes shall conform to ASTM A36.
All structural and miscellaneous steel shall be primed with a full 2.5 mils dry film thickness of
an inorganic zinc primer or hot-dip galvanized.
Anchor bolts shall conform to ASTM F1554.
2.2.10 General Structural Welding
The Supplier is ultimately responsible for the qualification of welders or welding operators,
whether his own or his sub-suppliers. Welder or welding operator performance qualification
testing shall be performed under the full supervision and control of Supplier.
The welder and welding operator qualification records shall be available at the shop facility
or construction site and shall be made available to the Purchaser for review when requested.
Owner reserves the right to review and inspect welds. Contractor is responsible for
coordinating the review and inspection of welds with Owner
Fabrication, assembly, and erection shall be in accordance with the applicable AWS code.
Welding shall not be performed when surfaces of the parts to be welded are wet. The parts to
be welded shall be protected from deleterious contamination and from rain, snow, and
excessive wind during welding.
Prior to welding, the weld preparation and adjacent base material surfaces shall be cleaned
and kept free from paint, oil, grease, dirt, scale, rust, and other foreign materials.
Acceptable cleaning solvents include new or redistilled acetone (acetone reclaimed by other
methods shall not be used), alcohol (ethyl, methanol, or isopropanol), methyl ethyl ketone, or
toluene (toluol). Halogenated cleaning solvents shall not be used for cleaning or degreasing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 602 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-14
Internal Use Only
Tack welds that are to remain in the completed weld shall have their stopping and starting
ends prepared by grinding or other suitable means for satisfactory incorporation into the
completed weld. Tack welds that are to become part of the completed weld shall be visually
examined; defective tack welds, including cracked tack welds, shall be removed.
Welded surfaces shall be uniform in width and size throughout their full length. The cover
pass shall be free from coarse ripples, grooves, overlaps, abrupt ridges, and valleys. The
surface condition of the finished welds shall be suitable for the proper interpretation of
nondestructive examination. If the surface of the weld requires grinding to meet the above
criteria, care shall be taken to avoid reducing the weld or base material below the minimum
required thickness.
Fillet weld sizes greater than 5/16 inch (8 mm) shall require a minimum of two weld layers,
except for those fillet weld joints welded with a mechanized or automatic welding process.
Welding slag and spatter shall be removed from all welds.
The responsible Supplier's welding inspector shall perform in-process visual inspections at
suitable intervals during the fabrication and erection process to ensure the applicable
requirements of the referenced code, design specification, and WPS are met. Such
inspections, on a sampling basis, shall be performed prior to assembly, during assembly, and
during welding.
All completed welds shall receive 100 percent VE.
Visual inspection of welds shall be performed prior to any painting, coating, or galvanizing.
Visual weld examination acceptance criteria shall be in accordance with AWS D1.1 or D1.3.
2.2.11 Painting and Coatings
All outdoor structural and miscellaneous structural steel shall be galvanized in accordance
with ASTM A123, ASTM A153, and ASTM A385.
All painting and coatings shall meet a minimum design life of 30 years.
Owner shall review Contractor's galvanization specification and approve all outdoor
structural designs.
Surface preparation shall conform to SSPC-SP5 white metal blasting, with 2-3 mils surface
profile.
A minimum corrosion allowance of 3/32-inch shall be added to both the flange and web of the
steel posts.
For ground-mounted systems, depending on the corrosivity of the soils, additional coatings,
such as high-performance epoxy with inert flake additive/reinforcement, high-performance
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 603 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-15
Internal Use Only
epoxy prime with polyurethane top coat, or inorganic zinc coat with polyamide epoxy and
polyurethane top coat may be required to prevent corrosion.
Contractor shall touchup all paintings and coatings prior to project completion.
2.3 CIVIL, STRUCTURAL AND ARCHITECTURAL INSTALLATION REQUIREMENTS
This Section describes Owner’s requirements for the methods and means of installation for the
Facility.
Contractor is responsible for construction of a fully operational and functional Facility as set
forth in this Specification, unless otherwise approved by Owner.
2.3.1 Site Development and Earthwork
Environmentally and culturally sensitive areas shall be identified and protected during
construction.
Contractor shall comply with permits and instructions from the local AHJs with respect to the
required archeological surveys.
Contractor shall coordinate the grading activity with the onsite Archeologist and Biologist on
a daily basis or as required by the AHJ.
Contractor is responsible for landscaping plans, tree mitigation, floodplain mitigation and
wetland mitigation, if required by the AHJ. Contractor to verify with the Owner the plans and
mitigations prior to construction.
Site grading shall be avoided or minimized wherever possible.
2.3.2 Clearing and Grubbing
Areas to be graded shall be cleared of vegetation as required for proper installation of roads
and electrical equipment.
Additional clearing outside of graded areas may be required to avoid shading of the solar PV
modules.
Grubbing shall be performed to remove organic materials and roots greater than 1 inch thick
to a minimum depth of 6-inches below grade.
In select locations to be identified by the Geotechnical Engineer of record, grubbing to greater
depths may be required.
In select locations individual trees, groups of trees, shrubs or other vegetation shall be
protected during construction as indicated on the drawings or Owner request.
2.3.3 Disposal of Unusable Soils
Where possible, excavated materials usable for fills shall be spread across the Site.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 604 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-16
Internal Use Only
These materials shall be graded so as to not interfere with proper drainage from the Site.
Unused materials shall be disposed of on the Site at a location approved by Owner.
2.3.4 Erosion Control
Temporary facilities shall be provided for control of wind and water erosion and turbid runoff
during earthwork operations and from graded areas until they are stabilized.
Temporary facilities shall be acceptable to local AHJ.
Contractor shall be responsible for obtaining any necessary erosion control and dust control
permits.
Permanent erosion control facilities for surface runoff as required for ditches and and
stormwater control features such as riprap, headwalls, permanent vegetation,, rock surfacing,
and slope pavement shall be provided and be acceptable to the AHJ.
2.3.5 Dust Control
Contractor shall be responsible for dust control during construction operations and shall
adhere to all applicable codes and requirements of the local AHJ.
Water shall be used to control dust as required.
Dust palliatives, if allowed by applicable law and permits shall be used to control dust on all
unpaved roads and any other non-vegetated areas if required by any approved dust control
plans and environmental permits.
2.3.6 Existing Underground Facilities
Contractor shall be responsible for identification, protection, redesign, relocation, or removal
of underground lines, services, obstructions, or other facilities present at the Site.
Contractor shall provide a utility improvement plan to the AHJ, if required.
Contractor shall be responsible for obtaining all existing utility drawings and contacting Miss
Dig a minimum of three business days before earth disturbing activities commence at the Site.
Contractor shall be responsible for inspecting, cleaning, and filling of municipal/county
drains, if applicable
2.3.7 Excavation
All excavations, sheeting, shoring, and temporary excavation support shall be performed in
accordance with OSHA 29 CFR Part 1926 Subpart P, “Excavations.”
The stability of previously constructed structures and facilities shall not be impaired or
endangered by excavation work.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 605 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-17
Internal Use Only
Contractor shall be responsible for dewatering and shoring of excavation Works.
All excavation shall be carried out and supported in such a manner as to prevent flooding or
ponding of water and damage or interference to structure services, or stored
equipment/materials.
The work shall include removing and disposing of unsuitable materials, such as organic
matter, from areas on which fill is to be placed, and excavating and disposing of materials
from area where existing grade is to be raised.
Unsuitable or unmitigated material shall be disposed of properly, as defined by the AHJ and
Owner requirements.
Grading of cuts, fills, and drainage ditches shall be provided in accordance with approved
grading plan.
2.3.8 Grading
Finish grading at the Site shall be sloped to prevent surface pooling and promote surface
drainage away from equipment and structures and to provide drainage.
Grading shall meet the requirements specified by the manufacturer of the module mounting
system.
Under no circumstances shall an increase in storm water rate or quantity be directed toward
adjacent residential areas.
Contractor shall provide the Owner with an as-built survey drawing of grading and drainage
prior to site construction.
2.3.9 Fill
Fill material shall be approved material in accordance with the soils report and suitable for
the intended purpose. It shall not include materials hazardous to health, materials
susceptible to attack by ground or ground water chemicals, materials susceptible to swelling
or shrinkage under changes in moisture content, highly organic or chemically contaminated
materials, rocks larger than three (3) inches, or any other unacceptable materials.
Areas to be backfilled shall be prepared by removing unsuitable materials.
The bottom of excavations shall be examined for loose or soft areas. Such areas shall be
excavated fully and backfilled with compacted fill.
Areas below foundations shall be over excavated to the depth below the bottom of
foundations specified by the Geotechnical Engineer and backfilled with approved engineered
fill.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 606 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-18
Internal Use Only
Areas below pavement shall be over excavated to the depth below the bottom of pavement
specified by the Geotechnical Engineer and backfilled with engineered soil type A-2 or better
(AASHTO Soil Classification System).
Backfilling shall be done in the layers of uniform thickness of six (6) to eight (8) inches or as
recommended by the Geotechnical Engineer.
Soil in each layer shall be properly moistened to facilitate compaction to achieve the specified
density, within -2 percent to +2 percent of optimum moisture content or as directed by the
project’s Geotechnical Engineer.
To verify compaction, representative field density and moisture-content tests shall be
performed during compaction operations.
Granular load-bearing backfill shall be sound, durable coral rock, crushed rock, clean sand,
and/or gravel.
Contractor is responsible for verifying acceptability of excavated soils for fill and for
providing suitable fill material from other sources.
Trench bedding material shall be clean sand, as required.
If suitable for use, Contractor may use excavated material for trench bedding, free of organic
material, compacted in eight-inch lifts, at optimum moisture content of standard proctor
density, or as specified by the Geotechnical Engineer. Bedding material shall be free of rocks
with any single dimension greater than half inch.
Where it is necessary to remove only a portion of the unsuitable materials and backfill, the
backfilling operation shall begin by stabilizing the existing materials to enable proof rolling or
normal construction equipment to operate thereon.
2.3.10 Compaction
Compaction of fill materials shall be carried out as soon as practicable after deposition of fill
materials.
Fill shall be compacted to the densities appropriate to the design requirements, fill type, and
depths of layers.
Structural fill supporting foundations, roads, and parking areas shall be compacted to a
minimum of 95 percent of the modified proctor maximum dry density, in accordance with
ASTM D1557, unless noted otherwise by the project Geotechnical Engineer.
Embankments, dikes, and backfill surrounding structures shall be compacted to a minimum of
95 percent, unless noted otherwise by the project Geotechnical Engineer.
General backfill shall be compacted to at least 90 percent, unless noted otherwise by the
project Geotechnical Engineer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 607 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-19
Internal Use Only
2.3.11 Site Restoration
All Site development areas disturbed during construction shall be stabilized and re-vegetated
with an appropriate MDOT specified seed mixture and restored in accordance with the Site
Grading Plan and Storm Water Pollution Prevention Plan (SWPPP) prepared by Contractor.
All areas occupied by solar modules shall be planted with a grass seed mixture specifically
intended for solar facilities and with a maximum growth height of 24 inches. Existing
vegetation shall be disked or chemically treated to eliminate regrowth and allow the specified
seed mixture to thrive. Minimum vegetation coverage by the specified seed mixture shall be
70% prior to acceptance by the Owner.
Contractor shall submit site restoration plan to Owner for approval.
2.4 TESTING AND INSPECTIONS
A program shall be utilized for testing soils during earthwork and when underground utilities
and foundations are installed.
The program shall include the following:
1. In-place representative field density tests shall be performed, preferably at the
frequencies specified in Table 2.3, in accordance with ASTM D2922.
2. The following frequencies shall be increased in areas where apparent difficulties exist:
Table 2.3. Testing Frequencies
FILL CLASS TESTING AREA FREQUENCY / CUBIC YARDS PER TEST
A Structural Fill and Foundation
Subgrades
250 (or 1600 ft2 of each lift, once per
work shift, or one per foundation,
whichever is more frequent)
B Backfill Surrounding Structures (Same as Class A)
B Roads, Shoulders, and Parking Lots 650
C General Backfill 1800
3. If a compacted area fails to meet the specified compaction requirements, two additional
tests shall be performed for that area.
4. If the results of either of the two additional tests prove unsatisfactory, the area shall
undergo additional compaction and testing until test results meet the minimum
compaction requirements.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 608 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Civil Structural 2-20
Internal Use Only
5. Records of inspection and testing of soils to ensure compliance with design assumptions
shall be turned over to Owner and shall comply with Prudent Industry Practices and the
requirements of applicable Law and the local authority regarding notification and
inspection.
6. Testing and inspections of structures shall be in accordance with the state building
codes and other licensing requirements.
7. Concrete test cylinder sets shall be taken at the minimum rate of one set per day, but not
less than once for each 150 cubic yards for slabs, foundations, or walls.
8. Concrete test cylinder sets for paving shall be taken at the minimum rate of one set per
day, but not less than once for each 150 cubic yards, nor less than once for every 5,000
square feet.
9. As a minimum, one set of cylinders shall be taken for each equipment foundation, with
the exception that one set of cylinders may be made for each concrete truck load where
multiple small foundations are poured from a single load.
10. Test procedures shall be in accordance with the appropriate ASTM standards.
11. Copies of test data shall be provided to Owner.
12. Contractor shall utilize a system to validate type and grade of high-strength bolts by
sampling and metallurgical testing.
13. A testing program of high-strength bolts and nuts shall be conducted by Contractor to
ensure that each bolt shipment meets the appropriate ASTM standards for dimensional
tolerances and material quality.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 609 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-1
Internal Use Only
3.0 Major Equipment
3.1 GENERAL REQUIREMENTS
3.1.1 Facility Operating Noise Level Requirements
Contractor shall provide a Noise Level Study indicating that the Facility will not exceed a
sound level of the lower of 65 dBA or the most restrictive local ordinance during the worst-
case (i.e. when all equipment is in full operation), at any point along the site boundary that
borders a residential structure or property that is designated as residential per local zoning
ordinances.
1. Contractor’s Noise Level Study shall include all site equipment including the local
electric utility provided transformers.
2. Owner shall review and approve this Contractor’s Noise Level Study.
3.1.2 Equipment Certifications
All utility-related items shall be furnished and installed in accordance with Local Electric
Utility requirements. All required equipment certifications shall be verified prior to shipment.
All PV modules shall be listed under UL 1703 for not less than the maximum DC voltage of the
solar PV array.
All Solar PV inverters shall be listed under UL 1741. Inverters designed to operate at greater
than 1,000 Vdc shall also be listed under UL 62109.
All other equipment shall be listed or certified by UL or another Nationally Recognized
Testing Laboratory (NRTL) as required by the applicable AHJs.
3.1.3 Solar PV Field
All equipment specified by Contractor shall be approved by Owner.
Design parameters other than those specified in this document shall be defined by Contractor
and subject to approval by Owner.
PV module row pitch (post-to-post) shall be adequate to allow access for customary
maintenance vehicles, such as a side by side ATV.
PV module strings – groups of PV modules electrically connected in series – shall be designed
in accordance with the inverter manufacturer’s maximum DC voltage input specifications and
applicable code requirements for maximum operating DC voltage.
PV module arrays – groups of PV arrays electrically connected in parallel – shall be designed
in accordance with the inverter manufacturer’s maximum DC current and power input
specifications and applicable code requirements for maximum operating DC current and
power.
The maximum overall DC cable voltage drop shall be 2 percent.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 610 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-2
Internal Use Only
3.2 MAJOR EQUIPMENT REQUIREMENT
3.2.1 Photovoltaic Modules
PV modules shall be designed to produce electricity for a minimum of 30 years under the
environmental conditions of the Site.
All PV modules shall have a minimum wattage rating of 320 W or greater.
The electricity generation capabilities of the PV modules shall meet or exceed the capabilities
defined by the PV module electrical data sheet of the product.
Annual degradation shall be specified by the manufacturer.
PV modules shall comply with the following parameters to ensure maximum quality and
performance.
1. Manufacturer.
a. The PV module manufacturer shall be as agreed upon by Contractor and Owner or
Owner's engineer.
2. All PV modules shall be listed as Tier 1 equipment as described by latest Bloomberg
tiering report (BNEF).Manufacturer Experience.
a. The manufacturer shall have at least five (5) years of experience manufacturing
photovoltaic modules.
3. Manufacturing Capacity.
a. The manufacturer shall have a current minimum manufacturing capacity of at
least 100 MW per year.
4. Specification Sheet.
a. The manufacturer/supplier shall provide detailed electrical and mechanical
specification sheets for the PV module.
b. The manufacturer shall provide the estimated annual degradation of the PV
module and justify the value provided with historical production data.
c. The maximum allowable annual degradation for PV modules used on this Facility
shall be 0.5 percent or less per year.
5. Technology.
a. The cell technology for the PV module shall be crystalline silicon (C-Si).
6. Codes and Standards.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 611 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-3
Internal Use Only
a. PV modules shall be listed under UL 1703 for not less than the maximum DC
voltage of the solar PV array.
i. The certificates of factory/laboratories tests and compliance to the
codes and standards referenced by the manufacturer shall be
provided to Owner.
7. Labeling.
a. The PV modules shall be provided with a permanent label indicating, at a
minimum, the following information:
i. Make/model
ii. Electrical characteristics, including open circuit voltage (Voc); short
circuit current (Isc); maximum power point voltage (Vmpp);
maximum power point current (Impp); nameplate power (W), and
maximum series fuse size
iii. Temperature coefficients of Isc, Voc and nameplate power
iv. Nominal power conditions (e.g. STC, NOCT, etc.)
v. Environmental operating conditions
vi. Compliances with applicable standards (UL, IEC, CE, etc)
vii. Warnings of electrical hazard
viii. Maximum system voltage
ix. Date and location of manufacture, manufacturing code
x. Serial number
PV module Design and Construction.
1. The PV modules shall be new and, in order to maintain the homogeneity of the system,
all cells and PV modules used throughout the Facility shall be supplied by the same
manufacturer, be of the same make and model types, and shall have the same nameplate
power rating.
2. The PV modules shall include factory installed power conductors and connectors.
a. 12 AWG or 4 mm2 copper conductors, rated at 2,000 Vdc, with clearly defined and
labeled polarities, PV WIRE type insulation, weather-proofed, UV
resistant/outdoor rated and with locking-type plug-in connectors of single
polarity with same environmental and electrical ratings as the power conductors.
b. PV module power conductors shall be of sufficient length to directly interconnect
two adjacent PV modules (with 1” separation) in either landscape or portrait
orientation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 612 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-4
Internal Use Only
c. PV module connector shall be listed under UL 6703 for not less than the maximum
DC voltage of the solar PV array.
d. All PV modules shall have the same make and model number connectors.
3. The PV modules shall include a grounding lug, grounding hole, or some other tested
grounding attachment mechanism (applicable for framed PV modules only).
4. Grounding attachment must specifically be approved by the AHJ.
5. The PV module framing, where provided, shall be corrosion-resistant, resistant to
damage from snow, wind, hail and windblown dust and sand.
3.2.2 Required Manufacturer’s Warranties
PV modules, at minimum, shall be supplied with a 10 year defects warranty and a 30 year
performance warranty.
3.2.3 Required Spare Parts
Contractor shall provide an additional 0.1 percent or two pallets, whichever is greater, of the
PV modules installed to be kept as spares.
Contractor shall provide storage on site for these panels in an Owner-approved weather-
proof permanent storage enclosure.
3.2.4 PV Module Mounting System
The PV Module Mounting System shall meet the following specifications:
1. The design specifications for the foundations of the PV module mounting system
("Mounting System") shall be provided by Contractor as part of the mounting system
design specifications.
2. The Mounting System foundation shall be designed to withstand the soil chemistry of
the Site location (ground-mounted system) for a minimum of 30 years without
replacement.
3. The foundation shall be designed to comply with all the environmental conditions of the
Site.
4. The Mounting System shall be designed to withstand wind speeds up to the maximums
specified by applicable codes, over its specified operating lifetime, without
compromising its structural integrity for a minimum of 30 years.
5. The Mounting System and PV modules shall have provisions to be continuously bonded
and grounded to the ground grid system of the array.
a. The Mounting System shall be certified to meet the requirements of UL 2703.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 613 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-5
Internal Use Only
6. The Mount System design shall ensure a minimum of 48” clearance between bottom of
modules and ground, or a clearance to maintain bottom of module above site flood level,
whichever is greater, unless otherwise approved by Owner.
7. The Mounting System shall be designed to be in compliance with the design criteria of
the geotechnical report.
In addition to meeting the requirements of the Mounting System, Contractor shall:
1. Provide detailed information on the materials and design of the Mounting System.
2. Provide a detailed structural analysis of the foundations and demonstrate that the
design conforms to the applicable standards and codes.
3. Demonstrate that the PV modules will stay attached to the Mounting System under all
environmental conditions specified by applicable codes.
4. Ensure that the design of the Mounting System specifies the attachment of the PV
modules to Mounting System in accordance with the mounting specifications provided
by the PV module manufacturer.
5. Submit all structural designs and calculations for the Mounting System to Owner for
review prior to purchase of any mounting system equipment.
a. 50 percent, within 45 days of the Contract being executed
b. 90 percent, within 90 days of the Contract being executed
c. 100 percent, within 115 days of the Contract being executed
6. Contractor shall prepare a design to mitigate the effects of corrosive soils on the
structural support system, which includes adding a sacrificial layer to the structural
steel members, galvanizing and/or coating the structural steel members with additional
epoxy coating as specified in the civil and structural sections of this specification.
7. Provide a detailed description of the method of installation for the Mounting System.
The Tracker system shall meet the following specifications:
1. The Tracker system shall withstand wind speeds up per Idaho Building Code, Exposure
C (project specific) or the maximums specified by applicable codes, whichever are more
conservative, over its specified operating lifetime, without compromising its structural
integrity for a minimum of 30 years.
2. The Tracker system shall operate normally after high wind conditions have been
cleared. Supplier shall provide for backup power if required for wind stowage.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 614 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-6
Internal Use Only
3. For single axis tracker, the system shall provide a tracking range of motion of at least
52°.
4. The Tracker system shall have provisions to be continuously bonded and grounded to
the grounding electrode system of the array.
a. The SAT system shall be certified to meet the requirements of UL 2703.
5. The Tracker system shall provide backtracking capabilities (optional).
6. The Tracker system shall provide communications and control capabilities that will
communicate using a common protocol with commercially available third party plant
monitoring or SCADA systems.
7. The control and communications system shall recover automatically (without human
intervention) from a loss of power event.
8. The control and communications system shall provide for local manual control at the
individual actuator motor level for manual stow and maintenance activities.
9. The Tracker system supplier shall submit all structural designs and calculations for the
Tracker system for review prior to purchase of equipment but only after supplier has
been given a Limited Notice to Proceed. Supplier shall provide structural calculation
package for the Tracker system, including foundation design loads, signed and sealed by
a Professional Engineer in the state of Idaho, to be submitted to the Authorities Having
Jurisdiction (AHJ) for permitting. Supplier is responsible for addressing any comments
and/or questions from the AHJ related to the permitting of the Tracker system and
obtaining permit approval from the AHJ.
3.2.5 Required Manufacturer’s Warranties
The PV module mounting manufacturer shall provide a product warranty of at least 25 years.
3.2.6 Required Spare Parts
All necessary hardware for at least two PV module racks shall be provided as spare parts.
3.2.7 Combiner Boxes
Each combiner shall include a fused connection between all ungrounded DC circuit wiring
from PV strings to provide over-current and short-circuit protection.
The grounded DC circuit wiring from PV strings (if any) shall be connected to a terminal block
and bus bar.
The combiner output circuit (homerun) shall be provided with a load-break disconnect
switch with exterior lockable handle, rated for the voltage and current of the combined PV
strings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 615 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-7
Internal Use Only
The string fuses and fuse holders shall be finger-safe and rated according to the string DC
current and voltage, and environmental conditions.
The power terminal blocks shall be rated for use with copper conductors and rated for
continuous duty at 2,000 V DC and 90°C conductor and terminal temperature ratings.
The combiner shall be equipped with a mechanical ground lug and bus, rated for terminations
with copper grounding conductors.
The combiner enclosure shall be outdoor-rated, weatherproof, fiberglass, NEMA 3R or NEMA
4 or NEMA 4X, and the doors shall be easily interchangeable.
The manufacturer shall supply a fully assembled combiner and shall provide detailed
drawings, specifications sheets, mounting instructions, and maintenance requirements of its
product.
Each combiner shall provide “touch-safe” power circuit terminations and include provisions
for bolted terminations of the output power circuit to the inverter.
Surge protective devices shall be installed at the PV module side of the main disconnect
switch.
Conduit entries into the combiner shall be from the side or bottom to prevent water ingress.
Each combiner shall include a provision for a padlock, including a padlock and key.
1. All padlocks shall be keyed the same.
2. Master Lock 1C444 or as specified by the Owner
The combiner door shall be interlocked with a load-break disconnect switch in such a manner
that the door cannot be opened when the switch is “closed.” In addition, the switch shall not
be capable of being placed in the “closed” position unless the combiner door is fully closed.
1. An external door interlock defeat mechanism shall be provided to allow authorized
personnel access to the interior of the combiner while the switch is in the closed
position for periodic inspection, troubleshooting, and electrical field measurements.
The combiner shall be listed to UL 1741 for not less than the maximum DC voltage of the solar
PV array, and rated for an operating temperature range of -40°C to +50°C.
Each combiner shall be suitable for application of permanent labels in the field and shall
include electrical warning labels.
All information and warnings required by the National Electrical Code sections 690 and 705
shall be provided on a permanent label attached to each combiner.
Arc Flash warning label not to include PPE requirements. The label shall be provided on a
permanent label attached to each combiner.
3.2.8 Required Manufacturer’s Warranties
Combiners shall have a manufacturer’s warranty of at least 5 years.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 616 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-8
Internal Use Only
3.2.9 Required Spare Parts
Contractor shall provide at least 1 spare combiner for every 2 MWac of installed capacity.
Each combiner shall include 4 spare fuses of each size and type.
3.2.10 Recombiner Boxes
Each recombiner shall provide a main DC disconnecting means.
Each recombiner shall be connected directly before the inverter input via throat connection.
Each recombiner shall also meet the following requirements:
1. The recombiner shall be listed to UL 1741 for not less than the maximum DC voltage of
the solar PV array, and rated for an operating temperature range of -40°C to +50°C.
2. Up to 12 input circuits with configurations up to 1200 A
3. Overcurrent protection (fuses or breakers)
4. If fuses are used, load break disconnects shall be provided that meet the provisions of
NFPA702014 (NEC) 690.16(A) and (B) (fuses: disconnecting means and fuse servicing).
5. 90°C rated terminals
6. Continuous duty rated
7. NEMA 3R or NEMA 4 or NEMA 4X
8. Each recombiner shall include a provision for a padlock, including a padlock and key.
9. All padlocks shall be keyed the same.
10. Ground bus
11. As an alternate, provide monitoring of PV output circuit currents.
Each recombiner shall be suitable for application of permanent labels in the field and shall
include electrical warning labels.
All information and warnings required by the National Electrical Code sections 690 and 705
shall be provided on a permanent label attached to each recombiner.
3.2.11 Required Manufacturer’s Warranties
Recombiners shall have a manufacturer’s warranty of at least 5 years.
3.2.12 Required Spare Parts
Each recombiner shall include 4 spare overcurrent protection device of each size and type.
3.2.13 Solar PV Inverters
Inverters shall meet the following requirements:
1. The inverters shall include the necessary DC circuit breakers/disconnect switches, AC
circuit breakers/disconnect switches, local controls, remote SCADA system interface,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 617 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-9
Internal Use Only
grid operator control interfaces, and accessories necessary for the inverter to meet all
code requirements and function properly as part of a power generation facility.
2. The AC disconnect switch if applicable shall be visible for its “open” and “close” position.
3. Environmental ratings: 20° to +50°C (4° to 122°F), Humidity: 15 % - 95%, non-
condensing, 6,500 ft. elevation with derating.
4. >0.99 power factor above 20% rated power and adjustable.
5. Power factor capability at the point of interconnection shall be at least 0.9 leading and
lagging and able to be actively controlled.
6. Power factor capability shall be compliant with the Connection Requirements.
7. Upon preliminary selection of the inverter make and model, Contractor will deliver to
owner a location where this inverter in operation.
a. Inverter manufacturer shall provide access for a site visit at this location by
Owner or Owner’s Representative to perform sound level testing.
b. Inverter must meet sound level requirements prior to proceeding with this
equipment selection.
8. Inverter maximum input voltage shall be 1500 VDC unless otherwise approved by
Owner.
9. Inverters shall be compliant with the most recent IEEE 1547standards.
10. Output current harmonics shall contain <3% total harmonic distortion (THD) at rated
power output, per IEEE 519.
11. Inverter CEC efficiency shall be >97% without medium voltage step-up transformer.
12. Inverters located outdoors shall be enclosed in lockable, NEMA 3R enclosures.
13. Inverters shall be equipped with a ground fault detection and protection system that
meets the requirements of the applicable version of NFPA 70 (NEC) section 690.5.
14. The Supplier's design shall include an analysis of the maximum anticipated operating
temperature to ensure that the manufacturer's recommended operating temperature is
not exceeded.
15. Enclosure shall have a door interlock system to prohibit the door(s) from being opened
while energized.
16. Inverters shall incorporate a non-load break, lockable disconnect switch for main DC
power disconnect for maintenance personnel safety.
17. Inverter output shall be protected by an AC output circuit breaker with short and long
time adjustable over current protection.
18. This circuit breaker shall be externally operated or the inverter shall be equipped with
an external on/off (start/stop) switch.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 618 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-10
Internal Use Only
19. Inverters shall be capable of rated output at 40°C ambient or higher without derating.
20. Inverters shall employ a maximum power point tracking (MPPT) scheme to optimize
inverter efficiency over the entire range of PV panel output for the given Site design
conditions.
21. Inverters shall be equipped with all hardware for data collection and communication to
the central SCADA server, including the ability to write to the control registers to reset
inverter and modify AC output parameters, including power factor and maximum
power.
22. Data collection points shall be integrated into the inverter monitoring and
communications package with DNP3 protocol.
23. DC input shall have monitoring capability via DNP3.
24. Data collection points included shall be (at a minimum):
a. AC Voltage
b. DC Voltage
c. AC Current
d. DC current
e. Real Power (kW)
f. Reactive Power (kVAr)
g. Apparent Power (kVA)
h. Energy (kWh)
i. Alarms
j. Inverter status and faults (including ground fault interrupts)
k. Met Station data
3.2.14 Required Manufacturer’s Warranties
The inverter manufacturer shall provide a warranty of at least 5 years.
3.2.15 Required Spare Parts
If a repair is needed, the manufacturer shall provide the necessary spare parts and assume
responsibility for the repair service under the warranty.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 619 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-11
Internal Use Only
3.3 INSTALLATION REQUIREMENTS
3.3.1 Photovoltaic Modules
PV modules shall be provided with the following information:
1. The PV module manufacturer shall provide results from flash testing of PV modules
being provided.
2. This flash test shall be conducted with an AM1.5G calibrated solar filter to approximate
the sun’s true spectral distribution following ASTM E927-97(1997) Class A and IEC-
904-9 ANSI standards and be made available to the Owner in electronic, CSV format.
3. The results of the flash test shall include, at a minimum, the following measured values:
Isc, Voc, Impp, Vmpp, and Pmpp, solar irradiance and cell temperature.
4. The flash test data shall also include the PV module serial numbers and associated pallet
numbers.
5. PV modules shall be shipped and delivered in clearly identified bins that indicate the
number of PV modules and nominal power per PV module with a manifest of each serial
number contained within.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
3.3.2 PV Module Mounting System
The PV module mounting system shall be installed in accordance with the Mounting System
manufacturer’s written installation instructions.
The PV module mounting system shall be installed to meet the following requirements:
1. The PV modules as installed and attached to the PV module mounting system shall not
be exposed to a loading pressure in excess of the maximum loading pressure rating
specified by the PV module manufacturer, when subjected to any wind and weather
conditions over the entire range defined by the local building code.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
3.3.3 Recombiner and Combiner Box
Adequate room for wiring slack shall be provided inside of each combiner to allow for both
PV module string wiring and PV output cable electrical voltage and current field
measurements.
Contractor shall secure combiners such that the centerline is 48 inches above grade, unless
otherwise accepted by the Owner.
Contractor shall install combiners to be plumb and level.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 620 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Major Equipment 3-12
Internal Use Only
Contractor shall permanently secure combiners on unistrut, piperack, pile, steel pier, or any
other suitable means of permanent attachment, subject to the approval of the Owner.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
3.3.4 Solar PV Inverters
Inverters shall be installed in accordance with the equipment manufacturer’s installation
instructions.
Contractor shall coordinate with inverter manufacturer to perform commissioning of the
inverter when back-feed power is available.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 621 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-1
Internal Use Only
4.0 Collection System
4.1 ELECTRICAL DESIGN AND EQUIPMENT REQUIREMENTS
4.1.1 Inverter AC Disconnect Switches
Disconnect switches shall meet the following requirements:
1. Voltage and continuous current ratings as specified on the drawings.
2. Three-pole.
3. NEMA 3R, 4, or 4X rated enclosure as specified on the drawings.
4. Operating handle whose position is easily recognizable and which can be locked in the
OFF position with multiple padlocks.
5. The ON and OFF positions shall be clearly marked.
6. The disconnect door shall be interlocked with the switch in such a manner that the door
cannot be opened when the switch is “closed.”
7. An external door interlock defeat mechanism shall be provided to allow authorized
personnel access to the interior of disconnect while the switch is in the closed position
for periodic inspection and troubleshooting.
8. NEMA rated.
9. UL listed.
4.1.2 Junction Boxes
Junction boxes shall meet the following requirements:
1. Indoor boxes (larger than switch, receptacle, or fixture type) and gutters shall be
constructed of galvanized steel.
2. Outdoor boxes shall be NEMA 3R, 4 or 4X as required with removable interior panel and
removable front, finished inside and out with manufacturer's standard enamel.
3. Bolt-on junction box covers 915 mm (3 feet) square or larger or heavier than 11 kg
(25 pounds) shall have rigid handles.
4. Covers larger than 915 by 1220 mm (3 by 4 feet) shall be split.
5. Boxes shall be sized in accordance with the minimum requirements of the National
Electrical Code.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 622 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-2
Internal Use Only
4.1.3 Concrete Pull Boxes
Concrete pull boxes shall meet the following requirements:
1. Pre-cast reinforced concrete body.
2. Pre-cast reinforced cover.
3. Extensions, as necessary.
4.1.4 Low Voltage Dry-Type Transformers
Low voltage dry-type transformers shall meet the following requirements:
1. KVA, voltage and number of phases as indicated on the drawings.
2. Transformers shall have copper or aluminum windings.
3. Transformers shall be air-cooled, dry type, wall or floor mounted, self-ventilated and
shall be class AA.
4. Transformer enclosures shall be NEMA 3R, 4, or 4X as specified on the drawings.
5. Transformers shall have a minimum of four 2-1/2 percent taps, two full-capacity above
normal (FCAN) and two full-capacity below normal (FCBN).
6. Transformers shall be UL listed.
7. Transformers shall emit sound no greater than 40 dBA, under any operating condition.
a. If a transformer emits sound greater than 40 dBA, supplier shall provide a means
of reducing the sound level to the required level
4.1.5 Low Voltage Panelboards
Low voltage panelboards shall meet the following requirements:
1. Panels shall be designed and constructed to NEC and NEMA requirements and
standards.
2. Panels shall be UL listed.
3. Panelboards shall be dead front with molded case circuit breakers of the size and type
as specified on the drawings.
4. Panelboards shall be of voltage, current and phase ratings as indicated on the drawings.
5. Panelboards shall have a surface-mounted enclosure.
6. Enclosures shall be NEMA 1 for installations indoors, or NEMA 3R, 4 or 4X for
installations outdoors as specified on the drawings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 623 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-3
Internal Use Only
7. The enclosure shall have a hinged trim (cover).
8. Breaker operating handles shall be accessible via latched, lockable doors.
9. Circuit breakers shall be thermal magnetic, bolt-on and shall indicate "On," "Off," and
"Tripped” positions.
10. Breakers with multiple poles shall be common trip.
11. Breakers shall have interrupting ratings as specified in the drawings and, if not
specified, not less than 10kilo amperes.
12. Handle clips to prevent casual operation of breakers shall be provided for 10 percent (at
least two) of the breakers and applied to the circuits directed.
13. Breakers and provisions for future breakers shall be provided in the quantities, number
of poles, and ampere ratings indicated on the drawings.
14. The panel shall have copper phase, ground and neutral buses with ratings as specified
on the drawings.
15. The panel shall have main lugs only or main circuit breaker as indicated on the
drawings.
16. Surge protection devices (SPD) shall be included as indicated on the drawings.
17. Panelboard designed as distribution panel shall equip visible disconnect switch to
identify the open and close position of the switch.
4.1.6 Medium Voltage, Pad-Mounted Transformers
This section covers compartmented, tamper-resistant, weatherproof, medium voltage, pad-
mounted transformers. Transformers shall be designed, constructed, and tested in
accordance with the applicable standards of ANSI C57, ANSI C57.12, NEMA, UL, and NEC, with
the following list of specific standards.
Medium voltage, pad-mounted transformers shall meet the following requirements:
1. Labeling and signage requirements:
a. A nameplate with unit description shall be provided on the interior and exterior of
each transformer.
b. An instruction nameplate shall be mounted in the low-voltage compartment and
shall be readable with cables in place.
c. All doors giving access to high-voltage parts shall be posted with DANGER - HIGH
VOLTAGE - KEEP OUT signs.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 624 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-4
Internal Use Only
d. The signs shall be constructed of heavy gage aluminum, with red letters on a white
background.
2. Transformers shall be rated for step-up operation with the direction of nominal power
flow originating from the low voltage windings to the high voltage windings.
3. Transformer high voltage winding configuration shall be as indicated on the drawings
and shall be compatible with the inverter(s) to be connected to the transformer.
4. Transformer low voltage winding configuration shall be as indicated on the drawings
and compatible with the inverter(s) to be connected to the transformer.
5. Transformer secondary low voltage winding configuration shall have two or more
windings if necessary for galvanic isolation as required for the inverter(s) to be
connected to the transformer.
6. Frequency shall be 60 Hz.
7. For multiple transformers to be connected in a daisy-chain configuration transformer
primary windings shall be loop type with feed-through inserts, integral fused disconnect
switch and surge suppression as shown on the drawings.
8. The transformer shall be completely enclosed, with one high-voltage and one low-
voltage compartment door.
9. The high-voltage side and low-voltage side compartment door shall be equipped with
interlocking mechanism.
10. The enclosure shall be of tamper-resistant design.
11. The low-voltage compartment door shall have a 3-point latching mechanism with vault
type handle and provisions for a single padlock.
12. If the low-voltage compartment contains exposed live parts the transformer shall be
equipped with a removable protective insulating barrier to allow the low-voltage
compartment door to be opened while the transformer is energized.
13. The doorsills shall be removable to permit the transformer to be rolled or skidded into
place over conduit stubs.
14. A tank-grounding pad shall be furnished in each compartment.
15. Transformer shall be self-cooled type with less-flammable liquid-insulated type
(KNAN).
16. Transformers shall meet efficiency standards set forth in the Department of Energy
“Energy Conservation Program for Commercial Equipment: Distribution Transformers
Energy Conservation Standards; Final Rule,” latest edition.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 625 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-5
Internal Use Only
17. Transformers shall be rated for inverter source operation.
18. The average temperature rise of the windings, measured by resistance, shall not exceed
65°C when the transformer is operated at rated kVA output at an average ambient
temperature of 40°C or maximum site temperature, whichever is higher, over 24 hours,
with a maximum of 50°C.
19. The primary winding shall have four 2 1/2 percent fully rated taps, two above and two
below rated voltage.
20. The transformer tank shall be of sealed construction, with a welded cover.
21. The tank shall have provisions for installation by lifting, jacking, or rolling into position.
22. The transformer shall be equipped with a liquid level indicator; a pressure gauge; a
temperature gauge; a pressure relief device; and standard provisions for filling,
draining, and sampling. The oil sampling valve and pressure relief device shall be
designed outside of electrical compartment so that operating of these devices will not
require opening the transformer compartment door.
23. The high-voltage terminations and equipment shall be dead-front type conforming to
ANSI C57.12.26.
24. Dead-front construction bushings shall be either universal bushing wells or one-piece
integrated bushings for use with separable connectors.
25. Six bushing wells shall be provided with ratings as shown on the drawings.
26. Bushings shall be externally clamped and front removable.
27. Each bushing shall have an adjacent parking stand.
28. Transformer primary fuse and disconnect switches shall be furnished to isolate the
transformer in case of an internal fault.
29. The transformer and switch configuration shall be designed for loop feed.
30. Switches shall be internal, liquid-immersed four-position load break type.
31. Switches shall be rated at 600 A continuous.
32. Bayonet type fuses shall be provided and shall be liquid-immersed, expulsion fuses
accessible through the primary compartment.
33. The fuses shall be removable for external replacement of fuse links using a hot-stick tool
without disassembly of the primary cabinet.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 626 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-6
Internal Use Only
34. The low voltage bushings shall be of molded epoxy, and shall be provided with blade-
type spade terminals with NEMA standard hole spacing arranged for vertical takeoff.
35. The low voltage neutral shall be an insulated bushing, grounded to the tank by a
removable link.
36. Each transformer shall have alarm contacts for the following conditions: oil level, oil
pressure, and temperature. Terminal blocks for external connection shall be mounted in
the low voltage compartment of the transformer.
37. All iron and steel surfaces, except stainless steel and machined surfaces, shall be shop
painted with the manufacturer's standard coating to a minimum thickness of 3 mils.
38. Finish color shall be ANSI 61 for indoor and outdoor equipment.
39. A sufficient quantity of additional coating material and thinner shall be furnished to
permit field touchup painting of damaged coatings. Contractor shall be responsible for
any touchup painting of damaged coatings prior to final completion.
40. All standard factory tests required by the ANSI/IEEE C57.12.90 standard shall be
performed.
41. Completed test reports shall be provided.
42. Transformer shall utilize a coal tar corrosion resistive coating, or equivalent, on the
bottom 3 inches of the transformer base flanges.
4.1.7 Medium Voltage Switchgear
Medium voltage switchgear shall meet the following requirements:
1. Medium voltage switchgear shall be metal-clad or metal-enclosed of the configuration,
size and type as specified on the drawings.
2. Switchgear shall conform to the applicable standards of the IEEE C37.20 series,
ANSI/IEEE C37.100.1, NEMA SG4 and, SG5 and other relevant ANSI and IEEE C37 Series
standards, UL, and NEC.
3. Nameplates:
a. A master nameplate shall be attached to the switchgear giving switchgear
designation, voltage and ampere rating, short circuit rating, manufacturer's name,
general order number and item number.
b. Each circuit breaker and instrument on the front of the switchgear shall have a
suitable nameplate.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 627 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-7
Internal Use Only
c. Each control device and each control wire terminal block connection inside the
units shall be identified with permanent nameplates or painted legends to match
the identification on the manufacturer's wiring diagram.
4. Frequency rating shall be 60 Hz.
5. Switchgear enclosure shall be NEMA 1 for indoor locations, or NEMA 3R, 4 or 4X as
indicated on the drawings for outdoor locations.
6. The lock for the enclosure shall be placed minimum 36 inches above grade level.
7. Switchgear lights, receptacles, heaters, and fans shall be served by an integral control
power transformer.
8. The switchgear assembly shall consist of individual vertical sections housing various
combinations of circuit breakers and auxiliaries, bolted together to form a rigid metal
clad switchgear assembly. Metal side sheets shall serve as grounded barriers between
adjacent structures.
9. The switchgear shall equip visible disconnect switch and observation window to
identify the open and close position of the switch.
10. Circuit Breakers:
a. The circuit breakers shall be three-pole, single-throw, and shall be furnished
complete with all equipment on a draw-out carriage.
b. The breakers shall be operated by a stored energy mechanism consisting of a
heavy-duty spring, charged normally by a universal electric motor, and, in an
emergency, by a manual handle.
c. Each circuit breaker shall contain three vacuum interrupters, separately mounted
in a self-contained, self-aligning housing which can be removed as a complete unit.
d. Each vacuum interrupter shall be provided with a contact wear gap indicator
which requires no tools to indicate available contact life, and is easily visible when
the breaker is withdrawn on the extension rails.
11. Bus:
a. The main bus shall consist of rigidly supported, tin-plated copper bars of suitable
design and cross-sectional area to satisfactorily carry the rated current without
exceeding the specified temperature rise.
b. Bus supports shall be glass polyester inserts.
c. The bus shall be capable of withstanding the magnetic forces imposed by short-
circuit currents equal to the close and latch rating of the largest circuit breakers.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 628 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-8
Internal Use Only
d. The current-carrying capacity shall be based on actual service conditions, including
skin and proximity effect, insulation, steel enclosure, and an ambient temperature of
40°C.
e. The bus shall be de-rated in accordance with NEMA SG 5 for ambient temperatures
higher than 40°C.
f. The bus shall be supplied in unit lengths that will permit the reassembly of the units
in the field.
12. Grounding:
a. An uninsulated ground bus of tin-plated high conductivity copper, with
momentary and short time ratings at least equal to those of the largest circuit
breaker shall be furnished through the entire length of the switchgear.
b. A clamp type connector shall be provided on each end of the ground bus for
external connection of a maximum 500 kcmil [240 mm2] stranded copper
grounding cable to the grounding system.
c. Provide a grounding disconnecting device between each circuit breaker
removable element and the equipment ground bus which shall maintain contact at
all times, except when the primary disconnecting devices are separated at a safe
distance.
13. Auxiliary Contacts:
a. Each breaker shall be furnished with a sufficient number of auxiliary contacts and
auxiliary switch contacts to provide all necessary interlocks for proper operation
of the equipment.
b. Not less than two spare NO and two spare NC auxiliary contacts shall be furnished
on each breaker.
c. All auxiliary contacts and auxiliary switch contacts, including spare contacts, shall
be wired to terminal blocks for use with control circuits.
14. Potential Transformers and Current Transformers:
a. Insulated cable connections shall be furnished for the potential transformers and
control power transformers.
b. The thermal and mechanical ratings of the current transformers shall be
coordinated with the circuit breakers. Shorting terminal blocks shall be furnished
on the secondary of all current transformers. Current transformers rated 600
amperes and smaller shall be of the wound type, with tin-plated primary
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 629 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-9
Internal Use Only
terminals and insulated to withstand ANSI standard test voltages for the
switchgear.
c. The accuracy of these current transformers shall be suitable for the meters and
relays specified with the normal burdens of the various devices, and not less than
ANSI standard accuracy classification of 0.3 with burdens B 0.1 and B 0.5, and 1.2
with burden B 2.0.
d. A compartment enclosed by metal plates shall be provided to house separately the
current transformers in each unit.
e. Metal barriers shall isolate each current transformer from other component parts
and adjacent circuits.
f. Potential and control power transformers shall be supplied in the quantities and
of the ratings specified herein or specified on the drawings.
g. Potential or control power transformers up to 15 kVA single phase shall be
mounted in a drawer or a tilt-out carriage in an auxiliary compartment.
15. Opening the drawer shall ground the primary fuses of the transformer and permit easy
inspection, testing, and fuse replacement.
16. Shutters shall isolate primary bus stabs when drawers are withdrawn.
17. All circuit breaker control switches mounted on the front instrument panels shall be
equipped with red, amber, and green indicating lights.
18. Green lights shall indicate breaker trip and shall be wired in series with a breaker
auxiliary normally closed contact and control switch slip contacts, so the light will not
be energized when the breaker is operated by the control switch.
19. Each electrically operated breaker shall be provided with a two-pole control power
disconnecting and protective device in the closing circuit and another in the tripping
circuit.
20. The disconnecting and protective device shall be either a molded-case circuit breaker or
an enclosed fuse pullout.
21. Additional control devices shall consist of auxiliary relays and switches, control wiring
and operating mechanism required for the particular breaker, an operation counter, a
manually operated trip bar or lever, and provisions for manual closing.
22. Switchgear protective relays shall be of the draw-out type in a semi-flush mounting
case, with test switches and devices incorporated in the relay unit.
23. Relays shall have hand reset indicators.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 630 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-10
Internal Use Only
24. Relays shall have low burden, microprocessor based circuitry and shall meet or exceed
ANSI/IEEE standards.
25. All settings shall be stored in non-volatile memory.
26. Relays shall be manufactured by Schweitzer, or Owner-approved alternate.
27. Microprocessor based metering and protection units shall be capable of monitoring and
displaying values of phase amperes, phase voltage, watts, VARs, power factor,
frequency, watt-hours, and watt demand shall be provided where shown on Drawings.
28. The protection functions shall include voltage phase loss, current phase loss, phase
voltage unbalance, phase voltage reversal, over voltage and under voltage.
29. The protection functions shall comply with all ENEE, CREE, and CND requirements.
30. Microprocessor based multiphase and ground, instantaneous and time overcurrent
relay (devices 50/51 and 50N/51N) shall have programmable trip parameters (time
curve, time dial, timed pickup and instantaneous) accessible from the front of the unit.
31. Fault records for at least four faults shall be stored in memory for use in trouble-
shooting and system analysis.
32. A lockout relay(s) (device 86), shall be wired to trip and close-block the bus tie and the
associated incoming feeder breakers.
33. Owner Metering sections shall consist of a sheet steel enclosed stationary cubicle of
sufficient width to provide the specified spacing and clearance required by the owner.
34. Utility Metering sections shall be included if required.
35. Control wiring shall terminate in approved, molded, screw type terminal blocks.
36. All secondary and control wiring within the high voltage compartment shall be
completely shielded in a protective grounded metal covering and shall be stranded.
37. A separate direct current power system shall be provided for the control circuits and
shall have ample capacity for the control functions indicated and shall be maintenance-
free, lead-calcium alloy grid type assembly in polypropylene – heat sealed case,
complete with inter-cell connectors and electrolyte.
38. The DC system shall provide 125 volts direct current for operation of the circuit
breakers and any controls deemed necessary for the safe operation of the switchgear in
accordance with all codes.
39. The battery system shall consist of individual cells with all interconnections, mounted
on a rack suitable for Seismic for the seismic condition of the area they are to be
installed.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 631 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-11
Internal Use Only
40. The battery rack shall be painted with two coats of acid-resistant paint before assembly.
41. The batteries shall have a minimum 240 ampere-hour capacity unless otherwise needed
for the equipment as shown on the drawings.
42. The battery system shall be sized in accordance with IEEE Standard 485. Calculations
shall be based on a 2-hour outage of the battery charger system with all the breakers
tripping at the end of the 2-hour period.
43. The battery system shall be provided with complete hardware and software, Battery
Monitoring System capable of automatically monitoring, displaying, recording all the
battery parameters.
44. The charger shall be static type silicon rectifier with no moving parts and shall be
equipped with automatic regulation and provision for adjusting the charging rate.
45. The output voltage shall be maintained within 1 percent from no-load to charger rated
output amperes with AC input voltage variation of plus or minus 10 percent and input
frequency variation of plus or minus 5-Hz.
46. Output voltage shall be provided with a suitable filter to allow the charger to be used as
a DC power supply without battery.
47. The charger shall have sufficient capacity in order to provide the following:
a. Supply the steady state load and float charge the battery between 2.20/2.24 volts
per cell.
b. Supply periodically and equalizing charge at 2.33 volts per cell.
c. Supply the load demand without being connected to batteries
d. Recharge the batteries from a 20 percent discharge condition to 80 percent of
capacity within 2 hours.
48. Special tools, instruments, and accessories required for proper maintenance; and
special devices for lifting or handling shall be furnished. The following accessories shall
be supplied with the metal-clad switchgear.
a. One set of special wrenches or tools required for installation, operation, or
maintenance of the equipment.
b. One test cabinet with test jumper for testing breakers out of the housing, for
mounting on the wall, and wired for a power source separate from the switchgear
control bus.
c. One breaker lifting device and transfer truck for moving the circuit breaker into
and out of the breaker housing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 632 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-12
Internal Use Only
d. One set of extension rails.
e. One maintenance closing lever for closing the circuit breakers.
f. One manual operating lever for moving the breaker element into and out of the
operating position.
g. One set of test plugs suitable for testing the relays.
4.1.8 Lightning Protection
Lightning protection shall be determined in accordance with risk calculations included in
NFPA 780-2014 using lightning flash density maps, or as specifically required by Owner.
Lightning protection with traditional air terminals shall be provided atop the following
structures, as applicable:
1. Inverter/transformer canopies
2. Inverter walk-in enclosures
3. Control building
4. Meteorological Stations.
5. Other similar structures
Lightning protection equipment shall be either Class 1 or Class 2, depending on the height of
the structure to be protected in accordance with NFPA 780 or UL 96.
Lightning protection equipment shall include, but not be limited to, the following:
1. Air terminals
2. Air terminal supports
3. Main conductor
4. Bonding conductor
Air terminals or other strike termination devices shall not be secured directly to the PV
modules or the module mounting system.
Lightning protection equipment design and installation shall comply fully with the applicable
requirements of NFPA 780-2014 Chapter 12.
All lightning protection equipment shall be UL listed.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 633 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-13
Internal Use Only
4.1.9 Raceways
Contractor shall design, provide, and install a complete electrical raceway, duct bank, or
trench system as required by applicable codes and as specified herein.
Contractor shall separate conductors by voltage as required by applicable codes and
standards.
Cables supported in free air as approved by the NEC are acceptable for installation of module
wiring and harnesses to the combiner boxes as applicable. Fencing will be required to ensure
not-readily accessible for the site.
Conduits shall be as specified in Section 4.1.11.
Conduit entrances shall be sealed.
4.1.10 Conduit
4.1.10.1 Rigid Metallic Conduit
A. RGS conduit shall meet the following requirements:
1. Hot dipped galvanized, corrosion resistant
2. Listed to UL 6 and UL 514B
3. Conform to ANSI C80.1
4. Fittings shall be threaded type and watertight
5. Used above grade or concrete encased
4.1.10.2 PVC Schedule 40 and Schedule 80 Conduit
A. PVC Schedule 40 and Schedule 80 conduit shall meet the following requirements:
1. Sunlight and UV Resistant
2. Listed for UL 651
3. Conform to NEMA TC-2
B. PVC Schedule 40 conduit can be used below grade.
C. Ridged galvanized conduit shall be used to transition from below grade to above grade and
in locations exposed to physical damage. Schedule 80 shall not be used without Owner
approval.
4.1.10.3 Liquid-tight Flexible Metallic Conduit (LFMC)
A. LFMC conduit shall meet the following requirements:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 634 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-14
Internal Use Only
1. Hot dipped galvanized steel core
2. Flame retardant PVC jacket
3. Sunlight or UV resistant
4. Moisture and oil resistant
5. Listed to UL 360
B. Fittings shall be threaded type and watertight.
C. Shall be used above grade only and only where specifically allowed in these specifications.
4.1.11 Grounding Systems
Owner Grounding Specs shall be considered in the grounding design. The contractor shall compare
the information in this section to the Owner Grounding Specs. The more stringent requirement
shall prevail in the design.
A. All grounding systems shall be designed and provided as required by NEC, NESC, IEEE, and
local code requirements.
B. All grounding systems shall comply with the following:
1. Ground loops shall be provided under/around major electrical equipment.
2. The grounding system shall consist of bare copper conductor and copper-clad steel
as indicated on the drawings.
3. The system shall be designed to protect personnel and equipment at the Facility
from the hazards that occur during power system faults and lightning strikes.
4. For ground grids below grade, each junction of the grid shall be bonded with
exothermic weld.
5. Major items of equipment such as inverters and transformers shall have integral
ground buses connected to the grounding electrode system.
6. Contractor shall route a grounding conductor parallel to all power conductors
operating above 50 volts.
7. The module DC system grounding electrode(s) shall be common with, or bonded to,
the AC grounding electrode as indicated in NEC Article 690.
8. All metal framed modules shall be grounded to meet the requirements of applicable
codes and UL subject 2703.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 635 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-15
Internal Use Only
9. Module grounding shall be in compliance with module manufacturer
recommendations for grounding.
4.1.12 Power and Control Wiring
4.1.12.1 General
A. Cables shall be selected with an insulation level applicable to the system voltage for which
they are used and ampacities suitable for the load being served.
B. The type of cable used shall be determined by individual circuit requirements, temperature,
and individual equipment manufacturer’s recommendations.
C. Current carrying conductors shall be copper only.
D. All exposed wiring shall be clearly indicated as sunlight or UV resistant.
4.1.12.2 DC Power Cable
DC conductor in grounded and underground systems over 600V shall be listed and
identified as 1000V or 2000V rated PV wire. The conductors shall meet the requirements of
UL4703 and UL 854. The conductor shall be rated 90 degree C for wet or dry locations and
be sunlight resistant.
DC conductors in ungrounded systems shall be rated for the voltage noted on the drawing.
The wire type shall be rated as sunlight resistant PV wire, insulated or jacketed with cross
linked polyethylene (XLPE)
The conductor shall be stranded copper or aluminum.
4.1.12.3 Low Voltage AC Power Cable
A. Copper conductor.
B. All power and control cables shall be UL listed.
C. Cables shall be routed in UL listed wireway, conduit, direct buried PVC conduit, or
underground duct banks, as required.
D. A maximum of 2 percent average ac voltage drop is acceptable in other ac circuits not
associated with solar power production.
E. Less than 600 V ac applications:
1. Cable insulation levels shall be rated 600 V.
2. Conductors installed in PVC conduit are acceptable.
3. Low voltage power cables for loads up to 480 volts ac and control cables (i.e., 120
volts ac) shall have copper conductor with 600 volt class insulation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 636 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-16
Internal Use Only
4. Power cables shall be Type XHHW-2 with concentric-lay, uncoated copper, strand B
conductor, rated for normal maximum operating temperature of 90°C in wet and dry
applications, cross-linked thermosetting polyethylene insulation, and conforming to
ICEA S-95-658 (NEMA WC 70).
F. Between 600 V ac and 1000 V ac applications:
1. Cable insulation levels shall be rated 1000 V or higher.
2. Conductors installed in PVC conduit are acceptable.
3. Insulation and jacket materials on all conductors, regardless of location, shall be made
from thermoset materials such as XLPE. No thermoplastic insulation or jacket
materials are permitted for conductors. Cable insulation type shall be rated for wet
locations, and have a temperature rating of 90° C or better.
4.1.12.4 Medium Voltage AC Power Cables
Medium voltage cable shall be rated for voltage noted on the drawings. Typically 15 kV, 25 kV
and 35 kV. The cable shall be suitable for environment in which they are to be installed.
The cable shall be rated 90 or 105 degrees C for normal condition, 140 degrees C for
emergency overload operation and 250 degrees C for short circuit condition.
The conductor shall be class B compress soft or annealed copper. Conductor shall meet
electrical resistance requirement of UL 1072.
The conductor shield shall be an extruded layer of black-colored, semi conductive ethylene
ethyl acrylate copolymer resin having allowable operating temperatures equal to or greater
than those of the insulation.
The insulation shall be discharge – free no lead EPR, white colored flexible thermosetting
dielectric based on an ethylene propylene elastomer.
The insulation shall be an extrude semi-conductive ethylene vinyl acetate copolymer resin.
A copper tape shall be included over the semi-conductive thermosetting material. The overall
jacket shall be black no lead polyvinyl-chloride.
Termination kits shall be cold shrink stress control and outer insulation tubes along with
stress relief mastic and rain shields if required.
Splices are not allowed without Owner’ written approval.
Ground shields of cables at terminations. Ground metal bodies of terminators, cable, and
separable insulated connector fitting and hardware.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 637 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-17
Internal Use Only
Ground concentric conductors of shielded cable as shown on the drawings. Maintain shield
continuity and connector to metal connector hardware at all connection points.
4.1.12.5 Control System Cables
Control cables shall include those used for:
1. System control, alarms, contacts, etc.
Shall be Type THHN/THWN 600 volt rated with stranded, uncoated copper conductor, rated
for normal maximum operating temperature of 90° C dry and 75° C wet applications,
polyvinyl chloride insulation, jacket thickness of 4 mils minimum, and conforming to ICEA S-
95-658 (NEMA WC 70) and UL 83.
4.1.12.6 Analog Instrumentation Cables
Analog instrumentation cables shall meet the following requirements:
1. Twisted Shielded Pair type
2. No less than16 AWG seven-strand
3. Concentric-lay
4. Uncoated copper conductor
5. Rated for normal maximum operating temperature of 90° C dry and 75° C wet
applications
6. Polyvinyl chloride insulation not less 15 mils average thickness
7. Twisted pair of 1-1/2 inch to 2-1/2 inch (38.10 mm - 63.5 mm) lay
8. Shield consisting of combination aluminum-polyester tape and seven-strand
9. 20 AWG minimum tinned copper drain wire
10. With shield applied to achieve 100 percent cover over insulated conductors
11. Jacket thickness of 4 mils minimum
12. Conductor color identification with one black conductor and one white conductor
13. Conforming to UL 62 for Type TFN, and UL 1277 for vertical-tray flame test
requirements.
4.1.12.7 Fiber Optic Cables
Fiber optic cable shall meet the following requirements:
1. 12 strand minimum multimode OM4
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 638 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-18
Internal Use Only
2. Single armor (corrugated steel tape), single jacket when installed in conduit
3. Black polyethylene inner and outer jacket.
4. Nominal wall thickness of 0.06 inches.
5. Overall water swellable barrier tape with 25 percent overlap
6. Tensile load (installation) of 600 lbs.
7. Minimum bending radius 20 times cable diameter
8. Operating temperature -40 °C to 70 °C
9. Wet location sunlight resistant
4.1.12.8 Category 6 Cables
Category 6 cable shall meet the following requirements:
1. Sunlight, oil, and gas resistant.
2. Industrial grade.
3. Solid copper conductor.
4. Polyolefin insulation.
5. Black PVC jacket, 0.03 inches.
6. UL listed.
7. Operating temperature of -25° C to 75° C.
8. Cat6 or higher is also acceptable.
9. Wet location sunlight resistant
4.1.13 GFCI Receptacles
Ground fault circuit interrupting (GFCI) receptacles shall meet the following requirements:
1. Duplex type.
2. 125 volts.
3. 20 amperes.
4. Differential tripping at 5 mA.
5. NEMA configuration 5-20R.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 639 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-19
Internal Use Only
6. Interrupting rating of 1,000 amperes without damage.
7. 12 AWG copper TW wire insulated pigtails.
8. Conform to NEMA WD 1.
9. UL listed.
4.1.14 Light Switches
Light switches for standard lighting systems shall meet the following requirements:
1. 120 or 277 volts.
2. 20 amperes.
3. Screw terminals.
4. One-way or three-way switches, as required.
5. Totally-enclosed.
6. AC type.
7. Quiet tumbler.
8. Suitable for 100 percent tungsten filament or fluorescent lamp loads.
9. Weatherproof, gasketed enclosure
10. High conductivity copper.
11. Operating handles color selected by Owner.
12. Conform to NEMA WD 1.
13. UL listed.
4.1.15 Site Lighting
Site lighting shall be provided at the following locations:
1. Main system entrance
2. Entry doorways to all buildings
3. As an option, at all inverter / transformer pads.
Site lighting shall meet the following requirements:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 640 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-20
Internal Use Only
1. Site lighting shall include light fixture, mounting poles, lighting controls, etc., as
applicable.
2. Light fixtures shall be suitable for outdoor locations.
3. Light fixtures shall be light emitting diode (LED) type and shall meet dark sky
requirements if applicable to local codes and standards.
4. All site lighting equipment shall be UL listed.
5. Lighting control shall consist of a HAND-OFF-AUTO switch.
6. Photocells shall be used for automatic control.
7. Photocells shall be weatherproof, swivel adjustable, with built-in time delay to prevent
accidental turnoff by momentary brightness.
8. Photocells shall be rated at 1800 VA, 120 volts ac.
9. Photocells shall be field adjustable from 1 ft./c turn-on to 15 ft./c turn-off.
Interior lighting shall be provided for all buildings and structures as applicable, to include
emergency and exit lights with battery backup.
4.2 INSTALLATION REQUIREMENTS
This Section describes Owner’s requirements for the methods and means of installation of the Solar
PV Collection System for the Facility.
Contractor is responsible for construction of a fully operational and functional Facility as set
forth in this Specification.
4.2.1 Lightning Protection
The lightning protection system shall be installed per NFPA 780, and UL 96A.
The lightning protection system shall be installed per the applicable standards and the
National Electrical Code, including NFPA 780-2014 chapter 12.
4.2.2 Raceways
Conduits shall be installed as follows:
1. RGS only in any exterior application unless specified otherwise below.
2. LFMC for short runs of less than 3 feet to combiner if approved in advance by Owner.
3. PVC schedule 40 for underground and direct buried conduit.
4. RGS for above ground application or place exposed to physical damage.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 641 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-21
Internal Use Only
5. Raceway shall be concrete-encased where subject to vehicle traffic, as shown on the
drawings.
6. Conduit, trench, and raceway sweeps and radius bends shall conform to the NEC for
each type of conduit and size, as applicable
7. Conduit couplings that transition from one type of conduit to another shall be
watertight and compatible with all materials in contact with the couplings
8. Trenching shall be required to meet all applicable codes and standards including IEEE
399 and 142, and minimum cover per the NEC and NESC.
9. Only clean, screened, sand or native backfill less than ½ inch diameter, free of any rocks
and debris which are capable of harming cable jacketing shall be permitted for back-
filling of trenches within 4 inches of direct buried conduit.
10. Backfill between 1 and 2 inches in diameter may be used for the remainder up to
finished grade, compacted to 95 percent minimum.
11. Underground duct banks subject to vehicular traffic shall be concrete-encased, 3000 psi
minimum, with PVC schedule 40 conduits buried at the depth required for direct buried
conduits. Underground duct banks shall be dyed red.
12. Direct buried conductors shall not be utilized.
13. Conduit shall be used to route lighting, telephone, and communication circuits where
installed above grade.
14. All raceway fittings in outdoor locations shall be rain-tight compression type, unless
specified by Engineering in Record.
15. Where conduit terminates in a cabinet or box, the conductors shall be protected by an
insulating bushing. The insulating fitting shall be suitable for bonding to ground in
accordance with NEC 250.92.
4.2.3 Grounding Systems
All materials required for a complete grounding installation shall be furnished.
Grounding components shall include ground rods, ground conductor, ground bus, above and
below grade grounding connections, grounding lugs, and any other hardware required for a
complete grounding system.
Grounding shall be compliant with NEC, IEEE 80, and local AHJ.
Suitable grounding facilities shall be furnished on electrical equipment not so equipped.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 642 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-22
Internal Use Only
The grounding facilities shall consist of irreversible compression type terminal connectors
bolted to the equipment frame or enclosure.
The conduit and raceway system are not considered to be a grounding conductor.
No equipment grounding conductor shall be smaller in size than 12 AWG unless it is a part of
an acceptable cable assembly.
All metallic equipment shall be connected to the equipment grounding network using
appropriate bushings or other connectors.
All metallic raceway shall be bonded at both ends of the raceway.
Metallic raceway shall not be relied upon as the sole equipment ground connector. All circuits
shall have a green or bare equipment ground conductor installed in the same raceway or
trench.
4.2.3.1 Ground Rods
Ground rods shall be copper clad manufactured in accordance with UL 467 or approved by
owner
The copper cladding shall be electrolytically bonded to the steel rod or bonded by a molten
welding process.
Individual ground rods shall be 3/4 inch diameter and 10 feet long.
Stainless steel ground rods shall be installed where soils conditions are considered to be
corrosive upon owner approval.
4.2.3.2 Conductors
Not required.
4.2.3.3 Bus Bars
Not required.
4.2.3.4 Compression Connection
Compression style lugs and terminations shall be rated for the maximum DC and AC voltage of
the system.
The fitting must be pre-filled with oxide inhibitor.
Wire stripping and brushing of conductor in accordance with vendor specs is required
immediately prior to lug installation.
Oxide inhibitor shall be applied to exposed conductor immediately after stripping and
brushing and immediately prior to installation of the lug.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 643 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-23
Internal Use Only
Used compression tool listed for use with selected compression connector.
A minimum 9 inches length of cold or heat shrink with a voltage rating equal to conductor
shall be applied to cover the connection between crimp and the conductor beginning at the
straight section of the crimp.
All connectors and corresponding crimping tools shall be UL listed for their specific
application.
4.2.3.5 Exothermic Connections
Exothermal connections shall be a standard duty copper molten weld conforming to the
requirements of IEEE 80.
Molds and powder cartridges used for making exothermal connections shall be furnished by
the same manufacturer.
Exothermal connections shall be similar to Type CADWELD as manufactured by Erico, or an
equivalent approved by Owner.
4.2.3.6 Ground Lugs
Ground lugs shall be two-hole type. Single-hole type (technical documentation required) can
be used upon approval by Owner. The ground lugs shall be compliant with NEC based on the
application, and compliant with the commissioning criteria for dissimilar metals.
Copper bars conforming to the requirements of IEEE 837 and UL 467.
Ground lugs used with the exothermal weld process shall be similar to Type LA as
manufactured by Erico, or an Owner acceptable equal.
Ground lugs used with the compression process shall be similar to Type YGHA as
manufactured by Burndy Electrical, or an Owner acceptable equal.
4.2.3.7 Grounding Installation
Grounding system components shall be installed as required by IEEE, NEC, NESC and
applicable local codes.
4.2.4 Power and Control Cabling
4.2.4.1 Cable Installation
Cable installation shall be in accordance with the following general rules:
1. The contractor shall provide a demo DC cable management plan on site. The proposed
DC cable management plan shall be approved by Owner prior to site-wide installation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 644 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-24
Internal Use Only
2. Cables shall be installed in accordance with the cable manufacturers' recommendations,
circuit lists, raceway lists, the drawings, and these Technical Specifications and Scope of
work.
3. Each circuit shall be assigned a unique number.
4. Cables shall be separated by voltage as required by NEC, regulation, and AHJ
requirements.
5. All cable supports and securing devices shall be installed to provide adequate support
without deformation of the cable jackets or insulation.
6. Oversized sunlight resistant nylon wire ties shall be utilized for bundling conductors for
all exposed wiring.
7. Wire ties shall be snug but allow for thermal expansion.
8. Contractor shall identify both ends of the circuits with number and color-coding
matching the drawings.
9. Contractor shall also identify all circuits at manholes and hand-holes.
10. Insulation should be color-coded and incorporated into a wire schedule.
11. All exposed wiring shall be neatly bundled so that exposed wiring is securely fastened.
12. PV string steel wire clips can be used upon Owner approval.
13. Exposed wiring running along metal surfaces shall be secured to prevent rubbing and
damage from the metal surface or wire tie.
14. Maximum spacing of 24 inches on center between fastening locations shall be such that
secured wiring is not free to move due to wind, snow, or other environmental
conditions.
15. Use insulating foam spiral wrap, or other means to prevent contact with exposed bolt
threads and sharp surfaces.
16. Phase tape shall be applied to each conductor at the terminations of all power and
lighting circuits that are not already properly color coded.
a. Green or bare copper shall be used for ground at every voltage level.
b. Phase taping circuits shall not be required if cable with colored insulation is
installed.
17. All energized conductors, connectors, and parts shall not be readily accessible
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 645 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-25
Internal Use Only
Table 4.2.1 Insulation Color Chart (Per Owner Approval)
CIRCUIT COLOR CODE
208Y/120 V Circuits Black –Phase A
Red – Phase B
Blue – Phase C
White –Neutral
480Y/277 V Circuits Brown –Phase A
Orange – Phase B
Yellow – Phase C
Gray/White -Neutral
4160V Circuits and Above Black –Phase A
Red – Phase B
Blue – Phase C
DC Circuits (Negatively Grounded System)Black - DC Positive
White – DC Negative
DC Circuits (Positively Grounded System)White –DC Positive
Black –DC Negative
DC Circuits (Floating System) Red –DC Positive
Black –DC Negative
Cable placement shall be in accordance with the following general rules:
1. Cable shall not be handled when the temperature is below the minimum temperature
recommended by the manufacturer.
2. If cable heating is required prior to placement, the cable shall be stored in a heated
building in accordance with the manufacturer's recommendations for at least 24 hours.
3. Cable shall be placed the same day it is removed from heated storage.
4. The pulling tension of any cable shall not exceed the maximum tension recommended
by the cable manufacturer.
5. Pulling mechanisms of both the manual and power types used by Contractor shall have
the rated capacity in tons clearly marked on the mechanism.
6. If any excessive strain develops, the pulling operation shall be stopped at once and the
difficulty determined and corrected.
7. Cable shall not be pulled using trucks, forklifts, cranes, or other devices where the
tension of the cable pull cannot be easily controlled.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 646 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-26
Internal Use Only
8. Cable Grips: When pulling loops are used, the entire loop shall be cut off, discarded and
recycled when the pull is completed.
9. Inspection: The outside of each cable reel shall be carefully inspected and protruding
nails, fastenings, or other objects which might damage the cable shall be removed.
10. A thorough visual inspection for flaws, breaks, or abrasions in the cable sheath shall be
made as the cable leaves the reel, and the pulling speed shall be slow enough to permit
this inspection.
11. Damage to the sheath or finish of the cable shall be sufficient cause for rejecting the
cable.
12. Cable damaged in any way during installation shall be replaced.
13. Cable Bends: Tape shielded, flat tape armored, and wire armored cable shall not be bent
to a radius of less than 12 times the overall cable diameter.
14. All other cables shall not be bent to a radius of less than eight times the cable diameter.
15. Spare Conductors: All spare conductors of a multi-conductor cable shall be left at their
maximum lengths for possible replacement of any other conductors in the cable.
16. Each spare conductor shall be neatly dressed for future use and marked as "spare
<<number>>”.
17. Lacing: UV rated ties shall be used to neatly lace together conductors entering
switchboards and similar locations after the conductors have emerged from their
supporting raceway and before they are attached to terminals.
18. Cable Identification
a. Both ends of all circuits listed in the circuit list shall be identified with a circuit tag.
b. Each marker shall bear the number of the circuit according to the Circuit List and
drawings.
c. At terminations, Contractor shall identify each circuit.
d. Each phase of multiphase power circuits shall be individually identified.
e. The circuit tag shall be so attached that it is readily visible for circuit identification.
4.2.4.2 Direct Buried Cables
None
4.2.4.3 Connectors
This Section defines methods of connecting cable between electrical systems and equipment.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 647 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-27
Internal Use Only
In this section, the term "connector" is applied to devices that join two or more conductors or are
used to terminate conductors at equipment terminals for the purpose of providing a continuous
electrical path.
Connectors shall be installed as follows:
1. Connector material shall be compatible with the conductor material to avoid the
occurrence of electrolytic action between metals.
2. All medium voltage and low voltage connectors shall be pressure type and secured by
using a crimping tool.
3. The tool shall produce a crimp without damage to the conductor, but shall ensure a firm
metal-to-metal contact.
4. The tool should be calibrated and approved by the manufacturer.
5. Low voltage terminations shall be permitted to be screw-down lugs where only screw-
down lugs are available, such as molded case circuit breakers and control/instrument
terminal blocks.
6. Medium voltage cables require stress cones at the termination of the cables.
7. Stress cones shall be of the preformed type suitable for the cable to which they are to be
applied.
8. Cables shall not be spliced.
9. Joints and connections in cable other than cable terminations at equipment shall not be
made.
10. Ring type connector shall be used for control wire.
4.2.4.4 Fiber Optic Cables
Contractor shall install fiber-optic cable and terminations as specified and in accordance with
the cable and equipment manufacturer's recommendations.
All fiber-optic accessories required for a complete installation shall be supplied and installed
by Contractor.
Examples of fiber-optic accessories include fan-out kits, end connections, dust caps, cleaving
tools, polishing equipment, etc.
Fiber-optic cable furnished may be 62.5 micron multi-mode, 50 micron multi-mode.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 648 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-28
Internal Use Only
4.2.4.5 Required Experience
Contractor personnel performing fiber-optic work shall be certified to perform termination
for fiber-optic work, and shall use the connectors, tools, or other special equipment by the
same Contractor as the equipment being installed.
Contractor shall furnish all required special tools.
Dust caps shall be installed on any un-terminated fiber-optic connectors.
4.2.4.6 Redundancy
A minimum of two spare fibers shall be terminated at each patch panel.
3 loops of the extra fiber cable at each end.
4.2.4.7 Splicing
Splicing of fiber-optic cables shall not be allowed.
4.2.5 Site Lighting
Site lighting fixtures shall be installed in accordance with the equipment manufacturer's
installation instructions.
Lighting fixtures shall be installed plumb and level and aimed as specified on the drawings, as
applicable.
4.2.6 Low Voltage Dry-Type Transformer
Low voltage dry-type transformers shall be installed in accordance with the equipment
manufacturer's installation instructions.
Mount transformers approximately where indicated on the drawings.
Load any vibration isolators external to the unit properly and provide complete isolation with
no direct transformer unit metal in contact with the mounting surface.
Connect electrical circuits to transformers by means of moisture proof, flexible metallic
conduit in a manner that prevents transformer vibrations from being transmitted to the
building or other equipment.
Ground neutrals (when required) and enclosures of all transformers and all moisture proof
flexible conduits in accordance with applicable codes and as otherwise may be indicated.
Connect voltage taps on all transformers to give as close as possible to rated output voltage
under normal system load conditions.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 649 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-29
Internal Use Only
4.2.7 Low Voltage Panelboards
Low voltage panelboards shall be installed in accordance with the equipment manufacturer's
installation instructions.
Mount panelboards securely where indicated, plumb, in-line, and square with walls.
Unless otherwise indicated, mount panelboard with top of its cabinet approximately 6-feet
above the finished floor.
Provide a typewritten circuit directory under a metal-framed transparent plastic cover inside
each panelboard.
Provide an engraved, laminated plastic nameplate on the outside of the panelboard showing
the panelboard designation, voltage, and phases.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
4.2.8 Medium Voltage Pad-Mounted Transformers
Medium voltage, pad-mounted transformers shall be installed as specified on the drawings.
Transformers shall be installed in accordance with the equipment manufacturer’s installation
instructions.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
4.2.9 Medium Voltage Switchgear
Medium voltage switchgear shall be installed in accordance with the equipment
manufacturer’s installation
All equipment requiring anchor bolts shall be provided with the anchor materials, complete
with bolts, nuts, and washers.
Sills and anchor materials shall be shipped ahead of the scheduled equipment delivery to
permit installation before concrete is placed.
The anchor bolts shall be designed for continued operation following a seismic event.
Anchor bolt calculations shall be provided and be signed/sealed by a Structural Professional
Engineer.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 650 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-30
Internal Use Only
4.2.10 GFCI Receptacles
GFCI receptacles shall be installed in accordance with the equipment manufacturer's
installation instructions.
Mount receptacles with grounding slot down except where horizontal mounting is indicated,
in which case mount with neutral slot up.
Ground receptacles to boxes with grounding wire, not by yoke or screw contact.
Mount weatherproof receptacles with the hinge for the protective cover above the receptacle
opening.
GRCI design shall be individual connection. Daisy chained design is not acceptable.
4.2.11 Light Switches
Light switches shall be installed in accordance with the equipment manufacturer's
installation instructions.
Mount switches for switch operation in the vertical position.
4.2.12 Disconnect Switches
Disconnect switches shall be installed in accordance with the equipment manufacturer's
installation instructions.
Mount switches for switch operation in the vertical position.
Mount the associated surge protective device in accordance with the equipment
manufacturer's installation instructions.
Mount the device so that the indicating panel is in the upright vertical position and can be
easily seen.
Use the conductors supplied with the surge protective device.
Do not extend the length of the conductors for the surge protective device.
Contractor shall clean debris off equipment by wiping down with a damp cloth. Contractor
shall touchup rust spots.
4.2.13 Equipment Location Tolerances
Equipment shall be located within +/- 0.5 inch of the dimensional location indicated on the
drawing unless otherwise permitted by Owner.
Some equipment is indicated schematically without dimensions.
Contractor shall coordinate the location of this equipment with all other equipment or
materials to be installed.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 651 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-31
Internal Use Only
4.2.14 Alignment
Rigid components such as bus, bus duct, throat connections, and enclosures shall be aligned
and connected with special care to prevent excessive stress in joints, supports, and
connections.
Correct "spacing" hardware necessary for "turning" of field assemblies, usually tracker
dampener shocks shall be used.
4.2.15 Bolted Electrical Connections
Where bolted connections are made between copper or brass surfaces, the metal surfaces
shall be thoroughly cleaned and coated with a suitable anti-oxidizing compound.
It shall be Contractor's responsibility to certify that the tightness of each bolt in all bolted
electrical connections is in accordance with the manufacturer's recommendations and the
NEC.
Factory bolt torques shall be verified as part of the equipment checkout and test procedures.
Mark with torque scribe lines.
Bolted electrical connections shall be tightened with manual torque wrenches.
Torque wrenches shall be constructed and calibrated, so that they will visually or audibly
indicate when the proper torque is reached.
Mark with scribe lines.
The tightened bolts in electrical connections shall be checked at random; 10 percent of the
connections shall be reviewed and documented.
Contractor shall be responsible for coordinating the checking of bolt tightness, so that
minimum interference with equipment installation and connections will be experienced.
If 1 percent of the 10 percent samplings fail, all connections should be re-torqued and
witnessed.
4.2.16 Equipment Finishes
Surfaces of most electrical equipment, such as panels, switchgear, transformers, and circuit
breakers are finished at the factory.
Care shall be exercised to prevent damage to this original finish during equipment installation
and during construction work.
If factory finish is damaged during the course of construction, the damaged component shall
be touched-up or refinished to the satisfaction of Owner, at no additional cost to Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 652 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-32
Internal Use Only
Refinishing paint, if furnished with the equipment, may be used; otherwise the paint shall be
obtained from the equipment manufacture.
Procedure for paint application should be in accordance with the manufacturers'
recommendation, including surface preparation and application of a primer coat.
4.3 EQUIPMENT TESTING
4.3.1 Ground System Testing
All ground resistance measurements shall be made with the Fall of Potential or slope methods
as defined in IEEE 81.
After connection of ground rods to the ground system, Contractor shall obtain a ground
resistance measurement from a selected location on the grounding electrode system, using
methods approved by Owner. The racking grounding resistance shall be less than 25 ohms
and the grounding grid around the transformer, service rack, major electrical gear, etc., shall
be less than 5 ohms.
This data shall be obtained, identified, and recorded.
The ground resistance measurement data may indicate that additional ground rods are
required.
Contractor shall furnish, install, and connect additional ground rods as necessary.
4.3.2 Electrical Testing
Contractor shall provide a third party electrical testing firm to perform testing of the
electrical installation.
Electrical testing firm shall perform electrical testing in accordance with NETA Acceptance
Testing Specifications (ATS) procedures and test forms.
Electrical testing field test personnel shall have a minimum of five years of experience
performing the type of electrical tests, as required.
Electrical testing shall include, but not be limited to, the following equipment:
1. All electrical cables, including
a. Low voltage AC power cables
b. Medium voltage AC power cables
c. Auxiliary power cables
d. Control cables
e. Analog Instrumentation cables
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 653 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-33
Internal Use Only
f. Fiber optic cables
2. Grounding systems
3. Dry-type transformers
4. Pad-mount transformers
5. Pad-mount switchgears
6. Panelboards
7. Relays
8. Metering devices
4.3.3 Testing
Contractor shall provide field-testing of all wire, cable, electrical devices and equipment, and
electrical systems delivered and installed at the Facility.
The following items shall be performed, and procedures shall be followed:
1. Test protocol and forms shall conform to NETA Acceptance Testing Specifications.
2. Contractor shall prepare and submit an electrical testing plan to Owner for review and
approval.
3. Owner shall be informed in writing a minimum of three days in advance of all scheduled
testing in order to witness any such electrical testing.
4. Written records of all electrical tests showing date of test, test equipment used,
personnel making test, equipment or material tested, tests performed, and results,
including any deficiencies found shall be created and maintained by Contractor and
shall be submitted for review by Owner.
5. All test reports shall include nameplate data of equipment being tested.
6. All tests on electrical equipment and systems shall be undertaken as directed by the
manufacturer's field service representatives.
7. Contractor shall provide all necessary test equipment, labor, materials, and
subcontracted testing services.
8. Contractor shall be responsible for any damage to equipment or material due to
improper test procedures or test apparatus handling, and shall replace, or restore to
original condition at Owner's discretion, any damaged equipment or material, at no
additional cost to Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 654 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-34
Internal Use Only
9. Contractor shall provide and utilize safety devices during electrical testing including
rubber gloves and blankets, protective screens and barriers, barricade tape, danger
signs, etc., to adequately protect and warn personnel in the vicinity in which tests are
being undertaken.
4.3.3.1 After Placement
Preoperational tests shall be performed on insulated conductors after installation, as follows:
1. Low voltage cables shall be either insulation resistance tested before connecting to
equipment or functionally tested (at equipment operation voltage) as part of the
checkout of the equipment and/or system.
2. Insulated conductors shall be continuity tested for correct conductor identification.
3. Direct buried cable shall be tested prior to and following backfill.
All circuits, including lighting circuits, shall be tested with the circuit complete except for
connections to equipment.
All splices, stress cones on shielded cable, and terminal connector attachments shall be
complete prior to testing. All splicing kit, tracking vault, protection jacket, and splicing
coordinates shall be approved by Owner prior to installation.
Splice technician shall have experience in cable splicing of given voltage class and shall
provide certificate of qualifications.
In addition to the tests performed after cable placement is complete, continuity tests shall be
performed on all supervisory and communication cable before and after each splice is made.
Any circuit failing to test satisfactorily shall be replaced and then retested, at no additional
cost to Owner.
All equipment and labor required for testing shall be furnished by Contractor.
4.3.3.2 Identification Testing
Identification tests shall include all tests necessary to confirm that the conductor being
investigated originates and terminates at the locations designated in the Circuit List or
indicated on the drawings.
4.3.3.3 Insulation Resistance Testing
All cables rated less than 5000 volts shall be insulation resistance tested, including:
1. Low voltage AC power cables
2. Medium Voltage power cables
3. Dry-type transformers
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 655 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-35
Internal Use Only
4. Pad-mount transformers
5. Pad-mount switchgears
Medium voltage power cable rated higher than 5000 volts shall be tested for Very Low
Frequency (VLF) cable testing.
Insulation resistance testing shall be performed with a 1000-volt megger or an equivalent
testing device.
Insulation resistance measurements shall be made between each conductor and ground and
between each conductor and all other conductors of the same circuit.
The minimum acceptable resistance value shall be 500 megohms.
4.3.3.4 Continuity Testing
Continuity tests shall include all tests necessary to confirm that each conductor is continuous
throughout its entire length.
4.3.3.5 Category 6 Cable Testing
All insulated conductors of communication cable shall be tested for continuity.
High performance cable certification shall be performed for the permanent link configuration
and documented for all CAT6 cables.
Testing shall be accomplished with a Level II (CAT6e) compliant test set with a minimum
spectral frequency range of 1 to 100 MHz (CAT6e).
The test specifications for all installed cables shall meet or exceed the specifications for
CAT6e cabling, respectively, that are documented within the TIA/EIA-568-B.2.
Cables not achieving a PASS rating shall be corrected and re-certified.
Cables that cannot achieve a PASS rating shall be replaced and re-certified.
A rating of *PASS (marginally pass) or *FAIL (marginally fail) is not acceptable.
4.3.3.6 Fiber-Optic Testing
As a minimum, all testing shall conform to the requirements of ANSI/TIA/EIA-568B, optical
fiber link performance testing, and TIA/EIA-526-14A, end-to-end attenuation testing.
Contractor shall submit test documentation to Owner that includes the circuit number, type of
test, date of test, test results, etc.
In addition, Contractor shall submit installation, termination and as-built documentation to
Owner as follows:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 656 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Collection System 4-36
Internal Use Only
1. Circuit installation documentation shall include circuit number; origin and destination;
routing; cable type, size, length; date of installation, etc.
2. Circuit termination documentation shall include circuit number; equipment termination
locations; date(s) terminated; etc.
3. Modifications to the fiber-optic routing, if any.
4. Locations and details of any splice points not included in original Design
Documentation, if any.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 657 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-1
Internal Use Only
5.0 HV Substation (If Applicable)
5.1 GENERAL
Conceptual Collection Phase System Substation system one-line diagram and general arrangement
drawings are included in the Master Appendix List. The Contractor is responsible for verifying the
assumptions and completing the design.
Contractor shall engineer, procure and construct one (1) substation (voltage levels dependent on
POI) including all grading and excavation work, crushed rock surfacing, foundations, ground grid,
control building, bus work, bus supports, breakers, switches, station auxiliary transformer, surge
arrestors, lightning protection, instrumentation and relays, programming, testing, and
commissioning in accordance with Section 4 and 5. Such substation shall be at the location
identified in the Master Appendix List.
The Collection System Substation shall be an outdoor air-insulated conventional utility
substation.
The Contractor shall procure equipment and services from reputable manufacturers or
subcontractors who have supplied similar equipment and services for at least eight (8) years in the
United States of America with proven designs, manufacturing and quality control processes and
who are ISO registered, certified and compliant and accept Owner witness testing. All equipment to
be used in the Collection System Substation shall be new and shall be subject to review and
approval by Owner for compatibility with the existing electric system and ensure that the Collection
System Substation can be operated safely, reliably and economically by Consumers operations and
maintenance personnel.
It is the responsibility of the Contractor to protect the materials and equipment against
damage and theft until the Owner accepts the project.
The information provided herein shall be the minimum requirements for the engineering, design
and installation of the substation. The Contractor shall be responsible for the complete design and
supply of the fully functional Collection System Substation in accordance with the Agreement and
the applicable standards and requirements.
5.2 DESIGN AND INSTALLATION REQUIREMENTS
5.2.1 Codes and Standards
The Collection System Substation shall be designed and installed to meet or exceed the
requirements of the latest revisions of the National Electric Safety Code (NESC), American National
Standards Institute (ANSI), Institute of Electrical and Electronic Engineers (IEEE) and all other
applicable industry standards organizations that are applicable to electric utility substations and
equipment included therein. The design and installation of the Collection System Substation shall
comply with all federal, state and local regulations and codes and the specific requirements of the
interconnecting utility. The Collection System Substation as designed and installed shall allow for
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 658 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-2
Internal Use Only
safe operation and maintenance of the facility in accordance with MIOSHA and OSHA regulations
and Owner’s operating policies and procedures.
5.2.2 Arrangement
The arrangement of the Collection System Substation shall provide for access by personnel,
equipment, and vehicles as required to operate, inspect, maintain, repair and replace all substation
equipment and materials. Whenever practical, the arrangement shall also allow the safe
maintenance of equipment while the remainder of the Collection System Substation remains
energized.
The arrangement design shall incorporate sufficient cutouts for maintenance and NERC required
protective relay testing to be performed while the Collection System Substation is energized.
Cutouts shall include CT, VT and a common cutout switch for relay inputs and outputs.
5.2.3 System Voltage
5.2.4 The Contractor shall determine the appropriate system voltage for the facility.
Electrical Clearances
Preferred normal and minimal electrical clearances from energized parts shall be in accordance
with the latest editions of IEEE, ANSI, NEC, and NEMA.
5.2.5 Noise Study
Contractor shall provide a noise study for the Collection System Substation demonstrating less than
45 dBA at the property line.
5.3 EQUIPMENT AND MATERIALS
5.3.1 Bus Conductors and Fittings
Collection System Substation buses shall be rigid. Each bus and all equipment connection
conductors shall have a rated ampacity at least as great as that of the connected equipment and as
required to carry the maximum load over the life of the facility.
Hot line taps (aluminum extension studs) shall be installed on a per phase basis for grounding
purposes on all exiting bus structures.
Flexible connections for all equipment supplied shall be provided as required, ensuring continuity
of service during thermal expansion or contraction, vibration and seismic activities. Contractor
shall design the Collection System Substation buses in accordance with IEEE 605, IEEE Guide for
Design of Substation Rigid-Bus Structures. Owner shall review the Collection System Substation
bus design and calculations.
5.3.2 Main Power Transformer
The main power transformers will be provided by the Owner. Specifications for the main power
transformers are included in the Master Appendix List.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 659 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-3
Internal Use Only
Contractor shall review and verify that equipment vendors’ (e.g. main power transformer)
drawings and documentations are appropriate for the successful interconnections and equipment
arrangements.
Contractor shall inspect and receive equipment and materials delivered to the job site to ensure
that the equipment and materials are undamaged and are in compliance with specifications.
Contractor shall off load (in a timely manner to avoid demurrage) and install the Collection System
Substation transformer and develop Crane Management Plan for the Work including the
maintenance, inspection, and pre-lift requirements. Contractor shall supply a Critical Lift Plan for
each critical piece of equipment; the Critical Lift Plan shall include PE stamped drawings and
calculations for the specific piece of equipment and crane type. Crane Management Plan shall be
provided to Owner for review and acceptance. Copies of the Crane Management Plan and each
Critical Lift Plan shall be included in the Job Books.
The list of Owner-furnished engineering drawings and specifications for the Collection System
Substation transformers are in the Master Appendix List. Transformer manufacturer
representative shall be present during the offloading and installation process. Contractor’s scope
does not include assembly, dressout, and acceptance testing of main transformers.
Contractor shall submit transformer energization plans to Owner for review fourteen (14) days
before energization, and coordinate energization with Owner. Owner shall authorize Contractor to
proceed before Contractor proceeds with the energization.
The transformer foundation containment pit shall be filled with river stone and include any
MIOSHA required handrail, if applicable (on the substation transformer foundations and oil
containment vault) to provide convenient access to the instruments and control equipment on the
transformer.
5.3.3 HV Circuit Breakers
HV circuit breaker shall match circuit breakers as specified in the Master Appendix List unless
otherwise approved by Owner.
5.3.4 HV Disconnect Switches
HV disconnect switches shall match HV disconnect switches as specified in the Master Appendix
List, unless otherwise approved by Owner.
5.3.5 High Voltage (HV) and Medium Voltage (MV) Surge Arresters
Medium Voltage (MV) Surge Arresters shall be station class metal-oxide, polymer housing arresters
with appropriate voltage and energy ratings. Contractor to match Surge Arrestor manufacturer as
specified in the Master Appendix List unless otherwise approved by Owner.
5.3.6 MV Circuit Breakers
MV breakers shall match the Master Appendix List unless otherwise approved by Owner
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 660 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-4
Internal Use Only
Medium voltage circuit breakers shall include an integrated grounding switch if on a Wye circuit in
accordance with Section 4.1.11.
Contractor shall provide permanent working platforms for MV Circuit Breakers to allow for
maintenance and operation of the equipment without use of a ladder.
5.3.7 MV Disconnect Switches
Disconnect switches shall match Master Appendix List or Owner approved alternate.
5.3.8 Instrument Transformers
5.3.8.1 Current Transformers
Relaying type current transformers shall have ANSI standard ranges and accuracy classification..
Relaying type current transformers shall have a thermal rating of 2.0 for all ratios. The thermal
rating shall be shown on the current transformer nameplate.
Revenue metering type current transformers shall have ANSI standard ranges and accuracy
classification of 0.3 at a minimum burden of 1.5. For dual ratio metering current transformers, both
ratios shall meet the accuracy and burden requirements. Revenue metering type current
transformers shall have a minimum rating factor of 2.0 for all ratios. The thermal rating shall be
shown on the current transformer nameplate.
All current leads shall be wired to the terminal blocks. Terminal blocks shall be States NT type
blocks with sliding links. Splices in the current transformer secondary leads are not acceptable.
The current transformers shall be shorted and tied to a ground reference at the terminal blocks
during shipment.
Current transformer sets shall be identified with polarity markings and secondary lead
designations as specified by NEMA SG 4.
Current transformer housing covers that prevent birds from building nests in or on the current
transformer shall be supplied as necessary.
The following shall be provided: complete ratio, accuracy, burden, thermal factor, and secondary
resistance information on all current transformers furnished with the circuit breaker. This
information shall include excitation and ratio correction factor curves for each type of current
transformer furnished. When revenue metering CT's are supplied, metering accuracy tests for each
CT unit are required including a ratio and angle correction chart over the normal IEEE meter CT
testing range in addition to relay accuracy tests (saturation and ratio) are required. Also when
revenue metering CT's are supplied, tracking paperwork that identifies which bushing the CT is in
is required. Certified factory test reports shall be provided for all CT’s supplied.
5.3.8.2 Potential Transformers
The electrical characteristics and mechanical features of the equipment supplied shall be capable of
meeting all the requirements specified within the latest revisions of ANSI C57.13. Certified factory
test reports shall be provided for all PT’s supplied.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 661 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-5
Internal Use Only
5.3.8.3 Automatic Voltage Regulator
The Contractor’s design shall incorporate Automatic Voltage Regulation (AVR). Contractor shall
submit the AVR for Owners approval and shall install any hardware necessary for a functional
system.
5.3.9 Switchboards
Switchboards shall match equipment manufacturers and shall be provided in accordance with the
specification included in Master Appendix List.
5.3.10 Metering
Contractor shall install high side revenue metering for the Solar PV farm at the substation in
accordance with the interconnection requirements included in the Master Appendix List. Owner
shall supply Meter for Contractor installation.
5.3.11 Reactive Power Compensation and MV Capacitor/Reactor Banks (If Needed)
The reactive power compensation system, if required, shall meet all the Owner’s requirements per
the interconnection requirements included in the Master Appendix List. The project shall deliver
+/- 0.95 PF at rated output at the POI. The step change caused by switching any elements of the
reactive power compensation system shall cause a maximum voltage step change of 3%. To achieve
this end the Contractor shall provide a price for option to design, procure, install and test the
appropriate equipment and controllers. The Contractor shall undertake the necessary studies to
determine the nature, size and location of the reactive power compensation equipment, the results,
along with a proposed control scheme, shall be provided to the Owner.
5.4 AUXILIARY POWER
The auxiliary power distribution system for the substation control building will be provided by the
substation control house vendor and shall be analyzed by the Contractor.
Substation auxiliary power shall be supplied from two (2) sources with an automatic change over
switch to switch from one to the other. One source shall be via a step-down transformer powered
from the LV substation bus, the other from the local distribution line.
The design of the auxiliary power distribution System shall be coordinated and optimized to make
certain that the bus voltage level sections, transformer ratings, and impedances, switchgear
interrupting ratings, bus duct short circuit ratings, cable sizes and load equipment ratings to meet
the applicable codes and standards.
5.4.1 DC and AC Systems
Contractor shall provide 125 VDC to all controls, protective relays, and instrumentation fed from
battery and charger system. For all other equipment not compatible with this power source,
Contractor shall provide a 120 volt AC Uninterruptible Power Supply (UPS) system to power critical
loads, including controls and instrumentation for the control, fire alarm, communication, and
security system. The UPS shall include a complete system and shall have twenty (20) percent spare
capacity.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 662 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-6
Internal Use Only
The DC system for the substation control building shall be provided by the Contractor. Batteries
shall provide the emergency DC power required for switchgear controls and critical DC loads as
well as the UPS. Batteries shall be flooded cell lead-acid type for stationary applications.
The duty cycle shall include a minimum of 30 minutes of power for the UPS and switchgear
breakers control power at the end of the 8 hour duty cycle.
Battery chargers shall be sized to fully recharge the batteries from a fully discharged state in not
more than twelve (12) hours while supplying normal continuous DC load.
Contractor shall provide 20% spare breakers in AC and DC panels.
5.4.2 Station Batteries and Charger
Contractor shall provide a 125 VDC Power System at the substation.
Batteries shall be flooded cell lead acid type for stationary applications and capable of eight (8)
hours of operation under normal load without intermittent charging or any supplemental form of
station power and shall have sufficient charge remaining after eight (8) hours to operate all
breakers’ trip coils and any additional tripping loads at least one time. All battery racks shall be
accessible from floor level, without use of a ladder, for visual inspection and maintenance activities.
The substation shall be equipped with redundant battery charging systems. All chargers supplied
under this specification shall be low ripple chargers.
Battery system shall have a monitoring system in compliance with NERC PRC-005-3 Table 1-
4(f). This includes but is not limited to voltage monitoring and alarming, electrolyte level
monitoring and alarming, unintentional DC ground monitoring and alarming, charger float voltage
monitoring and alarming, intercell and/or terminal connection resistance monitoring and alarming,
and internal ohmic value or float current monitoring and alarming. Additional requirements as
reflected in Brown Book (IEEE 399).
The Battery room shall have temperature and hydrogen monitoring with communications through
the substation SCADA system. The battery room shall have an eye wash system as well as
ventilation systems that provide external ventilation for gases generated by the lead-acid batteries
in accordance with NFPA 70 Article 320. Grounding, Lightning, Lighting, Security, and Operation
5.4.3 Grounding
The ground grid system shall be designed per the latest version of IEEE 80 to limit step and touch
potentials to safe levels for personnel both inside and outside the Collection System Substation for
the maximum available fault current. The grounding system shall be designed for a low grounding
resistance to minimize the maximum ground potential rise during line to ground faults. The
Collection System Substation ground grid shall be designed and installed to achieve an isolated (i.e.
the fully installed ground grid prior to any connection/bonding of the ground grid to the collection
system ground conductors and overhead line grounding conductors) tested resistance to true earth
of less than 0.5 ohm. The design fault current duration shall be 0.5 seconds.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 663 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-7
Internal Use Only
The ground grid system shall be 4/0 AWG copper conductor and copper-clad ground rods. The
modified grounding grid at the Collection System Substation shall consist of a number of
interconnected, bare conductors buried horizontally at a minimum depth of 18”. The grid shall be
supplemented by a number of driven ground rods as required. Ground rods shall be a minimum of
ten (10) feet in length, with the top of the rod buried eighteen (18) inches below the finished
surface. Grounding wells or other ground resistance enhancements may be used to meet the
maximum ground resistance specified above.
All metal structures, apparatus and equipment which are to remain at ground potential shall be
solidly connected to the ground grid by 4/0 AWG copper conductors. Individual ground mats (on
grade platforms) shall be provided at all high voltage disconnect switch locations and shall be
connected to the station ground grid. Below grade connections shall be made with an exothermic
welding process. Above grade connections may be welded, bolted or compression. Bolted
connections shall be used to connect the ground grid to substation galvanized steel structures and
equipment. All other connections shall be made in such a manner that the resistance of the
connection does not exceed that of the equivalent conductor.
All metallic grating shall be grounded by Contractor, and any material to ground it shall be provided
by the Contractor.
Communication cables, except for all-dielectric fiber optic, exiting the substation area shall be
adequately protected from the ground potential rise during ground faults by provision of suitable
protective devices. All-dielectric fiber optic cables do not require any of the foregoing protective
devices as they are not subjected to ground potential rise during faults. Any shielded cables shall be
grounded as required to control circuit transients and minimize noise.
The Collection System Substation ground grid shall be connected to the substation fence and the
grid shall be extended 3 feet beyond the fence line.
Collection System Substation grounding shall be designed in accordance with IEEE Standard 80
based upon the following conditions
MV circuit breaker total clearing times:
1. Normal: 6 cycles unless specific clearing times are based on procured equipment and
relaying used.
2. Breaker failure: 12 cycles
3. Line end fault clearing: 30 cycles (maximum) for MV system.
For substation EHV voltages below 345kV, touch and step potentials shall be in accordance
with IEEE Standard 80, calculated without considering the crushed stone layer.
Isolated personnel ground mat resistance: 5 ohms or less
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 664 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-8
Internal Use Only
Provisions shall be made for temporary grounding of Collection System Substation buses and
equipment.
Ground grid testing shall be in accordance with ANSI/IEEE Standards.
The grounding system shall exceed the minimum of the above Owner requirements,
Interconnecting Transmission Owner standards, NESC requirements and other applicable codes
and standards.
5.4.4 Lightning Protection
The Collection System Substation shall be protected from direct stroke lightning strikes by shield
wires and/or masts which are connected directly to the ground grid. The lightning protection
system shall be designed for an expected failure rate of no more than one (1) per hundred years.
The lightning protection system for the substation shall not have conductor crossings above live
power equipment or bus-work. All equipment/structural metallic surfaces shall be bonded at least
at two points. However, in all cases the Collection System Substation direct lightning stroke
protection shall meet or exceed the level of protection provide by IEEE Standard 998.
5.4.5 Lighting
Substation shall include permanently installed external lighting capable of illuminating all
equipment within the Substation. Collection System Substation lighting shall meet the minimum
lighting levels for the appropriate circumstances of indoor, outdoor, and roadway areas given in the
latest editions of NFPA 70 and ANSI C2. A substation lighting study and plan shall be submitted for
Owner review and approval.
If allowed by the local codes: infra-red motion detectors shall be used to control the outdoor
lighting when the substation is unattended, a bypass switch shall be provided for when the
substation is attended.
Emergency lighting shall be provided in attended areas in accordance with local codes and
regulations.
5.4.6 Security
All access gates to the Collection System Substation shall be padlocked with a standard issue lock.
Warning signs shall be installed in accordance with the National Electric Safety Code, and shall also
include a “no trespassing” sign.
Refer to Section 5.5.5 for perimeter fencing requirements.
5.4.7 Operating and Maintenance
The Contractor shall provide equipment manufacturer’s recommended list of operating equipment
such as tongs, insulating sticks, rubber gloves, grounds, voltage detection equipment, etc. needed
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 665 of 1056
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CO.| HV Substation (If Applicable) 5-9
Internal Use Only
for the safe performance of operating functions. The Contractor shall provide a proper inventory of
spare parts for the substation.
The Collection System Substation will be operated and maintained as an integral part of the Owner
Generation Assets and as such the substation bus, switch and equipment nomenclature system (and
correct coloring) including for control and relay panels, shall be compatible. Contractor shall obtain
from Owner all required nomenclature (and correct coloring) for the substation and attached
circuits at an appropriate time prior to energization.
The Control building shall be fitted with security sensors that provide indication of entry via the
SCADA system.
5.5 SUBSTATION CIVIL/STRUCTURAL DESIGN CRITERIA
5.5.1 General
This area of work consists of civil design of the substation with respect to grading, drainage and
structural design of structures and foundations for support of the air-insulated bus-work, power
transformer, switchgear and related electrical equipment.
5.5.2 Civil
Tree and vegetation removal, clearing, grubbing, grading, and compacting as necessary shall be
performed by the Contractor.
Contractor shall strip and stockpile topsoil for use during re-vegetation.
Clear, grade, and compact the area for the substation foundations. Substation final grade shall be
comprised of 6 inches of MDOT 6AA Crushed Limestone. Road surfaces internal to the substation
fence shall be of the same surface material as the wind farm site access roads, and be constructed of
at least the same structural section thickness as the wind farm site access roads.
5.5.3 Structures
The Contractor shall design, procure and install dead-end structures that will be used to connect
the Collection System Substation to the Radial Line designed and constructed by the Contractor
(refer to Master Appendix List for interconnect requirements). Contractor shall coordinate dead-
end structure design with METC under the generator interconnection agreement.
Collection System Substation bus and switch support structures shall be low profile (non-lattice)
type. Provisions shall be made for grounding the structures, disconnect switch operating
mechanisms, surge arresters and other equipment that require grounding in accordance with
industry standards.
5.5.4 Foundations
All foundations shall be designed and installed as described in Section 2 and Section 5.3.2.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 666 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-10
Internal Use Only
Contractor will provide the concrete foundations and oil containment pit and make all connections
and terminations to the power transformer. The foundation and oil containment shall be of suitable
strength to allow jack and slide installation of the main step transformer described more fully in the
Master Appendix List. The transformer foundation oil containment shall include an outlet to an oil
water separator detailed in the Master Appendix List, which allows storm water to drain out of the
system by gravity after passing through the oil-water separator.
5.5.5 Substation Fencing
Contractor shall fence the entire Collection System Substation in accordance with IEEE, NESC, and
Idaho Power design requirements. The fence shall prevent the entrance of unauthorized personnel
into the Collection System Substation and be separated from exposed energized parts so as to
prevent unsafe contact by objects inserted through or over the fence.
The Collection System Substation fence shall be standard galvanized steel chain link security fence
with gate and not less than seven (7) feet in height with an additional one (1) foot high barbed wire
topping and three (3) strands of barbed wire. In addition, the perimeter fencing shall contain
double "V" three-stranded barbed wire as well as a stiffener bar at the bottom of the mesh to
prevent lifting or undermining the mesh for entrance into the station.
Perimeter fencing shall be placed in accordance with the requirements of NESC, IEEE Standard
1119 and Idaho Power SEM standards. Fence setback from property line shall not be less than three
(3) feet to accommodate the installation of a buried perimeter ground wire.
Contractor shall install an outward opening, 20 feet wide, double leaf gates on the perimeter fence
for vehicle access to the substation. Perimeter warning signs shall be installed at all gates and at a
minimum of seventy-five (75) feet intervals along the fence. Contractor shall refer to the Master
Appendix List for fence, gate and animal barrier details.
5.5.6 Raceway
Contractor shall provide raceway for all electrical, control and optical fiber cables. Below grade
raceway shall be direct buried PVC conduit (Schedule 40 or heavier wall). If cable trench is used
design shall be drivable over all sections to allow for movement of operating and maintenance
vehicles throughout the substation. Above grade conduits shall be PVC or rigid galvanized steel. AC
and DC station power conductors shall be installed in dedicated conduits that are separate from the
instrumentation and control wiring. Contractor shall submit a conduit schedule and plan drawing
to Owner for review and approval.
5.5.7 Drainage
The site grading and drainage shall be designed to comply with all federal, state and local
regulations. The site shall be graded to convey storm water runoff away from permanent facilities.
Site drainage shall be designed to convey the runoff from a 4 percent probability (25 year) storm
event unless specific federal, state, local or utility regulations or utility easement requirements are
more stringent. Aggregate surfacing shall be provided and installed within and three (3) ft. outside
of the fenced area in a manner that allows the free movement of personnel, vehicles and equipment
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 667 of 1056
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CO.| HV Substation (If Applicable) 5-11
Internal Use Only
throughout the Collection System Substation under all weather conditions and is incorporated into
the grounding design for the substation.
Contractor shall backfill with a minimum of 6” of 1-1/2” gravel and shall slope the gravel such that
water drains away from major equipment.
5.5.8 Collection System Substation Vehicle Access (Outside Substation Fence)
Contractor shall provide access to the Collection System Substation site for installation,
maintenance and removal of all major equipment shall be provided. Typical maintenance vehicles
of up to 40 feet long by 8 feet wide with a turning radius of 30 feet and equipment delivery vehicles
up to 11 feet long by 10 feet wide with a turning radius of 50 feet require access to the substation
sites. Associated unloading equipment shall be accommodated as well.
5.5.9 Restoration and Landscaping
Upon completion of the Collection System Substation, Contractor shall restore the unused disturbed
land in accordance with requirements dictated by the Owner, and the Owner Permits. Temporary
structures and facilities supplied by the Contractor for use during construction shall be removed.
All temporary buildings, structures, concrete slabs and footings, tools, facilities, and other
Contractor property shall be removed from the site and the areas involved shall be restored to their
original or intended condition.
5.6 COLLECTION SYSTEM SUBSTATION CONTROL BUILDING
5.6.1 Design and Construction
Contractor shall adequately size and configure the Substation Control building to comply with
Owner’s standards and requirements and shall be complete with required equipment, foundation,
normal and emergency lighting, emergency egress, fire protection, heating and ventilation. The
heating and ventilation shall be designed and installed to maintain temperature and humidity
within the limitations of the control, communication, and protection equipment. The building shall
be 20 x 40 feet in size and designed in accordance with Owner’s standard control building layout as
included in the Master Appendix List.
The control building shall be a free-standing building provided complete with framing, or self-
framing panels, roofing, siding, insulation, doors, windows, hardware, fasteners, flashing, weather-
stripping, caulking, HVAC and other components as required or specified. All materials shall be
new, free from defects and fabricated with quality workmanship. The building design as a whole
shall result in a rigid structure that will maintain its shape and alignment against all design loads
and shall conform to ASCE 7.
Major equipment to be housed in the Collection System Substation control building include:
1. AC Panels
2. DC Panels
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 668 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-12
Internal Use Only
3. Termination Cabinet(s)
4. Battery Charger(s)
5. Battery Bank(s)
6. DC Disconnect Switch
7. Modular Steel Racks for all SCADA, Relay, protection and controls equipment including
but not limited to transformer rack, feeder rack, line rack, communication rack, RTU
rack, MV breaker racks, cap bank rack (If required), and other control and relay systems
necessary for a completely functional wind farm.
8. Eyewash Station(s)
9. AC Safety Switches
10. Transfer Switch
11. Telco Board with room for Telco Line Isolation (as needed)
12. HVAC Unit
13. Exhaust Fan
14. Fiber Optic Patch Panel
15. Fire Extinguisher
16. Desk
17. Miscellaneous equipment
In addition, the control building shall include adequate space for all other equipment including
spare parts necessary for a fully functional Collection System Substation in accordance with the
Agreement and the applicable standards and requirements.
5.7 COLLECTION SYSTEM SUBSTATION PROTECTION AND CONTROL
5.7.1 General
The Contractor shall be responsible for the detailed design and implementation of the protection
schemes necessary to satisfy Interconnection Agreement, ITC, MISO, and Owner’s
recommendations (Master Appendix List) and provide appropriate equipment protection
commensurate with normal Prudent Wind Industry Practices. All relay systems shall include dual-
primary protection in case of component failure in the primary protection system.
The Contractor shall be responsible for the detailed design and implementation of the Breaker
Failure protection schemes necessary to satisfy the Interconnection Agreement and Owner’s
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 669 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-13
Internal Use Only
requirements (i.e. BF detection trip paths, coordinating time delays, etc.). The Contractor shall
ensure the design is suitable for the substation and radial line interface to the Transmission Owner
(METC) according to the Interconnection Agreement attached in the Master Appendix List.
Subsections 5.8.2 through 5.8.6 provide general relaying and protection requirements. Owner
supplied Preliminary Relay Recommendations and Monitoring Recommendations are attached in
the Master Appendix List. Final relaying and monitoring recommendations are dependent upon
final PV Solar Field and design. In the event of any discrepancies, the Master Appendix List shall be
the definitive source for relaying requirements.
Contractor shall design protection schemes and supply all necessary electrical protection
equipment including, but not limited to, (i) primary 1 and primary 2 line protection, (ii) primary
1and primary 2 protection for the main step-up transformer, (iii) (iii) primary 1 and primary 2 bus
protection, (iiii) feeder protection.
5.7.2 HV Breaker and HV/MV Main Power Transformer Protection
HV breaker protection shall include dual-primary relays, including all Point of Interconnection
requirements, phase, ground, and neutral overcurrent protection. Lockout relays for the breaker
and breaker failure functions. Lockouts shall trip and close-block all appropriate upstream and
downstream breakers.
Primary protection of the HV/MV Main Power Transformers shall be provided by a current
differential relays with built-in backup overcurrent protection for the transformer. On transformer
trip, lockout relays shall be asserted which opens and close-blocks all feeder breakers served from
that transformer and opens and close-blocks the associated HV breaker(s). Contractor shall design
an appropriate protection scheme to be reviewed by the Owner.
5.7.3 MV Bus Protection
Backup protection of the MV bus shall include phase, ground and neutral overcurrent protection
measured on the low-side of the transformer. More detailed MV bus protection and tie-in breaker
protection and monitoring requirements are included in the Master Appendix List.
5.7.4 MV Switchgear Protection
Contractor shall design an appropriate protection scheme for the MV switchgear.
5.7.5 MV Collector Circuit Protection
The primary protection of additional collector circuits shall, as a minimum, include relaying with
the following protection capabilities:
Phase and ground time-overcurrent
Directional control
Voltage supervision and tripping
Breaker failure logic
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 670 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-14
Internal Use Only
5.7.6 MV Capacitor Protection
The protection of each capacitor bank, if required, shall include one or two relays that comply with
IEEE 37.99-2000 Guide for Protection of Shunt Capacitor Banks. The protection is dependent on the
final capacitor bank design. Unbalance protection shall be included to detect evolving faults and
prevent damage to unfaulted capacitor units.
The primary protection of each capacitor circuit shall include a single relay with the following
protection capabilities:
Unbalance
Phase and ground time-overcurrent
Voltage supervision and tripping
Breaker failure logic
5.7.7 Capacitor Bank Control
Should a capacitor bank be required, the control of each capacitor switch, shall be provided in the
capacitor bank protection and control relays. At a minimum the control scheme shall include the
following capabilities:
Voltage and pf/Var measurement on the HV or MV bus as appropriate
An Auto/Manual switch
Thresholds to accommodate the necessary switching steps
Switching control to rotate the duty of the capacitor banks evenly
Time delay logic to accommodate safety time limits before closing and to ride through
momentary system fluctuations
Zero voltage closing control if required due to step size and or duty
Undervoltage tripping
Overvoltage tripping
The Contractor shall be responsible for programming the reactive power controllers. Several hard
copy printouts and CDs of settings and programs shall be provided to the Owner.
5.7.8 Interconnection Protection
Collection System Substation protection shall meet all protection requirements of the
Interconnection Agreement included in the Master Appendix List.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 671 of 1056
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CO.| HV Substation (If Applicable) 5-15
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5.7.9 Wiring
The wiring of all control and protection devices shall be consistent with good wiring practices and
in accordance with the Master Appendix List. All wiring shall be adequately sized for its specific
application. All terminations shall be made using non-insulated solid Burndy barrel compression
ring lug terminals. No more than two terminations may be made to a single terminal point.
Control circuits shall be fused together with a fuse for the positive and negative legs. There will be
no individual circuit voltage monitoring.
Loss of DC to the Collection System Substation controls or other over voltage/under voltage
conditions shall provide an alarm to the Substation SCADA System.
The DC supplied to each panel, from the DC distribution panel, shall be terminated on an
appropriately sized terminal block located in the rear of that panel. Both positive and negative
supplies shall be fused using panel mounted fuse holders.
All lock-out circuits shall be monitored with blue indicating lamps.
AC supplies shall be fused using the same type fuse holder as indicated above. Only the hot leg
needs to be fused. A solid neutral for fuse block or “shorting lug” shall be supplied in the neutral leg
to provide an isolation point for maintenance purposes.
CT cables associated with redundant protective relaying systems shall be routed in a manner to
prevent common mode failure.
Wiring to the devices, which are removable from the front, shall be provided with enough slack (12
inches minimum) to permit removal of the item without disconnecting any wire. Wiring to control
(CSR) switches shall be adequate to remove switch from panel for work or further wiring without
disconnecting existing wires (see Appendix C).
Wires shall be neatly arranged and properly supported throughout the panels to prevent sagging
and breaking. Suitable raceways equivalent to 1-1/ 2 times the space required for wiring shall be
provided to permit the safe and accessible installation of wiring. All wiring shall be secured using
screws, nuts, and bolts or Panduit wiring duct. Adhesive mounting of wiring clamps is not
permitted.
A bladed disconnect with visible open shall be included in all non-CT circuits between the
substation yard and the substation control houses to enable safe switching and tagging procedures.
Wire identification/numbers shall be provided on all AC and DC schematics according to the
Owner’s standards. Circuit numbers shall be labeled on the cables and on the wire at the
termination points.
5.7.10 Control Panels
All control and protection equipment shall be installed on modular steel panels located in the
control building. Modular steel panels shall be fabricated and installed in conformance with
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 672 of 1056
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CO.| HV Substation (If Applicable) 5-16
Internal Use Only
Owner’s standards included in the Master Appendix List. All equipment mounted on the rear of the
panels shall be located in a manner to permit easy access. Each item of equipment shall be readily
removable without removal of other items. All terminal blocks shall include States NT type sliding-
link terminals or Owner approved alternative.
Panels shall be of standard sizes painted light gray (ANSI No. 61).
Panels shall be bonded to an adequately sized copper ground bus.
All equipment installed on the panels shall be labeled using black lamacoids with appropriately
sized white lettering, in accordance with the Owner provided naming scheduled.
All NERC relays shall be labeled using yellow lamacoids with appropriately sized black lettering in
accordance with the Owner provided naming schedule.
5.7.11 Relays
Relays shall be provided in accordance with the specification included in the Master Appendix List.
No relay substitutions are allowed.
5.7.12 Communications
1. Telephone circuits or appropriate Owner-approved alternative shall be provided for all
Collection System Substation communications including but not limited to voice, metering,
relay communication and interrogation and data transfer to and from disturbance monitoring
equipment or other equipment installed within the Collection System Substation.
2. All ordering and acquiring of the circuits shall be provided by Contractor.
3. The incoming telephone shall have a minimum of 25 pairs of conductors.
4. The incoming telephone cable shall be installed in the PVC conduit to the nearest roadway or
Telco trunk-line unless a reduced distance is approved by Consumers.
5. As a minimum, conduit extends 10’ beyond the substation fence or as required by the local
exchange carrier. The telephone cable may be direct buried from end of conduit to telephone
company termination point.
6. Stack end of telephone conduit.
7. Choose the precise location to provide ample space for operation and maintenance.
8. Install equipment in accordance with manufacturer's, Telco, and Owner’s recommendations.
9. Install pull rope in telephone conduit.
10. As a minimum, one dedicated 4-wire, non-IP data circuit shall be provided to support RTU
communications.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 673 of 1056
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CO.| HV Substation (If Applicable) 5-17
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11. A dial-up voice-grade circuit (POTS line) is required for metering access by Owner and
transmission provider in accordance with the interconnection requirements in EPC
Agreement, Exhibit D. POTS line shall be equipped with a Contractor supplied Teltone
Gauntlet line sharing switch or an Owner approved alternative.
12. Collection System Substation phone circuits will be installed with the proper high voltage
interface (HVI) protection. Contractor shall perform all necessary studies and shall coordinate
with telecom provider in design and installation.
13. No IP or routable protocols are currently permitted.
14. Any additional communications circuits or equipment necessary to support the Owner relay
recommendations and monitoring recommendations included in the Master Appendix List.
5.8 COLLECTION SYSTEM SUBSTATION BUS, SWITCH AND EQUIPMENT NOMENCLATURE SYSTEM
Owner will provide all required nomenclature for the Collection System Substation and attached
circuits at an appropriate time prior to energization.
5.9 SUBMITTAL REQUIREMENTS
The Owner and the Contractor shall identify in the project schedule, drawing submittal, review and
comment, and final approved submittal activities. Typical review times for Owner review and
comment shall be 30 days after receipt, but additional time may be requested based on the volume
or complexity of the submittal.
It is anticipated that initial submittal shall be of a conceptual nature and include as a minimum,
One-Line Diagrams of the:
Substation, including station power and any alternate sources
Farm interconnection/gathering system
Typical PV Module site, including station power
Complete drawing submittal of all project details shall occur following approval of conceptual
drawings and the detailed design process. Drawings shall be of engineering quality and conform to
the drafting procedure. Free hand sketches are not acceptable. The engineering drawings shall
include the following:
The location and ratios of the current and potential transformers used for the isolation
protection.
The connection of relay terminals in current, potential, and control circuits.
Relays identified by their IEEE device numbers and Owner-provided NERC identification
numbers.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 674 of 1056
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CO.| HV Substation (If Applicable) 5-18
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All RTU sequence of events monitoring with the IEEE device numbers.
The location of the current and potential transformers used for telemetering.
Breaker status contacts used for telemetering.
RTU location (note on drawing).
Power source for all protective relays, control equipment and RTU (note on drawing).
The Contractor shall provide information on those relays to be used for the protection of the
electric system, including the manufacturer of the relays, the relay types and calibration
range(s), and the model or style number of the relay.
The One-Line Diagram (described above) - A one-line representation of the three-phase
electrical system shall be provided. The one-line diagram shall indicate those electrical
system components (e.g. buses, feeders, transformers, and generators) that are necessary to
show how the wind farm will be built and how it will connect with the electric system. The
following information on these system components shall appear on the one-line diagram:
1. Breakers - Rating, location, and normal operating status (open or closed)
2. Buses - Operating voltage
3. Capacitors – Size of bank in kVAR
4. Circuit Switchers - Rating, location, and normal operating status (open or closed)
5. Current Transformers - Overall ratio, connected ratio
6. Fuses - Normal operating status, rating (Amps), type
7. Generators - Capacity rating (kVA), location, type, method of grounding
8. Grounding Resistors - Size (ohms), current (Amps)
9. Isolating transformers - Capacity Rating (kVA), location, impedance, voltage ratings,
primary and secondary connections, and method of grounding
10. Potential Transformers - Ratio, connection
11. Reactors - Ohms/phase
12. Relays - Types, quantity, IEEE device number, operator lines indicating the device
initiated by the relays
13. Switches - Location and normal operating status (open or closed), type, rating
14. Tagging Point - Location, identification.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 675 of 1056
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15. Rotation and Phasing
Detailed wiring drawings (point-to-point) shall be provided. These drawings shall depict all
panel and field-device terminations and interconnections. Wiring tables are not permitted
on either the Contractor-provided or equipment provider (supplier/shop) drawings. In
addition, the connections and wiring of supplier/shop drawings shall be transferred and
depicted in detail on the Contractor drawings so that a complete wiring package is shown
without referral to the supplier drawings.
Contractor shall perform point-to-point wiring verification of wiring prepared by
Contractor on-site as well as by subcontractors off-site (including but not limited to relay
panels).
5.10 TESTING
5.10.1 General
The Owner will self-perform substation testing. The Contractor shall provide a deduction Option
price for Owner to perform Substation testing as specified in the sections below.
Contractor’s base price shall include all tests as may be deemed necessary to demonstrate that the
equipment, as installed, complies with these requirements. All labor, instruments and apparatus
required for such tests shall be provided completely by the Contractor. If any of the equipment
fails, under test, the defects shall be rectified by readjusting, or removing and replacing, the faulty
equipment until, under test, all requirements are met.
Testing shall include, but is not limited to:
Point to point testing. Continuity shall be verified at every termination and jumper and also
from circuit end to circuit end. The schematics shall be highlighted as each termination is
verified and turned over to the Owner prior to energization.
Relay testing. Settings shall be programmed and verified.
Functionally test all equipment to verify relay settings and modifications to protective
scheme operate as designed. .
Load testing CT and PT circuits. Prior to energization, all CT and PT circuits shall be checked for
continuity as well as testing continuity with actual designed voltage.
Any testing of substation equipment performed by Contractor, including relays, instrumentation
transformers, AC and DC circuits and DC battery systems, shall be delivered in a format and
substance comparable to Owner’s typical testing documentation.
Contractor shall submit an initial draft commissioning plan and functional test procedures,
including proposed documentation format, for Owner review no less than one hundred twenty
(120) days prior to the tests. The final commissioning plan and functional test procedures shall be
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 676 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-20
Internal Use Only
submitted for Owner’s review and comment no less than sixty (60) days prior to the tests.
Contractor shall coordinate testing/commissioning activities with Owner.
Owner representative will be notified for witness functional and acceptance tests two weeks prior
to test schedule. Owner will witness test all testing.
Results of tests shall be formally transmitted for review and approval no later than 10 working days
prior to energization.
NERC protection testing procedure shall be transmitted for review no later than 60 working days
prior to the planned energization date. NERC protection testing shall not commence prior to Owner
approval of the testing procedure. Owner reserves the right to self-perform NERC protection
testing on the Collection System Substation
The Contractor shall make available appropriate staff during Owner testing of the HV systems
relaying and SCADA for assistance. The Contractor shall be responsible for testing and
commissioning all the work under this contract. All testing shall be performed in coordination with
METC and MISO under the interconnection requirements.
5.10.2 General Testing and Commissioning
The Contractor shall perform:
1. DC charger commissioning.
2. Substation Services commissioning.
3. Phase rotation checks.
4. Voltage test and tap change settings.
5. Operational switching and control during commissioning of MV equipment prior to
Owner acceptance of the substation. Contractor shall plan and coordinate all switch
and tagging requirements in advance with Owner.
HV Transformers, Circuit Breakers, CT’s, VT’s, disconnect switches and MV Switchgear and reactive
power support equipment at the Project Site affected or modified by the Scope of Work shall be
fully tested and commissioned.
5.10.3 Transformers Over 600V
The following tests shall be performed as a minimum:
1. Turns Ratio,
2. Voltage test tap change settings.
3. Insulation power factor, polarity, excitation, winding resistance (>10MVA only);
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 677 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-21
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4. Oil quality and Dissolved gas-in-oil analysis,
5. Fan controls and all device alarm points, as applicable;
6. Current transformer turns ratio, saturation, polarity, circuit loop checks, as applicable;
7. Bushing insulation power factor (>10MVA only),
8. Doble
5.10.4 Circuit Breakers Over 600V
The following tests shall be performed as a minimum:
1. Insulation power factor, contact resistance, operator controls and interlocks,
travel/timing where equipped with test attachments,
2. Gas pressure check,
3. Current transformer turns ratio, polarity, and circuit loop checks,
4. Bushing insulation power factor.
5.10.5 Switches Over 600V
The following tests shall be performed as a minimum: (1)
1. Contact resistance and operator adjustment.
5.10.6 Station Bus Systems
The following tests shall be performed as a minimum:
1. Low resistance continuity check at bus joints.
5.10.7 Protective Relays
The following tests shall be performed as a minimum:
1. Calibrate as required and test by current and voltage injection using Doble or equal
relay test equipment to ensure proper operate and restraint characteristics for in-zone
and out-of-zone faults. .
5.10.8 2. Functionally test to demonstrate circuit breaker and/or lockout actuation.
Owner/utility may witness test portions of the protective relays Station Control
Wiring
The following tests shall be performed as a minimum:
1. Perform point to point wiring checks of field control wiring and relay panel wiring,
complete functional check of the schematics (both AC and DC), functionally verifying
every circuit and termination point and highlighting the schematic diagram to
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 678 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-22
Internal Use Only
document the verification of each circuit. Highlighted schematics shall be turned over
to the Owner as part of testing results as specified in 5.11.1
2. Verify all remote monitoring, indication, and alarm points,
3. Perform loop checks on all current and potential circuits.
5.10.9 Grounding
The following tests shall be performed as a minimum:
1. Perform initial earth resistivity tests as part of ground grid design,
2. Perform completed grid tests per IEEE. 81
5.10.10 NERC Protection System Testing
Equipment to be included in the Owner’s NERC protection system shall be identified by the Owner,
and shall be tested by the Contractor according to the Owner’s NERC compliance program
documentation. Testing forms are unique for NERC devices, and will be provided by the Owner
prior to commissioning testing.
1. Protective relays which respond to electrical quantities
2. Communications systems necessary for correct operation of protective functions
3. Voltage and current sensing devices providing inputs to protective relays
4. Station dc supply associated with protective functions (including batteries, battery
chargers, and non-battery-based dc supply)
5. Control circuitry associated with protective functions through the trip coil(s) of the
circuit breakers or other interrupting devices
5.10.11 Maintenance and Testing
1. In addition to the commissioning and testing that the Contractor will provide, Owner will
likely perform testing of any of the relaying and control equipment that involves protection of
the Owner’s electric system
2. Testing records shall include both an exact calibration check and an actual trip of the circuit
breaker or contactor from the device being tested. For each test, a report shall be submitted
to the Utility indicating the results of the tests made and the "as found" and "as left" relay
calibration values.
3. Visually setting, without verification, a calibration dial or tap is not considered an adequate
relay calibration check.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 679 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| HV Substation (If Applicable) 5-23
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Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 680 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-1
Internal Use Only
6.0 SCADA System
6.1 GENERAL
The Substation SCADA System is required for the purpose of providing substation supervisory
control and data acquisition and aggregate control of the wind farm to the Owner/operator as well
as providing information about the wind farm and substation to the control area system operator.
The Substation SCADA System is also required to accept data (e.g. equipment status at the POI and
metering) from the Owner and provide such to the PV Module Supplier SCADA System. The
conceptual SCADA diagram for the Project is included in the Master Appendix List.
6.1.1 Contractor Scope of Work
The Contractor will analyze, design, coordinate and install the SCADA system for the Collection
System Substation, referred to hereafter as the “Substation SCADA System”. Contractor shall
provide the equipment and software to integrate all equipment as specified in Section 5 with the PV
Module Supplier SCADA System into a fully functional SCADA System.
6.1.2 General Design Philosophy
The following general design philosophy and requirements shall be complied with for the
Substation SCADA System. Information shall be collected utilizing Intelligent Electronic Devices
(IEDs) where available (example microprocessor based protective relays or intelligent meters)
through the RTU’s serial connection. An RTU shall be provided to collect the required information
from the IEDs or I/O modules. The RTU shall also provide required wind farm functionality to the
transmission service operator, and Owner. The RTU shall also interface with the PV Module SCADA
system and provide functional inputs and outputs to and from the Owner’s PV Module Supplier
SCADA System as needed. All data points listed in the “PV Solar Farm SCADA Points List” included
in the Master Appendix List shall be included in this system. At a minimum the following
communication protocols shall be supported: DNP 3.0 and Modbus.
6.1.3 System Layout
The Conceptual SCADA Diagram provided in the Master Appendix List shows a preliminary layout
of the SCADA system for the Project. The Contractor is responsible for finalizing the system
configuration and layout in coordination with the Owner.
6.1.4 SCADA Integration
The Contractor is responsible for providing a fully integrated SCADA system for the Scope of Work,
that is, the Contractor shall provide a fully functional system to connect all data points of the SCADA
system (e.g. communication, RTU, the Substation SCADA System, and the PV Module Supplier
SCADA system) together in a reliable cost effective manner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 681 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-2
Internal Use Only
6.2 TELEPHONE AND TELECOMMUNICATIONS SYSTEM
6.2.1 Communications Requirements
The Contractor shall be responsible to determine specific equipment required by the Owner and
the Transmission System Operator, specifically relating to SCADA, metering and telemetering due
to the Interconnection Agreement as well as equipment required to complete the indicated control
and protection requirements.
Communications facilities shall be provided between the:
1. Substation and the Transmission System Operator systems for transfer trip relay and
protection applications as required by the Interconnection Agreement.
2. Substation and Owner systems for Substation SCADA, RTU, telemetering, metering and
voice communications. Dedicated communications services (Multipoint DS0, DS1 or
Analog) are required for the Substation RTU, disturbance monitoring equipment and for
remote relay interrogation.
3. Substation and the System Operator for SCADA, telemetering, and voice communications.
The Contractor shall provide arrange and manage the delivery of the necessary telephone
lines/communication links for operation and maintenance of the facility, including those listed
above. The Contractor shall provide high speed internet access line(s) for communication with the
PV Module Supplier SCADA system by the Owner and the PV Module Supplier which will be brought
to the substation control building by others. The Contractor shall procure and install the necessary
isolation equipment and backer boards not supplied by the telecom provider, provide the required
isolation between the Project systems and the telecom provider’s systems if not provided by the
telecom provider; conduits from the communication panel and/or room inside the substation
control room to a point outside the foot print of the yard/building which shall be provided with pull
strings to be utilized by the connecting telecom utility.
The communications systems for the substation shall be coordinated with Owner to ensure
compatibility and cost effectiveness
6.3 SCADA SYSTEM SCOPE
The Contractor shall provide a complete working SCADA System for the substation including a DNP
3.0 serial interface with the PV Module Supplier SCADA system. The system shall include but not be
limited to the following items;
6.3.1 PV Module Supplier SCADA System
The PV Module Supplier SCADA system will be installed in a dedicated
telecommunications/network equipment room in the Substation Control House.
1. Install and maintain communications circuits in accordance with the Project Schedule
terminated to the Substation Control House
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 682 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-3
Internal Use Only
2. Supply fiber optic cable in accordance with Installation Instructions as included in the
Master Appendix List.
3. Install fiber optic network cable in conjunction with Collection System Circuits and junction
boxes
4. Install fiber optic cable at Tower base providing appropriate amount for terminations
5. Provide one Digital Private Line Multi Point DS3 service for Owner’s IP network
communications
6. Provide power supply and communication links for PV Module Supplier SCADA System
server
7. Supply and install fiber cable to PV Module Supplier SCADA System server location
6.3.2 Telemetry, Disturbance Monitoring and Substation SCADA System
1. Telemetry and disturbance monitoring is required at the substation. Owner relay
recommendations and monitoring recommendations included in the Master Appendix List
shall be used in the design of Telemetry, Disturbance Monitoring and Substation SCADA
system including the RTU points list.
2. In the substation, the equipment shall be located in a suitable switchboard panel location,
generally in the same panel row as other switchboard panels
3. The equipment shall be designed to operate on 125 V DC power.
4. All RTU I/O shall be real-time (update < 4 seconds)
5. Protected phone and data circuits shall be provided for the equipment.
6. The following will be telemetered at the substation (when available). Contractor shall
coordinate with Owner to develop complete list of data and control to be included in the
Substation SCADA System.
a. Real and reactive power flow
b. Voltage at the PCCT
c. Transformer MWatts
d. Transformer MVARS
e. Transformer low side voltage
f. Loss of station power AC
g. Loss of RTU DC power
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 683 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-4
Internal Use Only
h. Loss of metering potential
i. Pulses for Kwatt-hours in and out
j. Pulses for KVAR-hours in and out
k. Total Capacity Avail – MW/MVAR
l. Number available
m. Number online
n. Dispatch Setpoint
o. AGC Status
p. Mandatory Control
q. The status (normal/fail) of protective relay Communication Channels. A status
indication of "FAIL" indicates the Communication Channel used for relaying (i.e.
transfer trip) is unable to perform its protective function
r. The status (open/closed) of the main isolating breaker and any other substation
breakers.
7. The RTU will be equipped with “sequence of events” recording
8. The RTU configuration file should be provided to the Owner in the proper file type for
Owner review (.shp). Contractor shall allow Owner three weeks to review the RTU
configuration.
9. Digital inputs of:
a. An output contact of an instantaneous relay to act as a ground fault detector for faults
on the electric system. This relay shall be connected into the same sensing source as
the ground fault protective relay
b. Every trip of an interconnection isolation device, which is initiated by any of the
generator interconnection relaying schemes
c. Every trip of an interconnection isolation device, which is initiated by any of the
protective systems for the generator
d. Every trip or opening of an interconnecting isolation device, which is initiated by any
other manual or electrical means
e. A contact indicating the position of the Project’s primary-side main breaker
f. A contact indicating operation of the over/under voltage relays
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 684 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-5
Internal Use Only
g. A contact indicating operation of the under/over frequency relay or the Utility’s
ground fault relay. A contact indicating operation of the Project provided transformer
bank relaying
h. A contact indicating operation of any of the (51V) relaying
i. A contact indicating the position of the high-side fault-clearing device
j. A contact indicating the position of the reverse power relay
k. The following individual contact from each individual Direct Transfer Trip receiver
i. Loss-of-guard (LOG) alarm
ii. Receive-trip relay (RTX)
iii. Lockout relay
l. If any of the functions indicated the above items are combined into a multi-functional
device:
i. Each of those functions shall be monitored independently on the RTU, or;
ii. Provisions acceptable to the Utility shall be provided to interrogate the multi-
functional device such that the operation of the individual functions may be
evaluated separately
10. RTU Hardware
At the substation location, RTU hardware shall be comprised of a GE Harris D20 TRU and
associated I/O boards.
The RTU device shall be fed from the 125 VDC station/site power supply only.
Configuration/programming of RTU hardware at the substation shall be performed by
Contractor in coordination with Owner.
Preliminary RTU input/output (I/O) list shall be submitted by Contractor to Owner no later
than 120 days before substation is to be placed in service.
Final RTU I/O and subsequent programming files shall be submitted by Contractor to Owner
no later than 60 days before substation is to be placed in service.
All RTU I/O points shall be provided with scaling data.
To the extent possible, communication to the Collection System Substation IEDs for alarm and
status points shall be analog.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 685 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-6
Internal Use Only
Where Collection System Substation IEDs require digital communication, the RTU protocol
shall be DNP 3.0 serial over RS 485.
All circuits going to the RTU shall be terminated on terminal blocks in the RTU cabinet.
All RTU circuits shall use shielded cable and the shields shall be grounded only at the RTU.
Remote end shields shall be properly terminated and insulated to prevent inadvertent contact
with ground.
RTU shall be installed in a panel, not on the wall of the control building.
1. GPS Time Synchronization
The substation shall be equipped with an Owner’s standard (SEL or Arbiter) GPS time clock.
The clock will be connected to the RTU and connected to or distributed to all relays and
similar protective, or data acquisition devices and the PV Module SCADA System.
6.3.3 Substation Communication System Design
Contractor shall prepare a communication block diagram of the substation illustrating the
interconnection of SCADA devices at the substation. The block diagram shall identify devices, port
numbers, communication cable type, protocols and device addresses. Contractor shall also provide
a cable list detailing communication cable type, number of conductors, wire size, length, and
destinations. If special connections are required, a cable wiring diagram should be created.
Deliverables include: Communication Block Diagram, Communication Cable List as part of master
substation cable (circuit) list, Cable schematic drawings as needed.
6.3.4 SCADA Points Lists
Contractor shall work with the various parties involved and prepare a points list for each entity
listing the points being provided. A typical points list has been provided in the Master Appendix
List as a base document from which a complete points list can be developed. The Contractor shall
co-ordinate the review and approval of the points lists by the all the relevant parties. The points list
will be of sufficient detail to allow programming of the various slaves and masters. All digital points
shall be provided by “dry contacts” when not coming from an IED. Digital point wetting voltage
shall be 125 VDC. Status points which can change state multiple times between polls from the
SCADA system (typically 2 seconds) shall require a change detect status card (i.e. breakers). Wires
from metering systems, and for communication, shall be twisted shielded pairs, and the shields
shall be grounded in the substation SCADA cabinet only.
Expected deliverables include: Owner Points List, Owner Interconnect Points List, System/Area
Operator Points List.
6.3.5 Substation Device Configuration
The SCADA RTU shall interface with the Owner’s Master Station. Contractor will coordinate with
Owner to develop the configuration files for the Substation SCADA System devices based on the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 686 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-7
Internal Use Only
system design and points lists. Devices include, but are not limited to, communication
processors/RTUs, Ethernet Switches/Firewalls, meters (communication settings only), protective
relays (communication settings only).
Expected Deliverables include: Configuration files on CD and thumb drive.
6.3.6 Material Specification
Contractor shall prepare material lists containing an identifier, quantity, brief description and part
number for each item. Provide catalog cut sheets of each item on the material lists and referenced
with the same identifier.
Expected deliverables include: material lists and catalog cut sheets for communication processors/
RTUs and any other equipment required for a complete SCADA system.
6.3.7 Procurement, Installation and Implementation
Contractor shall procure, install, program and implement the design.
6.3.8 Commissioning
Contractor shall prepare a site acceptance procedure and submit for approval. Using the accepted
procedure, Contractor shall perform the tests to check for proper operation of the Substation
SCADA System including all analog information and digital status for both the substation and wind
farm. In addition the Contractor shall perform tests to check for proper integration of the SCADA
system and demonstrate appropriate functionality between the PV Module Supplier SCADA System,
Substation SCADA, Owner, and the System/Area Operator. The Contractor is only required, under
the SCADA scope, to demonstrate that the data points are supplied to the correct memory/port
locations for information being transferred to/from other parties, such that their masters can
read/write the data.
Commissioning and start-up of the PV Module Supplier SCADA system will be carried out by the PV
Module Supplier.
Expected deliverables include: Site acceptance procedure, onsite personnel for SCADA system
commissioning, completed acceptance test documentation demonstrating the appropriate
collection and distribution of all the data points.
6.4 FIBER OPTIC NETWORK DESIGN
6.4.1 Design Requirements
Contractor shall prepare fiber optic overview design drawings; specifically including all transitions
from OPGW to underground cable and the connections to the substation. Fiber Optic Network
Drawings
Contractor shall prepare fiber optic network drawings showing the fiber loop connections to the PV
Modules, meteorological towers, and substation. A minimum of (24) fibers shall be installed to each
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 687 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-8
Internal Use Only
PV Module. This design shall be based on that supplied by the PV Module Supplier and shall be
reviewed and approved by PV Module Supplier.
Prepare fiber optic network drawings as required for substation and radial line connections.
The fiber optic network design shall have sufficient capacity to support the installation of the PV
Module Supplier SCADA system. The Contractor shall submit for Owner’s review a complete set of
project Fiber Optic Network Drawings.
6.4.2 Fiber Optic Splice and Distribution Panel Details
Contractor shall prepare drawings detailing the splicing/connections required at all OPGW to
underground transitions, the substation fiber optic distribution panel, and Substation Control
House fiber optic distribution panel. Expected deliverables include: Fiber Optic Splicing Drawings,
Fiber Optic Distribution Panel Drawings.
6.5 FIBER OPTIC INSTALLATION
6.5.1 General Installation
Contractor shall furnish and install fiber optic cable interconnecting the PV Modules,
meteorological towers, the substation, and other locations as required. All cables shall be
appropriately labeled with a permanently attached label. Contractor shall provide spare fiber optic
cable to accommodate the addition of security card access, camera surveillance, etc., at all PV
Module locations at a future date.
The Contractor shall provide conduits as required for any fiber entry into the substation control
building including that associated with the Radial Line (e.g. OPGW). Conduit shall have a pull string
for pulling the cable. Fiber optic cables may be routed through substation control cable trenches
with other control wiring (subject to Applicable Laws, codes, and regulations) provided that a high-
visibility color inner duct is used for identification and protection of the fiber optic cables.
Contractor shall furnish and install fiber optic splice and distribution panels as required, including,
overhead to underground transitions and the project substation. All distribution panels shall be
neatly labeled with each fiber pair denoting the source and destination information. Fiber optic
distribution panels in the inverters shall be provided and installed by Contactor unless supplied
and installed by the inverter Supplier.
Contractor shall furnish and install above ground communications cable junction boxes as required.
6.5.2 Fiber Terminations
Contractor shall terminate all fiber optic cable utilized in the collection system, substation, and
other necessary locations. The cables shall be terminated with SC or ST connectors as required and
shall be in compliance with the inverter Supplier’s specifications. Connectors, break-out kits, and
other miscellaneous materials required for terminating shall be provided by the Contractor. Each
fiber pair shall be labeled with a permanently attached label.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 688 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| SCADA System 6-9
Internal Use Only
Expected deliverables include: Terminated fiber optic cables, Test reports.
Fiber patch cables from the fiber distribution panels to end devices shall be provided by others.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 689 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-1
Internal Use Only
7.0 Generator Lead Line
7.1 GENERAL
7.1.1 Definitions
Terms as found in this Scope of Work shall carry the definition as found in the General section.
Generator Lead Line shall include overhead or underground interconnection line from the project
substation to the POI.
7.1.2 General Specifications
Owner has prepared a conceptual Project design for the purpose of permit applications and
interconnection negotiations and specifying the minimum scope requirements for EPC of the
Project. Conceptual design drawings and equipment specifications shall be developed by the
contractor and shall verify all aspects of the conceptual design and shall provide final design, final
detailed specifications, and drawings for the Project in conformance with this Specification.
Contractor shall be responsible for design of the system based upon this conceptual design. All
conceptual drawings shall become the Contractor’s responsibility, and Contractor shall modify or
recreate all conceptual drawings to reflect actual design throughout the design and construction
phases of the Work. Modifications to the specifications within this Specification shall require
Owner review and approval.
Contractor shall design, complete all necessary studies, fabricate, furnish, install, test and
commission a complete, functional, and operating Project. All Contractor’s tasks shall be in
compliance with the applicable utility and all available utility business practice manuals,
LGIA/SGIA, PPA, Real Property Requirements, good utility practices, and in accordance with all
permits, federal, state and local regulations.
Contractor shall provide the appropriate personnel to manage all aspects of the work.
Contractor shall permanently assign the project management team upon authorization by Owner.
Any changes to Contractor’s management team will require prior approval by Owner. Contractor’s
Key Personnel (Project Manager, Site Construction Manager, and Project Engineering Manager, at a
minimum) shall be approved by Owner.
Contractor may use a sub-consultant for engineering design and studies work for this Scope of
Work; however, Contractor shall be the single point of contact for all of sub-consultant’s work and
deliverables. If Contractor plans to use specialized consultant to support any engineering/design
task in this Scope of Work, Contractor shall include name of the consultant and resumes for all
consultant team members for Owner’s approval with the original bid package submittal.
Contractor will organize monthly meetings to fit Owner’s needs. Monthly meetings may consist of
conference calls with file-sharing technology, ‘Face-to Face’ meetings at Owner’s facility , or
meetings held at the Project site. These monthly meetings will serve as the weekly meetings for
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 690 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-2
Internal Use Only
those particular weeks. It is anticipated that design work will be completed prior to mobilization at
the site. After mobilization meetings can be facilitated at the project site.
Contractor shall schedule the meetings with regular intervals to allow proper advance
planning by all participants.
Contractor shall provide a suitable meeting space for all participants with telephone and
internet WIFI connections available to all participants.
Contractor shall prepare and distribute an agenda for regularly occurring meetings, facilitate
the meetings, and prepare and distribute meeting notes following the meeting within 2
business days.
Contractor, and at Contractor’s discretion and as needed to support the project Contractor’s sub-
consultants and sub-contractors, and all other parties involved in the construction of the Project
shall attend preconstruction meetings as requested by Owner. Prior to mobilization, or as specified
below, Contractor shall present a construction plan including, but not limited to, the following:
Master project schedule (within XX days of the Effective Date),
Site specific safety plans,
Procurement plan (within XX days of the Effective Date),
Major equipment receipt, inventory and storage plan,
Construction sequence,
Methods and equipment to be used in all phases,
Tentative access and right-of-way roads,
Locations of staging areas,
Re-grading of roads,
Moving of equipment/property that will interfere or impact construction, and
Task-level construction schedule in MS Project format, showing all activities for the entire
duration of the Project from the first authorization through Final Completion.
Contractor shall be responsible for contacting all utility companies impacted by, or involved with,
the Project prior to starting any work to determine schedule of work and location of all temporary
and permanent facilities in the Project area.
Except as specified otherwise, Contractor shall provide all equipment, materials, transportation
services, labor, labor supervision, technical field assistance, scheduling, consumables, construction
equipment, construction tools, special tools, construction utilities, permanent utilities, testing
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 691 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-3
Internal Use Only
services, instruments, spare parts, and other services and items required for, or incidental to the
engineering, design, procurement, installation, construction, startup, testing, commissioning,
energization, and training for the Project. The supply of construction equipment shall include
lubricants, spare parts, and any other elements required for operation and maintenance. Spare
parts for Owner’s use after turnover are not included in the priced proposal unless specifically
listed.
Contractor shall include schedule and budget allowance for plan submittal to the authority having
jurisdiction for plan review and comment turn-around. All fees associated with plan submittals or
permit application fees are the responsibility of the Contractor. Contractor shall assume permitting
fees as normally expected.
Contractor shall include schedule and budget allowance for plans/studies submittals to Owner for
plans/studies review and comment turn-around to support Contractor’s Project schedule. The
minimum review time allotted for Owner reviews shall be 14 working days].
Contractor shall abide by the working hours established by Owner or by Project permits whichever
is more restrictive.
In general, work at the Project shall not be allowed on Saturdays, Sundays and federally
recognized holidays without prior approval by Owner.
Work hours shall be in compliance with the CUP for this Project.
7.1.3 Contractor Design Deliverables
Owner reserves 14 Business Days to review all design, procurement, and construction
deliverables (except where otherwise provided in the Agreement). Contractor shall build a
minimum review time as described here into all project schedules and scheduling documents.
Owner will make best efforts to review and comment on certain submittals with reduced
review and comment time provided Contractor requests accelerated review and comments
from Owner.
Contractor shall, at a minimum, provide all documents described in Section 7.1.2
Contractor shall provide design deliverables according to the Owner’s requirements as well
as the requirements of the Interconnecting Utility.
All drawings, specifications, studies, and calculations shall be sealed by a Professional
Engineer in good standing and licensed in the State of Idaho for the applicable discipline.
Contractor shall provide a 30 percent Generator Lead Line design deliverable to include, but
not be limited to, the following:
1. Environment loading criteria to include weather cases as specified by applicable codes
and standards with specific wind speed, wind load, ice thickness, wire temperature, etc.
for each weather case.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 692 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-4
Internal Use Only
2. Mechanical conductor loading criteria
3. Plan/Profile drawings and PLS-CADD model to include the entire Generator Lead Line
and final spans into the Substation
4. All material and construction specifications
5. Detailed pole-top configuration drawings for all anticipated structure types
Contractor shall provide a 60 percent Generator Lead Line design deliverable to include, but
not be limited to, the following:
1. Structure loading calculation details
2. Structure embedment calculations and designs
3. Insulation/Grounding design calculations
4. Steel pole procurement documents
5. Assembly detail drawings
6. Updated plan/profile drawings and PLS-CADD model to include the entire Generator
Lead Line and final spans into the Substation
Contractor shall provide an 90 percent Generator Lead Line design deliverable to include, but
not be limited to, the following:
1. All design drawings, calculations, specifications, etc. previously submitted updated
based upon Owner comments from previous submittals
2. Staking Sheets
3. Bid Schedules
4. Sag/Tension Report
5. Conductor Stringing Charts
6. All remaining design drawings, calculations, specifications, etc. usual and customary for
EPC of this Project
Design-period submittals shall conform to the following:
1. Deliverables shall be provided electronically via along with one printed copy to Owner’s
office .
2. Drawings shall be formatted as “full-size” sheets.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 693 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-5
Internal Use Only
3. Drawings shall be provided in Microstation unless otherwise agreed upon by Owner.
4. Generator Lead Line Interconnection design models shall be in PSSE, Aspen and PLS-
CADD format, v13.x, with SAPS structure analysis.
5. Text documents shall be in MSWord, latest version.
6. Spreadsheets shall be in MSExcel, latest version.
7. Project schedules shall be in Primavera P6, latest version.
Construction-Period Deliverables
1. Construction-period deliverables shall be provided, in hard-copy format, to Owner’s site
representative located at the project site and electronically
2. Contractor shall maintain, at the job-site, an up-to-date copy of all design deliverables
with “red-line” markups of any changes to the documents.
3. Material requisition proposals for Key Equipment as defined in the Specification.
Project Close-Out Deliverables
1. Contractor shall provide a copy of all final “red-line” design documents in hard-copy
format to Owner’s office in XXX and electronically via XX.
2. Contractor shall provide an as-built PLS-CADD, PSSE and Aspen Generator Lead Line
model,.
3. Contractor shall provide all detail drawings, assembly drawings, and equipment
drawings in Microstation.
4. Contractor shall abide by the requirements defined elsewhere in the Agreement for Job
Book submittal schedules and contents.
7.1.4 Owner Provided Facilities and Services
Owner-provided studies, equipment, etc.
7.1.5 Codes, Regulations, and Standards
Contractor shall design and construct the Project in accordance with, but not limited to, the
standards or organizations as shown below.
AA Aluminum Association
AASHTO American Association of State Highway and Transportation Officials
ACI American Concrete Institute
AISC American Institute of Steel Construction
AISE Association of Iron and Steel Engineers
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 694 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-6
Internal Use Only
ANSI American National Standards Institute
API American Petroleum Institute
AREMA American Railway Engineering and Maintenance Association
ASCE American Society of Civil Engineers
ASME American Society of Mechanical Engineers
ASNT American Society for Nondestructive Testing
ASTM American Society for Testing and Materials
AWS American Welding Society
CMAA Crane Manufacturer Association of America
CRSI Concrete Reinforce Steel Institute
EPA Environmental Protection Agency
HMI Hoist Manufacturer’s Institute
IBC International Building Code
ICEA Insulated Cable Engineers Association
IEC International Electrotechnical Commission
IEEE Institute of Electrical and Electronics Engineers
ISA Instrument Society of America
ISO The International Organization for Standardization
NACE National Association of Corrosion Engineers
NBS National Bureau of Standards
NEBB Nation Environmental Balancing Bureau
NEMA National Electrical Manufacturers Association
NERC North American Electric Reliability Council
NESC National Electrical Safety Code
NFPA National Fire Protection Association
OSHA Occupational Safety and Health Administration
SAE Society of Automotive Engineers
SDI Steel Deck Institute
SSPC Structural Steel Painting Council
UL Underwriters Laboratories, Inc
Contractor shall design and construct the Project in accordance with but not limited to the latest
versions of the standards or organizations as listed in this Section as well as any other Owner’s
contract documents.
In the case where standards have conflicting requirements, Contractor may select the most
stringent standards with Owner approval.
7.2 GENERATOR LEAD LINE MATERIAL AND DESIGN CRITERIA
7.2.1 General Requirements

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 695 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-7
Internal Use Only
There will be a redundant fiber-optic communication conductor buried or installed overhead
within the Generator Lead Line right-of-way from a splice vault, installed under this scope of
work, outside of Utility Operator’s facilities to a splice vault, installed under this scope of
work, outside of the Project Substation.
7.2.2 Generator Lead Line Design Criteria
Contractor shall design the Generator Lead Line according to the design criteria provided in
this Specification.
Contractor’s final design shall confirm all structure locations are in compliance with all
permitting requirements and/or all property requirements.
Contractor shall be responsible for the following:
1. Perform Generator Lead Line engineering, analysis, and design.
2. Prepare a complete construction package per the Scope of Work.
3. Procure equipment and material.
4. Receive, inventory, store, and protect equipment and material.
5. Construct the line.
6. Construct the Gen-Tie maintenance road.
7. Test and commission the Project.
8. Prepare as-constructed documents per the Scope of Work, which shall at a minimum
include the Gen-Tie facilities, right-of-way widths, easement areas, fences and gates, and
labeling of all major roads and points of interest in AutoCAD format.
9. It shall be the Contractor’s responsibility to complete all tasks necessary to provide
Owner with a complete and fully functional Generator Lead Line that meets all Owner’s
standards and specifications and meets generally acceptable industry standards.
7.2.3 Design Requirements
The Generator Lead Line must be designed and constructed in accordance with Owner’s
requirements and Interconnecting Utility’s requirements for the last structure outside of the
Utility’s substation.
The design specifications and drawing requirements provided or referenced in this document
are to be considered as minimum requirements. Any criteria not specifically addressed in this
specification shall as a minimum meet or exceed the requirement of the current edition of the
National Electric Safety Code (NESC) C2, and Owner’s specifications and requirements.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 696 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-8
Internal Use Only
Contractor shall use PLS-CADD, PESS and Aspen software to spot and perform detailed
analysis and design of the Generator Lead Line.
Phasing
1. Phasing shall be determined via coordination with the Facility design and
Interconnecting Utility’s requirements.
2. If it is determined that phase-swapping is required, the swap must occur on the
Generator Lead Line as close to the Interconnecting Utility’s substation and outside the
Project Substation as feasible. Final location must be approved by Owner.
OPGW and / or Fiber Optic Cable
1. The Generator Lead Line fiber optic design, installation, and testing shall meet
Interconnecting Utility’s requirements, LGIA requirements, and IEEE Guide to the
Installation of Overhead Transmission Line Conductors, Standard No. 824.
2. Contractor will coordinate OPGW and/or buried fiber optic cable termination design at
the Interconnecting Utility’s Switchyard with Owner and Interconnecting Utility to
ensure that the design is compatible with Interconnecting Utility design. [This could
require a splice box at the last structure, or it could require that sufficient surplus OPGW
and / or buried fiber cable be coiled at a below-grade structure leaving sufficient length
to allow Interconnecting Utility to pull the fiber-optic cables into Interconnecting
Utility’s substation for termination at their splice box, with Owner approval.]
3. For overhead fiber optic installations, the fiber-optic conductor installed as a shield
conductor at the top of the structure, with Owner approval.
4. For underground fiber optic installations, a redundant fiber optic communication line
shall be buried, and is assumed to follow the Generator Lead Line alignment to a
common fiber-optic splice box as installed by Contractor or Interconnecting Utility
adjacent to Interconnecting Utility’s Substation.
5. Splicing shall be done according to manufacturer’s recommendations. The contractor
shall record all final sag measurements. This report shall contain the following
information:
a. Date of the measurements
b. Span and span lengths
c. Ruling span
d. Wire temperature
e. Ambient temperature
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 697 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-9
Internal Use Only
f. Initial sag for the span
g. Time in blocks
h. Time of day
i. Sag measurements.
Conductor and Shield Wire
1. Contractor shall ensure that the selected conductor for the conductor and shield wire to
be used for the Generator Lead Line will meet the project technical requirements, with
Owner Approval.
2. The installation of the conductor and shield wire as well as the sizing of the stringing
sheaves and bullywheels to be utilized shall be in accordance with to the IEEE Guide to
the Installation of Overhead Transmission Conductors, Standard No. 524.
3. The contractor shall record all final sag measurements. This report shall contain the
following information:
a. Date of the measurements
b. Span and span lengths
c. Ruling span
d. Wire temperature
e. Ambient temperature
f. Initial sag for the span
g. Time in blocks
h. Time of day
i. Sag measurements.
7.2.4 Structure Types and Configurations
Contractor shall be responsible for establishing the configuration of every structure such that
electrical clearance requirements are met as well as any easement/permitting/right of way
requirements.
Contractor shall determine the ideal structure material for the structures in the event that the
owner does not specify. The material utilized shall be corrosion resistant or painted,
galvanized, or otherwise suitably protected in order to withstand the environmental
conditions for the design life of the structure.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 698 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-10
Internal Use Only
All structures shall be designed to withstand, without failure or permanent deformation, the
load cases required for the project. Structures shall be designed with methods to provide for
safe climbing.
All material/equipment is to be tested per the applicable clauses in the ASCE, ASTM, and ANSI
requirements, and certified test reports are to be provided.
Calculation of the design loads (load trees) is the responsibility of Contractor.
The last structure outside of Utility Owner’s Facility on the Generator Lead Line shall be
designed to Interconnecting Utility’s standards.
7.2.5 Generator Lead Line Foundation Design
Contractor shall interpret, evaluate, and apply all geotechnical reports, as provided by Owner
or as obtained by Contractor, and shall design the structure foundations taking into account
the structure loads, soil conditions, constructability, and other required factors.
Contractor shall design Generator Lead Line tower foundations to withstand hydrological
flows per drainage reports, as provided by Owner or as obtained by Contractor, including
depth, velocity, and scour potential.
Material used for the foundations shall be approved by the Owner.
All formwork used shall be according to ACI 301 and ACI 347. All reinforcement and
accessories used shall be according to ACI 301 and 315. The conveying, placement, and
vibration of the concrete shall be according to ACI 301.
All voids in the foundation shall be filled and all form ridges as well as other projections shall
be removed.
Contractor shall provide and maintain all bracing and shoring according to all applicable
safety regulations.
Contractor shall provide foundation according to owner requirements with appropriate
backfill material.
Contractor shall install permanent or temporary casing when it is apparent that the shaft
cannot be maintained due to sloughing or caving. The casing shall be installed as required to
counteract the sloughing or caving. In areas with a high water table where the excavation
cannot be pumped dry and the casing cannot restrict the flow of water into the excavation,
the shaft shall be augured under water or slurry. A detailed procedure and specification
describing the slurry displacement method for placing concrete shall be provided.
7.2.6 Material
Material shall be of new manufacture and unused and be free of defects and irregularities that
could cause corona.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 699 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-11
Internal Use Only
Contractor shall provide witnessing of factory acceptance tests for all key Equipment, as
defined in the Contract. Owner shall be given the opportunity, with a minimum of 21
calendar day’s notification, to attend all factory acceptance tests and shop visits for
equipment procured by Contractor.
Contractor shall bear the responsibility for delivery of equipment, spare parts, special tools,
and materials to the site and shall comply with the requirements specified in the Owner’s
documents as well as requirements in this Specification. All material shall be secured on site
in order to prevent, damage, theft, and to ensure protection from the elements.
These requirements also apply to any sub-suppliers making direct shipments to the jobsite.
Conductor surfaces shall be free of any and all defects that compromise the smoothness and
uniformity of the conductor’s contour, including die marks, dirt points, sharp edges,
abrasions, humped wires, or any other defect.
All material shall be packaged in weather-resistant cartons or crates that are suitable for
outdoor storage. Insulators shall be protected with material capable of preventing damage to
the sheds, connections, or end fittings during shipment. Storage shall be in compliance with
manufacturer’s requirements as well as the Owner’s requirements.
All items shall be checked against packing lists immediately on delivery to the site for damage
and for shortages. Damage and shortages shall be remedied with a minimum of delay at no
additional cost to the Owner.
Partial shipments shall be subject to review of Contractor before shipment, and, when
permitted, shall be plainly marked in such a manner to allow identification, accumulation, and
facilitation of eventual installation.
All assemblies, hardware, and components of assemblies shall be designed to meet the
requirements of the latest versions of ANSI, ASTEM, IEEE, NEMA, ASTM, and the NEC. The
material shall be made of steel, aluminum, malleable iron, or a combination of these materials,
material shall be chosen according to best performance. All ferrous metal components shall
be galvanized in accordance with ASTM A123, ASTM 153 or NEC G164.
Contractor shall verify that all material, assemblies, hardware, and components of assemblies
meet the strength requirements for the application and intended use as well as be designed to
avoid failure from fatigue.
Any piece of hardware in an insulator assembly must, at a minimum, match the ultimate
strength of the insulator. Each piece of hardware shall be marked with the specified
mechanical load, routine test load, assembly date code, and the manufacturer’s
identification/part/catalog number.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 700 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-12
Internal Use Only
All assemblies must assemble properly and be sized such that binding or overstressing of the
parts shall not occur during wire motion. The workmanship of all parts (threading, tapping,
etc.) shall be according to the Owner’s requirements as well as all applicable standards.
Contractor shall be responsible for design of the jumper assemblies such that all electrical
clearances are maintained.
All line hardware shall include all parts necessary in order to attach the conductors to the
insulators and to connect the insulators to the overhead line structure. This includes clamps,
links, clevises, shackles, pins, bolts, locking devices, etc.
All steel structures and support arms shall be hot dipped galvanized.
The Generator Lead Line conductors shall be non-specular and nonreflective, and the
insulators shall be nonreflective and nonrefractive.
Contractor shall produce a complete bill of material (BOM) for all equipment.
7.3 GENERATOR LEAD LINE SITE REQUIREMENTS
7.3.1 Site and Environmental Criteria
Contractor shall procure, obtain, and maintain all Contractor Acquired Permits, which includes
those permits required for the construction of the Project.
Contractor provided all permits required Some permits are clarified to be provided by others but
will require support from Contractor.
7.3.2 Fire Water during Construction/Fire Protection
Contractor is responsible for providing and permitting fire water and related systems at the Project
trailer complex, if required by applicable codes.
Fire Protection
1. Only work procedures which minimize fire hazards to the extent practicable shall be
used. Combustible debris and waste materials shall be collected and removed from the
work area each day. Fuels, solvents, and other volatile or flammable materials shall be
stored away from the construction and storage areas in well-marked, safe containers.
Good housekeeping is essential to fire prevention and shall be practiced by the
Contractor throughout the construction period.
2. Formwork, scaffolding, planking, cabling, and similar materials which are combustible
but which are essential to execution of the work shall be protected against combustion
resulting from welding sparks, cutting flames, and similar fire sources.
3. Contractor shall provide qualified personnel for fire control as appropriate. Contractor
shall provide adequate fire protection equipment in each warehouse, office and other
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 701 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-13
Internal Use Only
temporary structures, and in each work area for which Contractor is responsible.
Access to sources of fire water shall be kept open at all times. Suitable fire extinguishers
shall be provided in enclosed areas, in areas that are not accessible to fire water, or in
areas that may be exposed to fire that cannot be safely extinguished with water. Each
fire extinguisher shall be of a type suitable for extinguishing fires that might occur in the
area in which it is located. In areas where more than one type of fire might occur, the
type of fire extinguisher required in each case shall be provided. Each extinguisher shall
be placed in a convenient, clearly identified location that will most likely be accessible in
the event of fire.
4. Contractor, alone, shall be responsible for providing adequate fire protection of all
construction areas. Failure of the Contractor to comply or the Owner to enforce, the
above requirements shall not relieve Contractor from any responsibility or obligation
under the Contract.
7.3.3 Environmental Compliance
All design and construction shall comply with the EIS, EIR, and all other documents provided by
Owner
Reference Contract for definition of responsibility regarding environmental compliance by
Contractor.
7.3.4 Preserved Areas
Owner will identify areas designated as naturally preserved within the boundaries of the project
site and Contractor shall comply with Owner plans and restrictions.
7.3.5 Site Access
Contractor shall ensure that all of its employees, agents, guests, invitees, and other workers
under its direct or indirect control receive an access identification badge to be provided by
Contractor. Access identification badges shall be used to enter and exit the Project. Access of
personal vehicles to the Project will be limited to ingress egress, and parking at an employee
parking area to be designated by Owner. Contractor shall ensure that any vehicles driven by
Contractor’s employees, agents, guests, invitees, or other workers under its direct or indirect
control, are registered with Contractor prior to entering the Project and display Contractor
information on such vehicle. Personal vehicles of any kind are prohibited from entering areas
of the Project.
Contractor shall install a secured fence per approved design and permit drawings before
Contractor commences construction. If, in Contractor’s opinion and Owner’s concurrence, a
planned permanent fence can be installed in lieu of a temporary site fence, Contractor may
forego the temporary site fence and install the permanent fence to adequately protect the
Work area, any laydown areas, and prevent unauthorized access.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 702 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-14
Internal Use Only
7.3.6 Site Management
Contractor shall provide all necessary construction, safety, quality, and site management.
7.3.7 SWPP Plan
Contractor shall provide all materials, labor and equipment necessary to ensure compliance with
the requirements of the applicable permits and applicable laws. Compliance with the SWPP plan
and applicable laws is mandatory and will be verified by the Owner’s Site Representative.
Contractor agrees to be bound by Owner’s Site Representative’s findings.
7.3.8 Unloading and Staging
Contractor shall provide all equipment and labor to unload and stage materials and equipment
delivered to the Project related to this Scope of Work. Contractor shall receive all materials at the
laydown area unless an alternative location has been directed or approved by Owner. For materials
supplied by Owner, Contractor shall provide signed packing slips to Owner by the end of each work
day, which signed packing slip shall serve as evidence of Contractor acceptance of all materials
listed on packing slip. Contractor shall be responsible for all Owner-provided materials and
equipment after delivery to the Project or laydown area.
7.3.9 Site Facilities
Contractor shall provide all Project facilities, including all utilities and sanitary facilities, to be
cleaned and restocked daily, for Contractor’s own use. Contractor shall provide temporary above-
ground toilet facilities. Contractor shall provide all additional facilities as may be necessary to
support completion of this Scope of Work, including, but not limited to, any change trailers, lunch
rooms, hand washing facilities, shade tents, and drinking water. Contractor shall be responsible for
maintaining all Project facilities provided by Contractor. Daily cleaning of Project facilities is
mandatory and will be verified by random Owner inspection.
7.3.10 Cleanup
Contractor shall comply with all requirements herein, contractor’s Clean-up Plan (CUP)
requirements, or permitting requirements, whichever is more stringent.
Contractor shall be responsible, at its own expense, for daily cleanup of all areas and
equipment in which Work is performed under this Scope of Work. Contractor shall provide
waste facilities and dumpster and shall be responsible for off-site disposal of construction-
generated waste materials. Contractor shall be responsible for daily road cleaning of all
exterior roads used to access the Project. Contractor shall ensure that no mud or debris
remains on the roads. Compliance with daily cleanup is mandatory and will be verified by
random Owner inspection.
Special attention shall be given to keeping the Project and surrounding grounds clean and
free from trash and debris. Contractor shall require all disciplines under Contractor’s control
to thoroughly clean their work areas each working day. Contractor’s on-site manager shall be
responsible for site maintenance and cleanliness. This shall include sweeping the floor,
collecting and disposing of trash, and all other functions required to keep the Project, storage
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 703 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-15
Internal Use Only
areas, and temporary offices clean. All hoses, cables, extension cords, and similar materials
shall be located, arranged, and grouped so they will not block any access way and will permit
easy cleaning and maintenance.
Contractor shall be responsible for waste disposal on a regular basis to prevent waste build-
up at the Project and in all work areas under Contractor’s control. Contractor shall be
responsible for removal and lawful disposal of all discarded material, debris, rubbish,
unusable excavated material, and waste, including Hazardous Materials, if any, generated by
Contractor and its subcontractors and suppliers during construction of the Project.
7.3.11 Site Restoration
Contractor shall stabilize and restore all areas of the Project disturbed during execution of this
Scope of Work including taking all steps necessary to comply with the Dust Control Plan, SWPP
Plan, Revegetation Plan, applicable laws, and applicable permits. Contractor is responsible for
demobilizing and restoring the area disturbed as a result of its activities to Owner-acceptable
conditions, and is required to take all steps necessary to ensure that there are no conditions at the
Project at the conclusion of this Scope of Work that violate the Dust Control Plan, SWPP Plan,
Revegetation Plan, Applicable Laws, and Applicable Permits.
7.3.12 Trenches/Excavations
Contractor shall ensure all open trenches and/or excavations are cordoned off with approved
delineation means and signage. Contractor shall also closely coordinate with all of Contractor’s
Subcontractors to ensure that trenches and/or excavations minimally impede flow of pedestrian
and vehicular traffic through the Project. Road plate shall be used to ensure emergency vehicles
can cross trenches at all access roads. Contractor shall, at its own expense, remedy trench cave-ins
and water infiltration.
7.3.13 Equipment Condition
Contractor off-road, on-road and portable combustion equipment shall be delivered to the Site
clean of vegetation, soiling, and with no visible oil, grease, fuel staining or active leaks.
Documentation of the equipment to be delivered to the work area and used by Contractor shall be
provided to Owner, in a format to be specified by Owner, no later than two days prior to delivery.
Undocumented equipment shall only be allowed on Site with approval from Owner. Prior to
equipment leaving, documentation of equipment usage in hours or miles shall be provided to the
Owner.
7.3.14 Fuel Storage
Contractor shall abide by all applicable permits and local regulations pertaining to the fueling
of vehicles and equipment required while performing this Scope of Work. This may include
the requirement to refuel equipment at the Project Site for the purpose of minimizing overall
vehicle emissions caused by traveling away from the Project to refuel or resupply equipment.
Contractor may use mobile refueling or may provide stationary fuel storage tanks for
refueling Contractor’s vehicles. Owner will negotiate other scopes of work related to the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 704 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-16
Internal Use Only
Project in which fuel storage tanks may be permitted. Contractor is allowed to negotiate fuel
purchase agreements with contractors awarded other scopes of work for either mobile
refueling or refueling via fixed fuel storage tanks for other scopes of work.
7.3.15 Equipment Leaks and Spills
Contractor shall immediately report to Owner all equipment leaks and spills, other than
‘drips’ (by Owner’s definition), that occur. Clean-up of spills/leaks, accumulation of wastes
from the clean-up, and disposal of this waste by the Contractor shall be conducted under the
direction of Owner.
Contractor shall mitigate all fuel spills, at a minimum, according to requirements in the CUP
or as found in the permitting requirements, whichever is more stringent.
7.3.16 Work or Travel Violations of Marked Boundaries
Owner will establish and mark work area limits, buffers or boundaries by fence, rope, staking or
documents provided to Contractor. Contractor shall not move markers unless at the direction of
the Owner. Contractor shall not perform work or travel beyond work area limits. Contractor shall
immediately notify Owner when work or travel occurs beyond work area limits.
7.3.17 Recycling
Contractor shall ensure compliance with Owner’s goal of zero waste discharge such that all
materials that come onto the Project that are not incorporated into the Work shall be collected and
recycled. All materials that are not incorporated into the Work shall be recycled through
Contractor provided, and Owner approved containers. Contractor shall be responsible for properly
separating waste materials into the appropriate recycling containers. Contractor shall provide
proof of recycling at Owner’s request.
7.3.18 Site Connectivity and Communications
Contractor shall ensure that it has sufficient on-site internet and telephone connectivity
necessary for performance of the tasks under this Scope of Work.
Communication facilities to be installed on the Generator Lead Line for the permanent
installation shall be provided by Contractor. This includes the fiber-optic communication
lines from the Transmission Owner’s Substation to the Project Substation and connection
from the commercial telecom point of service to the Project Substation.
Contractor will contract with the local Telecom provider to connect service and will provide
the phone line isolation equipment as specified by the Telecom provider and shall be
responsible for any fees associated.
Contractor shall:
1. Provide the ground potential rise, fault values, X/R data etc. required by the local
telecom company for installation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 705 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-17
Internal Use Only
2. Verify with the telecom provider the telecom point of Demarcation for the telecom
service.
3. Install the telecom pedestal in a manner approved by the telecom provider in the
approved location.
4. Install all ducting required to and from the telecom pedestal location as well as all
cabling not provided by the telecom provider.
7.3.19 Transportation
Contractor shall be responsible for transportation of Contractor’s employees, agents, guests,
invitees, and all other workers under its direct or indirect control, and all material and equipment
necessary for performing the tasks under this Scope of Work. To the extent possible, Contractor and
Contractor’s Subcontractor’s vehicular traffic shall remain on designated roadways.
7.3.20 Lighting
Contractor shall provide all necessary artificial lighting for tasks performed under this Scope of
Work where artificial lighting is necessary.
7.3.21 Water
The Contractor shall supply potable water or bottled water required for Contractor’s construction
personnel as required throughout the construction period.
7.3.22 Dust Control/Non-Potable Water for Construction
Contractor shall provide a construction water source for use. Contractor shall be responsible
for transportation of construction water from the source throughout the Project as required
for soil conditioning and dust control.
Contractor is responsible for all fugitive dust emissions with respect to this Scope of Work,
including compliance with Applicable Permits and Applicable Laws and the requirements
identified in this Specification.
Contractor compliance with dust mitigation requirements (including the requirements
described in the Applicable Permits and Applicable Laws and this Specification will be
verified by Owner. Contractor agrees to be bound to Owner’s findings. Contractor is solely
responsible for any fees incurred or fines issued by any Governmental Authority related to
violations of Applicable Permits and Applicable Laws.
7.4 CONSTRUCTION
7.4.1 General
Contractor shall prepare, compile, issue, and update a construction specification for the work
described in this chapter.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 706 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-18
Internal Use Only
Contractor shall procure material and construct the Generator Lead Line such that, when in
operation, it does not cause nuisance audible noise or radio or television interference.
Contractor shall calculate estimated audible noise, radio interference, and television
interference levels and provide those results to Owner.
Contractor shall make all reasonable efforts to minimize all damages due to construction
activities. Damages to private property, of any type, are the responsibility of Contractor.
Contractor shall be responsible for preparing and acquiring all storm water construction
permits.
All temporary openings in fences created by Contractor shall be removed and the fence
repaired when access is no longer required. Contractor shall be held responsible for damage
to crops, livestock, or other property resulting from failure to keep fences, gates, or fence gaps
in proper condition.
Contractor shall be responsible for grounding all fences and structures along the Generator
Lead Line route according to applicable codes and standards.
Contractor shall repair and restore the right-of-way and clean up each structure location to
the satisfaction of Owner and according to all permitting requirements or landowner
agreements. All earthwork, culverts, bridges, and drainage structures constructed by
Contractor shall be removed when no longer required.
Contractor shall be responsible for preserving the operating capability of all active utility
infrastructure crossing or located within the project site. Any damage to the infrastructure
shall be promptly repaired to the satisfaction of the owner(s) of the infrastructure.
Contractor is responsible for staking structure foundations prior to excavation.
All excavated/displaced material as a result of foundation construction shall be removed from
site and disposed of by Contractor in compliance with all federal, state and local regulations
and applicable permits.
Site dewatering during construction is the responsibility of Contractor.
All parts of the structures shall be purchased and installed by Contractor.
Interconnecting Utility will install conductor from the last Generator Lead Line structure
(POI) to Interconnecting Utility’s facilities
Conductor and OPGW shall be installed in accordance with “IEEE Guide to the Installation of
Overhead Transmission Line Conductors”, Std. No. 524.
7.4.2 Surveying
Contractor shall employ a registered professional land surveyor for all survey work on this
project.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 707 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-19
Internal Use Only
Contractor is responsible for performing a survey of the Owner-established corridors
according to the Owner’s requirements.
Contractor is responsible for obtaining all necessary geotechnical data for final design of the
Generator Lead Line structure foundations.
Contractor’s survey firm is responsible for establishing a ground control network and
collecting controlled, color, digital, ortho-rectified photography and terrain data. Contractor’s
survey firm is also responsible for processing the raw data and delivering a digital elevation
model in a format readily imported into PLS-CADD.
7.4.3 Access
Site access shall be in accordance with local requirements and as described in Owner’s
requirements. The Contractor is responsible for the heavy haul route and for any necessary
improvements. The Contractor shall coordinate this work with other entities as required.
7.4.4 Outages
Contractor shall coordinate outages with the Transmission Provider (if applicable) and the
Owner, and submit an outage plan as required by the Owner and Transmission Planner. The
outage plan shall contain all scheduled interruptions of electrical power or other utilities- and
detail any interference that would affect the Project or any PV Project or third parties. This
plan shall be submitted by Contractor to Owner and affected parties for Owner’s review and
approval.
Contractor shall take reasonable efforts to schedule construction activities so that required
outages are minimized or can be scheduled during off-peak hours for the Transmission
Provider’s system.
7.4.5 Temporary Power
Contractor shall prepare a document detailing the temporary power that will be required for
the project. This document shall include the location of the temporary power facilities, labor
required to install the facilities, equipment and material needed, laydown/storage
requirements, outage requirements, construction activity required, safety procedures and any
other relevant information.
Contractor shall be responsible for arranging temporary power as needed for construction.
Contractor shall be responsible for the removal and disposal of any temporary power
facilities once construction is completed.
Contractor shall be responsible for any required permits, if required.
7.5 CLOSE OUT
At the time of substantial completion, all of the following documentation shall be provided by the
EPC provider:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 708 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Generator Lead Line 7-20
Internal Use Only
Owner’s manual including all equipment manufacturers’ manuals.
As-built drawings.
Test reports for all material/structures.
Startup and shutdown protocol for maintenance.
Safety protocol for maintenance.
Emergency response protocol.
Any other documentation deemed appropriate by the Owner/project requirements.
Orientation and training shall be provided by the Contractor at the time of substantial completion
for Operator participants.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 709 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-1
Internal Use Only
8.0 Commissioning
8.1 COMMISSIONING REQUIREMENTS
8.1.1 General Requirements
The Contractor shall be responsible for conducting a Commissioning Plan for the Facility that
includes all Commissioning Inspections and Tests outlined in this Specification, except for an
interconnecting substation when included in the Facility. The Commissioning Plan shall
comply with all of the requirements set forth by this Specification.
The Contractor shall include in the Commissioning Plan any additional tests or measurements
required by applicable Standards, Codes or the requirements of all AHJ, which may include
the Local Electric Utility and equipment manufacturers.
The Commissioning Plan shall include a safety plan.
All labor, materials, equipment, and tools used to complete the Commissioning Plan shall be
qualified and suitable for the assigned task.
All tests shall meet the requirements presented in this Specification and all referenced
industry standards.
All tests shall be performed in accordance with any applicable manufacturer’s instructions
and requirements.
The Contractor shall submit an initial draft of the Commissioning Plan to the Owner for
review a minimum of four weeks prior to the scheduled start of commissioning. The Owner
shall return comments to Contractor and Contractor shall amend and resubmit the
Commissioning Plan to Owner no more than ten business days after comments were received.
Contractor shall be responsible for finalizing the Commissioning Plan with Owner.
The Commissioning Plan shall include a proposed commissioning schedule that is consistent
with the overall project schedule (including start and end dates) and presents the following in
detail:
1. Each test to be performed
2. Expected duration of each test,
3. Plans for submission of test data and final test report
The Contractor’s Commissioning Plan shall include the Contractor’s standard punch list to
track progress in resolving issues identified during the execution of the Contractor’s
Commissioning Plan.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 710 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-2
Internal Use Only
1. The Owner and Contractor shall agree upon when the punch list is reviewed that in no
case shall exceed one week without written consent of the Owner.
2. The Contractor shall provide the punch list to the Owner as updates are made in
progress in resolving issues.
3. When issues can be rectified immediately, the Contractor shall record the issue on the
punch list as being closed.
8.1.2 Testing Requirements
The test procedures defined in the Commissioning Plan shall include, at a minimum, the
following information:
1. Prerequisites to the tests
2. Make and model of equipment to be used for measuring data
3. List of the data that will be collected
4. Test procedures which shall be used
5. Successful acceptance criteria
6. Any differences between tests in the Plan and this Specification
7. Test report templates, which are examples of all proposed inspection, responsible party
and test reporting forms
When conducting tests, the Contractor shall comply with the following requirements:
1. Provide at least ten business day notice to Owner prior to the commencement of any
inspections and/or tests
2. When all tests are successfully completed, the Contractor shall provide a Commissioning
Report to the Owner per section 8.1.6
3. All testing shall comply with all applicable pre-operational requirements set forth by the
local AHJs, and Owner approved Commissioning Plan
4. All testing equipment shall be calibrated in accordance with to the applicable
manufacturer's requirements and industry standards and be conducted by a certified
and recognized equipment testing authority
5. Provide equipment calibration certificates for all installed instrumentation as part of
submission of test documentation
Testing Personnel/Technicians performing these electrical tests and inspections shall be
trained and experienced concerning the apparatus and systems being evaluated. These
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 711 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-3
Internal Use Only
individuals shall be capable of conducting the test in a safe manner and with complete
knowledge of the hazards involved. They must evaluate the test data and make a judgment on
the serviceability of the specific equipment
Technicians shall be certified in accordance with ANSI/NETA ETT-2010, Standard for Certification
of Electrical Testing Technicians. Each on site crew leader shall hold a current certification, Level III
or higher, in electrical testing.
8.1.3 Testing Conditions
All equipment required for normal operation of the Facility shall be operated in normal,
automatic, or emergency, manual modes, as applicable.
During all tests, the Owner or Owner representative shall have access to the Facility and all
operating data for purposes of monitoring and calculating performance.
8.1.4 Calculations
All calculations prescribed within this Specification shall be carried out by the Contractor and
submitted to Owner for approval.
8.1.5 Required Inspections, Tests and Verifications
8.1.5.1 General Inspections
The General Inspections shall be performed by the Contractor with Owner or Owner
Representative prior to any Commissioning tests.
Any issues identified by the General Inspections shall be added to the Contractor’s punch list,
upon Owner agreement
The General Inspections shall be repeated for all issues on the punch list associated with the
General Inspections until each one is resolved.
8.1.5.1.1 Visual inspection
The General Inspections shall include the visual inspection of the constructed Facilities
against the design drawings for possible issues. The General Inspections shall identify any
issues and/or irregularities, including but not limited to the following:
1. All cables, modules, racking, inverters and other system components shall be visually
inspected to be free of physical damage
2. All electrical and communication wires and cables shall be visually inspected to ensure
that they are installed in a clean and workmanlike manner with no loosely hanging
wires
3. All connectors and ground connections will be inspected to make sure they are tight and
correct
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 712 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-4
Internal Use Only
4. All system components shall be visually inspected to be free of corrosion or oxidation
issues such as rusting
5. The Site shall be visually inspected for unforeseen obstructions which may cause
unexpected shading on modules
6. All welds performed in the field shall be visually inspected by a certified welding
inspector for issues
7. Visual torque marks shall be visually inspected on all lug and bolt heads.
8. Torque marks shall extend for the center of the bolt head continuously to the surface on
which the bolt is secured
9. The alignment of post shall be visually inspected.
10. Soil compaction and depth of embedded post for ground mounted systems shall be
tested against design.
11. The underground cable arrangement shall be inspected prior to the trench backfill.
Trench evacuated correctly.
12. Underground cable bending, Cable spacing, fiber cable and motor cable installed
properly, warning tape installed in proper depth, backfill material are free from debris
and rocks, all cable are free from stress, defect and visible physical damage.
13. Contractor shall repair major equipment components if damaged from Factory.
14. Contractor shall exclude any foreign material.
8.1.5.1.2 Design compliance verifications
The General Inspection shall verify the installation of system components complies with the
Facility design and include a review of the following are as required by these Specifications:
1. Markings and labels of all cables, circuits, protective devices, switches and terminals,
and all other equipment are suitably affixed and durable
2. Equipment ratings
3. Wire sizing
4. Module flash test review
5. Mounting or racking components
6. Tracker components (if applicable)
7. Equipment physical location and arrangement
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 713 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-5
Internal Use Only
8.1.5.2 Grounding Systems Inspections
The General Inspection shall include an inspection of the grounding systems to ensure that all
components are properly grounded according to design and specifications. The Grounding
System shall be inspected in accordance with NETA-ATS Section 7.13.
Grounding connections shall be inspected by an AHJ or other independent quality control
inspector to verify proper installation of all compression clamps, CAD welds, and mechanical
connections.
All groundings (DC and AC system, communication cables with grounded metallic
components, etc.) shall conform to all applicable codes and standards.
Visual inspection of the grounding systems shall at a minimum verify: All underground work
shall be documented and reviewed by Owner or Owner Representative during construction.
1. Racking posts grounded per specifications and connected to system grid
2. All connections
3. Mechanical attachment
4. Anti-oxidation coatings applied, as required
5. Lugs fully seated
6. Whip installed per manufacturer's requirements
7. Connections to grounding grid
8. Exothermic welds
9. Compression clamps
10. Grounding rods
a. Rods set to depth per drawings
b. Clamp fully engaged
c. Whip/cable fully engaged
8.1.5.3 Grounding Systems Testing
The Grounding System shall be tested in accordance with NETA-ATS Section 7.13 and E-11-01
“Grounding”.
The three point and two point test values shall be in accordance with NETA-ATS Section
7.3.2.3.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 714 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-6
Internal Use Only
Ground resistance testing shall be by the fall-of-potential method in accordance with IEEE 81.
8.1.5.4 PV String Open-Circuit Voltage Testing
Open-circuit voltage (Voc) string testing shall be conducted in order to assess overall module
and string performance.
The test shall be conducted and witnessed by at least one qualified technicians using best
practices and the following procedure:
1. The test shall be conducted during periods of irradiance greater than 700 W/m2 and
between the hours of 10:00 am and 2:00 pm solar time.
2. Inspect string fuses for appropriate use and correct sizing
3. Measure and record the following for every string:
4. String number and combiner box location (or similar relevant string identification)
5. Time of test and weather conditions
6. Module backsheet temperature at a location representative of the strings being tested
7. Plane-of-Array (POA) irradiance measurement for area of strings being tested
8. Open-circuit voltage (Voc) measurement of every string within each combiner box.
9. Measurement shall be made using a voltmeter with the suitable voltage rating and
accuracy of at least 0.5%
10. Each measured string Voc shall be within 5% from the expected Voc (Voc-expected) and
within 5% of adjacent strings under identical temperature and irradiance conditions.
The expected V_oc shall be calculated using the following equation:
=1 +
where:
= expected open-circuit voltage of the string
= module open-circuit voltage at reference conditions
= number of modules in series in tested string
= module open-circuit temperature coefficient (°C-1)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 715 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-7
Internal Use Only
= measured module backsheet temperature (°C)
= back of module temperature at reference conditions
Comparisons between all measured and expected Voc shall be analyzed in a spreadsheet
which shall include the following PASS/FAIL tests for each string:
1. String Voc-measured is within 5% of Voc-expected
2. String Voc-measured is within 5% of the Voc-measured of adjacent strings
3. Strings that fail either test shall be investigated for module defects, loose connections,
disconnected modules, or other possible defects
8.1.5.5 PV String IV Curve Testing
Contractor shall perform IV Curve Tests for all strings of modules connected to combiner
boxes at each combiner box location, unless specified by Owner.
The test shall be conducted and witnessed by at least two qualified technicians using best
practices and the following procedure:
1. The test shall be conducted during periods when irradiance is greater than 700 W/m2
and between the hours of 10:00am and 2:00pm solar time
2. Verify that the module and IV Curve Tracer are compatible
3. Shut down the inverter associated with the string and combiner box being tested
4. Disconnect the combiner box (or relevant DC disconnect switch) from the inverter and
all other DC systems
a. Measure, record and verify the following for every string:
b. String number and combiner box location (or similar relevant string
identification)
c. Date and time
d. POA irradiance at precise time of test
e. Module backsheet temperature (use a string representative of all others being
tested)
f. Ambient temperature
g. Wind speed
h. Weather conditions
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 716 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-8
Internal Use Only
i. Correct polarity shall be verified
5. Using an IV Curve Tracer, perform the curve trace using the manufacturer's
instructions.
6. The Curve Tracer shall be configured to record at least 10 current-voltage data points
and record the following values:
a. Maximum power (Pmax)
b. Voltage at maximum power (Vmp)
c. Current at maximum power (Imp)
d. Open circuit voltage (Voc)
e. Short circuit current (Isc)
f. Fill Factor (FF)
Short-circuit current test: Each measured string short-circuit current shall be greater than the
expected short-circuit current (Isc-expected) derived using the following equation:
=
where:
=expected short-circuit current of the string
= short-circuit current at Standard Test Conditions (STC)
as shown on module datasheet
= 0.95 (uncertainty and soiling factor)
= measured irradiance (W/m2)
= 1000 W/m2
8.1.5.6 Low Voltage Insulation Resistance Testing
All low voltage (LV) direct current (DC) and alternating current (AC) cables shall be tested for
insulation resistance in accordance with the NETA-ATS.
Measured insulation resistance values shall be adjusted to a 20°C reference in order to
determine acceptance with NETA-ATS Tables 100.1 and 100.14.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 717 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-9
Internal Use Only
All insulation resistance acceptance criteria shall be proposed by Contractor for approval by
Owner.
Any test results that fail to be in accordance with the NETA-ATS or do not meet the accepted
criteria, shall be documented as a deficiency on the test report.
Corrective action shall follow the identification of a failed test, followed by re-testing.
8.1.5.7 Low Voltage Cable Inspection and Testing
Low voltage cables shall include only those designed to operate at or below 1000 V.
All low voltage cables shall be inspected and tested in accordance with NETA-ATS Section
7.3.2.
Test Values shall be in accordance with NETA-ATS Section 7.3.2.3.
1. Note: NETA-ATS states that Section 7.3.2 is for low-voltage cables up to a 600 Volt
Maximum.
2. This section shall also be used for cables with voltages up to 1000 Volts
Test voltages applied in the field shall not exceed the maximum test voltage of NETA-ATS
Table 100.1
Verify uniform resistance for all parallel conductors
8.1.5.8 Medium Voltage Cable Inspection and Testing
Inspection and testing shall be performed after all splices and cable terminations have been
installed.
All medium voltage cables shall be inspected and tested in accordance with NETA-ATS Section
7.3.3. Test Values shall be in accordance with NETA-ATS Section 7.3.3.3.
The preferred test method for Section 7.3.3.2.4 is by partial discharge analysis. Test methods
other than those listed in NETA-ATS 7.3.3.2.4 may be used only with approval by the Owner.
Test voltages applied in the field shall not exceed 80% of the factory test value, and shall not
exceed the maximum test voltage shown in NETA-ATS Table 100.6.
Verify proper installation of faulted-cable indicators as shown in the project drawings, as
applicable.
8.1.5.9 Polarity Verification
All circuits shall be verified to have the correct polarity according to the design drawings and
Local Electric Utility.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 718 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-10
Internal Use Only
8.1.5.10 Low-Voltage Insulated/Molded-Case Air Circuit Breaker Inspection and Testing
Inspect and test each circuit breaker in accordance with NETA-ATS Section 7.6.1.1.
Confirm that if a breaker is being back-fed, it is rated accordingly.
Verify that the test values are in accordance with NETA-ATS Section 7.6.1.1.3.
8.1.5.11 Low-Voltage Power Air Circuit Breaker Testing
Inspect and test circuit breakers in accordance with NETA-ATS Section 7.6.1.2.
Confirm that if a Breaker is being back-fed, it is rated accordingly.
Verify that Test Values are in accordance with NETA-ATS Section 7.6.1.2.3.
8.1.5.12 Low Voltage DC and AC Switch Testing
Inspect and test each low voltage switch in accordance with NETA-ATS Section 7.5.1.1.
Confirm and document correct electrically-bonded equipment ground.
Confirm and document that metal-enclosed switches are clean and that any debris has been
removed.
Verify that switches used in DC applications are rated and installed accordingly.
Verify that warning signs (where provided) are in accordance with the National Electrical
Code (NEC), or equivalent electrical code that is applicable to the Facility.
Verify that Test Values are in accordance with NETA-ATS Section 7.5.1.1.3.
8.1.5.13 Switchgear Equipment Inspections
Contractor shall review factory testing and field testing documentation to confirm that all MV
and HV (as applicable) switchgear assemblies have passed all factory tests including, but not
limited to:
1. Insulation Resistance
2. AC High Voltage Withstand
3. Main Contact Resistance (Ductor Tests)
4. Earth Switch Resistance (Ductor Tests)
5. Oil Dielectric Strength
6. Functional Tests
7. Type Tests
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 719 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-11
Internal Use Only
Contactor shall review factory test and field test documentation to confirm that all LV
switchgear has passed all factory tests including, but not limited to:
1. Insulation Resistance
2. Contact Resistance
3. Functional Tests
4. Type Tests
8.1.5.14 Small and Large Dry-Type Transformer Testing
Inspect and test each Transformer in accordance with NETA-ATS Section 7.2.1.1 or 7.2.1.2
(small or large transformers).
Verify that Test Values are in accordance with NETA-ATS Section 7.2.1.1.3 or 7.2.1.2.3.
1. Proof and documentation of equivalent factory testing, if applicable, may be provided in
place of Contractor performing the tests described above.
Dry-Type Transformer noise level test.
8.1.5.15 Inverter Commissioning
Inverters shall be commissioned by the inverter manufacturer, or an authorized
representative of the manufacturer, using the manufacturer’s specified procedures.
Commissioning reports shall be in a format provided by the manufacturer.
At a minimum, inverter commissioning shall meet the following requirements:
1. Inverters shall be fully operational after commissioning completion
2. All shipping and packing materials shall be removed from inverter cabinets
3. Fuses and air filters shall be checked, verified as correct and in place
4. Torque wrench marks shall be recorded
5. Software updates and data acquisition (DAQ) communication shall be tested and
functional
6. If applicable, Noise Level Study shall indicate inverter meets requirements specified in
this Specification.
8.1.5.16 Pad-Mount Liquid Filled Transformer Commissioning
At a minimum, Pad-mounted liquid filled transformer commissioning shall meet the following
requirements:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 720 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-12
Internal Use Only
1. Transformer shall be fully operational after commissioning completion.
2. All shipping bracing materials shall be removed from transformer after placement.
3. PCB content labeling shall be presented.
4. Operation shall be normal for alarm, control, and trip circuits from temperature and
level indicators, pressure relief device, gas accumulator, and fault pressure relay if
applicable
5. Cooling fans and pumps shall operate correctly and have appropriate overcurrent
protection.
6. Verify correct liquid level in tanks and bushings.
7. Positive pressure is maintained on gas-blanketed transformers.
8. De-energized tap-changer position is left as specified.
9. The Contractor shall perform resistance measurements through bolted connections
with a low-resistance ohmmeter, if applicable.
10. Perform insulation-resistance tests, all winding-to-winding and each winding-to-
ground. Apply in accordance with manufacturer’s published data.
11. Perform turns-ratio tests at all tap positions. With the last test being on the selected
position
12. Perform insulation power-factor or dissipation-factor tests on all windings in
accordance with test equipment manufacturer’s published data.
13. Perform power-factor or dissipation-factor tests on each bushing equipped with a
power-factor/ capacitance tap. In the absence of a power-factor/ capacitance tap,
perform hot-collar tests.
14. Perform excitation-current tests in accordance with test equipment manufacturer’s
published data.
15. Measure the resistance of each high-voltage winding in each de-energized tap-changer
position. Measure the resistance of each low-voltage winding in each de-energized tap-
changer position
16. Collect a sample of insulating liquid in accordance with ASTM D 923. Sample shall be
tested for the following:
a. Dielectric breakdown voltage: ASTM D 877 and/or ASTM D 1816
b. Acid neutralization number: ANSI/ASTM D 974
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 721 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-13
Internal Use Only
c. Specific gravity: ANSI/ASTM D 1298
d. Interfacial tension: ANSI/ASTM D 971 or ANSI/ASTM D 2285
e. Color: ANSI/ASTM D 1500
f. Visual Condition: ASTM D 1524
g. Water in insulating liquids: ASTM D 1533.
h. Power factor or dissipation factor in accordance with ASTM D 924.
17. Collect a sample of insulating liquid in accordance with ASTM D 3613 and perform
dissolved-gas analysis (DGA) in accordance with ANSI/IEEE C57.104 or ASTM D3612.
8.1.5.17 Meteorological Monitoring Station Testing
All meteorological monitoring station equipment shall be commissioned, calibrated and
tested using the manufacturer's specified procedures with performance being compared to
the manufacturer’s specifications.
Current calibration certificates for each installed instrument shall be provided to Owner.
The following instrumentation, if it is part of the metrology equipment specified by Owner,
shall be tested, at a minimum:
1. Solar irradiance measurement device, as applicable, e.g.:
a. Global horizontal irradiance (GHI)
b. Plane of array (POA) irradiance
2. Anemometer (wind speed), as applicable
3. Module backsheet temperature, as applicable
4. Ambient temperature, as applicable
5. Rainfall gauge, as applicable
6. Data-logger and communications equipment, as applicable
8.1.5.18 Protective Relay Equipment Inspection and Testing
Protective relay equipment not part of an interconnecting or solar collector substation at the
Facility shall be inspected and tested in accordance with NETA-ATS Section 7.9.
Each equipment device shall be programmed with the specified relay settings provided by, or
approved by, the Local Electrical Utility or Owner.
The following shall be performed at a minimum:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 722 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-14
Internal Use Only
1. Verify that all grounding pins have been removed from all shorting-type terminal blocks
in non-spare current transformer circuits
2. Verify that all spare current transformers are properly shorted
3. Perform functional testing of each protection and control scheme, including breaker trip
tests, close inhibit tests, lockout relays, alarm functions, communication functions, and
breaker-failure schemes
8.1.5.19 Metering Equipment Inspection and Testing
Metering equipment not part of an interconnecting or solar collector substation at the Facility
shall be inspected and tested in accordance with NETA-ATS Section 7.11.
8.1.5.20 Surge Arrestor Inspection and Testing
Surge arrestors shall be inspected and tested in accordance with NETA-ATS Sections 7.19.1
and 7.19.2.
Test Values shall be in accordance with NETA-ATS Section 7.19.2.3.
8.1.5.21 Thermographic Surveys
Perform a thermographic (infrared) survey in accordance with NETA-ATS Section 9.
All thermo graphic images shall be provided to Owner and the survey shall meet the following
requirements:
1. The survey shall be performed after all other commissioning tests are complete and
while the Facility is operational
2. An infrared (IR) camera shall be used to detect areas of non-uniform temperature
3. The test shall be conducted during a minimum POA irradiance of 700 W/m2
4. The survey shall include the following equipment:
a. All combiner and recombiner boxes
b. All AC power distribution equipment
c. All inverters (if infrared test window is available)
d. All transformers (if infrared test window is available)
e. Ten (10) percent of all PV modules from the front (optional)
f. Ten (10) percent of all PV modules from the rear (optional)
5. Any covers, shields, or doors on equipment shall be opened, moved or removed during
testing of equipment to ensure the survey is free of obstructions to a clear IR image.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 723 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-15
Internal Use Only
6. Investigate and comment on the results of the thermographic survey in a report that
states either no issues were identified or comments on temperature differences greater
than:
a. Three degrees Celsius (3°C) between similar components in the same enclosure
b. Fifteen degrees Celsius (15°C) between components and ambient air
8.1.5.22 Communications System Inspection and Testing
Inspection and testing of optical fiber cables shall be in accordance with NETA-ATS Section
7.25.
The Contractor shall test the communication system to demonstrate its ability to support the
systems and communications connectivity dependent upon its proper functioning prior to the
testing of those dependent systems (i.e., the Solar PV Facility SCADA System).
Testing shall be done twice as applicable for each complete cable run between active devices:
when each cable segment is installed and when the final system interconnections between
active devices have been made.
1. All Ethernet communication cables shall be tested for proper installation according to
TIA-568-C and/or TIA-1005-A
2. Testing of optical fiber cables shall be performed using Tier 2 testing in TIA-568-C,
which includes the Optical Loss Test Set (OLTS) testing method and the Optical Time
Domain Reflectometer (OTDR) testing method
A. All communication system cable tests shall be successfully completed prior to starting the
testing of any systems being supported by the communications cables.
8.1.5.23 Instrumentation Testing
All instrumentation furnished by the Contractor and recommended or required by the
manufacturer for calibration shall be field calibrated and tested by the Contractor with
performance compared to the manufacturer’s specifications.
The Contractor shall furnish all material, tools, skilled labor, administrative and technical
assistance, test instruments, calibration equipment and calibration standards and devices.
Testing of instrumentation shall be as directed by manufacturer’s field service
representatives.
8.1.5.24 Solar PV Facility SCADA System Testing
A Site Acceptance Test (SAT) shall be performed for verification of all data points and SCADA
System performance.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 724 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-16
Internal Use Only
1. Tests shall verify the correct operation of the Solar PV Facility SCADA System and its
associated meters, sensors, meteorological instruments, inverters, etc., while verifying
the correct data input logging from trackers, breakers, and other components
monitored and controlled by the system (as required by the Solar PV Facility SCADA
System Specification).
2. All data points collected by the Solar PV Facility SCADA System shall be verified for
consistency from the field device to the master device and, if applicable, to all remote
monitoring facilities.
The SAT should include all tests from the Factory Acceptance Test (FAT) included in the Solar
PV Facility SCADA System Specification.
All Solar PV Facility SCADA System equipment shall be commissioned and tested using the
manufacturer's specified procedures.
Tests shall verify that the data collected is correctly received by the Solar PV Facility SCADA
System and can be used to produce any required performance or operation reports.
8.1.5.25 Security System Testing
Security system equipment shall be commissioned, tested and calibrated by a certified
installer of the equipment manufacturer using the manufacturer’s specified procedures.
Security system testing shall include testing of all operating modes and alarm conditions.
If applicable, camera coverage shall demonstrate the ability to observe any location within the
Facility area.
If available, security system commissioning reports shall use a reporting format or forms
provided by the security system provider.
8.1.5.26 Sound Level Testing
If applicable, verify noise levels of inverters, dry transformers and medium voltage
transformers.
Perform analysis and comparison of baseline sound study with post-construction sound
levels.
Measure sound levels at all property lines.
8.1.6 Commissioning Report Requirements
The Contractor shall prepare and submit to the Owner for approval a Commissioning Report
ten business days prior to Substantial Completion as defined in Contract. The Commissioning
Report shall include:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 725 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-17
Internal Use Only
1. Documentation of any discrepancy between this Specification and the tests/inspections
conducted in the field.
2. Documentation of each test and inspection from the Commissioning Plan showing at
least the test/inspection period, test/inspection conditions and the Contractor's
personnel responsible for test/inspection
3. A statement of whether each of the Commissioning tests/inspections either passed or
failed
4. If one or more test/inspections failed, a detailed explanation shall be documented in the
punch list, including resolution
5. A signed statement from Contractor and Commissioning Manager certifying that the
Facility complies with all of the Commissioning requirements set forth in this
Specification
6. The punch list showing all issues successfully resolved
The Commissioning Report shall include for each test:
1. Any mutually agreed upon deviations
2. A copy of the calibration certificate for all measurement instrumentation used
3. Field notes (weather conditions, observations, etc.)
4. Test data, including corrected test data
5. Test calculations, including expected results
6. Any deficiencies or issues identified during, or as a result, of testing
7. Any corrective actions taken shall be documented, and shall include any subsequent
retesting results, as applicable
8. Conclusions
9. Signatures of testing personnel and the Contractor’s witness
All Commissioning Report documentation containing numerical test data, calculated results,
and related information shall be included in the report in Comma Separated Value (CSV)
format.
All Commissioning Report files submitted to Owner shall be named in accordance with the
Commissioning Plan as applicable. For example:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 726 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-18
Internal Use Only
1. The Open-Circuit Voltage (Voc) String Test found in Section 8.1.5 shall have a
corresponding test report labeled "VocStringTestReport.pdf" and associated data files
labeled "VocStringTestData.csv"
8.1.6.1 Grounding Systems Inspection and Test Reporting
The grounding systems report shall document all inspections and tests in accordance with
NETA-ATS Section 7.13 and that the test values are in accordance with NETA-ATS Section
7.13.3.
8.1.6.2 PV String Open-Circuit Voltage Test Reporting
The PV string open-circuit voltage report shall include:
1. String number and combiner box location(s)
2. Date and time of test and weather conditions
3. Module backsheet temperature [°C]
4. POA Irradiance [W/m2], >=700 W/m2], at time of test
5. Measured open-circuit voltage (Voc-measured) [V], for each string
6. Expected Voc calculation (Voc-expected) [V], for each string
7. Percent difference between Voc-expected and Voc-measured
8.1.6.3 PV String IV Curve Test Reporting
The PV String IV curve test report shall include:
1. String number and combiner box location
2. Date and time of test and weather conditions
3. Ambient temperature [°C]
4. Module backsheet temperature [°C]
5. POA Irradiance [W/m2], >=700 W/m2], at time of test
6. Wind speed [m/s]
7. Verification of correct polarity
8. Measured short-circuit current (Isc-measured) [A], for each string tested
9. Expected short-circuit current calculation (Isc-expected) [A], for each string tested
10. Verification that Isc-measured is larger than Isc-expected
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 727 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-19
Internal Use Only
8.1.6.4 Low Voltage Insulation Resistance Test Reporting
The low voltage insulation resistance test report shall include:
1. Measured insulation resistance for each low voltage cable (in Megohms)
2. Verification that measured resistance exceeds recommended minimum insulation
resistances presented in NETA-ATS
3. Identification of replaced cables that fail the insulation test
4. Cable tests (low voltage)
a. Visual and mechanical inspections in accordance with NETA-ATS Section 7.3.2
b. Electrical tests in accordance with NETA-ATS Section 7.3.2
8.1.6.5 Low Voltage Cable Test Reporting
The low voltage cable test report shall document the results from all low voltage cable
inspections and tests in accordance with NETA-ATS Section 7.3.2.
8.1.6.6 Medium Voltage Cable Test Reporting
The medium voltage cable test report shall document the results from all medium voltage
cable inspections and tests shall in accordance with NETA-ATS Section 7.3.3.
8.1.6.7 Polarity Test Reporting
The polarity test report shall document that all circuits have the correct polarity according to
the design drawings.
8.1.6.8 Circuit Breaker Test Reporting
The circuit breaker test report shall document all inspections and tests in accordance with
NETA-ATS Section 7.6.
8.1.6.9 Switch Test Reporting
The switch test report shall document all inspections and tests in accordance with NETA-ATS
Section 7.5.1.
8.1.6.10 Switchgear Equipment Inspection Reporting
The switchgear equipment test report shall document the passing of the following factory
tests for low voltage switchgear assemblies:
1. Insulation resistance
2. AC high voltage withstand
3. Main contact resistance
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 728 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-20
Internal Use Only
4. Earth switch resistance
5. Functional tests
6. Type tests
8.1.6.11 Small and Large Dry-Type Transformer Test Reporting
The transformer test report shall document all inspections and tests in accordance with
NETA-ATS Section 7.2.1.
8.1.6.12 Inverter Test Reporting
The inverter test report shall be from the manufacturer or authorized manufacturer
representative.
The inverter test report shall document at least the following:
1. Inverters are fully functional
2. Fuses and air filters have been checked and verified as correctly installed
3. Torque wrench marks have been recorded and mechanically verified
4. Software is tested, up-to-date, and functional
5. Noise level is within specified levels and all power output levels
8.1.6.13 Meteorological Station Test Reporting
The meteorological station test report shall document at least the following:
1. Provision of calibration certificates for all meteorological monitoring station
instruments
2. Verification that all meteorological monitoring station equipment has been tested and
verified as to the manufacturer’s specifications and is functional
8.1.6.14 Protective Relay Equipment Test Reporting
The protective relay equipment test report shall document all inspections and tests in
accordance with NETA-ATS Section 7.9.
The following shall be documented at a minimum:
1. All grounding pins have been removed from all shorting-type terminal blocks in non-
spare current transformer circuits
2. All spare current transformers are properly shorted
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 729 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-21
Internal Use Only
3. Functional testing of each protection and control scheme, including breaker trip tests,
close inhibit tests, lockout relays, alarm functions, communication functions, and
breaker-failure schemes
8.1.6.15 Metering Equipment Test Reporting
The metering equipment test report shall document all inspections and tests in accordance
with NETA-ATS Section 7.11.
8.1.6.16 Surge Arrestor Test Reporting
The surge arrestor test report shall document all inspections and tests in accordance with
NETA-ATS Section 7.19.1 and 7.19.2 and that the test values were in accordance with Section
7.19.2.3.
8.1.6.17 Thermographic Survey Reporting
The thermographic survey test report includes the results and analysis of the thermographic
(infrared) survey in accordance with NETA-ATS Section 9.
The test report includes submission of infrared scans for:
1. All combiner boxes
2. All recombiner boxes
3. All AC power distribution equipment
4. All inverters and transformers (if infrared test window is available)
5. Ten percent (10%) of all PV modules, both front and back scan (Optional)
The thermographic survey report shall comment on the results of the thermographic survey
and document any issues identified.
8.1.6.18 Communications System Test Reporting
The communications system test report documents that the all components of the
communications cabling are properly installed.
8.1.6.19 Solar PV Facility SCADA System Verification Reporting
The Solar PV Facility SCADA System test report documents that data collected by the Solar PV
Facility SCADA System from meters, sensors, weather station instruments, trackers, breakers,
inverters and other components monitored by the system is correctly received and meets the
requirements of the Solar PV Facility SCADA Specification.
8.1.6.20 Instrumentation Test Reporting
The instrumentation test report shall document at least the following:
1. Provision of calibration certificates for all instrumentation
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 730 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
CO.| Commissioning 8-22
Internal Use Only
2. Verification that all instrumentation equipment has been tested and verified as to the
manufacturer’s specifications and is functional
8.1.6.21 Security System Test Reporting
The security system test report includes the installer’s verification of the completed
commissioning, testing and calibration of the security system.
The security system test report shall show that all operating modes and alarm conditions
have been tested.
8.1.6.22 Sound Level Reporting
If applicable, the sound level test report shall document the noise levels of inverters, dry
transformers and medium voltage transformers.
The sound level test report shall document how the post-construction sound levels compare
to the baseline sound study.
The sound level test report shall document the sound levels at all property lines.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 731 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-1
9.0 Performance Testing
9.1 FUNCTIONAL TEST
A functional test of 72 hours of uninterrupted operation of the Facility shall be designed to
demonstrate and document the items below. Prior to commencement of this test, all Facility
equipment shall be operable:
Facility functionality. The test will demonstrate that the Facility is capable of operating
through daily generation cycles.
Data collection. Facility information will be collected and logged, demonstrating operability of
the SCADA system and communication/monitoring systems.
Reporting. Demonstrate that the SCADA system is capable of producing any operational
reports required to document Facility performance.
Design parameters. Monitoring of the Facility and components will permit verification of
Facility operation within expected ranges of design parameters. Contractor shall use data
from the 72-hour test to demonstrate that the Facility is producing a minimum of 95% of the
energy output expected of the Facility based on input irradiance, temperature and wind speed
conditions. Performance results below 100% shall be accompanied by a written explanation
of the deficiency.
Compliance. The ability of the Facility to comply with all material safety, system reliability,
environmental, and other applicable Laws, Governmental Approvals, the EPC Agreement, the
Power Purchase Agreement, and the Interconnection Agreement.
9.2 SHORT TERM PERFORMANCE RATIO TEST
9.2.1 Purpose
The Performance Ratio of a solar photovoltaic (PV) power generating facility (the Facility) is
defined as its energy production (kWh) divided by the product of: its DC capacity (MWp), and the
normalized irradiance and a temperature correction factor over the Test Period.
The purpose of a Performance Ratio Test is to compare the Measured Performance Ratio of the
Facility to its Expected Performance Ratio.
The Performance Ratio Test in this Specification is an application of the methodology
recommended by the US National Renewable Energy Laboratory (NREL).
Prior to the Short Term Performance Ratio Test, contractor shall successfully complete the 72
hours functional test listed in Section 9.1 Functional Test.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 732 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-2
9.2.2 Measurement Requirements
9.2.2.1 Measurement Instrumentation Requirements
The following measurement instrumentation shall be used during the Test Period:
Plane of Array Solar Irradiance [W/m2]:
1. The Plane of Array (POA) shall mean the plane defined by the (array of) PV modules.
2. POA irradiance shall be measured using ISO 9060 secondary standard rated
pyranometers installed so that they are co-planar with the POA of the PV modules.
3. A minimum of two of secondary standard grade pyranometers shall be installed for
every 20 MWp of Facility capacity.
4. Three (or more) pyranometers shall be installed proximate to the PV array (up to 20
MWp) that they are monitoring.
PV Module Backsheet Temperature [°C]:
1. PV module backsheet temperature shall be measured using platinum resistance
temperature detectors (RTDs) that are adhered to the back of operational PV modules
using a thermally conductive compound consistent with the PV module manufacturer’s
recommendations.
2. The accuracy of the RTDs shall meet or exceed IEC 751-95 Class A.
3. A minimum of three RTDs shall be installed for every 20 MWp of Facility capacity.
4. The RTDs shall be attached to PV modules that are located near the center of the PV
array (up to 20 MWp) that they are monitoring.
Inverter Output Power [Wac]:
1. Each inverter under test shall report its output power.
AC Energy Production [kWh]:
1. The energy production of the Facility shall be measured at the Point of Metering using
an AC watthour meter that meets or exceeds the accuracy standards set forth in ANSI
C12.1.
Copies of current calibration certificates for all required instruments shall be submitted to
Owner for review and acceptance.
All required instruments shall be installed and maintained in accordance with their
respective manufacturer’s specifications and recommendations.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 733 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-3
All pyranometers shall be cleaned daily in accordance with the manufacturer’s
recommendations.
All required instruments shall be connected to a Data Acquisition System (DAS) that supports
the requirements of this Specification, in accordance with the manufacturer’s specifications,
and that complies with the instrumentation manufacturers’ specifications and
recommendations.
9.2.2.2 Measurement Data Record Requirements
All required measurement data shall be collected and recorded at one-minute intervals.
Each measurement data record shall include the date and time, with one-minute resolution,
when it was recorded.
9.2.2.3 Required Measurement Data Fields
Each data record shall include the following data fields:
Date-Time Stamp: Date (Month, Day, Year) and Time (Hour, Minute).
Each required pyranometer.
Each required RTD.
The output power of each inverter.
The watthour meter.
9.2.2.4 Required Channel-Averaged Measured Data Fields
Each measurement data record shall include the following channel-averaged measured data fields:
The channel-averaged measured POA irradiance, shall be calculated as the average over all of
the individual POA irradiance readings.
The channel-averaged measured RTD temperature, shall be calculated as the average over all
of the individual RTD temperature readings.
9.2.3 Test Period
The Test Period is the period of time during which the required data for the Performance Ratio Test
is collected for the purposes of analysis. The duration of the Test Period shall be sufficient to
include a minimum number of Eligible Measurement Averaging Intervals (EMAIs).
9.2.3.1 Minimum Number of Eligible Measurement Averaging Intervals
The minimum number of EMAIs for the Performance Ratio Test shall be 150.
9.2.3.2 Eligible Measurement Averaging Intervals
An Eligible Measurement Averaging Interval (EMAI) shall:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 734 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-4
1. Be a contiguous five-minute interval.
2. Not overlap any other EMAI.
3. Meet or exceed the Minimum Irradiance Requirement.
4. Only include measurements when the PV arrays do not experience any significant
Shading Loss.
5. Only include measurements when the output of each inverter is below its Clipping Limit.
6. Exclude times when snow, ice or any other obstructions cover a portion of the array.
7. Exclude time periods when force majeure events beyond the control of the Facility
Operator impact the energy production of the Facility.
8. Not have any missing or flawed required measurement data.
9.2.3.3 Minimum Irradiance Requirement
The Minimum Irradiance Requirement for an EMAI is an average POA irradiance of 700
[W/m2] in the Plane of Array over the interval.
9.2.3.4 Shading Loss
Shading Loss is significant if it is greater than 1 percent.
9.2.3.5 Inverter Clipping Limit
The Clipping Limit of an inverter is defined as 98 percent of its nameplate output rating.
9.2.3.6 Interval-Averaged Measured Data
The following measured 1 minute data entries within each EMAI shall be averaged over the interval
to produce an EMAI data record of interval-averaged value for that EMAI:
Channel-averaged measured POA irradiance.
Channel-averaged measured RTD temperature.
The watthour meter.
9.2.3.7 Date-Time Stamps for EMAI Data Records
Each EMAI data record shall be stamped with the date and time to at least 1 minute resolution of
the earliest-occurring data record included in that EMAI.
9.2.4 Calculation of Expected Performance Ratio
The Performance Ratio Test compares the Measured Performance Ratio, of a solar PV facility
to its Expected Performance Ratio, .
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 735 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-5
9.2.4.1 Performance Model, Expected Solar Resource and Energy Production Estimate
Calculation of the Expected Performance Ratio, utilizes the following items, which shall have
been mutually agreed to by The Parties prior to the commencement of the Performance Ratio Test:
A representative Performance Model for the Facility.
A complete Typical Year of hourly-resolution (8,760 hours/year) solar resource and weather
dataset for the Facility location.
A complete-year of hourly-resolution (8,760 hours/year) Expected Energy Production
Estimate using the above.
Furthermore, the Performance Model for the Facility must also report for each hour of the Typical
Year (8,760 hours/year):
Expected POA irradiance.
Expected PV module backsheet temperature.
9.2.4.1.1 Losses Excluded From the Energy Production Estimate
The following losses shall be excluded from the PE used in the Performance Ratio Test:
Long-term degradation in PV module performance.
Long-term soiling loss.
System availability loss (Availability shall be 100 percent).
Production losses due to snow.
9.2.4.2 Use of the Results from the Energy Production Estimate
The Expected Average Irradiance-weighted PV Module Temperature, ,and the Expected
Performance Ratio, ,for each month, are calculated using the hourly results, from the PE;
specifically:
Expected POA irradiance, G ,[W/m2].
Expected PV module temperature, T ,[oC].
Energy production at the point of metering, E ,[kWh].
Hours in the PE where one or more inverters operating at or above their Clipping Limit shall
be excluded.
The remaining hourly results in the PE shall be grouped by month, k.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 736 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-6
9.2.4.3 Monthly Expected PV Module Temperatures and Performance Ratios
Expected irradiance-weighted average PV module backsheet temperature for the kth month,
T ,shall be calculated as:
,=,,
,

The Expected Performance Ratio for the kth month, PR ,shall be calculated as:
,=,
,
where any hours excluded per Section 9.1.4, ,and ,are set equal to zero:
,=,= 0 for any excluded hours
and where:
VARIABLE UNITS DESCRIPTION
,[oC] Expected irradiance-weighted average PV module backsheet
temperature for the kth month (see Table 9.4.1)
,[oC]Expected PV module backsheet temperature for the jth hour in a
given month
,[%] Expected Performance Ratio for the kth month (see Table 9.4.1)
,[kWh] Expected Energy Production in the jth hour of the PE
[kWp] Contracted DC Capacity of the Facility at STCA
= 1.0 [hours] Hourly time step in the PE
[W/m2] Irradiance at STC(1)
,[W/m2] Expected POA irradiance in the jth hour of the PE
Index running over all months, ={1…12}
Total number of hours in the kth month
Index running over all hours within a given month, ={1…}
(1)2 o .
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 737 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-7
9.2.4.4 Table of Expected Monthly Values
Table 9.4.1 provides places for the monthly Expected Performance Ratios, ,and monthly
Expected Average Irradiance-weighted PV Module Temperatures, ,for each month, to be
entered.
The values shall be entered in Table 4-1 prior to the start of the Test Period in accordance
with this Specification, as part of the terms of agreement between the Owner of the Facility
and the Party that is responsible for its performance.
Table 9.4.1 Monthly Expected Performance Ratios and Expected Average
Irradiance-Weighted PV Module Temperatures
k Month , [%],[OC]
1 January To Be Identified through RFP Process
2 February
3 March
4 April
5 May
6 June
7 July
8 August
9 September
10 October
11 November
12 December
9.2.4.5 Expected Values for the Performance Ratio Test
If n EMAIs occur in month k, and m =(N m) EMAIs occur in month (k + 1), then PR and T
shall be calculated from Table 9.4.1 as:
=1 ,+,
=1 ,+,
9.2.5 Calculation of Measured Performance Ratio
The Expected Performance Ratio, shall be calculated as:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 738 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-8
=,
,,,
,,= 1 +,
where:
VARIABLE UNITS DESCRIPTION
[%] Measured Performance Ratio
, [kWh] Measured Energy Production over the ith EMAI
[kWp]Contracted DC Capacity of the Facility at STCA
[hours] Time duration of the EMAIs (held constant over the Test Period)
[W/m2]Irradiance at STC(1)
,[W/m2]Measured POA irradiance over the ith EMAI
,,PV module temperature correction factor for the ith EMAI
[%/oC]Temperature coefficient of Power (negative) for the PV modules
,[oC]Measured PV module backsheet temperature over the ith EMAI
[oC]Expected irradiance-weighted average PV module backsheet
temperature for the Test Period (see Section 9.1.4)
Total number of EMAIs
Index running over all EMAIs, ={1 …}
(1)Standard Test Conditions (STC): 1000 [W/m2] POA irradiance, 25 [oC] cell temperature.
9.2.6 Performance Ratio Test
The Performance Ratio Test compares the Measured Performance Ratio, of the facility to its
Expected Performance Ratio, reduced by the Measurement Uncertainty Allowance (MUA).
9.2.6.1 Measurement Uncertainty Allowance
The Measurement Uncertainty Allowance (MUA) allows for the inherent uncertainty in the
measurement equipment.
A. The MUA shall be 2 percent.
9.2.6.2 Acceptance Threshold of the Performance Ratio Test
A. The result from a Performance Ratio Test is acceptable if:
(1 )
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 739 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-9
9.2.7 Reporting Requirements
The following data and calculations shall be provided to Owner in the Performance Ratio Test
Report and associated documents.
9.2.7.1 General Requirements
The Performance Ratio Test Report shall include:
1. Dates of the Test Period, test conditions and Contractor’s personnel responsible for The
Performance Ratio Test.
2. A statement of whether the Performance Ratio Test either passed or failed.
3. If the Performance Ratio Test failed, a detailed explanation shall be submitted to Owner
for review.
4. A signed statement from Contractor that the Project complies with all of the
requirements set forth in this Specification.
9.2.7.2 Requirements for Reporting Measured Data
A copy of all required measurement data collected throughout the entire Test Period shall be
submitted to Owner for review and acceptance.
9.2.7.3 Requirements for Reporting Test Results
The result from the calculation in Section 9.1.6 shall be submitted to Owner for review and
acceptance.
9.3 ONE YEAR ADJUSTED ENERGY TEST
9.3.1 Purpose
The Adjusted Energy Production [kWh] of a solar photovoltaic (PV) power generating facility (the
Facility) is calculated by inputting the measured solar irradiance and weather conditions
(Measured Conditions), collected over the Test Period, into the Performance Model of The Facility.
The purpose of an Adjusted Energy Test is to compare the Measured Energy Production of the
Facility over the Test Period to the Adjusted Energy Production.
9.3.2 Measurement Requirements
9.3.2.1 Measurement Instrumentation Requirements
The following measurement instrumentation shall be used during the Test Period:
Solar Irradiance [W/m2]:
1. Solar Irradiance shall be measured using ISO 9060 secondary standard rated
pyranometers.
2. The Plane of Array (POA) shall mean the plane defined by the (array of) PV modules.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 740 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-10
3. The pyranometers shall be installed in accordance with irradiance input requirement of
the Performance Model for The Facility, typically either:
So that they are co-planar with the POA of the PV modules (POA Irradiance).
or
On a horizontal plane (Global Horizontal Irradiance, GHI).
4. A minimum of three of secondary standard grade pyranometers shall be installed for
every 20 MWp of Facility capacity.
5. Three pyranometers shall be installed proximate to the PV array (up to 20 MWp) that
they are monitoring.
Temperature [°C]:
1. Temperature shall be measured in accordance with irradiance input requirement of the
Performance Model for The Facility, typically either:
PV module backsheet temperature.
or
Ambient air temperature.
2. If PV module backsheet temperature is to be measured.
PV module backsheet temperature shall be measured using platinum resistance
temperature detectors (RTDs) that are adhered to the back of operational PV modules
using a thermally conductive compound consistent with the PV module manufacturer’s
recommendations.
The accuracy of the RTDs shall meet or exceed IEC 751-95 Class A.
A minimum of three of RTDs shall be installed for every 20 MWp of Facility capacity.
The RTDs shall be attached to PV modules that are located near the center of the PV
array (up to 20 MWp) that they are monitoring.
3. If ambient air temperature is to be measured.
An ambient air temperature sensor with ±0.1 [oC] accuracy or better shall be used.
Wind Speed [m/s], if required as an input to the Performance Model for The Facility:
1. A non-directional anemometer with ±0.5 [m/s] accuracy or better shall be used.
2. A minimum of one anemometer shall be installed for every 20 MWp of Facility capacity.
Inverter Output Power [Wac]:
1. Each inverter under test shall report its output power.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 741 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-11
AC Energy Production [kWh]:
1. The energy production of The Facility shall be measured at the Point of Metering using
an AC watthour meter that is appropriately sized according to the manufacturer’s
specifications for the generating capacity being metered, and meets or exceeds the
accuracy standards set forth in ANSI C12.1.
Copies of current calibration certificates for all required instruments shall be submitted to
Owner for review and acceptance.
All required instruments shall be installed and maintained in accordance with their
respective manufacturer’s specifications and recommendations.
All pyranometers shall be cleaned at least once per week in accordance with the
manufacturer’s recommendations.
All required instruments shall be connected to a Data Acquisition System (DAS) that supports
the requirements of this Specification, in accordance with the manufacturer’s specifications,
and that complies with the instrumentation manufacturers’ specifications and
recommendations.
9.3.2.2 Measurement Data Record Requirements
All required measurement data shall be collected and recorded at 1 minute intervals.
Each measurement data record shall include the date and time, with 1 minute resolution,
when it was recorded.
9.3.2.3 Required Measurement Data Fields
Each data record shall include the following data fields:
Date-Time Stamp: Date (Month, Day, Year) and Time (Hour, Minute).
Each required pyranometer.
Each temperature sensor.
Each wind speed sensor, if required.
The output power of each inverter.
The watthour meter.
9.3.2.4 Required Channel-Averaged Measured Data Fields
Each measurement data record shall include the following channel-averaged measured data fields:
The channel-averaged measured irradiance, for each type of irradiance measured, shall be
calculated as the average over all of the individual irradiance readings of the same type.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 742 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-12
The channel-averaged measured temperature, for each type of temperature measured, shall
be calculated as the average over all of the individual temperature readings of the same type.
The channel-averaged measured wind speed, if required, shall be calculated as the average
over all of the individual wind speed readings.
9.3.3 Test Period
The Test Period is the period of time during which the required data for the Adjusted Energy Test is
collected for the purposes of analysis.
The Test Period shall be one calendar year (365 days)
The Test Period shall be divided into 5 minute Measurement Averaging Intervals
9.3.3.1 Eligible Measurement Averaging Intervals
An Eligible Measurement Averaging Interval (EMAI) shall:
1. Be a contiguous 5 minute interval.
2. Not overlap any other EMAI.
3. Meet or exceed the Minimum Irradiance Requirement.
4. Only include measurements when the PV arrays do not experience any significant
Shading Loss from obstructions not included in The Model.
5. Exclude times when snow, ice or any other obstructions cover a portion of the array.
6. Exclude time periods when force majeure events beyond the control of the Facility
Operator impact the energy production of the Facility.
7. Not have any missing or flawed required measurement data.
9.3.3.2 Shading Loss
Shading Loss is significant if it is greater than 1 percent.
9.3.3.3 Inverter Clipping Limit
Not applicable.
9.3.3.4 Minimum Irradiance Requirement
The Minimum Irradiance Requirement for an EMAI is an average POA irradiance of
500 [W/m2] over the interval.
9.3.3.5 Interval-Averaged Measured Data
The following measured 1 minute data entries within each EMAI shall be averaged over the interval
to produce an EMAI data record of interval-averaged value for that EMAI:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 743 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-13
Channel-averaged measured irradiance, for each type of irradiance measured.
Channel-averaged measured temperature, for each type of temperature measured.
Channel-averaged measured wind speed, if required.
The watthour meter.
9.3.3.5.1 Date-time stamps for EMAI data records
Each EMAI data record shall be date-time stamped with the Date-Time Stamp of the earliest
occurring data record included in that EMAI.
9.3.3.6 Hour-Averaged Measured Data
The year in which the Test Period occurs shall be sub-divided into 8,760 (=365*24) hourly
intervals.
Any EMAI data records collected on February 29 (leap year) shall be excluded.
Each EMAI data record within each hour of the Test Period shall be averaged the hour to
produce a hourly data record for that hour.
9.3.3.6.1 Date-time stamps for hourly data records
Each hourly data record shall be date-time stamped with the date of the earliest occurring
EMAI data record included in that hour, and the ending hour of that hourly interval.
9.3.4 Adjusted Energy Calculation
The Adjusted Energy Test compares:
The Measured Energy Production, E (Test Period
) [MWh] of The Facility over the Test
Period.
To its Expected Energy Production, E (Test Period) [MWh].
to calculate an energy production adjustment factor that is then applied to:
The original Expected Annual Energy Production Estimate, E ,(TMY) [MWh/yr] for the
Facility.
To produce an adjusted Annual Energy Production Estimate, E ,(TMY) [MWh/yr] for the
Facility.
9.3.4.1 Performance Model for the Facility
There shall be a performance model (The Model) for The Facility that has been mutually
agreed to by The Parties prior to the commencement of the Adjusted Energy Test.
The Model shall:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 744 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-14
1. Include all information necessary to fully describe the performance characteristics of
the Facility.
2. Specify the performance modeling software (the Software) package it is used by.
3. Specify the software version (the Version) to be used.
9.3.4.2 Losses Excluded from the Model
The following losses shall be excluded from the Model used in the Adjusted Energy Test:
Long-term degradation in PV module performance.
System availability loss (Availability shall be 100%).
Production losses due to snow.
9.3.4.3 Expected Solar Resource and Weather Dataset
There shall be a typical year solar resource and weather dataset (TMY), with at least hourly
resolution, for the location of the Facility that has been mutually agreed to by all parties.
9.3.4.4 Original Expected Annual Energy Production
E ,(TMY) shall be calculated by inputting the TMY dataset into The Model and run by the
Version of the Software.
E ,(TMY) shall be calculated prior to the start of the Test Period in accordance with this
Specification, as part of the terms of agreement between the Owner of the Facility and the
Party that is responsible for its performance.
9.3.4.5 Measured Energy Production During the Test Period
E (Test Period) shall be calculated as the difference between the measured (hourly)
watthour meter readings taken at the start and at the end of the Test Period, exclusive of any
excluded hours.
9.3.4.6 Expected Energy Production During the Test Period
E (Test Period) shall be calculated by inputting the channel-averaged, hourly-averaged
measured data into The Model in accordance with the requirements of the Software Version
and run through The Model, exclusive of any excluded hours.
9.3.4.7 Adjusted Expected Annual Energy Production
E ,(TMY) shall be calculated as:
= ( )
( )
,()=,()
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 745 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-15
9.3.5 Adjusted Energy Test
The Adjusted Energy Test compares the Adjusted Annual Energy Production Estimate, ,
[MWh/yr] for the Facility to a Minimum Annual Energy Production Criteria, [MWh/yr] that has
been mutually agreed to by The Parties.
9.3.5.1 Measurement Uncertainty Allowance
The MUA allows for the inherent uncertainty in the measurement equipment.
The MUA shall be 3 percent.
9.3.5.2 Acceptance Threshold of the Adjusted Energy Test
The result from a Adjusted Energy Test is acceptable if:
,(1 )
9.3.6 Reporting Requirements
9.3.6.1 Reporting Requirement for Measured Data
A copy of all required measurement data collected throughout the entire Test Period shall be
submitted to Owner for review and acceptance.
9.3.6.2 Reporting Requirement for Modeling and Calculations
The results from each required modeling runs and calculations in Section 9.2.4 shall be
submitted to Owner for review and acceptance.
9.3.6.3 Reporting Requirement for Test Results
The result from the calculation in Section 9.2.5 shall be submitted to Owner for review and
acceptance.
9.4 SHORT TERM CAPACITY TEST
9.4.1 Purpose
The purpose of a Capacity Test of a solar photovoltaic (PV) facility (the Facility) is to compare the
Measured AC Capacity (Wac) of the Facility to its Expected AC Capacity (Wac).
The Capacity Test described in this Specification is an application of method standards 2,3 published
by ASTM International.
2ASTM Standard E2848-13, "Standard Test Method for Reporting Photovoltaic Non-Concentrator System
Performance.”
3ASTM Standard E2939-13, "Standard Practice for Determining Reporting Conditions and Expected Capacity
for Photovoltaic Non-Concentrator Systems.”
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 746 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-16
9.4.2 Measurement Requirements
9.4.2.1 Measurement Instrumentation Requirements
The following measurement instrumentation shall be used during the Test Period:
Plane of Array Solar Irradiance [W/m2]:
1. The Plane of Array (POA) shall mean the plane defined by the (array of) PV modules.
2. POA irradiance shall be measured using ISO 9060 secondary standard rated
pyranometers installed so that they are co-planar with the POA of the PV modules.
3. A minimum of two of secondary standard grade pyranometers shall be installed for
every 20 MWp of Facility capacity.
4. Each pair (or more) of pyranometers shall be installed proximate to the PV array (up to
20 MWp) that they are monitoring.
Ambient Air Temperature [°C]:
1. Ambient Air temperature shall be measured using a temperature sensing instrument
that has a resolution of 0.1 [°C] or smaller and is accurate to within ±1 [°C].
2. The instrument shall include a radiation shield compliant with ASTM D6176.
3. The instrument shall be placed close to the array without interfering with the array’s
thermal boundary layer.
4. At least one ambient air temperature sensing instrument shall be installed for every 20
MWp of Facility capacity.
Wind Speed [m/s]:
1. Wind speed shall be measured by an anemometer that has an accuracy of ±0.5 [m/s] or
better.
2. The instrument shall be placed close the array but away from any wind flow
interference caused by the solar PV array or other obstacles.
3. At least one anemometer shall be installed for every 20 MWp of Facility capacity.
Inverter Output Power [Wac]:
1. Each inverter under test shall report its output power.
AC Capacity of the Facility [Wac]:
1. The AC Capacity of the Facility shall be measured at the Point of Metering using an AC
watthour meter that meets or exceeds the accuracy standards set forth in ANSI C12.1.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 747 of 1056
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| Performance TestingApproved Vendor List 9-17
Copies of current calibration certificates for all required instruments shall be submitted to
Owner for review and acceptance.
All required instruments shall be installed and maintained in accordance with their
respective manufacturer’s specifications and recommendations.
All pyranometers shall be cleaned daily in accordance with the manufacturer’s
recommendations.
All required instruments shall be connected to a Data Acquisition System (DAS) that supports
the requirements of this Specification, in accordance with the manufacturer’s specifications,
and that complies with the instrumentation manufacturers’ specifications and
recommendations.
9.4.2.2 Measurement Data Record Requirements
All required measurement data shall be collected and recorded at one-minute intervals.
Each measurement data record shall include the date and time, with one-minute resolution,
when it was recorded.
9.4.2.3 Required Measurement Data Fields
Each data record shall include the following data fields:
Date-Time Stamp: Date (Month, Day, Year) and Time (Hour, Minute).
Each required pyranometer.
Each required ambient air temperature sensing instrument.
Each required anemometer.
The output power of each inverter.
AC Capacity of the Facility.
9.4.2.4 Required Channel-Averaged Measured Data Fields
Each measurement data record shall include the following channel-averaged measured data fields:
The channel-averaged measured POA irradiance, shall be calculated as the average over all of
the individual POA irradiance readings.
The channel-averaged measured RTD temperature, shall be calculated as the average over all
of the individual RTD temperature readings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 748 of 1056
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| Performance TestingApproved Vendor List 9-18
9.4.3 Test Period
The Test Period is the period of time during which the required data for the Capacity Test is
collected for the purposes of analysis. The duration of the Test Period shall be sufficient to include
a minimum number of Eligible Measurements.
9.4.3.1 Minimum Number of Eligible Measurements
Post-filtered data shall represent a dataset covering at least 1500 minutes of operation:
If using 5 minute averaging intervals, at least 300 data intervals are required.
If using 15 minute averaging intervals, at least 100 data intervals are required.
9.4.3.2 Eligible Measurements
An Eligible Measurement shall:
1. Meet or exceed the Minimum Irradiance Requirement.
2. Only include measurements when the output of each inverter is below its Clipping Limit.
3. Exclude times when snow, ice or any other obstructions cover a portion of the array.
4. Exclude time periods when force majeure events beyond the control of the Facility
Operator impact the energy production of the Facility.
5. Not have any missing or flawed required measurement data.
9.4.3.3 Minimum Irradiance Requirement
The Minimum Irradiance Requirement shall be 500 [W/m2] in the Plane of Array.
9.4.3.4 Shading Loss
Shading Loss is significant if it is greater than 1 percent.
9.4.3.5 Inverter Clipping Limit
The Clipping Limit of an inverter is defined as 98 percent of its nameplate output rating.
9.4.3.6 Date-Time Stamps for Measured Data
Each measured data record shall be stamped with the date and time to at least one-minute
resolution when it was collected.
9.4.4 Determination the Reporting Conditions (RC)
9.4.4.1 Performance Model of Record
A Performance Model of Record (the Model) shall be used to calculate the expected performance of
the solar. At a minimum, the Model shall use as inputs: POA irradiance (), ambient temperature
(), and wind speed () to calculate a modeled power output.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 749 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-19
9.4.4.2 Historical Meteorological Dataset of Record
A Historical Meteorological Dataset of Record () shall include typical values of the following, for
each hour over an entire year, ={1,…,8760}:
POA irradiance (Irr ,).
Ambient temperature (T ,,).
Wind speed (WS ,).
The historical meteorological dataset shall be used determine the Reporting Conditions () for
each month of a typical year, = {1,…,12}.
9.4.4.3 Calculating the Reporting Conditions
The Reporting Conditions (RCj) shall be calculated for each month over a calendar year, by
following the procedure outlined below in accordance with the test method outlined in ASTM
E2939. The RCs will be monthly averages of POA Irradiance, Ambient Temperature, and Wind
Speed, calculated using the filtered datasets.
Calculate the median POA Irradiance for each month (Irr ,):
1. Irr , shall be the median irradiance of the filtered data for each month and shall not be
less than 500 W/m2.
Calculate average ambient air temperature for each month (T ,,):
1. T ,,shall be the average ambient temperature of the filtered data for the relevant
time period.
Calculate average wind speed each month (WS ,):
1.WS ,shall be the average wind speed of the filtered data for each month.
9.4.4.4 Reporting Conditions Table
Table 9.3.1 shall be filled in prior to Contract signing. The Reporting Conditions presented in Table
9.3.1 shall be used to calculate Expected Capacity in Section 9.3.5 of this Specification.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 750 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-20
Table 9.3.1 Monthly Reporting Conditions and Expected Capacity
MONTH (J)
EXPECTED
CAPACITY
,[KW]
REPORTING CONDITIONS
POA
IRRADIANCE
,[W/M2]
AMBIENT
TEMPERATURE
,,[°C]
WIND SPEED
,[M/S]
January XX XX XX XX
February XX XX XX XX
March XX XX XX XX
April XX XX XX XX
May XX XX XX XX
June XX XX XX XX
July XX XX XX XX
August XX XX XX XX
September XX XX XX XX
October XX XX XX XX
November XX XX XX XX
December XX XX XX XX
Note: in the event that the Test Period spans across the boundary between two months, the Reporting
Conditions (RC) shall be calculated as a weighted average of the RCs from each of the two months,
where the weighting coefficients are based on the percentage of filtered measured data that falls
within each month.
9.4.5 Determination of Expected Capacity
Expected Capacity shall be calculated for each month over a complete calendar year (12 months) at
the corresponding Reporting Conditions, as determined in Section 9.3.4 of this Specification.
9.4.5.1 Calculate “From Historical” Regression Coefficients
Use the filtered modeled power output, filtered plane of array irradiance (), filtered ambient
temperature (,), and filtered wind speed data () to fit the four “from historical”
regression coefficients {,,, } using the following equation, as specified in ASTM
E2848, Section 4.1:
=× (++,+)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 751 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-21
9.4.5.2 Calculate Expected Capacity
The Expected Capacity is then calculated by substituting the “from historical” metrology data
,,, with the corresponding Reporting conditions (RC) for each month
,,,,,, into the following equations:
=, × (+,+,,+,)
9.4.5.3 Expected Capacity Table
Table 9.3.1 shall be filled in prior to Contract signing. The Expected Capacity recorded in Table 9.3.1
shall be used in comparison with the Measured Capacity, as determined per Section 9.3.6 of this
Specification.
9.4.6 Measured Capacity
Measured Capacity shall be determined using ASTM E2848, Section 4 using data collected over the
Test Period.
9.4.6.1 Filtered Measured Data
Filter the measured energy production data, measured plane of array irradiance, measured ambient
temperature, and measured wind speed in accordance with ASTM E2848, Section 9.1.
9.4.6.2 Calculate “From-Measured” Regression Coefficients
Use the filtered dataset of measured (M) POA irradiance (), ambient temperature (,), and
wind speed () data, as described in Section 9.3.2 of this Specification, to calculate the “From-
Measured” regression coefficients {,,, } using the following equation, as specified in
ASTM E2848, Section 4.1:
=× (++,+)
9.4.6.3 Calculate Measured Capacity
Calculate Measured Capacity by substituting using the regression coefficients from the Measured
(M) Power Output {,,,}, as obtained per Section 9.3.6 of this Specification, and the
corresponding metrology values for Reporting Conditions (RC) ,,, , for the
Test Period into the following equation:
=× (++,+)
9.4.7 Capacity Test
The Capacity Test compares the Measured Capacity, [Wac] of the Facility to its Expected
Capacity, [Wac], reduced by the Measurement Uncertainty Allowance (MUA).
9.4.7.1 Measurement Uncertainty Allowance
The Measurement Uncertainty Allowance (MUA) allows for the inherent uncertainty in the
measurement equipment.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 752 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-22
The MUA shall be 3 percent.
9.4.7.2 Acceptance Threshold of the Capacity Test
The result from a Capacity Test is acceptable if:
(1 )
9.4.8 Reporting Requirements
The following data and calculations shall be provided to Owner in the Capacity Test Report and
associated documents.
9.4.8.1 General Requirements
The Capacity Test Report shall include:
1. Dates of the Test Period, test conditions and Contractor’s personnel responsible for test.
2. A statement of whether the Capacity Test either passed or failed.
3. If the Capacity Test failed, a detailed explanation shall be submitted to Owner for
review.
4. A signed statement from Contractor that the Project complies with all of the Capacity
Test requirements set forth in this Specification.
9.4.8.2 Data required for entire Project
Owner-Approved Historical Meteorological Dataset, including for each hour of a calendar year
(8760 hours/year):
1. POA Irradiance [W/m2].
2. Ambient Temperature [°C].
3. Wind Speed [m/s].
Owner-Approved Energy Production Model of Record.
One calendar year of modeling results at hourly resolution (8760 hours/year) from using the
Owner-Approved Historical Meteorological Dataset as input into the Owner-Approved Energy
Production Model of Record, including:
1. Energy [kWh].
2. Calculations and results used to determine the “From Historical” fitting coefficients, for
each month: {A ,B ,C ,and D }.
3. Calculations and results used to determine the Reporting Conditions, for each month:
Irr ,,T ,, ,WS ,.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 753 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-23
4. Calculations and results used to determine the Expected Capacity, for each month:
Expected Capacity .
5. A completed version of Table 9.4.1.
Unfiltered measurements for the entire project, for each averaging interval:
1. Energy [kWh] from revenue meter.
2. POA Irradiance [W/m2], for each solar irradiance measurement device.
3. Ambient Temperature [°C], for each temperature sensor.
4. Wind Speed [m/s], for each wind speed sensor.
Filtered measurements for the entire project, for each averaging interval:
1. Energy [kWh] from revenue meter.
2. POA Irradiance [W/m2], for each solar irradiance measurement device.
3. Ambient Temperature [°C], for each temperature sensor.
4. Wind Speed [m/s], for each wind speed sensor.
Calculations used to determine the “From-Measured” regression coefficients:
{A ,B ,C ,and D }.
Calculations used to determine the Measured Capacity.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 754 of 1056
IPC | SOLAR PV SPECIFICATION JUNE 21, 2021
| Performance TestingApproved Vendor List 9-24
APPENDIX A.Approved Vendor List
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 755 of 1056
Idaho Power 2026 All Source RFP
Exhibit J – Solar Technical Specifications

Appendix A – Owner Approved Vendor List

6/28/2021
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 756 of 1056
Owner Approved Vendor List
Appendix A
1

The following equipment manufactures shall be approved by the Owner for use:
Solar Facility Acceptable Manufacturers List
Electrical Enclosures Hoffmann ,Saginaw Controls Engineering,
High Voltage Group
Operated Substation
Switches
Cleaveland type V2-CA, Hubbell type AVR, Pascor type
TTR-8, Morpac type EA,
High Voltage Substation
Hookstick Disconnects
Morpac type STU ,Royal type BT
High Voltage Circuit
Breakers
MEPPI, Siemens, ABB
Inverters ABB, GE, SMA, Mitsubishi (TMEIC), Yaskawa Solectria
Low Voltage Circuit
Breakers
Allen-Bradley, Eaton Cutler Hammer, General Electric,
Square D
Low Voltage Panel Boards Eaton, Square D
Main Power Step-Up
Transformer
ABB , Delta Star, SPX
Medium Voltage Cable Anixter, General Cable Corporation, Houston Wires & Cables,
Marmon , Okonite, Southwire
Medium Voltage
Disconnect Switches
Cleaveland type V2-CA, Emspec type VB1, Hubbell type
AVR, Morpac type EA, Pascor type TTR-8, S&C PME, S&C
Alduti-rupter, Southern States type TA-OC or EV
Medium Voltage
Switchgear
ABB, Eaton, General Electric, Powell, Siemens, Square D
Medium Voltage
Transformers
ABB, Eaton , General Electric, Siemens
Power Supplies Phoenix QUINT , PULS, SOLA
Protective Relays Schweitzer Engineering Laboratories (SEL)
PV Modules First Solar Series 6, Hanwah Q-Cells, JA Solar, Jinko Solar,
LONGi ,Trina, REC
SCADA Rockwell Automation ,SEL RTAC
Single Axis Trackers ATI, Game Change , NexTracker, Solar Flex Rack
Capacitor Banks ABB, Cooper, General Electric
Meteorological Campbell Scientific, Empro, Hukseflux, Kipp & Zonen, Lufft,
Texas Electronics
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 757 of 1056
Idaho Power 2026 All Source RFP
Exhibit K – Wind Technical Specifications

IDAHO POWER COMPANYWIND SPECIFICATION
PREPARED FOR
Idaho Power Co.
28 JUNE 2021
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 758 of 1056
Idaho Power 2026 All Source RFP
Exhibit K – Wind Technical Specifications

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 759 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents i
Table of Contents
1.0 General....................................................................................................................................................1-1
1.1 Contractor Scope of Work and Supply ........................................................................................ 1-1
1.1.1 General ............................................................................................................................... 1-1
1.1.2 Roads ................................................................................................................................... 1-5
1.1.3 Foundations ..................................................................................................................... 1-5
1.1.4 Wind Turbine Generators .......................................................................................... 1-5
1.1.5 O&M Facility (if applicable) ....................................................................................... 1-6
1.1.6 Meteorological Towers ................................................................................................ 1-6
1.1.7 Collection System ........................................................................................................... 1-7
1.1.8 34.5 kV/345 kV Project Collector Substation .................................................... 1-7
1.1.9 Project Collector Substation SCADA System and Fiber-Optic
Network ............................................................................................................................. 1-8
1.2 Wind Turbine Generators ................................................................................................................. 1-9
1.2.1 General ............................................................................................................................... 1-9
1.2.2 WTG Installation ............................................................................................................ 1-9
1.3 Design and Construction Requirements ................................................................................... 1-10
1.3.1 Design Requirements ................................................................................................. 1-10
1.3.2 Codes and Standards .................................................................................................. 1-11
1.4 Design Submittals .............................................................................................................................. 1-13
1.4.1 Design Documents ....................................................................................................... 1-13
1.5 Design Reviews ................................................................................................................................... 1-14
1.6 Construction Observation .............................................................................................................. 1-14
1.7 Construction Facilities ..................................................................................................................... 1-14
1.7.1 General ............................................................................................................................. 1-14
1.8 Laydown and Storage ....................................................................................................................... 1-15
1.9 Construction Utilities ....................................................................................................................... 1-15
1.10 Security .................................................................................................................................................. 1-16
1.11 Construction Tools and Equipment ............................................................................................ 1-17
1.12 Signage ................................................................................................................................................... 1-17
1.13 Safety ....................................................................................................................................................... 1-17
1.13.1 Hazard Prevention and Control ............................................................................. 1-17
1.14 Site Fire Protection ............................................................................................................................ 1-18
1.15 Cleanup ................................................................................................................................................... 1-18
1.16 Services for the Project Owner ..................................................................................................... 1-18
1.16.1 Owner’s Offices and Temporary Facilities Requirements .......................... 1-18
1.16.2 Turbine Supplier’s Offices and Temporary Facilities ................................... 1-19
1.17 Environmental..................................................................................................................................... 1-19
1.17.1 Protection of Sensitive Areas .................................................................................. 1-19
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 760 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents ii
1.17.2 Environmental Constraints During Construction...........................................1-19
1.17.3 Suppression of Dust and Dirt .................................................................................. 1-20
2.0 Civil...........................................................................................................................................................2-1
2.1 Design Basis ........................................................................................................................................... 2-1
2.2 Site Preparation .................................................................................................................................... 2-2
2.2.1 General ............................................................................................................................... 2-2
2.2.2 Site Survey ........................................................................................................................ 2-2
2.2.3 Erosion and Sediment Control ................................................................................. 2-2
2.2.4 Waste Management ....................................................................................................... 2-2
2.2.5 Clearing and Grubbing ................................................................................................. 2-3
2.2.6 Earthwork ......................................................................................................................... 2-3
2.3 Permanent Fences and Gates .......................................................................................................... 2-3
2.4 Construction and Temporary Facilities ...................................................................................... 2-3
2.5 Site Access and Parking ..................................................................................................................... 2-4
2.6 Laydown and Storage ......................................................................................................................... 2-4
2.7 Drainage ................................................................................................................................................... 2-4
2.8 Crane Pads .............................................................................................................................................. 2-4
2.9 Turbine Assembly / Erection Area ............................................................................................... 2-4
2.10 Turbine Foundation Apron .............................................................................................................. 2-5
2.11 Excavation ............................................................................................................................................... 2-5
2.12 Dewatering ............................................................................................................................................. 2-5
2.13 Backfilling ................................................................................................................................................ 2-5
2.14 Signage ..................................................................................................................................................... 2-6
2.15 Project Entrance & Access Roads .................................................................................................. 2-6
2.15.1 Reconnaissance and Road Location ....................................................................... 2-6
2.15.2 Road Subgrade and Surfacing ................................................................................... 2-7
2.15.3 Execution ........................................................................................................................... 2-7
2.15.4 Compaction ....................................................................................................................... 2-8
2.15.5 Finishing ............................................................................................................................ 2-8
2.15.6 Testing by Contractor .................................................................................................. 2-9
2.15.7 Maintenance ..................................................................................................................... 2-9
2.16 Temporary Internal Access Road Curve Widening .............................................................. 2-10
2.17 Temporary Public Road Intersection Widening.................................................................... 2-10
2.18 Road Drainage ..................................................................................................................................... 2-10
2.19 Design of Stream Crossing Structures ....................................................................................... 2-11
2.20 Maintenance ......................................................................................................................................... 2-11
2.21 Erosion Control ................................................................................................................................... 2-11
2.22 Crop Damage and Tile Repair ....................................................................................................... 2-12
3.0 ................................................................................................................................3-1
3.1 Design Basis ........................................................................................................................................... 3-1
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 761 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents iii
3.2 Excavation, Subgrade Preparation, Backfill, and Compaction........................................... 3-1
3.2.1 General ............................................................................................................................... 3-1
3.2.2 Execution ........................................................................................................................... 3-1
3.3 Structural Requirements .................................................................................................................. 3-3
3.3.1 Anchor Bolts ..................................................................................................................... 3-3
3.3.2 WTG Foundation Concrete and Tower Base Grout .......................................... 3-3
3.3.3 Steel Reinforcing ............................................................................................................ 3-6
3.3.4 Miscellaneous Concrete Embedments .................................................................. 3-6
3.3.5 Tower Erection and Anchor Tensioning Requirements ................................ 3-7
3.3.6 Tolerances ......................................................................................................................... 3-7
3.4 Testing and Inspection ...................................................................................................................... 3-8
3.5 Construction Considerations ........................................................................................................... 3-9
3.5.1 Placing of Concrete ........................................................................................................ 3-9
3.5.2 Joints ................................................................................................................................. 3-10
3.5.3 Cold Weather Requirements ................................................................................... 3-11
3.5.4 Hot Weather Requirements ..................................................................................... 3-11
3.5.5 Finishing .......................................................................................................................... 3-11
3.5.6 Cleanup ............................................................................................................................ 3-12
3.5.7 Curing ............................................................................................................................... 3-12
3.5.8 Repairing Defective Concrete ................................................................................. 3-12
4.0 ..............................................................................Error! Bookmark not defined.
4.1 Document Overview ........................................................................................................................... 4-1
4.2 Standards................................................................................................................................................. 4-1
4.3 System Description and General Requirements ..................................................................... 4-2
4.3.1 General ............................................................................................................................... 4-2
4.3.2 Standards .......................................................................................................................... 4-2
4.3.3 Losses.................................................................................................................................. 4-2
4.3.4 BIL (Basic Insulation Level)....................................................................................... 4-2
4.3.5 Electrical Clearances..................................................................................................... 4-2
4.3.6 Collector System As-Built Location ........................................................................ 4-3
4.3.7 Grounding ......................................................................................................................... 4-3
4.3.8 Testing ................................................................................................................................ 4-3
4.3.9 Spare Parts ........................................................................................................................ 4-4
4.4 MV Cable Specification ....................................................................................................................... 4-4
4.4.1 General ............................................................................................................................... 4-4
4.4.2 Equipment Requirements .......................................................................................... 4-4
4.5 Installation .............................................................................................................................................. 4-6
4.5.1 General Installation Requirements......................................................................... 4-6
4.5.2 Cable Routing and Terminal Points ........................................................................ 4-7
4.5.3 Handling of Cable ........................................................................................................... 4-8
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 762 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents iv
4.5.4 Trenching.......................................................................................................................... 4-8
4.5.5 County, Private Road, and County Drain Crossings (Where
Applicable) ........................................................................................................................ 4-9
4.5.6 Streams and Wetland Crossings ............................................................................ 4-10
4.5.7 Easement Crossings (Where Applicable) ........................................................... 4-11
4.5.8 Fenced and Irrigation Pipeline Crossings (Where Applicable)................. 4-11
4.5.9 Archeological and Sensitive Animal Species Sites .......................................... 4-11
4.5.10 Feeder Cable Crossings.............................................................................................. 4-11
4.5.11 Backfill with Select Native Material ..................................................................... 4-11
4.5.12 Cable and Trench Markers ....................................................................................... 4-12
4.5.13 Conduits ........................................................................................................................... 4-12
4.6 Grounding ............................................................................................................................................. 4-12
4.6.1 Trenches .......................................................................................................................... 4-12
4.6.2 Junction Boxes ............................................................................................................... 4-13
4.6.3 Pad Mount Step-Up Transformers ........................................................................ 4-13
4.6.4 Substation Riser ........................................................................................................... 4-13
4.7 Testing .................................................................................................................................................... 4-13
4.7.1 Factory Testing ............................................................................................................. 4-13
4.7.2 Cable Inspection ........................................................................................................... 4-14
4.7.3 Installation Inspections ............................................................................................. 4-14
4.7.4 Conductor Continuity ................................................................................................. 4-14
4.7.5 Insulation Resistance Testing ................................................................................. 4-14
4.7.6 Cable Testing – Partial Discharge Method / VLF Hi-Pot Method ............. 4-14
4.8 Numbering and Labeling ................................................................................................................ 4-15
4.8.1 MV Cables Numbering ............................................................................................... 4-15
4.8.2 MV Cable Labeling at 4-Way, 3-Way, and 2-Way Junction Boxes;
Splice Boxes; and Switchgear .................................................................................. 4-15
4.8.3 MV Cable Labeling at Pad Mount Step-Up Transformers ............................ 4-15
4.8.4 MV Cable Labeling at Risers .................................................................................... 4-16
4.9 Pad mount Step-Up Transformers .............................................................................................. 4-16
4.9.1 General ............................................................................................................................. 4-16
4.9.2 Equipment Requirements ........................................................................................ 4-16
4.10 Installation ............................................................................................................................................ 4-17
4.10.1 Transformer and Cable Box Pad ............................................................................ 4-18
4.10.2 Transformer Mounting .............................................................................................. 4-19
4.10.3 Low Voltage (2000 V) Phase Conductors and Terminations ..................... 4-19
4.10.4 Oil Containment Design ............................................................................................. 4-19
4.11 Testing .................................................................................................................................................... 4-19
4.11.1 Factory Testing ............................................................................................................. 4-19
4.11.2 Testing by Contractor ................................................................................................ 4-20
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 763 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents v
4.12 Numbering and Labeling................................................................................................................4-21
4.12.1 General ............................................................................................................................. 4-21
4.12.2 Pad Mount Step-Up Transformer .......................................................................... 4-21
4.13 Low Voltage (LV) Cable ................................................................................................................... 4-21
4.13.1 General ............................................................................................................................. 4-21
4.13.2 Equipment Requirements ........................................................................................ 4-21
4.13.3 Shipping Requirements ............................................................................................. 4-22
4.13.4 Installation ...................................................................................................................... 4-22
4.13.5 Grounding ....................................................................................................................... 4-23
4.13.6 Testing .............................................................................................................................. 4-23
4.13.7 Numbering and Labeling .......................................................................................... 4-24
4.14 Junction Boxes ..................................................................................................................................... 4-24
4.14.1 General ............................................................................................................................. 4-24
4.14.2 Equipment Requirements ........................................................................................ 4-24
4.14.3 Installation ...................................................................................................................... 4-25
4.14.4 Grounding ....................................................................................................................... 4-26
4.14.5 Testing .............................................................................................................................. 4-27
4.14.6 Numbering and Labeling .......................................................................................... 4-27
4.15 Miscellaneous Equipment .............................................................................................................. 4-27
4.15.1 General ............................................................................................................................. 4-27
4.15.2 Equipment Requirements ........................................................................................ 4-27
4.15.3 Installation ...................................................................................................................... 4-28
4.15.4 Grounding ....................................................................................................................... 4-28
4.15.5 Testing .............................................................................................................................. 4-28
4.15.6 Numbering and Labeling .......................................................................................... 4-28
4.16 Meteorological (MET) Tower 120V Cable ............................................................................... 4-28
4.16.1 General ............................................................................................................................. 4-28
4.16.2 Equipment Requirements ........................................................................................ 4-28
4.16.3 Installation ...................................................................................................................... 4-29
4.16.4 Grounding ....................................................................................................................... 4-29
4.16.5 Testing .............................................................................................................................. 4-29
4.16.6 Numbering and Labeling .......................................................................................... 4-29
4.17 Fiber-Optic Communication Cable .............................................................................................. 4-29
4.17.1 General ............................................................................................................................. 4-29
4.17.2 Equipment Requirements ........................................................................................ 4-29
4.17.3 Installation ...................................................................................................................... 4-32
4.17.4 Testing .............................................................................................................................. 4-33
4.17.5 Numbering and Labeling .......................................................................................... 4-34
4.18 Ampacity Study ................................................................................................................................... 4-34
4.18.1 Purpose and Scope ...................................................................................................... 4-34
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 764 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents vi
4.18.2 Required Methodology..............................................................................................4-34
4.18.3 Required Submittals ................................................................................................... 4-35
4.19 Reactive Power Flow Study ........................................................................................................... 4-36
4.19.1 Purpose and Scope ...................................................................................................... 4-36
4.19.2 Required Methodology .............................................................................................. 4-36
4.19.3 Required Submittals ................................................................................................... 4-37
4.20 VAR Control Philosophy .................................................................................................................. 4-37
4.20.1 Purpose and Scope ...................................................................................................... 4-37
4.20.2 Required Methodology .............................................................................................. 4-38
4.20.3 Required Submittals ................................................................................................... 4-38
4.21 Short Circuit Study ............................................................................................................................ 4-38
4.21.1 Purpose and Scope ...................................................................................................... 4-38
4.21.2 Required Methodology .............................................................................................. 4-38
4.21.3 Required Submittals ................................................................................................... 4-39
4.22 Harmonics Study ................................................................................................................................ 4-40
4.22.1 Purpose and Scope ...................................................................................................... 4-40
4.22.2 Required Methodology .............................................................................................. 4-40
4.22.3 Required Submittals ................................................................................................... 4-41
4.23 Electrical Losses Study .................................................................................................................... 4-41
4.23.1 Purpose and Scope ...................................................................................................... 4-41
4.23.2 Required Methodology .............................................................................................. 4-41
4.23.3 Required Submittals ................................................................................................... 4-42
4.24 Temporary Overvoltage (TOV) Study ........................................................................................ 4-42
4.24.1 Purpose and Scope ...................................................................................................... 4-42
4.24.2 Required Methodology .............................................................................................. 4-42
4.24.3 Required Submittals ................................................................................................... 4-43
4.25 Insulation Coordination Study ..................................................................................................... 4-43
4.25.1 Purpose and Scope ...................................................................................................... 4-43
4.25.2 Required Methodology .............................................................................................. 4-43
4.25.3 Required Submittals ................................................................................................... 4-43
4.26 Step and Touch Analysis ................................................................................................................. 4-44
4.26.1 Purpose and Scope ...................................................................................................... 4-44
4.26.2 Required Methodology .............................................................................................. 4-44
4.26.3 Required Submittals ................................................................................................... 4-44
4.27 Effective Grounding Study .............................................................................................................. 4-45
4.27.1 Purpose and Scope ...................................................................................................... 4-45
4.27.2 Required Methodology .............................................................................................. 4-45
4.27.3 Required Submittals ................................................................................................... 4-45
4.28 Relay Settings Philosophy .............................................................................................................. 4-45
4.28.1 Purpose and Scope ...................................................................................................... 4-45
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 765 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents vii
4.28.2 Required Methodology..............................................................................................4-45
4.28.3 Required Submittals ................................................................................................... 4-46
4.29 Arc Flash Study ................................................................................................................................... 4-47
4.29.1 Purpose and Scope ...................................................................................................... 4-47
4.29.2 Required Methodology .............................................................................................. 4-47
4.29.3 Required Submittals ................................................................................................... 4-48
4.30 Minimum Approach Distance (MAD) Study ............................................................................ 4-49
4.30.1 Purpose and Scope ...................................................................................................... 4-49
4.30.2 Required Methodology .............................................................................................. 4-49
4.30.3 Required Submittals ................................................................................................... 4-49
4.31 Project Collector Substation-Specific Studies ........................................................................ 4-50
4.31.1 AC Station Service Study ........................................................................................... 4-50
4.31.2 DC Station Service Study ........................................................................................... 4-51
4.31.3 Lighting Study ............................................................................................................... 4-52
4.31.4 Lightning Study ............................................................................................................. 4-53
5.0 Substation..............................................................................................................................................5-1
5.1 General ..................................................................................................................................................... 5-1
5.1.1 Identification ................................................................................................................... 5-1
5.1.2 Numbering System ........................................................................................................ 5-1
5.1.3 Equipment Testing ........................................................................................................ 5-1
5.1.4 Preshipment Inspection .............................................................................................. 5-2
5.1.5 Shipments ......................................................................................................................... 5-2
5.1.6 Shipping Notice ............................................................................................................... 5-2
5.1.7 Recommended Spare Parts ........................................................................................ 5-2
5.1.8 Electronic Material List ............................................................................................... 5-2
5.1.9 Codes and Standards .................................................................................................... 5-3
5.2 Technical Scope and System Performance Requirements .................................................. 5-3
5.2.1 Technical Scope of Work ............................................................................................. 5-3
5.2.2 Quantity of Supply ......................................................................................................... 5-3
5.3 Civil Requirements .............................................................................................................................. 5-4
5.3.1 General ............................................................................................................................... 5-4
5.3.2 Site Preparation .............................................................................................................. 5-4
5.3.3 Fencing ............................................................................................................................... 5-4
5.3.4 Camera Conduits ............................................................................................................ 5-4
5.4 Structural Requirements .................................................................................................................. 5-4
5.4.1 General ............................................................................................................................... 5-4
5.4.2 Codes and Standards .................................................................................................... 5-4
5.4.3 Concrete Foundations .................................................................................................. 5-5
5.4.4 Miscellaneous Concrete Embedments .................................................................. 5-5
5.4.5 Structural Steel ............................................................................................................... 5-5
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 766 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents viii
5.5 Outdoor Disconnect Switches......................................................................................................... 5-6
5.5.1 General ............................................................................................................................... 5-6
5.5.2 Codes And Standards.................................................................................................... 5-6
5.5.3 Equipment Required .................................................................................................... 5-6
5.5.4 Insulators .......................................................................................................................... 5-6
5.5.5 Ratings ................................................................................................................................ 5-6
5.5.6 Switch Construction (If Applicable) ....................................................................... 5-6
5.5.7 Hookstick Operated Switches ................................................................................... 5-8
5.5.8 Group Operators (If Applicable) .............................................................................. 5-8
5.5.9 Tightening of Connections ......................................................................................... 5-8
5.5.10 Manufacturers ................................................................................................................. 5-8
5.6 Insulators ................................................................................................................................................ 5-8
5.6.1 General ............................................................................................................................... 5-8
5.6.2 Codes and Standards .................................................................................................... 5-9
5.6.3 Equipment Required .................................................................................................... 5-9
5.6.4 Design Requirements ................................................................................................... 5-9
5.6.5 Station Post Insulators (If Applicable) .................................................................. 5-9
5.6.6 Manufacturers ................................................................................................................. 5-9
5.7 Voltage Transformers ........................................................................................................................ 5-9
5.7.1 General ............................................................................................................................... 5-9
5.7.2 Codes and Standards .................................................................................................... 5-9
5.7.3 Equipment Required .................................................................................................... 5-9
5.7.4 Ratings .............................................................................................................................. 5-10
5.7.5 Construction Details ................................................................................................... 5-11
5.7.6 Base Support Assembly ............................................................................................. 5-11
5.7.7 Manufacturers ............................................................................................................... 5-11
5.8 Capacitor Voltage Transformers.................................................................................................. 5-11
5.8.1 General ............................................................................................................................. 5-11
5.8.2 Codes and Standards .................................................................................................. 5-11
5.8.3 Equipment Required .................................................................................................. 5-12
5.8.4 Ratings .............................................................................................................................. 5-12
5.8.5 Details of Construction .............................................................................................. 5-12
5.8.6 Capacitor Units .............................................................................................................. 5-13
5.8.7 Base Support Assembly ............................................................................................. 5-13
5.8.8 Manufacturers ............................................................................................................... 5-13
5.9 Revenue Metering .............................................................................................................................. 5-13
5.9.1 General ............................................................................................................................. 5-13
5.9.2 Codes and Standards .................................................................................................. 5-14
5.9.3 Equipment Required .................................................................................................. 5-14
5.9.4 Ratings and Metering Requirements ................................................................... 5-14
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 767 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents ix
5.9.5 Construction Details...................................................................................................5-14
5.9.6 Base Support Assembly ............................................................................................. 5-15
5.9.7 Grounding ....................................................................................................................... 5-15
5.9.8 Terminals ........................................................................................................................ 5-15
5.9.9 Paint................................................................................................................................... 5-15
5.9.10 Insulating Oil .................................................................................................................. 5-15
5.9.11 Lead Markings ............................................................................................................... 5-16
5.9.12 Accessories ..................................................................................................................... 5-16
5.9.13 Testing .............................................................................................................................. 5-16
5.9.14 Manufacturers ............................................................................................................... 5-16
5.10 Surge Arresters ................................................................................................................................... 5-16
5.10.1 General ............................................................................................................................. 5-16
5.10.2 Codes and Standards .................................................................................................. 5-17
5.10.3 Equipment Required .................................................................................................. 5-17
5.10.4 Ratings .............................................................................................................................. 5-17
5.10.5 Construction Details ................................................................................................... 5-17
5.11 Power Circuit Breakers ................................................................................................................... 5-18
5.11.1 General ............................................................................................................................. 5-18
5.11.2 Codes and Standards .................................................................................................. 5-18
5.11.3 Equipment Required .................................................................................................. 5-18
5.11.4 Construction Details ................................................................................................... 5-18
5.11.5 Enclosures ....................................................................................................................... 5-19
5.11.6 Operating Mechanism ................................................................................................ 5-19
5.11.7 Auxiliary Power Supply ............................................................................................. 5-20
5.11.8 Auxiliary Power and Control Power Disconnects .......................................... 5-20
5.11.9 SF6 Gas System .............................................................................................................. 5-20
5.11.10 Arc Containment Chamber ....................................................................................... 5-21
5.11.11 Space Heaters ................................................................................................................ 5-21
5.11.12 Current Transformers ................................................................................................ 5-21
5.11.13 Insulating Oil .................................................................................................................. 5-21
5.11.14 Oil Preservation System ............................................................................................ 5-22
5.11.15 Ground Fault Current Transformers.................................................................... 5-22
5.11.16 Current Transformer Secondary Terminations .............................................. 5-22
5.11.17 Assembly and Configuration ................................................................................... 5-22
5.11.18 Bushings .......................................................................................................................... 5-23
5.11.19 Auxiliary Power and Control Circuits .................................................................. 5-23
5.11.20 Pre-insertion Closing Resistors (If Applicable) ............................................... 5-23
5.11.21 Grading Capacitors ...................................................................................................... 5-23
5.11.22 Spare Parts ...................................................................................................................... 5-23
5.11.23 Factory Tests.................................................................................................................. 5-23
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 768 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents x
5.11.24 Preparation for Breakers for Shipment..............................................................5-24
5.12 Main Power Transformer (sections as applicable) .............................................................. 5-24
5.12.1 General ............................................................................................................................. 5-24
5.12.2 Codes and Standards .................................................................................................. 5-24
5.12.3 Products ........................................................................................................................... 5-25
5.12.4 Mechanical Construction .......................................................................................... 5-25
5.12.5 Additional Equipment ................................................................................................ 5-31
5.12.6 Factory Tests.................................................................................................................. 5-36
5.12.7 Photographs ................................................................................................................... 5-39
5.12.8 Shipping - Impact Recorders, Dew Point Temperature, and
Receipt Inspection ....................................................................................................... 5-40
5.12.9 Assembly and Field Testing ..................................................................................... 5-40
5.13 Shunt Capacitor Bank (If Applicable) ........................................................................................ 5-40
5.13.1 General ............................................................................................................................. 5-40
5.13.2 Equipment Required .................................................................................................. 5-40
5.14 Control Equipment Enclosure ...................................................................................................... 5-40
5.14.1 General ............................................................................................................................. 5-40
5.14.2 Equipment Required .................................................................................................. 5-40
5.15 Control, Protection and Measurement Panels ....................................................................... 5-41
5.15.1 General ............................................................................................................................. 5-41
5.15.2 Codes and Standards .................................................................................................. 5-41
5.15.3 Equipment Required .........................................
5.15.4 Products ........................................................................................................................... 5-41
5.15.5 Factory Tests.................................................................................................................. 5-46
5.15.6 Special Shipping Requirements ............................................................................. 5-47
5.16 Relay Protection & Control ............................................................................................................ 5-47
5.16.1 General ............................................................................................................................. 5-47
5.16.2 General Protective Relaying Requirements ...................................................... 5-47
5.16.3 Component Protective Relaying Requirements .............................................. 5-48
5.16.4 Protective Relay Settings and Implementation ............................................... 5-49
5.17 Battery Bank and Charger .............................................................................................................. 5-50
5.17.1 General ....................................................................
5.17.2 Equipment Required .................................................................................................. 5-50
5.18 Station Service Transformer ......................................................................................................... 5-50
5.18.1 General ....................................................................
5.18.2 Equipment Required .................................................................................................. 5-50
5.19 Grounding Transformers ................................................................................................................ 5-50
5.19.1 General ............................................................................................................................. 5-50
5.19.2 Equipment Required .................................................................................................. 5-50
5.20 Grounding System ............................................................................................................................. 5-50
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 769 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents xi
5.20.1 General.............................................................................................................................5-50
5.20.2 Codes And Standards.................................................................................................. 5-50
5.20.3 Materials Required ...................................................................................................... 5-51
5.20.4 Execution ......................................................................................................................... 5-51
5.20.5 Grounding Installation ............................................................................................... 5-52
5.20.6 Grounding Measurements ........................................................................................ 5-55
5.21 Electrical Startup, Testing, and Checkout ................................................................................ 5-55
5.21.1 General ............................................................................................................................. 5-55
5.21.2 Codes and Standards .................................................................................................. 5-56
5.21.3 Execution ......................................................................................................................... 5-56
5.21.4 Equipment Testing ...................................................................................................... 5-57
5.21.5 As-Built Drawings ........................................................................................................ 5-61
6.0 ...............................................................Error! Bookmark not defined.
6.1 Network and Communications Infrastructure Requirements .......................................... 6-1
6.1.1 General Requirements & Scopes of Work ............................................................ 6-1
6.1.2 Required Equipment .................................................................................................... 6-3
6.1.3 Required Drawings in Final Design Package ...................................................... 6-4
6.1.4 Standards .......................................................................................................................... 6-4
6.1.5 Communication Protocols .......................................................................................... 6-4
6.2 Project Collector Substation SCADA System Requirements............................................... 6-4
6.2.1 Project Collector Substation SCADA System Communication
Design ................................................................................................................................. 6-4
6.2.2 Control Display Screens .............................................................................................. 6-5
6.2.3 Trend Displays ................................................................................................................ 6-6
6.2.4 System Acceptability .................................................................................................... 6-7
6.2.5 System Interface Requirements ............................................................................... 6-8
6.2.6 Remote Web Server Interface ................................................................................... 6-9
6.2.7 Minimum Required Points List ................................................................................ 6-9
6.2.8 Project Collector Substation SCADA System Functional Control
Requirements .................................................................................................................. 6-9
6.2.9 Project Collector Substation SCADA System Commissioning
Requirements ................................................................................................................ 6-10
7.0 .............................................................................................................................................7-1
7.1 Permanent MET Tower ..................................................................................................................... 7-1
7.2 Temporary MET Tower ..................................................................................................................... 7-1
7.3 Tower and Instrument Spec – 80 Meter ..................................................................................... 7-2
8.0 .........................................................................................................8-1
8.1 Standards and Codes .......................................................................................................................... 8-1
8.1.1 Product Options and Substitutions .............
8.2 Products ................................................................................................................................................... 8-2
8.2.1 Design Conditions .......................................................................................................... 8-2
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 770 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Table of Contents xii
8.2.2 Mechanical Equipment................................................................................................ 8-2
8.2.3 Electrical Equipment .................................................................................................... 8-6
8.2.4 Special Systems ............................................................................................................... 8-9
8.2.5 8.2.5 Controls ................................................................................................................ 8-10
8.2.5.1 W .........................................................................................8-10
8.2.5.2 .....................................................................................................................8-12
8.3 Electrical Startup and Commissioning ...................................................................................... 8-14
8.3.1 General ............................................................................................................................. 8-14
8.3.2 Not Used .......................................................................................................................... 8-16
8.3.3 Execution ......................................................................................................................... 8-16
8.3.4 Personnel ........................................................................................................................ 8-17
8.3.5 Tools and Test Equipment ....................................................................................... 8-17
8.3.6 Test Instrument Certification ................................................................................. 8-17
8.3.7 Calibration or Testing Certification Sticker ...................................................... 8-17
8.3.8 Checkout and Test Report Forms .......................................................................... 8-17
8.3.9 Startup .............................................................................................................................. 8-17
8.3.10 Electrical and Instrumentation Checkout .......................................................... 8-18
8.4 Mechanical Startup and Commissioning .................................................................................. 8-20
8.4.1 General ............................................................................................................................. 8-20
8.4.2 Not Used ................................................................. defined.
8.4.3 Execution ......................................................................................................................... 8-21

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 771 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-1
1.0 General
1.1 CONTRACTOR SCOPE OF WORK AND SUPPLY
The purpose of this document is to provide a general description of scope. The Contractor shall be
responsible for filling any scope gaps between the Contractor, Owner, and Turbine Supplier. The
Contractor shall perform all work in accordance with Turbine Supplier’s requirements. The work
and requirements of the Contractor shall include, but not be limited to, the following:
1.1.1 General
All necessary labor and materials, commodities, software/hardware and licenses,
construction equipment, facilities, temporary works, utilities, auxiliaries, accessories, lifting
equipment, and specialty tools needed to perform all studies, testing, operations, material
handling, and work required for design, procurement, fabrication, furnishing, delivery,
equipment erection, storage, maintenance, material transportation, offloading, installation,
refurbishing, cleaning, finishing, painting, testing, commissioning and completion of the
balance-of-plant work portion of the Project. Contractor shall be responsible for all
commissioning and testing on this Project (including, but not limited to, Owner, Turbine
Supplier, and Transmission Owner systems).
Lead an initial project kick-off and regular progress report meetings. Contractor shall
distribute meeting minutes after submitting to Owner for approval and receiving said
approval. Meetings will be hosted by Owner at agreed upon site.
Contractor shall develop project schedule including engineering, procurement,
construction, and startup.
Construction and project turnover plan, including QA/QC program and WTG erection plan.
All necessary QA/QC plans, procedures, programs, audits, and documentation shall be in
accordance with the requirements set forth in the Contract.
All necessary safety and security plans, procedures, programs, audits, inspections, and
documentation. Safety training and orientation for all site personnel. All operations shall be
conducted in accordance with the Contract.
All construction operations shall be done in a manner to ensure worker safety and be in
accordance with current Occupational Safety and Health Administration (OSHA) standards.
Temporary, separate office facilities for the Owner and Turbine Supplier, including office
furniture, equipment, supplies, restrooms, janitorial service, cleaning supplies, sanitation
facilities, potable water, and electrical power. Contractor shall provide internet, phone
service, and 2-way radio for the Project, including for any Subcontractors. Any facilities or
other infrastructure provided to the Turbine Supplier shall be in accordance with Turbine
Supplier requirements.
Preparation of lay-down, parking, storage, and craft change areas including restoration after
construction as agreed to between Owner and Contractor.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 772 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-2
Maintain sufficient security in accordance with Section 1.11.
Construction lighting in accordance with Section 1.10.
First aid services, fire protection, and drug sampling/testing facilities.
Coordination with local emergency services.
Waste removal services for the entire Project, including hazardous and non-hazardous
waste.
Material recycling program during construction.
Execute construction focused spill prevention, countermeasure, and control plan.
Provide other construction utilities as described in Section 1.11.
Perform interference-checking for underground utilities.
Provide all warning, danger, and arc flash signage for all applicable equipment (except for
the WTGs, which shall be provided by Owner).
All necessary quality reports, scheduling reports, conference calls as necessary with Owner,
equipment commissioning / test results and records, and Project closeout reports.
Job books, project completion/close-out documentation, manuals, training and other
submittals. Files shall be in original and editable format.
Coordination with participating land owners prior to commencement of any field work on
landowner’s property, as well as any visits to a landowner’s property. All Contractor
communications with landowners shall be coordinated with the Owner.
Coordination with state, county and local municipalities.
Documentation of all communication with all land owners.
Participation in Owner’s design review, oversight, and approval process which shall include
pre-engineering planning meetings; 30%, 60%, 90%, and IFC design and calculation
reviews; and design update teleconferences and/or meetings. Upon initial completion of
each aspect of the Project’s design, all Project designs and calculations shall be submitted to
the Owner for review and approval prior to construction.
All planning, engineering, drawings, additional specifications and other information as
required for the completion of the balance-of-plant portion of the Project.
The design, procurement and construction of all above- and belowground site
infrastructure and improvements including roads, foundations, structures, buildings
collection system, Project Collector Substation, together with the procurement, delivery,
erection and installation of all equipment, auxiliaries and accessories including the Main
Power Transformer (MPT) (and O&M facility if applicable).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 773 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-3
Document location and repair of all damage to drain tiles.
Any necessary grubbing and clearing work that is not in the Owner scope of supply.
Obtaining and maintaining all necessary permits and approvals from local and other
authorities, statutory authorities, and in accordance with building and construction
regulations. Contractor shall comply with all permits and permit conditions for the Project
obtained by either Owner or Contractor, and shall provide copies of all Contractor-obtained
permits to Owner.
Operations, maintenance, and storage during construction in accordance with all original
equipment manufacturer (OEM) requirements and standards.
Supply recommended balance-of-plant spare parts.
Contractor shall take all reasonable measures to protect the materials including, but not
limited to, painting, humidity and temperature control, mechanically exercising, greasing,
installing rust-preventive oil, covering or wrapping all materials externally and internally
from mechanical damage or damage from the elements. Contractor shall store and maintain
the materials in accordance with the local government authority and OEM
recommendations. Additionally, Contractor shall protect all instruments and control panels
from damage, including corrosion due to humidity, precipitation, temperature, atmospheric
and environmental conditions in accordance with the respective OEM recommendations. All
equipment procured under this Contract shall be labeled with permanently affixed durable
nameplates which will include the OEM's name, equipment model number, equipment serial
number, equipment tag number and all appropriate design parameters as agreed between
Contractor and Owner during the review process prior to the installation of nameplates.
Contractor shall construct all Project facilities in a manner such that the Project site drains
properly to prevent ponding.
All grading, drainage, storm water collection, and erosion control specified by the IFC
construction plans.
Project electrical grounding system shall be in accordance with IEEE Std. 80 requirements,
local utility requirements, Prudent Wind Industry Practices, and Section 4.
WTG grounding system shall be in accordance with Turbine Supplier requirements as
shown in the requirements of IEEE Std. 80, local utility requirements, Prudent Wind
Industry Practices, and Section 4.
WTG erection staging area sufficiently prepared so as to enable safe staging and assembly of
the WTG and its components and to meet the Turbine Supplier’s requirements and Section
2.
Restoration of all temporarily disturbed areas, such as but not limited to, WTG erection
staging areas and crane paths, shall be restored in accordance with all environmental
permits.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 774 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-4
Supply permanent service power to Project Collector Substation (and O&M facility if
applicable).
Provide backup generators for pre-commissioning in case grid permanent power is not
available. This shall include any necessary permitting to authorize placement and operation
of the generators.
Lead, participate in, and prepare reports for factory inspections and tests.
Any additional geotechnical and geothermal investigations necessary to complete the
design and construction.
Any additional site surveys.
Participation in final WTG, site road, and collection system micro-siting including field
verification for constructability.
Contractor permits and support of Owner’s permit activities per Section 1.
Permit and land use permit conditions not outlined as the responsibility of the Owner in
Section 1.
Any temporary utilities connection from the Contractor’s facilities to the local utility.
Additional survey work necessary for the design and construction of the Project including
but not limited to aerial, topographic and site surveys.
Environmental monitoring per requirements set forth in Section 1.
Crop loss payments for any damage caused by Contractor or its Subcontractors outside of
the participating parcels.
Design, procurement, and construction of the temporary and permanent security facilities.
Receive, document, inspect, and unload all materials. The Contractor shall keep adequate
and convenient records of their location and shall keep a continuously accurate inventory.
The required receiving documentation shall be completed by the Contractor and copies
distributed to Contractor and the Owner. Contractor shall provide a delivery checklist and
documentation for non-conformance reporting. Any recorded damage prior to unloading
shall be the responsibility of the Contractor. In certain instances where packaging does not
readily allow inspection, the Contractor may choose, after unloading part, to open/inspect
at a later date as agreed to by the Owner.
Contractor will provide Owner with at least four (4) radios capable of listening to all
channels on all frequencies on which any of Contractor’s communications related to the
Work are taking place. This is to include, but not be limited to, all turbine erection and
crane activity.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 775 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-5
1.1.2 Roads
Design, construction and maintenance of new access and site roads which meets or exceeds
the requirements of Section 2 as well as the Turbine Supplier’s requirements
Pre- and post-construction road surveys and inspection reports.
Construction area signage along onsite and public roads for the duration of the project.
Modification, repair and maintenance (including traffic maintenance) of all existing roads to
meet WTG and main power transformer delivery specifications, all other specifications of
Section 2 and Turbine Supplier’s requirements. Contractor shall also satisfy all county road
use agreement requirements. Contractor to assume all risk of improving and repairing all
roads (public and private) during construction and restoring all roads (public and private)
to the county’s satisfaction after construction.
Install an aggregate maintenance ring/apron around each WTG.
1.1.3 Foundations
Furnish, design and construct WTG foundations in accordance with the recommendations of
the final geotechnical report for the site, Turbine Supplier loading information. Contractor
shall furnish and install WTG anchor bolt template ring, anchor bolts, nuts washers, and
shims.
Furnish and install WTG ground grids and provide ground strap and hardware in tower
base.
Design, furnish, and construct all balance-of-plant foundations including (O&M building
foundation if applicable) flatwork and MET (meteorological) tower foundation.
For concrete required for all foundations, pads, walks, etc., verify capability of local concrete
suppliers to provide adequate concrete for the project. If batch plant is deemed necessary,
the Contractor shall supply all raw materials necessary including cement, sand, aggregate
and water to produce the quantity of concrete necessary for the entire project. Contractor
shall also provide batch plant equipment and assembly if batch plant is necessary. The cost
for the supply of the raw materials including permitting and drilling a well for water, if
needed, shall be included in the Contractor’s bid price.
Perform concrete and grout testing for each WTG foundation and provide lab test results to
Owner.
1.1.4 Wind Turbine Generators
Procure and deliver Non-PTC turbines.
Offload, store, stage, and inspect WTG components prior to erection.
Install/erect WTGs and associated equipment to mechanical completion. Contractor will
lead mechanical completion inspections.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 776 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-6
Provide, install, and operate temporary Federal Aviation Administration (FAA) lighting
during construction.
Provide and install permanent FAA lighting and brackets.
Permanent crane pads adjacent to each WTG foundation sufficient to enable the safe
operation of an appropriately sized, crawler crane.
Design, construction and restoration of crane walk paths. Any necessary utility crossings
shall be the Contractor’s responsibility.
Turbine erection staging area is Contractor’s responsibility.
Final level adjustment of tower base section and grouting.
Provide WTG anchor bolt corrosion protection plan.
Post tension foundation anchor bolts. Grease anchor bolts and install anchor bolt protective
caps. Contractor shall include a maintenance plan (schedule) for anchor bolt checks and re-
tensioning requirements.
Support power performance testing.
Provide all special tools not provided by Turbine Supplier and special rigging that are
required for WTG erection including but not limited to slings, lifting beams, shackles, chains,
turning gear, and bolt torqueing equipment.
1.1.5 O&M Facility (if applicable)
Design, procure, construct and install a new, fully functional, O&M facility, security devices
and equipment.
Support delivery and installation of O&M building computers, IT equipment, furniture, and
appliances by Owner.
Contractor shall provide for parking, drainage, additional lots after construction, lighting,
training, internet and phone connection, and utilities.
1.1.6 Meteorological Towers
Furnish, design, and install temporary and permanent power performance MET towers,
including booms, sensors, and associated cabling and data loggers which will interface with
Project SCADA system.
Remove temporary power performance MET towers, if applicable.
Furnish and install FAA lighting on the MET Towers and connection to the Project Collector
Substation SCADA system.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 777 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-7
Furnish and install electrical, power and communications systems for permanent MET
towers.
Program and commission all MET tower data loggers.
1.1.7 Collection System
Design and install the collection system between the Project Collector Substation and the
WTGs. This includes trenching, laying and splicing of medium voltage (MV) power cables;
installing ground cables, furnishing and installing ground rods and fiber optic (FO) cable;
terminating the MV power cables at junction boxes, padmount step-up transformers, the
Turbines and any other system connection point; terminating FO communication cables at
the Project Collector Substation, in the WTGs and meteorological (“MET”) towers;
furnishing and installing power circuits and termination materials for the MET towers; and
installing conduits, grounding rods and grounding at junction boxes. Contractor shall
furnish and install padmount step-up transformers at each WTG, directional fault
indicators, and junction boxes. The Contractor shall also test all power and communication
cables and systems prior to energizing and commissioning and provide a list of
recommended spare parts for the collection system. The Contractor must also adhere to
Owner’s labelling and numbering requirements for equipment.
Furnish, install, and terminate low voltage (LV) cables between WTG switchgear and
padmount transformers.
The Contractor’s electrical design shall provide for estimated annual energy losses,
calculated between the output terminals of each WTG and the revenue meters.
As required, WTG padmount step-up transformers, as well as foundations and/or box pad.
Contractor shall place padmount transformer doors out of the wintertime prevailing wind
at the site. However, the padmount transformer doors shall not be on the side of the tower
opposite the access road. In the cases where the wind comes from the direction of the
access road, the padmount transformer doors shall be placed in a direction 90 degrees to
the wind.
Test, energize, and commission the collection system. Contractor shall also test and
commission WTG ground grid.
1.1.8 34.5 kV/345 kV Project Collector Substation
Procure and install all equipment and facilities required for the Contractor’s design,
construction, testing and commissioning of the Project Collector Substation including, but
not limited to, foundations, any required reactive power compensation equipment, station
service transformers, circuit breakers and/or switchgear, termination materials, disconnect
switches, surge arrestors, metering, bus work, protective relaying, Project Collector
Substation SCADA System (including all related hardware/software and licenses,
equipment, materials and commodities), battery backup power system and Uninterruptible
Power Supply (UPS), ground grid, grounding transformers, lightning protection,
34.5 kV/345 kV transformer, dead-end structure, bus and equipment support structures,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 778 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-8
the associated termination equipment up to the Point of Change of Ownership (PCO), and
control facilities. Per the GIA (Generator Interconnect Agreement) or the E&P (Engineering
and Procurement) Agreement, the PCO shall be the point where the Owner’s span from the
Project Collector Substation connects to the terminals of the 345 kV dead-end structure at
the Project Interconnect Substation.
Contractor shall perform all above- and belowground site infrastructure, procurement,
delivery, installation and on-site testing for the 34.5 kV/345 kV main power transformer(s)
(MPT) and associated equipment (including assembly and vacuum fill).
Design and build an open (future) bay on each 34.5 kV bus.
Design, procure and install revenue metering system in accordance with GIA.
Operation of Project Collector Substation upon energization of the interconnection facilities.
Contractor shall be required to energize the collection system and Project Collector
Substation.
Provide access roads and perimeter fences with access gate(s) and signage at the Project
Collector Substation.
All equipment shall be labeled per Owner’s requirements.
Grade collection and interconnection substations.
1.1.9 Project Collector Substation SCADA System and Fiber-Optic Network
Furnish, design, and install fiber-optic network and communications systems which shall
interface with Turbine Supplier’s systems as well as Owner’s and Transmission Owner’s
systems. Design of the Project Collector Substation SCADA System shall be performed in
cooperation between Turbine Supplier, Contractor, Transmission Owner, Transmission
Provider, and Owner to ensure an operational system that meets interconnection
requirements. Contractor is responsible for ensuring that all network and Project Collector
Substation SCADA Systems integrate properly. The PCO for the fiber-optic wire will be at
the splice box on the 345 kV dead-end structure in the Transmission Owner’s Project
Interconnect Substation.
Test all Project Collector Substation SCADA System and fiber-optic network infrastructure
on this Project, and as otherwise indicated in this Section.
Install Project SCADA system cabinets, servers, and associated fiber, hardware, software,
and software licenses.
Install Project protection system fiber-optics, including coordination with transmission
provider.
Support Project SCADA system and Owner SCADA system testing and commissioning.
Lead Project Collector Substation SCADA system testing and commissioning.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 779 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-9
The Project Interconnect Substation is provided by transmission owner. Contractor’s scope
of work excludes the Project Interconnect Substation.
Coordination with transmission owner during construction.
1.2 WIND TURBINE GENERATORS
1.2.1 General
The Turbine Supplier shall ship all WTG components (for both Non-PTC and PTC Turbines) to the
Project in coordination with the Contractor and Owner. Contractor shall offload and erect WTGs for
the Project. Turbine Supplier will provide the Project Contractor with (a) technical
representative(s) to advise on offloading, initial staging, erection, project startup, inspection and
related work.
1.2.2 WTG Installation
1.2.2.1 Erection of WTGs
Contractor shall undertake all work associated with erection and installation of all WTG equipment
to mechanical completion. The Turbine Supplier’s technical representative(s) shall provide
oversight and provide the Contractor with any specialized training.
Turbine Supplier will provide qualified blade repair technicians as required to make necessary
repairs of damage caused during shipment (while in custody of the Turbine Supplier) and
documented upon receipt.
Contractor shall place WTG door out of the wintertime prevailing wind at the site. However, the
WTG door shall not be on the side of the tower opposite the access road. In the cases where the
wind comes from the direction of the access road, the door shall be placed in the direction
90 degrees to the wind that would hold the door open (i.e., wind will be in the direction of door
opening).
1.2.2.2 Cleaning and Painting
The Turbine Supplier will deliver components to the Project with appropriate wrapping and
sealing. An inspection by the Contractor at delivery shall be performed to identify excessive grime
or tarp damage. Contractor shall clean WTG components by means of pressure washing of towers,
nacelle, rotor assembly, and blades to remove loose dirt and debris prior to installation.
Turbine Supplier will supply touch-up paint for tower and other painted surfaces as required.
Turbine Supplier will perform all finish painting as required.
1.2.2.3 Tower Wiring
The Contractor shall perform all WTG wiring where required and such wiring. Contractor shall
make final connections for lighting inside the tower.
Contractor shall ensure all power, control, and fiber optic equipment and cabling is connected for
immediate use from the nacelle to the WTG base. Contractor shall follow Turbine Supplier
instructions for completing this work.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 780 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-10
1.2.2.4 Commissioning
Commissioning of the WTGs will be completed by the Turbine Supplier in coordination with the
Contractor and Owner.
1.2.2.5 Aviation Obstruction Lighting
Contractor shall plan, furnish and install aviation obstruction warning lights and mounting brackets
for WTGs. Aviation obstruction warning lights and brackets shall meet Federal Aviation
Administration requirements for wind turbine lighting and the project-specific aviation lighting
plan (specified on the turbine Determinations of No Hazard from the FAA). The Contractor shall
also furnish and install all necessary Project Collector Substation SCADA System connections. The
Contractor shall include a material list and unit pricing for the proposed aviation obstruction
lighting scheme in their bid.
Contractor shall provide power supply, including temporary connections if required, for MET
towers and aviation obstruction lighting. Contractor shall make provisions for the aviation
obstruction lighting on the MET towers and WTGs to strobe in unison.
Contractor will include provisions for temporary aviation obstruction lighting of WTGs during
construction. For air traffic safety reasons, Contractor acknowledges that WTGs will be lit and that
temporary lighting and appropriate forms must be filed with jurisdictional agencies for each WTG
for the duration needed.
1.2.2.6 Project SCADA System
Contractor shall supply and install fiber-optic termination cabinets in each WTG base and at each
MET tower base, and Project Collector Substation, (and O&M facility if applicable) for easy fiber
optic access and troubleshooting. Contractor shall connect the Project SCADA system servers
located in the Project Collector Substation’s control building to Turbine Supplier’s services and
equipment. Contractor shall also provide power supply and communication links for Project SCADA
system servers. Contractor shall furnish and install the Project Collector Substation SCADA System
in accordance with OEM requirements. For terminations at each tower, Contractor shall provide
appropriate amount for terminations.
Contractor shall select permanent MET tower instrumentation and data loggers which are
approved by Turbine Supplier to interface with Project SCADA system.
1.3 DESIGN AND CONSTRUCTION REQUIREMENTS
1.3.1 Design Requirements
Contractor designs shall be prepared in accordance with all applicable laws, applicable
standards, permits, Prudent Wind Industry Practices, the Generator Interconnect
Agreement (GIA), WTG requirements. Any departure from the referenced codes or
specifications, must be fully explained in writing and submitted for the Owner’s review and
approval.
Contractor shall complete all applicable studies and calculations required for the design
including but not limited to those specified in Section 2, 3, and 4.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 781 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-11
The Contractor shall be fully responsible for adhering to the scope of work. The Contractor
shall provide a complete design as well as all quality control and design checks.
Contractor shall design and construct all permanent Project facilities including but not
limited to Turbine foundations, access roads, collection system, Project Collector Substation,
and MET towers (and associated MET tower foundation and booms design and engineering)
(and O&M facilities if applicable) for a minimum of a 40 year operational life.
The Project Collector Substation and the collection system shall be designed and built by the
Contractor.
The Contractor shall design the Project to complement landowner property use and
integrity. Contractor shall ensure minimal disruption to farming activities.
Prior to the start of work, the Contractor shall submit to Owner a design plan, or design
basis document, which shall serve as the basis for each component of the detailed design.
This documentation will summarize the basis of initial design criteria and be kept up to date
during the design process. This document will be finalized at the end of the design process
as to provide a record of how the design was performed.
1.3.2 Codes and Standards
Unless stated elsewhere, all work governed by this Contract shall conform to the most
recent version of all applicable standards and codes specified in this Section, as well as
Prudent Wind Industry Practices.
Contractor shall comply with all safety standards including OSHA regulations and all others
where applicable.
If any conflicts exist between any codes, standards, regulations, or exhibits, the most
stringent document shall apply.
Contractor shall comply with all relevant and current standards, including, but not limited
to, those from the following governing bodies:
1. OSHA – Occupational Safety and Health Administration
2. ICEA - Insulated Cable Engineers Associated
3. NEC – National Electrical Code
4. ANSI – American National Standards Institute
5. IEEE – Institute of Electrical and Electronics Engineers
6. ASTM International
7. NEMA – National Electrical Manufacturers Association
8. UL
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 782 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-12
9. AEIC – Association of Edison Illuminating Companies
10. TIA – Telecommunications Industry Association
11. EIC – Electronics Industries Alliance
12. IEC – International Electrotechnical Commission
13. AISC – American Institute of Steel Construction
14. ACI – American Concrete Institute
15. CRSI – Concrete Reinforcing Steel Institute
16. IBC – International Building Code
17. ASCE – American Society of Civil Engineers
18. AASHTO – American Association of State and Highway Transportation Officials
19. ASME - American Society of Mechanical Engineers
20. NESC - National Electrical Safety Code
21. NETA - InterNational Electrical Testing Organization
22. NIST - National Institute of Standards and Technology
23. NERC - North American Electric Reliability Corporation
24. MISO – Midcontinent Independent System Operator
Contractor shall adhere to all applicable NERC standards including but not limited to:
1. CIP-002
2. CIP-003
3. EOP-004
4. FAC-008
5. MOD-025
6. MOD-026
7. MOD-027
8. PRC-001
9. PRC-005
10. PRC-019
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 783 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-13
11. PRC-024
12. PRC-025
13. VAR-001
14. VAR-002
Contractor shall assist Owner in filling out all applicable NERC forms, including, but not
limited to, the following. This shall require that Contractor provides necessary technical
information so that Owner can complete these forms:
1. FAC-008
2. MOD-025
3. PRC-005
a. For the avoidance of doubt, Contractor shall perform point-to-point wiring
diagram checks in the field and provide the highlighted drawings to Owner.
4. VAR-002
Contractor shall execute applicable scope in accordance with MISO requirements and
standards.
1.4 DESIGN SUBMITTALS
1.4.1 Design Documents
All Design Submittals shall be made via Owner’s Document Control System, Unifier. In all cases, the
Owner may engage an Owner’s Engineer to further review and approve design documents and
calculations.
The Contractor shall submit all Owner-approved calculations and drawings to the local authority
for planning and building regulation approval. Immediately prior to such submission, the
Contractor shall provide the Owner with a complete set of all documents intended for inclusion in
the submission.
Under all circumstances, construction will not be permitted on-site until the relevant designs and
drawings have been reviewed and in all cases the relevant local authority approvals and permits
have been obtained.
The Contractor shall submit individual sets of calculations as requested by the Owner. All sets shall
be of similar format, self-explanatory and clear to review.
When required, the Contractor shall provide an explanation together with evidence to validate
computer programs used for design calculations. Calculations and drawings shall always be
submitted with document number, revision suffix and date of issue.
All drawings shall be to scale and fully detailed, dimensioned, and legible.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 784 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-14
Deviations from these designs shall be submitted in writing and require Owner approval before
implementing. The Contractor shall also submit the design drawings and calculations for the
Project’s design to the Owner for review and comment at points roughly equivalent to being 30, 60,
90 % complete, and IFC unless otherwise specified in other specifications.
1.4.1.1 As-Built Drawings
The Contractor shall provide the Owner with a complete set of ‘as-built’ drawings, sealed by the
Engineer of Record, incorporating all modifications that may have been made during the
construction period. Contractor shall furnish the ‘As-Built’ drawings in accordance with the Project
schedule.
The drawings shall be presented in hard copy and electronic format. Hand-markups will not be
accepted.
1.5 DESIGN REVIEWS
The Contractor shall support, cooperate with, and participate in pre-design meetings, design
reviews and teleconferences for every aspect and submittal of the Project’s design.
Design submittals shall include work performed by the Contractor and Subcontractors. All
Subcontractor submittals shall be reviewed and accepted/approved by the Contractor prior to
submittal to the Owner and Owner’s Engineer.
Owner and Owner’s Engineer shall use reasonable effort to accommodate Contractor and the
Project schedule during design reviews. All comments and respective resolutions shall be made in
writing.
All final drawings and calculations shall be sealed by the Engineer of Record.
1.6 CONSTRUCTION OBSERVATION
The Owner may require the presence of third party inspectors or Owner’s representatives at any
construction or testing activities. The Contractor shall be responsible for accommodating and
cooperating with these personnel, including providing any necessary site-specific safety training. If
the presence of third party inspectors or Owner’s representatives within the Project site is an issue,
or if there are any special requirements related to the presence of third party personnel at Project
activities, the Contractor shall detail these in a document for Owner review.
1.7 CONSTRUCTION FACILITIES
1.7.1 General
All temporary construction facilities including buildings, utilities, personnel sanitation facilities,
parking, material and equipment storage, vehicle and equipment maintenance, fuel storage,
signage, fire safety, Site security, material lay-down areas, spill cleanup kits, refuse containers, and
associated construction support facilities shall be provided and maintained by the Contractor.
1.7.1.1 Construction and Temporary Facilities
The Contractor shall furnish all construction and temporary facilities, equipment, materials and
supplies required for Project execution.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 785 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-15
All temporary structures and facilities provided by the Contractor will remain the property of the
Contractor. When the construction is complete, all such temporary structures, buildings, concrete
slabs and footings, tools and facilities shall be removed from the site, and the areas involved shall
be restored to their original or intended condition unless otherwise requested by Owner.
The Contractor’s temporary facilities shall be located within the Project site. The Contractor shall
prepare the area to be used during construction for temporary office trailers, parking, laydown,
storage, sanitation facilities, fuel tanks, security checkpoint, etc. If additional land is needed for lay-
down area Contractor will be responsible for securing land and all necessary permits to utilize
additional area.
All facilities shall be regularly and systematically maintained and cleaned by the Contractor
throughout Project construction to ensure proper and efficient operation.
1.7.1.2 Site Access and Car Parking
The Contractor shall provide access to the Project during construction through the construction of
permanent or temporary roads for the Project. The Contractor shall construct car parking facilities
suitable for the use of construction personnel, any Subcontractor’s personnel, and as may be
required. The Contractor shall enforce back-in, head-out parking at all site parking facilities. Unless
otherwise specified by Owner, upon completion of the Project, the Contractor shall restore all areas
to original or intended condition.
1.8 LAYDOWN AND STORAGE
An area within or near the Project shall be allocated by Owner for laydown and storage use by the
Contractor. The Contractor shall develop this area and shall provide any required security, lighting,
and construction power.
The Contractor-provided construction management and lay-down area shall be set up with
construction trailers and other temporary facilities to support Project Collector Substation
construction. The arrangement of these construction-phase (temporary) facilities will not inhibit
the installation nor configuration of temporary or permanent telecommunications, Project Collector
Substation SCADA system, relaying, or security hardware in any way. The use of a continuous
TCP/IP based web camera system is encouraged for the construction phase as part of physical
security.
All platforms, enclosures, shoring, and weatherproof coverings for storage use shall remain the
Contractor’s property and shall be removed upon completion of the Project and the lay-down and
storage area shall be restored to original or intended condition.
1.9 CONSTRUCTION UTILITIES
The Contractor shall obtain construction electrical supplies and shall pay for all construction power
required for Project construction including generators, transformers, breakers, disconnects, cables,
etc.
The Contractor shall provide and maintain a system of temporary lighting for use in the general
construction areas and lay-down yard where required. If work must be accomplished during non-
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 786 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-16
daylight hours, adequate lighting must be supplied in accordance with applicable NEC, OSHA, and
any other Prudent Wind Industry Practices, or safety requirements.
The Contractor shall supply water and distribute water on the Project. The Contractor shall pay for
all water required for Project construction.
The Contractor shall supply all fuel required for machinery, vehicles, and all equipment.
The Contractor shall supply a construction communication system as required by the Contractor for
control of all construction activities.
The Contractor shall furnish and maintain portable toilets for use by all site construction personnel
in accordance with all applicable regulations. Sanitation facilities shall be gender-segregated.
The Contractor shall provide for the disposal of all construction rubbish and waste materials from
the Project. The Contractor shall be responsible for obtaining any required permits.
Temporary fences shall be removed after completion of construction.
Contractor shall provide access road and parking area snow removal.
Contractor shall provide weed/grass control at lay-down yard, access roads, turbine areas, and the
Project Collector Substation.
Contractor shall provide any workforce housing and transportation.
1.10 SECURITY
During construction, security shall be provided by the Contractor. Any necessary security fence at
the Project will be constructed by the Contractor. In addition, the Contractor will provide for the
security of all construction, lay-down material, storage, and office and parking area. The
Contractor’s and Subcontractor’s tools, equipment, and materials will be the responsibility of the
Contractor. Contractor shall promptly replace all equipment and material lost to theft.
All Contractor and Subcontractor personnel employed at each site location must have a form of
personal identification. This identification must be kept in the possession of all site personnel at all
times while on the Project site and will be presented for identification upon request. All authorized
vehicles will have site stickers or window hangers or other form as agreed to by Owner.
All visitors to the site will report to the main construction office and are required to produce
identification upon request and obtain clearance from the party to be visited through the security
personnel, and complete and sign the visitor registration upon entering the Project. The visitor will
be issued a pass, hardhat, safety glasses, and earplugs and shall be escorted by Contractor or
Owner’s Representative while on site. At the conclusion of the visit to the site, the visitor will return
all items to the security personnel at the main gate.
Security personnel will be assigned assembly and accountability duties for personnel on site in
cases of emergencies. A list will be maintained of all personnel on site at any particular time and
date.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 787 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-17
1.11 CONSTRUCTION TOOLS AND EQUIPMENT
The Contractor shall provide all tools, hoists, cranes, earthmovers, air compressors, trucks, welding
machines, power tools, jacks and all other general or special tools, specialty lifting equipment,
construction machines, and equipment required for the construction work and WTG erection and
lifting. Note that Turbine Supplier will supply special tools to site and is responsible for the cost of
shipping these tools from site. Any tools required beyond that shall be supplied by the Contractor.
1.12 SIGNAGE
The Contractor shall install all permanent and temporary signs at each WTG location, clearly
indicating the respective WTG number, 911 address and traffic/safety signs. The Contractor shall
also provide temporary signs at public and site access road intersections to provide direction to
WTG locations, substation, and site exit. In addition, the Contractor shall provide signs indicating
which roads shall not be used. Contractor shall also provide fence signage at the Project Collector
Substation. All signs shall be weather resistant, and shall remain legible and in place throughout the
construction period.
The Contractor shall erect and maintain such danger signs, signals, lights, guards, and notices as
may be necessary to adequately protect Contractor’s work and personnel against injury or property
damage. The Contractor shall provide signage if required by permits.
1.13 SAFETY
Contractor shall prepare a safety plan before construction commences for approval by Owner.
1.13.1 Hazard Prevention and Control
Where feasible, workplace hazards are prevented by effective design of the Site or the Work. Where
it is not feasible to eliminate such hazards, they must be controlled to prevent unsafe and
unhealthful exposure. Elimination or control must be accomplished in a timely manner once a
hazard or potential hazard is recognized. Specifically, as part of the safety plan, Contractor should
establish procedures to correct or control present or potential hazards in a timely manner.
Use engineering techniques where feasible and appropriate.
Establish, at the earliest time, safe work practices and procedures that are understood and followed
by all affected parties. Understanding and compliance are a result of training, positive
reinforcement, correction of unsafe performance and, if necessary, enforcement through a clearly
communicated and documented disciplinary system. Contractor shall implement the following
safety practices and policies:
Use of proper work procedures, mechanical guards and personal protective equipment
when engineering controls are not feasible.
Use administrative controls, such as reducing the duration of exposure.
Maintain the facility and equipment to prevent equipment breakdowns.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 788 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-18
Plan and prepare for emergencies, and conduct training and emergency drills, as needed, to
ensure that proper responses to emergencies will be "second nature" for all persons
involved.
Establish a medical program that includes a nurse or nurse practitioner on the Site to
reduce the risk of any injury or illness that occurs.
1.14 SITE FIRE PROTECTION
Prior to the start of work, the Contractor shall develop and maintain a fire response plan applicable
to the Project in concert with the local authorities as part of the emergency response plan.
1.15 CLEANUP
As a part of the punch list work, the Contractor shall remove all tools, equipment, and surplus
materials. All temporary structures, buildings, temporary concrete footings and slabs, and
scaffolding furnished by the Contractor in the course of the construction shall be removed and the
involved areas shall be left in their intended or original condition. All trash, rubbish, debris, and
nonnative materials shall be promptly removed from the Project upon completion of the Project.
Site cleanup shall include seeding, landscaping, and other restorative efforts as necessary.
1.16 SERVICES FOR THE PROJECT OWNER
The Contractor shall establish, prior to the commencement of other work, two temporary office
facilities at the Project. One shall be for use by the Owner and one for Turbine Supplier’s personnel
when on site during construction. Such offices for the Owner and Turbine Supplier shall be in close
proximity to those of the Contractor. Connection and monthly charges for power shall be the
responsibility of the Contractor. The size and number of office trailers shall meet all requirements
below and will be agreed upon by the Contractor and Owner.
1.16.1 Owner’s Offices and Temporary Facilities Requirements
Contractor shall provide the following temporary facilities for the Owner. Construction trailer
complex shall consist of the following:
Six trailers aligned side-by-side with interconnectivity that provides at least 72 feet by 60
feet of space, windows with drapes
Multiple stair sets to gain access to exit/egress doors
Office furniture and hard-walled offices for 12 staff members
Receptacle power, data circuits, lights, heating/ventilating/air conditioning equipment
Contractor shall provide telephone and high speed Internet infrastructure
Computer/IT (Information Technology) office
Office supplies and equipment
Conference room space (12 feet by 30 feet minimum)
Potable (bottled) water
Sanitation facilities may be shared with the Contractor’s facilities if the facilities are in close
proximity, gender specific, and maintained clean.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 789 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-19
Lavatory facilities (four internal stalls and water closets) with janitor space
Janitorial services and cleaning supplies
1.16.2 Turbine Supplier’s Offices and Temporary Facilities
Contractor shall furnish Turbine Supplier’s offices and temporary facilities in accordance with
Turbine Supplier requirements.
1.17 ENVIRONMENTAL
1.17.1 Protection of Sensitive Areas
All identified sensitive areas shall be located on the Project’s design drawings and appropriate
design action taken to avoid impacts to these areas. The Contractor shall minimize the areas
impacted by construction and shall furnish and install temporary low-impact, high-visibility fencing
to identify and protect these sensitive areas where they are inside or adjacent to the planned crane
paths or other work areas and shall maintain the fencing during the Project’s construction. The
Contractor shall remove the fencing at the completion of construction. The Contractor shall protect
these environmentally sensitive areas and comply with the conditions of related permits during
construction.
Contractor shall identify the areas on the Project’s design drawings and take appropriate design
action to avoid impacts to the areas. If historic, cultural or archaeological areas are discovered
during excavation or other construction-related work, the Contractor shall stop work immediately
and notify the Owner. The Contractor shall assist the Owner in remediation and mitigation of such
discovered areas.
1.17.2 Environmental Constraints During Construction
The Contractor shall not discharge any toxic, poisonous, or polluted effluents onto land at the
Project or any streams, creeks, rivers, ponds, or other bodies of water at any time.
Contractor shall develop an Environmental Management Program for the construction phase of the
Project. The Environmental Management Program shall reflect the terms of all permits which are
applicable to the Project. Contents of the plan should include, but not be limited to, the following:
Storm Water Pollution Prevention Plan (SWPPP)
Waste management (including hazardous wastes)
Spill Prevention, Control, and Countermeasure (SPCC) Plan
Fugitive dust control
Measures for protecting sensitive environmental resources
All components of the Environmental Management Program shall be completed by the Contractor
and approved by the Owner and the applicable permitting authorities as required prior to the start
of any field work. The Environmental Management Program shall be updated to reflect any new,
amended, or modified permits that are received or mitigation measures that are developed
following production of the initial Environmental Management Program.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 790 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| General 1-20
1.17.3 Suppression of Dust and Dirt
The Contractor shall develop a fugitive dust control plan sufficient to meet state and local
regulations or preferences. Contractor shall indicate how dust plumes will be avoided, and how
impacts to nearby residents and public road visibility will be minimized. Calcium chloride or an
Owner-approved alternative may be used in place of water for dust control.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 791 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-1
2.0 Civil
Civil works shall include the design, detailing, micrositing, material procurement, layout, erection,
and construction of foundations, structures, buildings, installations, and services required for the
installation, commissioning, operation and maintenance of all equipment and plant which make up
the Project.
The Contractor shall locate, design, and construct a crane pad and temporary turbine
assembly/erection area at each turbine location in accordance with the Contract, the Turbine
Specifications, and these specifications. The Contractor shall also install a permanent aggregate
apron around each turbine foundation in accordance with the Contract, the Turbine Specifications,
and these specifications. The Owner will furnish the turbine locations to the Contractor. The
location, layout, and design of the crane pads and turbine assembly/erection areas shall be
reviewed by the Owner.
The Contractor shall cut, fill, and/or grade the crane pads, turbine assembly/erection areas, and
turbine foundation sites of the Project as necessary and sufficiently to achieve the finished grades of
the Contractor’s design. The spoils from this construction shall be utilized as needed to re-grade
areas of the Project. If required, fill material shall be provided by the Contractor. The fill material
shall be inert, free draining, free from any deleterious materials and placed to a degree of
compaction adequate for the use of the fill.
No crane pad, turbine assembly/erection area, or turbine foundation apron fill shall be placed in
wetlands. The Contractor shall identify and mark wetland boundaries prior to commencement of
construction activities. All Project crane pad, turbine assembly/erection area, and turbine
foundation apron construction shall conform to the Storm Water Pollution Prevention Plan
(SWPPP).
The Contractor shall undertake all reasonably necessary tests to demonstrate the crane pads,
turbine assembly/erection areas, roads, and turbine foundation aprons are fit for purpose. The
Contractor shall provide an approved third-party independent testing agency for certification of
turbine foundation, crane pads, assembly, and erection sub-base preparation; compaction of
backfill around the turbine foundations; any fills associated with the turbine foundation, assembly,
or erection areas; and final surfacing of the turbine assembly and erection areas.
2.1 DESIGN BASIS
The design and construction of all turbine areas, lay-down areas, and access roads shall conform to
the 2015 International Building Code, federal, state, county and municipal codes and regulations,
and the requirements specified below.
The information contained in the Contract, and these specifications, provides a basis for the
engineering and design associated with the design and construction of the access and site roads for
the Project. Cement-stabilized access roads shall be designed using “Department of the Army
Technical Manual 5-822-12, Design of Aggregate Surfaced Roads and Airfields”, or an equivalent
Owner approved methodology. If the above referenced method is used, calculations must be
performed for both the required depth above the natural subgrade and the required depth above
the cement stabilized subgrade. For the natural subgrade, a saturated design CBR value of one-
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 792 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-2
third of the in-situ value shall be used. Calculations shall utilize a design index of 4 or greater. As
stated in Sections 4a and 4i of Technical Manual 5-822-12, the aggregate surfacing thickness shall
not be less than 4 inches with this method.
The Contractor shall provide permanent roads to and within the Project to provide adequate access
to each turbine, the Project Collector Substation, the O&M Facility and Storage Warehouse
Buildings, and other Project facilities. The roads shall be designed to be capable of carrying all
vehicles likely to be used during construction and throughout the life of the Project.
The Contractor shall cut, fill, and/or grade the access and site roads of the Project, as necessary, and
sufficiently to achieve the finished grades of the Contractor’s design. The spoils from road
construction excavation shall be utilized as needed to re-grade areas of the Project. Excavated or
stripped soil must be placed within the same landowner’s property, unless written consent is
provided by that landowner to remove soil from the property. If required, fill material shall be
provided by the Contractor. The fill material shall be inert, free draining, free from any deleterious
materials, and placed to a degree of compaction adequate for the use of the roadway.
No road fill shall be placed in wetlands. The Contractor shall mark provided wetland boundaries
prior to commencement of construction activities. All Project road construction shall conform to the
SWPPP.
2.2 SITE PREPARATION
2.2.1 General
The Contractor shall design and prepare the Project, including all layout, surface grading, clearing,
erosion control, earthwork, trenching, material stockpiling and protection as well as avoidance of
all environmentally, historically, culturally, and archeologically sensitive areas identified by the
Owner or by the Contractor. Prior to the start of construction, the Contractor shall acquire all
necessary permits.
2.2.2 Site Survey
The Contractor shall perform all Site survey work necessary for the design and construction of the
Project, including topographic data, boundary locations, aerial photography, and the location of
existing aboveground and belowground utilities and facilities. The Contractor shall provide all
survey information to the Owner for documentation purposes.
2.2.3 Erosion and Sediment Control
The Contractor shall develop a SWPPP to be used during construction in conformance with U.S.
Environmental Protection Agency (EPA) National Pollutant Discharge and Elimination System
(NPDES) standards. The Contractor is responsible for the design, implementation, management,
and maintenance of all erosion control measures required for compliance with applicable
regulations (federal, state, and local).
2.2.4 Waste Management
The Contractor shall dispose of all construction solid waste debris into permitted landfills.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 793 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-3
2.2.5 Clearing and Grubbing
The Contractor shall clear and grub the construction area of vegetation at the Site. The Contractor
shall strip and stockpile the topsoil for re-spreading. Topsoil stockpile areas must be contained by
silt fence or equivalent measures to prevent soil migration. Clearing must not unreasonably exceed
that necessary to complete the Work. Waste from clearing shall be disposed of off-site in
accordance with state and local regulatory requirements.
Clearing work shall include clearing and removing trees within the construction areas; cutting and
removal of all brush, shrubs, debris, and vegetation to approximately flush with the ground surface;
and disposal of all cuttings and debris. Mowing will be considered adequate for the cutting of light
vegetation.
Grubbing work shall include the complete removal and disposal of all stumps and roots larger than
approximately 2 inches in diameter, including matted roots, regardless of size. Grubbing shall
extend to a minimum depth of approximately 4 inches below the natural surrounding ground
surface.
All excavations made by clearing and grubbing work shall be backfilled with compacted earth.
2.2.6 Earthwork
The Contractor shall perform all earthwork activities required to complete the Work, in accordance
with federal, state, and municipal regulatory requirements and the requirements specified below.
2.3 PERMANENT FENCES AND GATES
The Contractor shall provide permanent gates in locations where roads must be constructed
through existing fencing. The permanent gates shall always be closed as necessary to maintain
control. Cattle guards may be used in lieu of permanent gates with notice and approval of Owner.
The Contractor shall install fencing as necessary for livestock.
Where overhead and/or underground collection systems pass through a fence, a temporary gate
shall be installed. At the completion of construction of the Project, the original fencing will be re-
established.
2.4 CONSTRUCTION AND TEMPORARY FACILITIES
All temporary construction facilities, including buildings, utilities, personnel sanitation facilities,
parking, material and equipment storage, vehicle and equipment maintenance, fuel storage,
signage, fire safety, Site security, turbine erection (crane) mats, material lay-down areas, spill
cleanup kits, refuse containers, and associated construction support facilities shall be provided and
maintained by the Contractor.
All temporary structures and facilities provided by Contractor will remain the property of
Contractor. When the construction is complete, all such temporary structures, buildings, concrete
slabs and footings, tools, and facilities shall be removed from the site, and the areas involved shall
be restored to their original or intended condition unless otherwise requested by Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 794 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-4
Contractor’s temporary facilities shall be located within the Project site or at a nearby location.
Contractor shall procure and prepare the area to be used during construction for temporary office
trailers, parking, laydown, storage, sanitation facilities, fuel tanks, security checkpoint, etc.
All facilities shall be regularly and systematically maintained and cleaned by the Contractor
throughout Project construction to ensure proper and efficient operation.
2.5 SITE ACCESS AND PARKING
Contractor shall provide access to the Site during construction through the construction of
permanent or temporary roads for the Project. The Contractor shall construct automobile parking
facilities suitable for the use of construction personnel, any subcontractor’s personnel, and as may
be required. Unless otherwise specified by Owner, upon completion of the Project, the Contractor
shall restore all areas to original or intended condition.
2.6 LAYDOWN AND STORAGE
The Contractor shall procure, design, and construct an aggregate surfaced area to be used during
construction for laydown and storage. The Contractor shall strip and stockpile topsoil prior to
surfacing.
The Contractor shall provide any required security, lighting, and construction power. All platforms,
enclosures, shoring, and weatherproof coverings for storage use shall remain the Contractor’s
property and shall be removed upon completion of the Project and Project Collector Substation, and
the lay-down and storage area shall be restored to original or intended condition.
2.7 DRAINAGE
Each turbine site, including the crane pad and turbine assembly/erection area, shall be graded such
that runoff water will drain away from the site. The top of all permanent foundations shall be
placed a minimum of 12 inches above the 100 year flood elevations.
2.8 CRANE PADS
The Contractor shall construct a crane pad at each turbine site in accordance with the Turbine
Specifications and these specifications. Topsoil shall be removed and stored on-site during
construction for replacement after decompaction and remediation. The access road shall be utilized
as a portion of the crane pad in order to limit additional land disturbance. The engineered civil
plans shall include detailed crane pad dimensions, position, and orientation at every turbine site.
At a minimum, the crane pad must be able to safely support the combined loading of the erection
crane and the maximum anticipated turbine component load.
2.9 TURBINE ASSEMBLY / ERECTION AREA
The Contractor shall construct and compact a sufficient turbine assembly/erection area at each
turbine site in accordance with these specifications.
At a minimum, the turbine assembly/erection area must be able to support the assembly and
erection activities associated with the installation of the turbine.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 795 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-5
If aggregate is used for the surface of the turbine assembly/erection area, it shall be removed after
construction.
2.10 TURBINE FOUNDATION APRON
The Contractor shall install a permanent crushed rock apron around the turbine foundation. The
apron shall encompass the pedestal foundation, pad mount transformer and junction box,
extending a minimum of 10’ beyond the outer edge of each, in a manner that enables vehicular
access around the perimeter. The apron shall be composed of 8 inches of a 1 inch (maximum size)
crushed rock laid on top of a geotextile fabric. After all construction activities at the turbine are
completed, an additional 1 inch layer of the same crushed rock shall be installed and compacted.
2.11 EXCAVATION
The Contractor assumes responsibility for knowledge of underground structures and clearances
that may be encountered or affected by the BOP Work hereunder.
A maximum variation in depth of excavation of 2 inches above or below established grade will be
permitted. All foundations shall be in undisturbed soil.
Excavated material shall be piled so as to be available for backfill; wasting and borrowing will not
be permitted except as specifically directed by the Owner. Operations shall be confined to the
minimum work area consistent with efficient operation.
Adequate precautions shall be taken to prevent caving of foundation excavations and to assure that
walls are kept reasonably vertical. All excavations in loose or unstable soil shall be protected by
such means as timbering, lining, or shoring, until the foundation is placed. Excavations shall be kept
free of water except where in the sole opinion of the Owner it is impractical to do so. In this event,
either the design of the foundation or method of installations, or both, will be modified.
Special care shall be taken to avoid disturbing or loosening the soil below designated grade. Any
accumulation of sand, silt, mud, refuse, or other material shall be removed before foundation is
placed. Timbering, lining, shoring, and all means of removing water are to be considered as a part of
the excavation.
2.12 DEWATERING
Contractor shall provide, maintain, and operate any and all equipment necessary to dispose of
water that interferes with foundation construction. Water shall be removed from excavations
before depositing concrete, except where under-water concrete placement is allowed for drilled
piers as provided for below.
2.13 BACKFILLING
Excavations shall be backfilled in a maximum of 6 inch layers and compacted to 95% of the
maximum density as determined by the Standard Method Test for Compaction and Density of Soils.
Contractor shall be responsible for the maintenance of all constructed embankments and shall
replace at his own expense any portion which may have become displaced or damaged due to his
operations. Excavated material in excess of the quantity that can be placed in backfill, and material
unsuitable for use as backfill shall be hauled away and wasted (disposed of) by the Contractor at
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 796 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-6
locations approved by the Owner. Wasted material shall not be left in unsightly piles but shall be
leveled off and shaped so as to present a neat appearance and not obstruct drainage. Disposing of
surplus waste or unsuitable material, including hauling, shall be considered as part of the BOP
Work. All backfill shall be cleaned and free of frozen earth, snow, ice, refuse timber, vegetation, or
other foreign matter.
2.14 SIGNAGE
Contractor shall install temporary signs at each turbine location clearly indicating the respective
turbine number. Contractor shall also provide temporary signs at public and site access road
intersections to provide direction to turbine locations, substation, and site exit. In addition,
Contractor shall provide signs indicating which roads shall not be used. All signs shall be weather
resistant and shall remain legible and in place throughout the construction period.
Contractor shall erect and maintain such danger signs, signals, lights, guards, and notices as may be
necessary to adequately protect Contractor’s work and personnel against injury or property
damage. Contractor shall provide signage if required by permits.
2.15 PROJECT ENTRANCE & ACCESS ROADS
2.15.1 Reconnaissance and Road Location
The Contractor is responsible for selection of road routes in cooperation with the turbine supplier.
Prior to the start of construction, the condition of public roads to be used for hauling equipment
and delivery of materials shall be documented by the Contractor with the government authority
having jurisdiction. Upon completion of construction or use of public roads, the Contractor and the
applicable local authority will perform a final inspection of the public roads to determine if any
damage or deterioration of the roads has been caused by the Contractor or the Contractor’s
Subcontractors. In the event that the damage or deterioration of the roads has been caused by the
Contractor or the Contractor’s Subcontractors or Suppliers, the Contractor shall make all such
repairs.
Variable grades and alignments shall be utilized to locate roads on the most suitable terrain. Road
grades shall not exceed those recommended by the turbine supplier and shall be minimized
wherever practical to limit potential for erosion.
Road locations shall minimize the risk of materials entering waters of the state and municipality
and minimize disturbance to stream channels, lakes, wetlands, and floodplains. Where viable
alternatives exist, roads shall not be located on steep slopes, slide areas, or high-risk sites, or in
wetlands, riparian management areas, channels, and floodplains.
When possible, locations of roads parallel to and in close proximity to streams shall be avoided
because such locations have a higher than normal potential to deliver sediments directly into the
channel. Stream crossings shall be as close to a right angle with the stream as possible in order to
enter and exit the stream with minimal intrusion.
Alternative road locations shall be considered where natural resources are impacted. The most
favorable road locations are those that provide the best combination of meeting objectives and
minimizing economic and environmental costs.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 797 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-7
Engineer of Record shall provide final road section design along with supporting calculations
demonstrating adequacy for anticipated loads. The final design shall meet or exceed the minimum
requirements shown below.
2.15.2 Road Subgrade and Surfacing
Roads shall be no wider than necessary to accommodate the anticipated use. Roads shall be
designed to be constructed with a balanced cut and fill cross section where possible and where this
does not pose a risk of slope instability. Where a balanced cross section is not possible, excess
excavation material shall be used in the road design when possible and not wasted. Designs shall
call for full bench construction and end-hauling of excess excavation material when roads are
located on steep slopes and/or high-risk sites. To prevent fill failures, road designs shall provide for
stable fills by using compaction, buttressing, subsurface drainage, rock facing, or other effective
means.
Maximum allowable dips and bumps and minimum allowable crest shall be in accordance with the
turbine manufacturer’s transportation specifications.
Topsoil shall be stripped and stockpiled in windrows to achieve specified road section and provide
adequate drainage during construction. When project construction is complete, topsoil shall be
placed and compacted to achieve the final section.
The Contractor shall maintain the subgrade and take the necessary precautions to protect the
finished subgrade from damage. The Contractor shall ensure that the subgrade has been graded to
drain at the end of each day. The routing of traffic over the finished subgrade shall be limited to that
which is essential for construction purposes. Any damage resulting from construction operations
shall be repaired at the expense of the Contractor.
Roadway aggregate surface course materials shall conform to the requirements of Department of
Transportation Class A Crushed stone for the specific state. Aggregate shall be placed on the
subgrade in layers of uniform thickness not exceeding 6 inches in loose thickness. Aggregate
compaction shall achieve a minimum of 98% of the maximum dry density. Following aggregate
placement and compaction, Contractor shall proofroll to verify road bearing capacity is adequate
for turbine delivery.
Following Project construction, the final aggregate surface course material shall be added to
achieve a smooth, well-draining surface. After delivery and erection of turbines is complete, road
shoulders and crane walk paths shall be removed, decompacted and restored. Topsoil windrows
shall be replaced and graded to drain.
Crane walk paths shall be used only for tracked crane walks and related activities; paths shall not
be used for general construction traffic, including rubber-tired cranes or telehandlers.
2.15.3 Execution
Mixing shall not be performed when the soil aggregate or subgrade is frozen. Soil-cement shall not
be mixed or placed when the air temperature is below 40° F, unless the temperature is at least 35° F
and rising.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 798 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-8
The entire width of the area designated for stabilization shall be processed as a single operation.
The cement shall be spread uniformly on the subgrade at the required rate of application by a
method acceptable to the Purchaser. Cement that becomes displaced after spreading shall be
replaced before mixing is started.
Processing shall be performed in one course. The processing shall result in a uniform distribution
of cement and water at the specified density.
After the cement has been applied, mixing shall begin within 30 minutes. The soil and cement shall
be mixed until the cement has blended sufficiently with the soil to prevent formation of cement
balls when water is applied.
Immediately after soil and cement mixing is complete, the water required to obtain the specified
compaction shall be added. If the moisture content exceeds that specified, the mixture shall be
worked by remixing or blading to reduce the moisture content to within the specified range.
Excessive concentrations of water shall be avoided. During the application of water and after all
mixing water has been applied, mixing shall continue until a uniform and intimate mixture of soil,
cement, and water is obtained.
2.15.4 Compaction
Compaction of the soil-cement shall begin immediately after mixing is completed. The start of
compaction of the soil-cement mixture shall begin within 30 minutes after the last moist-mixing
pass is complete.
At the start of the compaction operation, the percentage of moisture in the mixture and in
unpulverized soil lumps, based on dry weights, shall be within a tolerance of two percentage points
of optimum moisture content.
The optimum moisture content and maximum density shall be determined in the field by the
methods prescribed in ASTM D558 on representative samples of the soil-cement mixture obtained
from the area being processed.
The loose mixture shall be uniformly compacted to not less than 95 percent of maximum density.
Material compacted to less than 95 percent of maximum density shall be recompacted, removed, or
replaced as directed by the Purchaser.
2.15.5 Finishing
After compaction is complete, the cement-stabilized soil surface shall be shaped to the required
lines, grades, and cross section. The resulting surface shall be compacted to the specified density.
Rolling shall continue until the entire grade conforms to the specified density requirements.
During the finishing operation, the moisture content of the surface material shall be maintained at
not less than two percentage points below its specified optimum moisture content. Surface
compaction and finishing shall produce a smooth, dense surface, free of compaction planes, cracks,
ridges, and loose material.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 799 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-9
2.15.6 Testing by Contractor
Field and laboratory testing shall be performed by an independent testing laboratory acceptable to
the Purchaser.
At least one pair of Dynamic Cone Penetrometer (DCP) determinations shall be performed for each
500 lineal feet of road. At each location, two DCP tests shall be performed, one on each side of the
road. The first test for each road shall consist of two points located 4 feet from the road centerline
on each side. The second test shall consist of two points located 7.5 feet from the road centerline on
each side. The test locations shall continue to alternate between pairs of 4 foot offsets and pairs of
7.5 foot offsets for the remainder of the tests at each access road. Every DCP test shall have results
recorded at 3, 6, 9, and 12 inch depths. In areas where DCP tests fail to achieve the required results,
additional tests shall be taken every 50 feet on each side of the original test until passing results are
achieved.
As part of the final civil engineering design, the Engineer of Record shall specify the required CBR
value for the cement stabilized subgrade. Engineer shall also specify a remediation plan for areas
with failed DCP tests.
At least one field moisture content and one density determination shall be performed for each
1,500 lineal feet of compacted material with a minimum of one of each test per day, whichever is
greater. Field samples shall be taken at locations selected by the Purchaser. If additional field
control tests are necessary, in the opinion of the Purchaser, such tests shall be made.
Maximum density for the compacted soil-cement materials shall be determined in accordance with
ASTM D558. The terms "maximum density" and "optimum moisture content" shall be as defined in
ASTM D558.
The location of each test moisture, density, and DCP test shall be documented by GPS coordinates.
Subgrade adequacy shall be further confirmed by proofrolling with a tandem axle truck. The truck
shall be loaded such that the front axle is loaded to a minimum of 18,000 pounds, and the total
weight of the truck and load is a minimum of 52,000 pounds. The tire width must not exceed 17
inches for front tires and 11 inches for rear tires. Tires shall be inflated to within 2 psi of tire or
vehicle manufacturer's maximum psi rating. The minimum psi rating must be 80 psi.
Each road shall be proof rolled with three complete passes, one on each side of the road centerline
and one with the truck in the center of the road. The truck shall be operated at a speed between 2.5
and 5.0 miles per hour. The speed shall be adjusted to allow the Engineer to measure the ruts. For
acceptance of the test, the subgrade must not show pumping or rutting in excess of 1.5 inches
measured from the top to the bottom of the rut at the outside edges.
A copy of each test result shall be furnished to the Owner within 24 hours of testing.
2.15.7 Maintenance
The cement-stabilized soil shall be maintained in its finished condition until all work is complete
and accepted by the Owner. Maintenance shall include immediate repair of any defects. Faulty
work shall be replaced for the full depth of the layer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 800 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-10
2.16 TEMPORARY INTERNAL ACCESS ROAD CURVE WIDENING
The Contractor shall design and construct temporary internal access road curve widening at sharp
curves in the access roads to allow for turbine deliveries. The Contractor shall strip and stockpile
topsoil. The subgrade and aggregate surfacing of the widenings shall be tested to verify that a
minimum of 98% of maximum density has been achieved. Widenings also shall meet performance
requirements through proof rolling. The widenings will be removed after turbine deliveries. The
subgrade base will be de-compacted, and topsoil will be replaced. Upon replacement of topsoil from
the temporary stockpiles associated with each landowner (unless otherwise negotiated), the
temporary curve widening areas will be restored to pre-construction contours and elevations.
Landowners may be contacted to ensure an appropriate seed mix is planted in areas not subject to
tilled agriculture.
2.17 TEMPORARY PUBLIC ROAD INTERSECTION WIDENING
The Contractor shall design and construct temporary public road intersection widenings to allow
for turbine deliveries. The Contractor shall coordinate with applicable permitting agency for all
work within the public road right-of-way. The Contractor shall strip and stockpile topsoil. The
subgrade and aggregate surfacing of the widenings shall be tested to verify that a minimum of 98%
of maximum density has been achieved. Widenings also shall meet performance requirements
through proof rolling. Contractor shall ensure proper road drainage and maintain existing
intersection drainage patterns. The widenings will be removed after turbine deliveries, along with
any associated temporary drainage features. The subgrade base will be de-compacted, topsoil will
be replaced and restored.
2.18 ROAD DRAINAGE
Road drainage shall be designed to limit interruption of the existing topography and drainage
patterns. All drainage facilities, such as swales, culverts, and concrete low-water crossings, shall be
designed to accept and convey all runoff from a 25 year storm event unless permit requirements
are more stringent.
Concrete low-water crossings are the preferred method of drainage conveyance at road crossings,
and shall be utilized wherever practical.
Good road surface drainage is required to minimize siltation and to keep subgrades firm and stable
to support the designed loads. Surface runoff water intercepted by roads shall be returned to
natural flow routes as quickly as practical. Methods of achieving this are listed below:
(a) Shapes. The road cross section shall be shaped to move water away from the road. Road surfaces
shall be crowned or cross-sloped for drainage. A crowned road surface is preferred since it
provides the shortest distance for water to travel off the road surface (from centerline to either
road edge). A transverse-sloped road surface shall typically be used as needed in horizontal curves
to maintain vehicle stability as the vehicle travels through the curve.
(b) Grades. Road grades shall be minimized to the extent possible and shall conform to industry
standards and requirements of the turbine manufacturer for permissible maximum grades.
(c) . Ditches, culverts, and low water crossings shall be used as necessary to
effectively control and disperse surface runoff water to minimize erosion of the road. Water shall
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 801 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-11
not be diverted from existing channels except as necessary to construct stream crossings. Drainage
shall be provided when roads cross or expose springs, seeps, or wet areas. Road drainage water
shall not be discharged into headwalls, slide areas, or high-risk sites.
(d) Surface. The surface of the road shall be designed for its anticipated use. Roads shall have
rocked surfacing that will provide subgrade reinforcement and resist the erosive effects of water.
2.19 DESIGN OF STREAM CROSSING STRUCTURES
Stream crossing structures shall protect aquatic and riparian habitats and provide fish passage, as
well as preserve the stability and use of the road. As a minimum, all new stream crossing
installations or replacements of existing crossings shall be sized to pass stream flow levels as
predicted by the 24 hour duration, 25 year storm event, unless permit requirements are more
stringent.
All permanent stream crossing structures shall be designed and approved by a Licensed
Professional Engineer and in accordance with permit.
2.20 MAINTENANCE
The Contractor shall maintain all access and site roads, including associated drainage infrastructure
and erosion control measures, in order to ensure suitable conditions for use until such time as all
conditions have been met for BOP Final Completion.
The Contractor shall perform the BOP Work required to remedy repairs of any damage to the
Project access and site roads occurring during the construction period, including that caused by
precipitation. All modification and repair of public roads at the interface of public roads and the
Project roads shall be performed in accordance with applicable permits.
The Contractor shall execute the BOP Work required for fugitive dust prevention or suppression in
accordance with state and local requirements. The Contractor shall implement measures to
minimize the transfer of soil and debris onto public roads from construction activity and clean the
public roads of soil and debris as necessary in a timely manner. The Contractor shall provide dust
control on roads used for construction during times when construction traffic results in excessive
dust which may present a driving safety hazard or otherwise affect residences in the vicinity. Aside
from the Contractor’s discretion to implement dust control measures, this may also include dust
control requests received from Land Owners where the dust is the result of construction traffic.
2.21 EROSION CONTROL
Contractor shall provide temporary and permanent erosion control in accordance with the Project
SWPPP. Please note that unless the SWPPP Notice of Intent is transferred from the Contractor to
Owner, the Contractor would continue to be responsible for final stabilization of the site. The storm
water permit defines final stabilization as:
“all soil disturbing activities at the site have been completed, and that a uniform perennial
vegetative cover with a density of 70% for the area has been established or equivalent stabilization
measures have been employed or which has been returned to agricultural production.” After
finishing the roadway to its final design cross section, the Contractor shall prepare a seedbed,
fertilize, seed and mulch the slopes, ditch bottom and other disturbed areas. Within a cultivated
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 802 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Civil 2-12
field, Contractor shall spread topsoil to blend with surrounding field topography upon final
construction completion. Seed shall be locally available and able to thrive in the climate. In the
event the seeding occurs at a time (i.e. winter) where seed germination is unlikely, the Contractor
shall agree to perform the work at a later date to increase the probability of successful seed
germination. Irrigation or watering of the seed is excluded.
2.22 CROP DAMAGE AND TILE REPAIR
Crop damage must not unreasonably exceed that necessary to complete the BOP Work. The
Contractor shall coordinate with the Land Agent to reimburse landowners for any additional
damage to growing crops to the extent caused by the Contractor’s or Subcontractor’s operations.
The Contractor shall locate and flag drain tiles along access roads, crane walk paths, and collection
system trenches before construction. Where possible, damage to drain tiles shall be avoided. The
Contractor shall document, using GPS tools, any drainage tile damaged by the Contractor’s or
Subcontractor’s operations, repair or restore any tile damage before completion of Project
construction, and record drain tile locations on the As-Built drawings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 803 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-1
3.0 WTG Foundations
The Contractor shall be responsible for the design, detailing, material procurement, layout,
erection, and construction of wind turbine generator (WTG) foundations and structures, as
required for the installation and operation of the Project. The Contractor shall take due care to
ensure that the WTG foundations are designed and installed with respect to each of the two specific
WTGs being utilized in this Project.
The Contractor is responsible for providing Design Documents that meet the turbine supplier’s
specifications and the requirements described herein.
The Contractor shall design, procure, and construct concrete foundations in accordance with these
specifications for all concrete work required for the installation and operation of the Project.
Concrete work shall include, as required, slab-on-grade equipment pads, isolated structure support
footings, O&M facility foundations and flatwork (if applicable), WTG foundations, deep concrete
drilled pier foundations, mudmats, and other miscellaneous flatwork.
3.1 DESIGN BASIS
The design and construction of all WTG foundations and structures shall be in accordance with all
federal, state, and municipal codes and regulations, as well the codes and standards listed below:
International Building Code 2015 (IBC 2015).
Building Code Requirements for Structural Concrete, American Concrete Institute (ACI 318-
14).
Manual of Steel Construction, American Institute of Steel Construction (AISC, 15th Edition).
Minimum Design Loads for Buildings and Other Structures, American Society of Civil
Engineers (ASCE 7-16).
International Standard, Wind Turbines-Part 1: Design Requirements (IEC 61400-1, Edition
3.1, 2014-04).
The design operational lifetime of all WTG foundations, including fatigue, shall be forty (40) years.
Loading information is provided in the referenced manufacturer specifications and shall be taken
into consideration by the Contractor in developing the detailed foundation design(s).
3.2 EXCAVATION, SUBGRADE PREPARATION, BACKFILL, AND COMPACTION
3.2.1 General
The Contractor shall coordinate the excavation, subgrade preparation, backfill, compaction, and
grading activities in accordance with the final geotechnical report. The requirements specified
herein are based on preliminary geotechnical information and are meant to supplement the
aforementioned documents. The soil work shall include all soil requirements specified in the
transformer box pad installation instructions (box pad by others).
3.2.2 Execution
The Contractor shall confirm the location of turbine coordinates in the final geotechnical report. If
turbine coordinates are offset by more than 50 feet, obtain written instructions from the Owner as
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 804 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-2
to the means of additional investigation to be undertaken. Obtain written confirmation from the
geotechnical engineer that the specified investigation was completed.
Topsoil shall be removed from the plan area and stored in an Owner-designated area. The topsoil
shall be used for site restoration on the landowner’s property.
Excavate soils or rock using techniques that will minimize disturbance to the subgrade. The
Contractor shall be responsible for control of surface water and/or groundwater flows into the
excavation.
If granular soils are encountered across the entire footprint of the foundation, surface compact the
top of the subgrade to consolidate loose soils created during excavation. Refer to the final
geotechnical report for recommended subgrade preparation techniques.
If rocky conditions are encountered across the entire footprint of the foundation, substantially
remove all loose rock greater than 3 inches in size from the bottom of the excavation. As practically
as possible, remove material below 3 inches in size to expose undisturbed rock. If the bottom of the
excavation is of variable elevation, establish a level bench by use of lean concrete fill. Lean concrete
fill to be provided under transformer box pad footprint at elevation provided by box pad
manufacturer.
Place lean concrete fill for protection of the subgrade and to establish a level working surface. The
lean concrete surface should be placed as soon as possible after excavation is complete and must be
level and of a uniform thickness. Prior to placing a protective lean concrete surface, have a
professional geotechnical engineer inspect the subgrade conditions and record the soil type
encountered, groundwater conditions, or other subsurface conditions. A copy of the geotechnical
engineer’s findings shall be provided to the Owner for review and approval.
Based on preliminary geotechnical information, ground improvement may be required for multiple
WTG foundation sites due to the presence of non-competent subgrade materials or shallow
groundwater levels. The Contractor should refer to the final geotechnical report for any applicable
subgrade preparation requirements and recommended subgrade preparation techniques. The final
WTG foundation support design(s) shall be based on the final geotechnical report.
If soil conditions are encountered that are not consistent with the final geotechnical report, or if
subgrade uniformity or strength is insufficient, obtain written instructions from the Owner as to the
means of correction to be undertaken. Obtain written confirmation from the geotechnical engineer
that the specified corrective actions were completed.
Place and compact common fill materials to the limits, depth, and dry density indicated on the
referenced drawings. In addition to the dry density requirement, backfill must be compacted to a
minimum of 95% standard proctor. Place fill in maximum loose lifts of 12 inches or less to achieve
the specified density. Backfill may be placed when the footing and pedestal have reached 2,000 psi.
Grade the site at 1/4 inch per foot to prevent water from ponding over the foundation, while
maintaining at least the minimum depth of fill required for the structural stability of the WTG
foundation. The WTG foundation design should clearly specify the required in-place unit weight for
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 805 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-3
any backfill to be used for the WTG foundations. The Contractor shall also install a turbine
foundation apron, as specified in Section 2.0.
3.3 STRUCTURAL REQUIREMENTS
3.3.1 Anchor Bolts
All WTG anchor bolts shall be in accordance with the turbine supplier’s specifications and the
requirements herein.
The bolts shall be all-thread rebar fabricated from ASTM A615 (Grade 75) or ASTM A722 (Grade
150) material. The diameters of the bolts are determined by the turbine supplier and must be
followed accordingly. All anchor bolts shall be supplied with heavy hex nuts and washers
compatible with the bolts, as required by the design. WTG anchor bolts shall be provided with PVC
sleeves conforming to ASTM D1784, Class 10000, and manufactured to ASTM D2241 requirements.
All WTG anchor bolts shall be installed by use of an anchor bolt template provided by the
Contractor. Exposed portions of all bolts shall be provided with a corrosion inhibiting wax or grease
compound. Bolt projections above top of concrete shall be set per the requirements of the
tensioning device used to post-tension the anchors. The Contractor shall specify the required bolt
projection length necessary for post-tensioning and take measures to ensure consistent bolt
projections across all WTG foundations. Tolerances shall be strictly adhered to during construction.
WTG anchor bolts shall be tensioned using an Owner-approved tensioning procedure. A lock-off
force shall be applied to each bolt to achieve a minimum tension force in each anchor, as
determined by the detailed WTG foundation design. The lock-off force shall be selected by the
Contractor, accounting for tension losses due to the tensioning procedure, to ensure that the
specified tension test value is achieved. The tensioning equipment for the anchor bolts shall be
calibrated in accordance with the approved procedure on a regular basis to ensure required
tensions are achieved.
After all WTG anchor bolts have been tensioned, a minimum of 10% of the total bolts installed per
WTG foundation shall be randomly tested to verify that the required tension load has been achieved
by use of an approved tension testing procedure. If any of the anchor bolts do not meet the required
tension test value, then all bolts of the tower must be re-tensioned and the tension test must be
repeated until the required tension load can be verified.
3.3.2 WTG Foundation Concrete and Tower Base Grout
Cast-in-place concrete shall be in accordance with the latest applicable requirements of the federal,
state, and municipal specifications, ACI, ASTM, and CRSI, except as modified by these specifications.
All references to codes and standards are to the latest edition of each.
Concrete materials shall be in accordance with these requirements:

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 806 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-4
Table 3-1 Concrete Material Requirements
Cement ASTM C150, Type I or II.
Fly Ash ASTM C618, Class C or F.
Water Clean, potable, and free from injurious amount of oil, acid, alkali, organic
matter or other deleterious substances.
Coarse Aggregate ASTM C33, crushed stone, washed gravel, or other acceptable inert granular
material.
Fine Aggregate ASTM C33, clean natural sand.
Air-Entraining Agent ASTM C260.
Plasticizing Retarder ASTM C494, Type B or D.
Plasticizer ASTM C494, Type A.
Form Oil Light colored paraffin oil or other acceptable non-staining material.
Membrane curing
compound
MasterKure HD 100WB, produced by Master Builders, or approved
equivalent.
Floor Sealer MasterKure HD 300WB, produced by Master Builders, or approved
equivalent.
Concrete Repair MasterEmaco, produced by Master Builders, or approved equivalent.
Compound MasterEmaco, produced by Master Builders, or approved equivalent.
Joint Sealant MasterSeal, produced by Master Builders, or approved equivalent.
Non-Shrink, Epoxy Grout : MasterFlow 649, produced by Master Builders, or
approved equivalent.
: MasterFlow 648, produced by Master Builders, or
approved equivalent.
Pre-Formed Joint Filler Sonoflex F, produced by Sonneborn, or approved equivalent.
Concrete mix designs shall be in accordance with the conditions of the site, the application purpose,
and structural requirements.
Ready-mixed concrete manufacturing and delivery shall conform to ASTM C94.
Use air-entraining admixture in exterior-exposed concrete. Add air-entraining admixture at the
manufacturer's prescribed rate to result in concrete at the point of placement having air content in
accordance with ACI 318 for concrete exposed to freezing and thawing and shall have a tolerance of
+/- 1.5% from the design value.
During hot weather, or under conditions contributing to rapid setting of concrete, a shorter mixing
time than specified in ASTM C94 may be required. When the air temperature is between 85° F and
90° F, reduce the mixing and delivery time from 90 minutes to 75 minutes, and when the air
temperature is above 90° F reduce the mixing and delivery time to 60 minutes.
The maximum aggregate size shall not exceed 1-1/2 inches. Smaller maximum aggregate size, such
as 3/4 inch, may be necessary for pumped or tremie concrete. Rounded aggregates may be
necessary to produce desired workability.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 807 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-5
A nominal slump at the point of delivery shall be as follows:
Table 3-2 Concrete Slump Requirements
Reinforced Walls and Footings 6” max., 2” min.
Slabs-on-Grade 4” max., 2” min.
Drilled Piers (Dry, Uncased, or Permanent Casing Drill Method) 6” max., 4” min.
Drilled Piers (Temporary Casing Drill Method, Wet and Dry) 8” max., 6” min.
Drilled Piers (Slurry Displacement Drill Method) 9” max., 7” min.
WTG Foundations 6” max., 2” min.
The Contractor shall select a concrete mixture that meets the design requirements for each
structure type and exposure classifications in accordance with ACI 318. The minimum concrete
compressive strength at age 28 days shall be 4,000 psi for structural concrete and 2000 psi for non-
structural concrete (e.g., lean work slabs, duct banks, and fill concrete). For WTG foundations, the
minimum concrete compressive strength at age 28 days shall be 4,500 psi.
A delivery ticket shall be prepared for each load of ready-mixed concrete delivered and handed to
the authorized representative of the Contractor by the truck operator at the time of delivery.
Tickets shall show the number of cubic yards delivered, the quantities of each material in the batch,
the outdoor temperature in the shade, the time at which the cement was added, and the numerical
sequence of the delivery. Delivery tickets shall be handed to the authorized representative of the
Owner on the agreed schedule.
Additional test specimens shall be taken as follows:
As a minimum, a set of nine (9) grout cubes for each WTG foundation shall be cast.
Exposed grout edges shall be tapered.
Table 3-3 Required Grout Test
Compressive Strength ASTM C109
Two tests (average of three cube breaks each) shall be conducted at an age of
twenty-eight (28) days. An additional three cubes of each set shall be held in
reserve at a safe location, on-site or at the laboratory, pending the results of
the other tests.
The Contractor shall furnish the Owner certified reports of all tests made by the testing laboratory.
The test results shall be prepared and sent to the Owner on the next business day after tests are
conducted.
Reports of grout compressive strength tests shall contain the Project identification name and
number, date of grout placement, location of grout placement, name of manufacturer,
manufacturer’s grout product data, manufacturer’s approved instructions for grout placement,
name of grout testing service, design compressive strength at 28 days, compressive breaking
strength, and type of break for 28 day tests.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 808 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-6
: Additional tests of in-place WTG tower base grout will be required when test
results indicate that the specified strengths and other characteristics have not been attained in the
structure, as directed by the Owner. Tests to determine the adequacy of the WTG tower base grout
shall be by testing the reserve grout cubes, or by other methods as agreed. Contractor shall pay for
such tests conducted, and any other additional testing as may be required, when unacceptable
grout is identified.
3.3.3 Steel Reinforcing
All reinforcing steel, including welded wire mesh, shall be accurately located and held in position by
the use of proper reinforcing steel supports, spacers, and accessories in accordance with ACI
Manual of Concrete Practice.
At time of placing concrete, all reinforcing shall be free of loose rust, scale, oil, paint, mud or other
coatings which will destroy or reduce the concrete bond. All reinforcing bars must conform to
ASTM A615 and have minimum yield strength of 60 ksi, unless noted otherwise.
The Contractor shall take into consideration any necessary corrosion protection for all reinforcing
steel. Where not otherwise specified or shown by the written dimension, the minimum coverage of
the concrete over the reinforcing steel shall be as follows:
Concrete cast against, and permanently exposed to, earth: 3”
Formed concrete exposed to earth or weather: 2”
Concrete in beams and columns not exposed to ground or weather: 1-1/2”
Concrete slabs and walls not exposed to weather: 1”
3.3.4 Miscellaneous Concrete Embedments
The Contractor shall coordinate the location and placement of all miscellaneous concrete
embedments, as required for the operation and maintenance of the Project.
The referenced turbine supplier specifications detail the requirements for grounding grids, control
conduit, and electrical conduit. The Contractor shall make accommodations for all conduit options,
unless noted otherwise by the Owner. The Foundation Design Engineer shall coordinate with the
Electrical Design Engineer on the placement of conduits for the LV cables. Conduit placement
details shall be submitted to the Owner for approval.
The Contractor shall incorporate a drainage design that will allow for the drainage of water from
the top of the pedestal inside the WTG tower. The drain shall empty outside of the pedestal above
final grade. The floor drain shall be capped and the drainage outlet shall be equipped with a locking
ball valve, or an Owner-approved alternative. Drainage design details shall be included in the WTG
Foundation Design Documents and submitted to the Owner for approval.
All miscellaneous embedments shall adhere to the following requirements:
Miscellaneous embedments will be located as not to interfere with the foundation’s
structural reinforcing steel.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 809 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-7
Miscellaneous embedments will be properly secured to prevent movement during concrete
placement.
The top of any embedded conduit must be a minimum of 24 inches below the top of the
foundation pedestal.
Drainage outlets shall be placed in a location outside of the pedestal that does not interfere
with other surrounding installations and can be easily accessed by maintenance personnel.
Any concrete-embedded iron or steel shall be protected from corrosion utilizing the
provisions of ACI 318 for clear cover, mix design and place and detailing requirements. Due
consideration shall be given to exposure classifications, admixtures, alkali aggregate
reactivity and any other deleterious conditions common to the project locations. Refer to
the project specific geotechnical report and any applicable manufacturer’s specifications for
additional corrosion considerations.
3.3.5 Tower Erection and Anchor Tensioning Requirements
The Contractor shall coordinate the erection of WTG towers and tensioning of anchor bolts in
manner that shall not affect the structural integrity of the WTG foundations or towers. Tower
erection details shall be submitted to the Owner for approval.
Up to two tower sections may be erected, leveled, and grouted when the concrete strength
of the footing and pedestal has reached a minimum of 75% of the 28 day compressive
strength and has sufficient strength to support the loads from the erected tower sections.
Anchors may be tensioned when: (1) the concrete strength of the footing and pedestal have
reached 100% of the design 28 day compressive strength , and (2) the grout strength has
reached 75% of the design compressive strength and has sufficient strength to resist the
loading.
Additional tower sections, the nacelle, and blades may be erected when: (1) the concrete
strength of the footing and pedestal has reached 100% of the design 28 day compressive
strength, (2) the grout strength has reached 100% of the design compressive strength, and
(3) anchor bolt tensioning and testing has been completed, verifying that the required
tension value has been achieved.
3.3.6 Tolerances
WTG foundations, anchor bolts, and towers shall be set carefully and maintained at the lines and
elevations within the following tolerances:
Reinforcing plan spacing: plus or minus 2”
Reinforcing vertical spacing: plus or minus 1”
Footing clear concrete cover: minus 0” or plus 3”
Pedestal clear concrete cover: minus 0” or plus 2”
Footing plan dimensions: minus 0” or plus 3”
Footing thickness: minus 0” or plus 3”
Pedestal plan dimensions: minus 0” or plus 2”
Pedestal height: minus 1” or plus 0”
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 810 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-8
Pedestal centered: within 2” relative to footing
Horizontal angular alignment (rotation) of anchor bolt group: ±1°
Anchor bolt plan location: ±1/16”
Anchor bolt deviation from vertical (out of plumb): ±0.25°
Template/embedment ring plan dimensions: ±1/16”
Embedment ring level: ±1/4"
Embedment ring elevation: ±1/2”
3.4 TESTING AND INSPECTION
Testing shall be the responsibility of the Contractor.
The Contractor shall engage the services of a qualified third party testing/inspection agency to
ensure the following construction quality control testing and inspection requirements are executed.
All required testing/inspection reports and Submittals shall be issued to the Owner for review and
record.
Test specimens shall be taken as follows, unless otherwise directed:
As a minimum, a set of six (6) 6x12 or set of nine (9) 4x8 concrete compression test
cylinders shall be made each day concrete is placed.
One set for each 150 cubic yards of concrete, or fraction thereof, of each concrete class
placed in any one day.
Each set of concrete compression test cylinders shall be marked or tagged with the date and
time of day the cylinders were made, the air content (for pedestals and above grade
concrete), and the slump.
Concrete test cylinders shall be made, cured, stored, and delivered to the laboratory in
accordance with ASTM C31. No water may be added to the concrete after the samples have
been taken.
Table 3-4 Required Tests
Concrete
Slump ASTM C143
One test on concrete taken at point of discharge into the forms for
each 25 cubic yards of concrete, or fraction thereof, of each
concrete class placed in any one day. Record ambient air
temperature and concrete temperature per ASTM C1064.
Air Content ASTM C231, pressure method
One for each 25 cubic yards of concrete, or fraction thereof, for all
air entrained concrete mix designs placed in any one day. Record
ambient air temperature and concrete temperature per ASTM
C1064.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 811 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-9
Concrete
Compressive Strength ASTM C39
Two (2) 6x12 or three (3) 4x8 cylinders shall be tested at age
seven (7) and twenty eight (28) days. An additional two (2) 6x12
or three (3) 4x8 cylinders shall be held in reserve at a safe
location, on site or at the laboratory, pending the results of the
other tests. Any additional testing required or requested by
construction shall be in sets of two (2) for 6x12 and three (3) for
4x8 cylinders.
The Contractor shall furnish the Owner certified reports of all tests made by the testing laboratory.
The test results shall be prepared and sent to the Owner on the next business day after tests are
conducted.
Reports of concrete compressive strength tests shall contain the wind farm identification name and
number, date of concrete placement, name of Contractor or Contractor’s representative, name of
concrete supplier and truck number, name of concrete testing service, location of concrete pour,
design compressive strength at 28 days, compressive breaking strength, and type of break for both
seven-day tests and 28-day tests.
: Additional tests of in-place concrete will be required when test results indicate
that the specified strengths and other characteristics have not been attained in the structure, as
directed by the Owner. Tests to determine the adequacy of the concrete shall be by testing the
reserve cylinders and/or by cored cylinders complying with ASTM C42, or by other methods as
agreed. Contractor shall pay for such tests conducted, and any other additional testing as may be
required, when unacceptable concrete is identified.
3.5 CONSTRUCTION CONSIDERATIONS
3.5.1 Placing of Concrete
Concrete shall be placed only in the presence of a duly authorized Contractor’s representative.
Concrete placement shall not be permitted when weather conditions or other pertinent factors
prevent proper placement and consolidation.
Concrete shall be conveyed from mixer to forms as rapidly as practicable without segregation or
loss of ingredients. Concrete shall be placed in forms neatly as practicable in final position to avoid
re-handling. Concrete shall be discharged within 90 minutes or before 300 drum revolutions after
the introduction of the mixing water to cement and aggregates, or the introduction of the cement to
wet aggregates. During hot weather or other conditions which contribute to the rapid setting of
concrete, discharge times shall be decreased in accordance with Section
.
Chutes, if used, must slope sufficiently to insure flow of properly proportioned concrete and must
be kept free of hardened or partially set concrete.
Concreting shall be carried in at such a rate that the concrete is at all times plastic and flows readily
into the spaces between the bars. No concrete that has partially hardened or been contaminated by
poor material shall be utilized for the wind farm, nor shall re-tempered concrete be used.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 812 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-10
Immediately after depositing, concrete shall be compacted by agitating thoroughly in approved
manner to force out air pockets. Mixture shall be worked into corners around reinforcement and
inserts to prevent formation of voids. Tapping or other external vibration of forms will not be
permitted. Care shall be used in use of vibrators to prevent segregation of sand pockets or bleeding.
Vibrators shall be moved continuously in and out of concrete, keeping stationary only a few seconds
in any position. Vibrators shall not be used to transport concrete within forms.
For concrete poured within forms, concrete shall not drop freely over 60 inches in unexposed work
or over 36 inches in exposed work. Where greater drops are required, tremies, concrete pump, or
other approved methods shall be used. The Contractor shall take care to avoid excessive concrete
splatter.
Concrete may be dropped into drilled piers installed using the dry method under the conditions
that concrete shall not hit any reinforcing bars or sidewalls and that concrete with all aggregates
shall be able to flow freely into the spaces between the reinforcing bars. Vibration of concrete
falling more than 20 feet is not required. The concrete shall be placed in the pier in one continuous
operation unless agreed otherwise by the Owner.
For mass concrete structures, generally structures with a minimum cross-sectional dimension that
approaches or exceeds 36 inches or when cement contents above 600 lb/cy is used, contractor shall
provide a mass concrete procedure to mitigate the adverse effects heat produce by hydration.
Procedure shall include concrete mix design, placement procedure and thermal control plan in
accordance with ACI 301 and ACI 207.2R. Contractor shall insure concrete cools gradually during
and at the conclusion of the specified cure period. The maximum drop in concrete surface
temperature during the curing period shall not exceed 20° F in a 24 hour period with a thermal
gradient between the center and surface no exceeding 35° F. The temperature of concrete when
deposited shall be a maximum of 70° F and minimum of 35° F unless an alternative placement plan
is approved. Cast-in-place concrete at the Contractor's option may be placed by pumping in
accordance with ACI 304; however, it shall use a specifically designed mix for pumping concrete
because fine aggregate gradation and water and cement content are more critical and different
from the regular concrete mix. Slump may be increased by one inch for individual batches at point
of discharge. Do not convey through aluminum or aluminum alloy pipes. The loss of slump in
pumping equipment shall not exceed two inches. The mortar used for lubricating the pumping
equipment shall be discarded. Slump and air tests shall be taken at point of discharge from the line.
Concrete cylinders shall be taken at the point of discharge from the line.
If required, any concrete-embedded iron or steel should be protected from corrosion (e.g., through
the use of cathodic protection or a polyethylene wrap). The Contractor shall refer to the
geotechnical report and any applicable manufacturer’s specifications for additional corrosion
considerations.
3.5.2 Joints
At construction joints, a good bond and watertight joint are required. These shall be obtained by
adequately preparing and protecting the surface of the first pour or lower part of the construction
joint. This surface should be fairly level and reasonably rough, clean, moist, and some aggregate
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 813 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-11
particles should be exposed. Any laitance or soft layers shall be removed from the top surface of the
hardened concrete.
3.5.3 Cold Weather Requirements
If cold weather is anticipated during the construction of the Project, then the following
requirements shall be followed. After the first frost and until the mean daily temperature in the
vicinity of the work falls below 40°F for more than one day, the concrete shall be protected against
freezing for not less than 48 hours after it is placed. Whenever the mean daily temperature in the
vicinity of the work falls below 40°F for more than one day, the concrete shall be maintained at a
temperature not lower than 50°F for a least 72 hours after it is placed and shall be protected
against freezing for 5 days immediately following the 72 hours of protection at 50°F. This
continuance of protection against freezing shall be such that the drop in temperature of any portion
of the concrete will be gradual and will not exceed 40°F in 24 hours. When artificial heat is
employed, special care shall be taken to prevent the concrete from drying. The use of calcium
chloride will not be permitted. A non-corrosive, non-chloride set accelerating admixture may be
used when approved by the Owner. Concrete damaged by freezing shall be removed and replaced
at the Contractor’s expense.
The Contractor shall be cognizant of any cold weather considerations necessary to ensure the
proper construction and integrity of any installed concrete work. Ground frost concerns may
require subgrade improvements or other site preparations.
3.5.4 Hot Weather Requirements
When hot weather conditions exist that would seriously impair the quality and strength of concrete,
place concrete in compliance with ACI 305.1 and as specified herein. Cool ingredients before mixing
to maintain concrete temperature at time of placement below 90° F. Mixing water may be chilled, or
chopped ice may be used to control the concrete temperature, provided the water equivalent of the
ice is calculated to the total amount of mixing water. Cover reinforcing steel with water-soaked-
burlap if it becomes too hot, so that the steel temperature will not exceed the ambient air
temperature immediately before embedment in concrete. Do not use retarding admixtures unless
otherwise accepted in mix designs.
3.5.5 Finishing
All fins and other surface projections shall be removed from all formed surfaces. All surfaces are to
be at the specified elevation and left true and level. Surfaces that will be exposed shall be cleaned
and rubbed to produce a smooth, uniform surface free of marks, voids, surface glaze, and
discolorations. Exposed surfaces shall have a smooth broom finish.
Care shall be taken to see that all excess water is removed before making any finish. The unformed
surfaces of concrete shall be screeded and given an initial float finish followed by additional floating
and troweling as required. Precaution shall be taken by the Contractor to protect the finished
surface from stains and abrasions.
The removable ends of all form ties shall be removed and the recesses resulting from such removal
shall be filled with dry patching mortar.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 814 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Foundations 3-12
An Owner-approved sealant shall be applied to the outside of all foundations to a depth of 1’-0”
below final ground grade.
3.5.6 Cleanup
During the concrete finish and cleanup, the Contractor shall remove concrete adhering to the
portions of the anchor bolt extending above finished concrete grade, giving particular attention to
concrete at the finish grade line which would prevent base plates from seating fully on the finished
concrete elevation.
3.5.7 Curing
Concrete shall be protected from loss of moisture per ACI requirements for membranes. Curing
compound may be used in lieu of membrane. The curing medium shall be maintained so as to
prevent detrimental loss of water from the concrete for the duration of the entire curing period.
Concrete shall not be permitted to freeze for at least seven (7) consecutive days following
placement. Unhardened concrete shall be protected from heavy rains, flowing water, excessive heat,
or mechanical damage.
3.5.8 Repairing Defective Concrete
Defects in formed concrete surfaces shall be repaired to the satisfaction of the Owner within
24 hours, and defective concrete shall be replaced within 48 hours after the adjacent forms have
been removed. All concrete which is porous, honeycombed, and otherwise defective to a depth in
excess of 1 inch shall be cut out and removed. Defective concrete shall be repaired by cutting out
the unsatisfactory Material and placing new concrete, which shall be formed with keys, dovetails, or
anchors to attach it securely in place. The Contractor shall take necessary precaution to protect
finished surfaces from stains, abrasions, or physical damage.
Concrete slab surfaces that contain defects which adversely affect durability, strength, or
appearance, shall be repaired by a method approved by the Owner or they shall be replaced.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 815 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-1
4.0 Collection System
4.1 DOCUMENT OVERVIEW
This specification is for the complete engineering, procurement, installation, testing, and placing
into service of a medium voltage (MV) underground collection system, fiber-optic communication
system, and other work specified to be completed in accordance with Prudent Wind Industry
Practices.
4.2 STANDARDS
Contractor shall follow the current adopted versions of applicable standards, including but not
limited to, the following:
National Electrical Code (NEC)
ANSI/IEEE C2 - National Electrical Safety Code
ANSI/IEEE C57.12.00 - General Requirements for Liquid Immersed Distribution, Power, and
Regulatory Transformers
C57.12.70, Terminal Markings and Connections for Distribution and Power Transformers
ANSI/IEEE 386, Standard for Separable Insulated Connector Systems for Power
Distribution Systems Above 600 V.
ANSI/IEEE C57.12.80, Terminology for Distribution and Power Transformers.
ANSI/IEEE C57.12.90, Standard Test Code for Liquid-Immersed Distribution, Power, and
Regulating Transformers
ANSI C57.12.28 - Pad-Mounted Enclosure Integrity
National Electrical Manufacturers Association (NEMA)
ANSI C.57.12.10
ANSI C.57.12.26
IEEE PC57.106
ASTM D3487
ASTM D4059E1
NEMA TR1
ANSI Z535.1
ANSI Z535.2
ANSI Z535.3
UL No. 44
UL No. 1685
NEMA/ICEA WC-8/ICEA S-68-516
NEMA/ICEA WC-70/ICEAs-95-658-1999
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 816 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-2
ASTM B-33
ASTM B-172
ICEA/NEMA WC26
ICEA S-87-640
ICEA S-94-649
UL 1072
AEIC CS8
ICEA S-87-640
TIA/EIA 598B
Note: Where conflicts exist between AEIC CS8 and ICEA S-94-649, the AEIC CS8 requirement will
govern. If any other standards or this specification conflict with one another, the most stringent
shall apply.
4.3 SYSTEM DESCRIPTION AND GENERAL REQUIREMENTS
4.3.1 General
All collection system components shall be designed to operate at 34.5kV +/- 10% and 38 kV
maximum.
Each of the wind turbine generators (WTGs) shall have an appropriately sized and grounded
transformer procured by the Contractor with feed-through connection capability located at each
turbine.
4.3.2 Standards
The Project shall be designed, manufactured, installed, and tested in accordance with this section
and the applicable sections of the latest revision of the accepted standards for electric utility
equipment and construction referenced in Section 1.0.
4.3.3 Losses
The total annualized energy losses from the low voltage terminations at the base of all turbines to
the revenue meter shall be less than 2.5% based on WTG production frequency.
4.3.4 BIL (Basic Insulation Level)
System voltage: 34.5 kV
BIL: 200 kV
4.3.5 Electrical Clearances
Preferred normal and minimal electrical clearances from energized parts shall be in accordance
with the latest editions of ANSI C2, IEEE Std. 1119, NESC, and NEC Article 110.34.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 817 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-3
4.3.6 Collector System As-Built Location
Contractor shall locate constructed buried power lines, junction boxes, transformers, and all major
equipment for the creation of easements and as-built drawings. Lines will be located at
approximately 300 linear feet (LF) intervals and deflection points and provided in UTM 15N
coordinates in electronic format to a positional accuracy of 1 meter or better, suitable for importing
to Microstation and AutoCAD.
4.3.7 Grounding
The collection grounding system consists of the following: WTG grounding, pad mount step-up
transformer grounding, junction and splice box grounding, and MET tower (meteorological tower)
grounding. These grounding systems are to be designed and installed by the Contractor. The copper
concentric neutral on each conductor and the trench ground wire will interconnect these ground
systems.
4.3.7.1 WTG Grounding Requirements
All WTG grounding and testing shall be in accordance with the requirements of the turbine
manufacturer or IEEE Standard 80, whichever is more stringent. Contractor shall perform a step
and touch analysis.
The Contractor shall use the four point fall of potential method per IEEE STD 81 for measuring and
testing the ground resistance at the WTGs.
The grounding point shall be connected to any bare copper grounding conductor (e.g., copper
ground inside the tower) as the system reference point (E). The minimum distance from E to the
current electrode (CE) should be 5-6.5 times the diagonal distance of the grounding system being
measured. Resistance measurements shall be taken with the potential electrode (PE) at 1%, 10%,
20%, 30%, 40%, 50%, 60%, 61.8%, 70%, 80%, 90%, and 99% of the diagonal distance. The
Contractor shall compare the reading at point (E) to the theoretical value from the step and touch
analysis. The test shall be performed with all phase and ground connections lifted so that the
equipment being tested is isolated from the rest of the grounding system. Testing direction shall be
perpendicular to any parallel conductive path (trench, conduit, fence, overhead or below-grade
lines, etc.) A sketch of the testing route shall be provided for each test. Contractor shall ensure that
this testing is done in accordance with turbine supplier’s requirements, as well as the Engineer of
Record’s requirements from the step and touch analysis.
4.3.7.2 Grounding Transformer Requirements
Each feeder shall have at least one grounding transformer to ensure that the feeders are effectively
grounded. The grounding transformers must provide effective grounding as defined by
IEEE C62.92.1 at all points on the collector system. The use of a particular grounding transformer
shall be validated in accordance with the analyses and studies.
4.3.8 Testing
The Contractor shall complete the test forms supplied or created for each test and submit them in
the “job completion manual” to the Owner. A detailed testing procedure with forms will be supplied
by the Contractor. Specific testing to be completed is detailed throughout this document.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 818 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-4
4.3.9 Spare Parts
In general, Contractor shall not leave reels of cable MV in excess of the MV cable required as spare
parts.
4.4 MV CABLE SPECIFICATION
4.4.1 General
This section describes the requirements, installation, grounding, testing, labeling, and numbering of
the MV underground cables. The Contractor shall specify and procure MV cable and quantities.
Contractor shall inspect all parts upon receipt to ensure they meet the bill of material, drawings,
and equipment specifications. Contractor shall provide receipt inspection checklists and store
equipment with all accessories in a safe location.
4.4.2 Equipment Requirements
MV cable shall be jacketed, single-conductor aluminum, concentric-neutral wire, MV underground
distribution MV-90 or MV-105 power cable insulated with tree-retardant cross-linked polyethylene
(TRXLPE), and rated at 35 kV. This cable shall be of a discharge free design and suitable for direct
burial, installation in duct and exposure to sunlight on an alternating current, three-phase, nominal,
60-Hertz power system. Flat strap neutrals are not allowed.
All cable shall meet the requirements of the latest revision of the following documents unless stated
otherwise in this document: (a). Association of Edison Illuminating Companies (AEIC) No. CS8,
Specification for Extruded Dielectric, Shielded Power Cables Rated 5 through 46 kV, (b). Insulated
Cable Engineers Association (ICEA) No. S-94-649, Standard for Concentric Neutral Cables Rated
5,000-46,000 Volts, and (c). Insulated Cable Engineers Association (ICEA)/National Electrical
Manufacturers Association (NEMA) No. WC26, Wire and Cable Packaging.
Note: Where conflicts exist between AEIC CS8 and ICEA S-94-649, AEIC CS8 requirements shall
govern.
The conductor shield, insulation, and insulation shield shall be applied in a true triple-extrusion
(through a common head), continuous single-pass process. Then all three layers shall be
simultaneously cross-linked. A dry-cure process shall be used. A water-swellable powder shall be
placed between the insulation shield and the jacket to block the progression of moisture.
The allowable conductors are 1/0 AWG, 4/0 AWG, 500 kcmil, 1000 kcmil, and 1250 kcmil. All
conductors shall be Class B stranded. The trench ground shall be minimum 2/0 copper or
equivalently-sized copper-clad steel. Fiber-optic cable shall be installed in innerduct and in
accordance with this section. Owner may approve alternate cable choices not specified above.
Owner preference for concentric shield wire sizes is as follows:
1/6 concentric for 1250 kcmil and1000 kcmil, 1/3 concentric for 500 kcmil, 1/2 concentric
for 4/0 AWG, and a full concentric for 1/0 AWG.
Larger neutral sizes may be used if deemed necessary by the Engineer of Record, with
Owner approval.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 819 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-5
Contractor shall verify that the above concentric sizes are appropriate. The concentric shield
conductors shall be sized to withstand the worst-case fault condition for that particular cable
segment. Multipoint grounding may be used if deemed necessary by the Engineer of Record.
Power cables shall not be longer than 8,200 feet before entering an above-ground junction box to
allow for partial discharge testing.
All underground collection cables shall have appropriate ampacities based on the measured backfill
and surrounding native soil rho values while maintaining conductor temperatures at or below the
rated temperature of the cable. An ampacity model shall be provided by Contractor showing that
the cable temperature will remain below the rated temperature at maximum output.
The central stranded conductor shall be 1% to 3% compressed concentric-lay, Class B stranded and
three-quarter hard drawn (H16 or H26) 1350 aluminum. All spaces between conductor strands
shall be filled with a sealant to block the progression of moisture. The compound used shall be
compatible with the conductor and conductor shield.
The conductor shield shall be black, super smooth, and extra clean.
The insulation thickness for TRXLPE shall be 345 mils (as defined by the 100% insulation level).
Diameters shall be as defined by AEIC CS8.
The insulation shield shall be semi-conducting, thermosetting material and shall strip freely and
cleanly within the tension limits of 6 pounds minimum to 20 pounds maximum. Diameters shall be
as defined by AEIC CS8.
The concentric neutral conductor shall consist of solid round bare copper wires, helically-applied
and equally-spaced over and in contact with the insulation shield.
The jacket shall be black, extruded, insulating, linear low density polyethylene or cross-linked
polyethylene (LLDPE or XLPE). The jacket shall encapsulate (fill the spaces between) the concentric
neutral wires or flat straps and be in contact with, yet strip freely from the insulation shield.
Environmental Requirements:
Jacket will comply with EPA 40CFR, Part 261 for a leachable lead content of less that 5mg/L using
the Toxicity Characteristic Leaching Procedure (TCLP).
The jacket shall contain three (3) longitudinally extruded red stripes, approximately 1/4 inch wide,
and equally-spaced around the circumference of the cable in accordance with ICEA S-94-649.
The cable will be sequentially marked throughout its length in two foot increments on the outer
surface of the cable jacket. Jacket printing will be in accordance with the minimum identification
requirements of ICEA-S-94-649.
Each reel shall consist of one continuous run of cable (no splices allowed).
MV cables shall be suitable for direct burial at the depth specified in Subsection 4.5.11, or deeper.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 820 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-6
Packaging:
Each reel shall be covered with Class 2 material to detect damage to the cable during transit,
storage and handling.
Each cable end shall be suitably sealed to prevent entrance of moisture and contaminants. Ends of
cable shall be secured such that they remain inside the reel flange to prevent damage. Inside ends of
cable shall be secured such that they do not back out while winding/unwinding cable onto/from
the reel.
The reels will be shipped upright on the flanges and securely blocked in position so they will not
shift during transit. Reels will be lifted only with a suitable center shaft and sling with a spreader
bar to prevent damage to the reels and cable
Reels shall be marked to show beginning and ending sequential footage, in addition to the
requirements of AEIC CS8.
A durable label will be securely attached to each reel of cable. The label will indicate:
The Purchaser's name and address.
Purchase order number.
Cable description.
Reel number.
Feet of cable on reel.
Tare and gross weight of the reel.
Beginning and ending sequential footage numbers.
Documentation of UL cable approval.
4.5 INSTALLATION
The Contractor shall perform all installation work of the MV cables in accordance with Prudent
Wind Industry Practices.
4.5.1 General Installation Requirements
The Contractor shall optimize cable usage to minimize cable waste and the number of cable splice
boxes. If at all possible, splice boxes shall be located adjacent to roads or road rights-of-way.
All cable shall be installed direct burial in a prepared trench. The ground wire shall be installed
throughout and parallel with the power cable in compliance with the turbine manufacturer
specifications. The fiber-optic cable in innerduct shall also be installed in the same trench as the MV
power cables where possible. Contractor shall install fiber-optic cable in accordance with
Subsection 4.5.11. The configuration of the cables, ground wire and fiber-optic conduit shall be
submitted to Owner for review and approval.
All construction shall be done in accordance with the collection system location and routing plans,
specification, construction drawings and details, and applicable industry standards.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 821 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-7
4.5.2 Cable Routing and Terminal Points
The Contractor shall determine, and the Owner shall approve, the exact cable routing. The
collection system design shall be optimized by the Contractor. When practical, the cable trench shall
be at a depth to accommodate the agricultural land use to the maximum extent practicable. The
cable trench shall be routed between terminating equipment and alongside WTG strings; the
preferred route is opposite WTG tower doors. As much as reasonably possible, cables shall be run
next to access roads to avoid damaging extra drain tiles. The routing of cables shall be in
compliance with county and local township ordinances. Cable shall not be routed through
compacted fill areas or crane pads located around WTG towers except to terminate at an individual
WTG pad mount step-up transformer. The Contractor shall repair any ground wires,
communication circuits or other utilities damaged by the Contractor during trenching or other
excavation.
No more than one cable shall be installed in a road right-of-way ditch at one time (i.e., installing
parallel cables in one ditch is not allowed). Contractor shall coordinate with the county engineer to
ensure that roadside ditches are cleaned out prior to installing cables.
Any cables installed under a slope shall maintain a minimum distance of 4 feet to air in all
directions.
Paralleled feeder cables shall be separated by a minimum of 10-feet to avoid reduction in cable
current rating due to thermal conduction of the soil.
The Contractor shall terminate the cables at the dead front MV 2-way, 3-way, and 4-way junction
boxes, pad mount step-up transformers, and Project Collector Substation as indicated on the
drawings. All junction boxes and pad mounted transformers shall be furnished with a 3-phase set of
load-break reducing tap plugs to permit easy installation of grounding elbows for maintenance
activities. MV cable terminated at the pad mount step-up transformers shall be supported to
reduce stress on the transformer bushings. The Contractor shall leave sufficient cable slack to allow
installation of elbows and termination of the cable to the appropriate junction box and/or step-up
transformer terminal and permit ready disconnection of the elbows and mounting on the parking
stands. Where feasible, a minimum of 18 inch excess slack shall be provided to allow re-termination
in the event of failure. Cables shall be routed through appropriately sized PVC (polyvinyl chloride)
chase nipples or conduit, at a depth of approximately 36-inches below grade. The excess slack at the
WTG pad mount step-up transformers shall be in the form of a maintenance loop as indicated on
the drawings.
The Contractor shall route the trench ground cables into each junction box and pad mount step-up
transformer. Ground cables shall be routed through the PVC conduits or bushings that are used for
the MV cables. Cables shall be terminated with 2-hole compression lugs and connected to the
ground bus supplied with the junction boxes and pad mount step-up transformers. If no ground bus
is supplied by the junction box manufacturer, the Contractor shall supply a ground bus capable of
terminating all trench grounds, shield grounds, and pigtails to the grounding grid or ring.
Grounding connections at junction boxes and pad mount step-up transformers shall be bolted to
facilitate separation of grounds for continuity testing and ground mat testing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 822 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-8
The concentric cable shields of the medium voltage power conductors shall be grounded at the pad
mount transformers, junction boxes, and splice points. Concentric neutrals shall be grounded
additionally as found necessary by the Engineer of Record. The concentric shields are to be
grounded by bonding them to the trench grounding conductor and/or to a grounding rod installed
at each location.
The Contractor shall furnish and install stress cone terminations on the MV cable at each of the
substation termination structures. Terminations shall be 3M Model 7666-S-8-19-AL-3P-BT or
approved equivalent.
4.5.3 Handling of Cable
Cable shall be handled carefully at all times to avoid damage and shall not be dragged across the
ground, fences, or sharp projections. Care shall be exercised to avoid excessive bending of the cable.
The ends of the cable shall be sealed at all times against moisture with suitable end caps. Where it is
necessary to cut the cable, the ends shall be terminated or re-sealed immediately after the cutting
operation. Minimum bending radius of primary cable is 12 times the overall diameter of the cable
measured from the inside of the bend. Also, the inside of conduits shall be adequately cleaned prior
to pulling cables. Cable damaged by Contractor mishandling shall be replaced by the Contractor at
Contractor’s expense.
4.5.4 Trenching
4.5.4.1 General
The Contractor shall perform all trenching required to install the power, communication, and
grounding cables as indicated on the drawings. Details concerning depth, backfill and arrangements
shall be indicated on the construction drawings and/or as specified in these technical
specifications. It is assumed that as the Project progresses, the Contractor may need to alter the
cable routing to avoid obstructions, rock beds or other unforeseen obstacles. The Contractor shall
repair any drain tiles that are damaged during trenching or other. Contractor shall prepare as-built
drawings for construction record.
Any deviations from the construction trench drawings described below (and in general) need to be
approved by the Owner and validated with additional ampacity.
The minimum allowable burial depth for MV cables shall be the minimum depth specified in
Subsection 4.5.11or below frost depth, whichever is greater.
4.5.4.2 Crossings
In many cases, the cables will cross roads, wetlands, pipelines, buried utilities, easements, and other
feeder cables. All crossings shall be specified on the construction-approved cable layout drawings.
However, if additional restricted crossings are encountered, the Contractor shall secure any
permits required for the crossing. For crossings involving horizontal directional bores, only one set
of feeder cables shall be allowed per bore tube.
4.5.4.3 Difficult Digging
If rock or other difficult digging is involved, the Contractor shall determine nature and extent of the
difficulty, and the Contractor will determine whether rerouting, rock trenching, or other changes
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 823 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-9
are necessary. Loose soil or crumbling rock will not be considered as “difficult digging.” The trench
widths as specified on design drawings may be increased if necessary to obtain required depths in
loose soils.
4.5.4.4 Trench Width and Depth
All excavations shall be measured from the final official grades and/or benchmarks. Minimum
excavation depths and widths shall be specified in the construction drawings and/or as specified in
these technical specifications. Excavation shall be made to provide the ultimate minimum cover
specified in the trench detail drawings. Trench bottoms shall be level, flat and without surface
irregularities, and shall be clear of rock and debris.
4.5.4.5 Cable Installation in Trench
The MV power cable, grounding cable, and fiber-optic cable shall be placed in the trench as soon
after trenching as feasible. Wherever possible the power cable, grounding cable, and fiber-optic
cable shall be played out from a reel mounted on a moving vehicle or trailer. The reels shall be
supported so that they can turn easily without undue strain on the cables. The power cable,
grounding cable, and fiber-optic cable placement shall be performed under constant supervision to
be certain that no damage to the cables occurs.
4.5.4.6 Cable Visual Inspection
The power cable and fiber-optic cable shall be inspected carefully as it is removed from the reel in
the laying operation to be certain that it is free from visible defects. The Owner shall decide upon
corrective action when defects are discovered.
4.5.4.7 Power Cable Configuration
The MV power cable shall be laid in a trefoil configuration. Contractor shall prove or validate that
their trenching method provides consistent placement without the use of cable ties or a spiral
binder. Where Contractor is unable to do so, the cables shall be secured with cable ties, or be bound
with a spiral binder as necessary to maintain trefoil configuration. The Contractor shall obtain
approval by the Owner if a binding installation method other than cable ties is utilized.
If cable ties are used, proper tie-wrap tools shall be used to prevent over-tightening of the cable tie.
4.5.4.8 Erosion Control
In the case of trenching on slopes, erosion control measures shall be implemented.
4.5.4.9 Blasting
Blasting is not allowed under any circumstances.
4.5.5 County, Private Road, and County Drain Crossings (Where Applicable)
All county and private road crossings shall be completed in conformance with the regulations set
forth by the local agency having jurisdiction. All road crossings are subject to permit requirements.
The horizontal directional boring (HDB) minimum depth will extend for the full length of the bore
within road right-of-way and/or easement.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 824 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-10
4.5.5.1 Paved Road Power Cable Crossings
Where MV collection feeders cross under paved roads, these cables shall be installed in conduit
installed by HDB under the roadway. A ground wire shall be installed with each feeder and routed
through a separate conduit if required. Contractor shall verify all horizontal directional bore depths
prior to installation. OSHA-approved warning tape shall be installed as detailed in Subsection
4.5.11. The Contractor shall obtain all necessary permits before commencing work.
The Contractor shall prepare drawings or sketched details of the cable crossing as part of the
permit application. The Contractor shall be responsible for applying and securing any and all
permits and permit payments and/or application fees.
Contractor shall obtain Owner approval for boring plan before the work for the bore commences.
4.5.5.2 Other Road Crossings (Where Applicable)
Cable and conduit may cross under other paved, gravel, or dirt roads in other locations. Contractor
shall verify all granular road crossing depths prior to installation. OSHA-approved warning tape
shall be installed as detailed in Subsection 4.5.11. Disturbed portions of the roadway shall be
restored to original condition. The backfill shall be made in 6 inch lifts mechanically tamped and
packed, and the last 12 inches of the backfill shall be of stable 3/4 inch minus crushed rock or
gravel, or as required by the applicable permits. Care shall be taken not to damage cable during
compaction of gravel. The Contractor shall obtain any and all permits, for each county road
crossing, before commencing work. The Contractor shall prepare drawings or sketched details of
the cable crossing as part of permit application. The Contractor shall be responsible for all permit
payments and/or application fees.
4.5.6 Streams and Wetland Crossings
If the Contractor must cross or impact intermittent or permanent streams or other wetland
features, the Contractor shall follow all procedures or restrictions made by federal, state, county,
and township agencies that regulate streams and wetlands. Most crossings will require HDB. The
Contractor shall verify with the Owner which wetland/stream crossings are allowed to be trenched
or require HDB.
Restrictions may apply based on local ordinances.
4.5.6.1 Work Window
If intermittent streams are flowing at the time the Project commences, work in and around
intermittent streams may be restricted until surface waters are no longer flowing.
4.5.6.2 Erosion Control
In the case of stream and wetland crossings, erosion control measures shall be implemented in
accordance with Section 2.0.
4.5.6.3 Restoration
Where trenches cross intermittent streams, the topsoil from the trench shall be temporarily
stockpiled on-site. After cables are installed in the trench, the trench shall be filled to pre-
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 825 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-11
construction conditions with the stockpiled top soil and reseeded with native grasses if the crossing
is not tilled for farming.
4.5.6.4 Horizontal Directional Boring
In most cases, restriction by federal, state, and/or county agencies may require that the cables be
installed by HDB to prevent disturbing permanent streams. The Contractor shall follow all
restrictions for crossing or drilling under any permanent streams.
The specific areas utilizing HDB shall be determined by the local authority. The minimum
boundaries for HDB shall be the crossing right of way or otherwise defined by jurisdictional
agencies.
4.5.7 Easement Crossings (Where Applicable)
The collection system cables and conduits may cross existing power, communication, and gas line
easements. All existing lines shall be located and exposed by hand. The Contractor shall contact the
owners of existing utilities and obtain approval and any required permits. The Contractor shall take
care in making cable crossings to avoid damage to underground utilities.
When crossing any heat-producing utilities, Contractor shall obtain Owner approval for crossing
plan.
4.5.8 Fenced and Irrigation Pipeline Crossings (Where Applicable)
The Contractor shall take reasonable care in locating and identifying crossed facilities such as
fences, drain tiles, domestic water lines, and irrigation pipeline. The Contractor shall notify
landowner, take reasonable care in crossing landowner’s or occupant’s facilities, and shall be
responsible for damages and repairs to all facilities. The Contractor shall return crossed surfaces to
“as found” conditions.
4.5.9 Archeological and Sensitive Animal Species Sites
The Contractor shall avoid all cultural resources, sensitive or protected species habitat to be
preserved, and buffer or setback areas to be preserved. When construction activities approach
these avoidance areas, setback and buffer boundaries shall be located and clearly marked. The
Contractor shall be responsible for ensuring that the areas within the marked boundaries are not
disturbed by any of the construction activities.
4.5.10 Feeder Cable Crossings
Feeder cable crossings are not allowed unless approved by Owner. Any feeder cable crossings shall
be identified by GPS (Global Positioning System) coordinates on the as-built drawings and by
marking tape and crossing locator balls.
4.5.11 Backfill with Select Native Material
4.5.11.1 General
The bedding and padding backfill material for the trench shall be excavated free of rocks (no rocks
larger than what would pass through a Number 4 screen) and free of wood, roots, vegetable matter,
or other deleterious material. Four to six inches of bedding material shall be placed into the trench
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 826 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-12
before the MV power cables are placed in the trench. The cable, trench ground, and fiber innerduct,
when laid on the bedding material, shall be at least 48 inches below the finished grade to top of
cable.
Twelve to 18 inches of padding shall cover the cables and be compacted in lifts with maximum
uncompacted thickness of 8 inches unless otherwise approved by the Owner. An OSHA-approved
warning tape (Red tracer warning tape marked “DANGER – BURIED HIGH VOLTAGE CABLE”) shall
be laid on the compacted level at least 24 inches below finished grade. The remaining 24 inches of
the trench shall then be backfilled over the warning tape. Final backfill material shall be compacted
to eliminate voids with additional backfill added to allow for settling. Topsoil shall be managed in
accordance with landowner agreements.
All backfill material shall be compacted to no less than 85 percent of maximum dry density per
ASTM D698 or as required by design. Compaction shall be by proven methodology and shall be
approved by the Owner. Test reports of backfill from previous wind projects using the same
methodology to be used in this Project may be submitted to prove methodology. Field testing of
trenches shall be conducted using Owner-approved test equipment to prove methodology. Test
reports of trench compaction shall be submitted to the Owner and filed in the job books. Testing of
trench compaction shall be performed on each lift at a minimum frequency of 1 test per 500 feet of
trench unless otherwise approved by the Owner.
Any nonpaved road crossings shall be compacted in accordance with Section 2.0.
4.5.11.2 Soil Thermal Resistivity Analysis
Soil Thermal Resistivity Analysis shall be performed as a part of the Geotechnical Investigation.
4.5.12 Cable and Trench Markers
Utility markers shall be placed as a minimum on each side of roadway pipeline, telephone, and
communication easement crossings. For continuous trench in an easement greater than 1,000 feet,
a marker shall be placed every 1,000 feet. Markers shall be installed as shown on construction
detail drawings.
4.5.13 Conduits
MV cables shall be installed in conduit at transformers and junction boxes and pulled in accordance
with cable supplier’s recommended pulling and installation practices. All exposed ends of conduits
shall be plugged during construction until cables are installed, sharp projections that might damage
cable shall be removed, and the conduit shall be extended beyond the finished base by 6 inches. The
conduits shall be sealed to prevent rodent entry. Contractor shall also clean and router the end of
conduits and install bell ends.
4.6 GROUNDING
4.6.1 Trenches
An appropriate grounding conductor procured by Contractor shall be installed in all trenches that
contain MV power cables. The cable size shall be a minimum of 2/0 AWG bare copper or
equivalently sized copper-clad steel. However, Contractor is responsible for sizing the ground wire
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 827 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-13
based on ampacity, grounding studies, applicable codes and standards, and mechanical strength
considerations. The Contractor shall consider the mechanical strength of the grounding conductor
throughout the life to the project to ensure protection against handling during installation, minor
digging operations, and corrosion.
4.6.2 Junction Boxes
For the MV power cables terminating in 4-way, 3-way, or 2-way junction and splice boxes, all trench
ground cables shall be brought into the junction and splice boxes through the MV cable conduits.
Each trench ground shall be terminated with a compression type, 2-hole lug and connected to a
common ground bus. Each trench ground cable shall be labelled with the corresponding power
cable number to facilitate identification, disconnection, and testing if required. If a ground bus is not
supplied with the junction box by the material supplier, the Contractor shall supply a ground bus
large enough to accommodate terminating all trench ground cables, grounding ring cable and cable
shields.
4.6.3 Pad Mount Step-Up Transformers
For the MV power cables terminating at the turbine pad mount step-up transformers, all trench
ground cables shall be brought up into the high voltage terminal compartment through the MV
cable conduits, terminated with a compression type 2-hole lug, and connected to the transformer
tank ground pad. Each trench ground cable shall be labelled with the corresponding power cable
number to facilitate identification, disconnection, and testing if required.
MV cables shall maintain minimum depth requirements until they enter the transformer and cable
box pad described in Section 3.0.
4.6.4 Substation Riser
The neutral at the ends of the MV cables at the substations shall be bonded to ground.
4.7 TESTING
4.7.1 Factory Testing
Factory testing shall be completed in accordance with ICEA S-94-649 and shall include the “partial
discharge test.” A qualification test report shall also be required in accordance with ICEA S-94-649.
Certified test data for all required tests shall be kept on file for a minimum of 5 years and shall be
submitted to the Owner upon request. Each reel shipped shall be traceable to certified test data. A
certificate of compliance shall be supplied to the Owner for all cables upon request. The certificate
of compliance shall show that the cable has passed all required tests and include the following
information:
Manufacturer name.
Complete description of cable.
Reel numbers for each lot of cable.
Length of cable on each reel.
Copy of packing list.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 828 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-14
Purchase order number.
Specification number and date.
Documentation of UL compliance.
Process control charts on the thicknesses of the conductor shield, insulation, insulation shield, and
jacket from throughout the cable extrusion run shall be included with the certificate of compliance.
These charts should clearly show the limits used for the run.
Packaging, reel marking, and transportation shall be in accordance with AEIC CS8, NEMA WC26,
and the following requirements.
4.7.2 Cable Inspection
Contractor shall inspect cables at the time of delivery and during installation.
4.7.3 Installation Inspections
Contractor shall inspect exposed cable sections for physical damage.
Contractor shall also inspect shield grounding, cable supports and terminations for proper
installation.
4.7.4 Conductor Continuity
Contractor shall perform tests to verify conductor continuity.
4.7.5 Insulation Resistance Testing
The concentric shields of all MV cables shall be tested to ground with a 1000/500 VDC megohmeter
at 1000 VDC to check the integrity of the outer jacket.
The Contractor shall record megohm values over a 10 minute period with recordings every minute.
Megohmeter cable tests shall be per “International Electrical Testing Association Acceptance
Testing Specifications,” NETA ATS-2013.
4.7.6 Cable Testing – Partial Discharge Method / VLF Hi-Pot Method
Each of the MV collection system cables shall be tested by the partial discharge (PD) method in
accordance with IEEE 400.3 and ICEA S-94-649. Each completed collection system feeder shall be
tested by the “VLF Hi-Pot” method in accordance with IEEE 400.2.
In all cases, the tested sections shall include all cable sizes and shall test the cable insulation, the
terminations and the splices (if any) on the cable sections.
The PD method test voltage shall be a minimum 2.0 times rated voltage (2.0Uo), at 60 Hz, with at
least 5pC sensitivity and shall include a documented sensitivity assessment performed in
accordance with IEEE 400.3 on every cable system to assure the test results are comparable with
IEEE and manufacturer levels as specified in the table below. The design of the collection system
shall be such that the cables can be sectionalized into lengths of 8,500 feet, maximum, and 1/6th or
larger neutral to support PD testing as performed by IMCORP or other service provider who has
been previously qualified by the Owner. Cable lengths shall be coordinated with normal splice
points and above ground junction boxes with separable connectors used to minimize cable splicing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 829 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-15
Table 4-1 Table of Acceptable PD Threshold Levels
Standard
IEEE 48 Terminations
IEEE 404 Joints
IEEE 386 Separable Connectors No
ICEA S-97-683 Metallic Shield MV Cable
ICEA S-94-683 Concentric Wire MV Cable
4.8 NUMBERING AND LABELING
The Contractor shall provide material and labor for installation of cable numbers and labels.
4.8.1 MV Cables Numbering
The MV power cables shall be numbered at each of the following termination points: Turbine pad
mount step-up transformers and MV 4-way, 3-way, and 2-way cable junction and splice boxes.
Power cables and equipment shall be labeled at each termination point with identification numbers
identified by the owner. Each power cable will also be identified for phasing with the following
colored tape: red for Phase A, white for Phase B, and blue for Phase C. The phasing will be the same
throughout the Project.
4.8.2 MV Cable Labeling at 4-Way, 3-Way, and 2-Way Junction Boxes; Splice Boxes; and
Switchgear
Each individual MV cable inside the termination compartment shall have a cable number label
installed. These labels shall consist of reflective numbers and letters to correspond to the feeder
number to be provided by the Owner. Both ends of these E-Z Tag holders shall be secured to each
power cable with nylon cable ties with 0.2 percent carbon filled, locking, black, and weather
resistant such as “Pan-Ty” or “Ty-Rap”. Cable ties shall not be tightened excessively to cause
deformation of the tag holder. The labels shall be visible when the termination is accessed from a
normal access point. To and from information shall be included on cable labels. Phase identification
shall be as follows: red for Phase A, white for Phase B, and blue for Phase C.
4.8.3 MV Cable Labeling at Pad Mount Step-Up Transformers
Each MV cable inside the high voltage compartment of the pad mount step-up transformers shall
have a cable number label installed. These labels shall consist of reflective numbers and letters
installed on the panels to correspond to the feeder number to be provided by the Owner. These
aluminum utility panels shall be secured to the cables with nylon cable ties with 0.2% carbon filled,
locking, black, and weather resistant such as “Pan-Ty” or “Ty-Rap”. Phase identification for the pad
mount step-up transformers is as follows: H1A and H1B is Phase A (red tape), H2A and H2B is
Phase B (white tape), and H3A and H3B is Phase C (blue tape).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 830 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-16
4.8.4 MV Cable Labeling at Risers
MV cable labeling at the substation risers shall be in accordance with Section 5.0. Phase
identification at the risers shall be as follows: Phase A is red tape, Phase B is white tape, and Phase C
is blue tape.
4.9 PAD MOUNT STEP-UP TRANSFORMERS
4.9.1 General
This section describes the equipment, installation, testing, labeling and numbering of the pad
mount step-up transformers. This equipment is to be specified and installed by Contractor to meet
all requirements of the Turbine Supplier and these specifications. Contractor will procure based on
engineering specification provided by Contractor and approved by Owner.
Contractor shall inspect all parts upon receipt to ensure they meet the bill of material, drawings,
and equipment specifications. Contractor shall provide receipt inspection checklists and store
equipment with all accessories in a safe location.
4.9.2 Equipment Requirements
The transformers shall have feed-through connection capability on the MV side. That is, there shall
be two sets of high side bushings to allow transformers to be stringed together. They shall also
include external MV switch operator handle and external oil sampling valve, both within lockable
covers.
4.9.2.1 Transformer Specifications
The pad mount step-up transformers will have the following specifications:
Oil-filled
o External oil-sampling and nitrogen filling if necessary
3-Phase, 60 Hz
Contractor shall size transformer kVA rating to accommodate the maximum withstand fault
current of the WTG converter
High side: 34.5 kV delta
Low side: 690 V wye
o Low side terminal: NEMA standard 10-hole spade type, including supports, tinned, in
accordance with the latest edition of ANSI/IEEE standard C57.12.26.
BIL: standard value at 690 Volts; 200 kV at 34.5 kV (higher than minimum 150 kV for the
project)
Impedance: 5.75 +/- 7.5%
Temperature rise: 65°C
Taps: (2) 2.5% steps above and below (for a total of five taps)
Instrumentation enclosure shall be externally mounted
Dead front (high side)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 831 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-17
600 A bushing arrangement (high side)
Sectionalizing oil-immersed load break 2 position LBOR switch:
o Rated 300 amp continuous.
o Gang-operated rotary, permanently attached, hook stick operable and clearly marked
for circuit identification.
Shielded core
Fusing shall be sized to ensure less than a Category 4 arc flash blast at appropriate working
distance on the low voltage compartment.
Contractor to include secondary switch on low side
Transformer shall be painted olive green (Munsell #7GY3.29/1.5)
Contractor to quote option for ice shield
Contractor shall furnish and install ground ball studs on the LV bushing spades
Contractor shall furnish any equipment safety grounds or other equipment required to
support Turbine Supplier commissioning activities.
Prior to manufacturing, a design review shall be conducted between the transformer
manufacturer and the Owner. Topics to be included but not limited to are:
o The addition of a static shield placed between the coil and the core to reduce any partial
discharge activity in the core.
o Location of the load break oil switch after the fuses versus in front of the fuses.
o Additional sudden pressure relief capability above standard.
o Partial discharge testing as described by the specification.
Tank shall have an automatic pressure relief device or valve.
Tank pressure under rated conditions for sealed transformers shall not exceed two
atmospheres (203 kPa) absolute pressure unless requirements of applicable sections of the
ASME Boiler and Pressure Vessel Code (BPVC) are met.
Unit protection:
o Provide unit protection with a partial-range current limiting fuse on each primary phase
(under oil, factory replaceable only).
Electrical connections inside the LV compartment shall be designed not to exceed 90°C, with
an assumed 40°C ambient temperature.
4.9.2.2 Pad Mount Step-Up Transformer MV Terminations
The Contractor shall furnish and install 600 amp dead break elbows as required for all turbine pad
mount step-up transformer MV terminations. The elbow connectors shall be 600 A, three-phase
rated (21.1/36.6 kV) dead break and shall meet the full requirements of ANSI/IEEE Standard 386.
4.10 INSTALLATION
The Contractor shall perform all installation of the pad mount step-up transformers in accordance
with Prudent Wind Industry Practices.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 832 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-18
4.10.1 Transformer and Cable Box Pad
This subsection covers the minimum requirements for the furnishing of both a telescoping box pad
intended for supporting a generator step up transformer and a box pad intended for supporting a
grounding transformer which will be used in a 3-phase 35 kV wind project. The Contractor shall
install these box pads per these specifications. Contractor shall install the transformer and box pad
on lean concrete to provide a level working surface.
4.10.1.1 Quality Assurance
A top loading test will be performed to mimic the weight displacement of the appropriate
transformer that will be used for the specified box pad. This test is performed to verify a robust
design that will not fail in the field.
4.10.1.2 All Box Pad Details
Box pads shall have appropriate factors of safety. Design using allowable stress design shall
have a factor of safety of 2.0. Designs utilizing strength design shall use load factors and
strength reduction factors in accordance with the International Building Code.
All box pad designs shall account for appropriate side wall loading from the soil and water
table as applicable, as well as the weight of the transformer including the ice shield.
The telescoping portion will extend 24 inches on the low voltage side with a width of 36
inches. The telescoping portion will extend on the same side that has the provisions for the
cable entering the transformer. (For telescoping box pads only.)
Each box pad request will be accompanied with a cut sheet of the transformer design to aid
the box pad designer. This will be included with the request for proposal.
The pad will have a rigid, flat, and stable top surface.
The pad will not warp, rust, or be UV degradable.
The finished pad will not sustain combustion.
The pad will not be affected by asphalt, road salts, fertilizers, transformer oils and heating,
other common chemicals, weather or other service conditions that it might be exposed to.
The pad will be designed and constructed so that it and any hardware used will not trap or
hold water and will be able to withstand repeated seasonal freeze/thaw cycles.
The pad will be capable, with equipment installed, of withstanding temperature variations
of -40° C to +65 ° C without cracking, splitting, or deforming.
Tamper resistant construction.
Box pads shall be protected from damage during shipping. Box pads will be shipped on a
suitable pallet. When stacking box pads, on a pallet, appropriate provisions for a safe,
damage free arrival will be taken.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 833 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-19
4.10.1.3 Pad Mount Step-up Transformer and Grounding Transformer Box Pads Details
Shall be of concrete construction (no fiberglass allowed).
Where equipment installation is not immediate covers shall be installed to prevent damage,
unwanted litter, and accidental falling.
4.10.2 Transformer Mounting
The Contractor shall install the pad mount step-up transformers on the box pads and install the
high and low voltage cable connections. Transformers shall be properly anchored to prevent
movement during short-circuits and seismic events. The Contractor shall furnish and install the 600
A dead break elbows as required for the pad mount step-up transformer MV terminations.
4.10.3 Low Voltage (2000 V) Phase Conductors and Terminations
See Subsection 4.13.4.
4.10.4 Oil Containment Design
The Contractor shall install an oil containment fabric surrounding the pad-mounted transformers.
The fabric shall be laid underneath the finished gravel surrounding the transformer, and the area
covered shall be from the area where the tank begins to a distance 2 feet beyond the radiators or
cooling fins. The material shall be a PIG® MAT 1205 or similar product that absorbs oil and allows
water to pass through.
4.11 TESTING
4.11.1 Factory Testing
Factory tests will be performed for the transformer in accordance with ANSI/IEEE C57.12.90:
1. Resistance measurements.
2. Polarity and phase relation.
3. Ratio.
4. No-load losses and excitation current.
5. Load losses and impedance voltage.
6. Dielectric tests.
a. Impulse test – all units
7. DGA analysis.
a. Start of the test.
b. Start of heat run.
c. Completion of heat run.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 834 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-20
d. Completion of dielectric.
e. Completion of all tests.
8. Partial discharge test recording, inception voltage, and drop-out voltage levels using
the procedures in IEEE C57.113, C57.12.90, and with voltages as specified in
C57.12.00 for 34.5 kV equipment.
a. Partial discharge test acceptable limit shall be 300 pC, notwithstanding a
less stringent requirement by IEEE.
9. A heat run test shall be completed on the first unit of each manufacturing batch.
10. This transformer shall be treated as a “Class I” power transformer.
4.11.2 Testing by Contractor
All pad mount step-up transformers shall be inspected for physical damage by Contractor upon
delivery. After transporting a transformer to its final location, Contractor shall complete the
following tests and interpret the results:
Transformer turns ratio test.
Winding resistance test.
Insulation resistance test.
Dissolved gas analysis.
Analysis of the following chemical properties of the oil:
o Dielectric strength.
o Interfacial tension.
o Power factor at 25° C.
o Neutralization number.
o Water content.
o Specific gravity.
o Dissolved gas analysis .
o PCB (polychlorinated biphenyl).
Final visual inspection of all components, gauges, and controls.
All testing and interpretation of results shall be performed by qualified personnel. Contractor shall
record and provide results for the above tests. Tests results shall be traceable to the serial number
of the corresponding transformer. If a transformer is moved after the above tests have been
completed, Contractor shall repeat these tests.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 835 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-21
4.12 NUMBERING AND LABELING
4.12.1 General
The Contractor shall provide identification nameplates. Nameplates shall be approved by the
Owner. Edges shall be chamfered. Nameplates shall be mounted to the equipment by using one
adhesive and stainless steel screws. These screws can be either the self-drilling or drilled and
tapped type. Pop rivets are not acceptable.
4.12.2 Pad Mount Step-Up Transformer
Each of the pad mount step-up transformers shall have an engraved phenolic label with reflective
numbering system identifying the transformer. These labels shall be installed on the MV
compartment door and shall be approved by the Owner.
Pad mount step-up transformers shall be identified with Owner-provided identification numbers.
4.13 LOW VOLTAGE (LV) CABLE
4.13.1 General
This section describes the requirements, installation, grounding, testing, labeling, and numbering of
the LV cables at the WTGs. The Contractor shall specify and procure LV cables. Contractor shall
inspect all parts upon receipt to ensure they meet the bill of material, drawings, and equipment
specifications. Contractor shall provide receipt inspection checklists and store equipment with all
accessories in a safe location. Cable shall be of flexible type similar to DLO (diesel locomotive cable)
or equivalent.
4.13.2 Equipment Requirements
The Contractor shall procure 1/C 2000V 777 kcmil DLO copper cables, rated at least 90° C, and
suitable for wet and dry locations in conduit or underground duct systems. The cable type, size, and
quantities shall be validated through ampacity analysis and meet minimum turbine supplier
requirements. Insulation shall meet or exceed all requirements of applicable ICEA, NEMA, and UL
Standards. The conductor shall be uncoated copper material in accordance with ASTM B-8. The
cables shall be factory tested to ensure compliance with the requirements of the referenced codes
and standards. Contractor shall design and coordinate cable sizes, raceway sizes and cable lug
terminations to the WTG equipment for a complete installation.
Other requirements:
Contractor shall ensure that the conduits for the LV cables receive approval from the
foundation design engineer.
The cable will be suitable for an installation temperature of -18° C.
The conductor will be flexible, stranded, uncoated copper conductor in accordance with
ASTM B-33 and ASTM B-172.
Insulation will be ethylene propylene rubber (EPR).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 836 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-22
Jacket and separator:
o The copper conductor, insulated with EPR will be cabled together with a separator and
jacketed overall with chlorinated polyethylene (CPE). The separator will be a paper or
polyester tape.
4.13.3 Shipping Requirements
A durable label will be securely attached to each reel of cable. The label will indicate:
The Purchaser's name and address.
Purchase order number.
Cable description.
Reel number.
Feet of cable on reel.
Tare and gross weight of the reel.
Beginning and ending sequential footage numbers.
Recognition of generic cable approval by a national recognized testing laboratory (such as
UL).
The final cutting lengths and put-ups must be confirmed with the Contractor prior to winding the
cable onto shipping reels.
Each cable end will be suitably sealed to prevent the entrance of moisture and contaminants.
The end of each cable will be secured to remain inside the reel flange to prevent damage.
The inside end of each cable will be secured to not back out while winding/unwinding cable
onto/from the reel.
The reels will be lagged or covered with a Class 2 material suitable to provide physical protection to
the cable during transit and during ordinary handling and storage.
The reels will be shipped upright on the flanges and securely blocked in position so they will not
shift during transit. Reels will be lifted only with a suitable center shaft and sling with a spreader
bar to prevent damage to the reels and cable.
4.13.4 Installation
Contractor shall install the LV cables between the terminals of each pad mount step-up transformer
and the WTG low voltage distribution panel (LVDP).
The Contractor shall terminate cables (phase and ground conductors) at the transformer bushings
or LV breaker terminals and at the turbine LVDP using Burndy compression lugs with NEMA two-
hole pads and all associated hardware to accommodate dissimilar metal connections (Al to Cu).
Compression lugs shall be installed with tooling specific to the lugs used. In general, any
connecting/terminating hardware not provided by the turbine supplier shall be provided by the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 837 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-23
Contractor. Contractor shall install cables in accordance with turbine supplier requirements. The
cables must be supported to reduce stress on the transformer bushings.
These cables shall be installed in conduit and pulled in accordance with cable supplier’s
recommended pulling and installation practices. All exposed ends of conduits shall be plugged
during construction, sharp projections that might damage cable shall be removed, and the conduit
at the transformer shall be extended beyond the finished base by 6 inches. The conduits shall be
sealed at the turbine tower end to prevent rodent entry.
4.13.5 Grounding
4.13.5.1 LV Grounding Cable to LVDP
The Contractor shall furnish and install grounding conductors specified by turbine supplier
between the pad mount step-up transformer’s LV neutral terminal and the turbine’s LVDP ground.
These grounding conductors shall meet applicable standards and be sized to withstand expected
short circuit currents.
4.13.6 Testing
4.13.6.1 Factory Testing
Testing will be done in accordance with the latest edition of ICEA S-94-649 to include the partial
discharge test.
1. The cable manufacturer will provide a qualification test report in accordance with ICEA S-94-
649.
2. Certified test data for all required tests will be kept on file for a minimum of 5 years and will be
submitted to Owner upon request. Each reel shipped will be traceable to certified test data.
3. A certificate of compliance will be supplied to the Owner for all cable within 30 days of each
shipment. The certificate of compliance will show that the cable has passed all required tests
and include the following information:
Manufacturer name.
Complete description of cable.
Reel numbers for each lot of cable.
Length of cable on each reel.
Purchase order number.
Specification number and date.
Copy of packing list.
4.13.6.2 Insulation Resistance Testing
The Contractor shall test all cables rated 2000 V.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 838 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-24
The Contractor shall record megohm values over a 10 minute period with recordings every minute.
Megohmeter cable tests shall be per International Electrical Testing Association Acceptance Testing
Specifications, NETA ATS-2013.
4.13.7 Numbering and Labeling
Contractor shall provide phase identification on each end of the LV cables. Phase color coding shall
be as follows: X1 is Phase A (brown tape), X2 is Phase B (orange tape), and X3 is Phase C (yellow
tape).
4.14 JUNCTION BOXES
4.14.1 General
Termination of the underground feeders in the Project Collector Substation is by the Contractor.
4.14.2 Equipment Requirements
4.14.2.1 General
All equipment shall be designed and manufactured for the cable to be utilized and rated for outdoor
35kV use.
Dead-front, load-break, and/or dead-break elbows shall be supplied with test ports in addition to
directional fault indicators. These accessories shall be installed at intervals in accordance with
Subsection 4.15.2 of this document.
-
4.14.2.2 MV 3-Way and 4-Way Junction Boxes
The Contractor shall furnish and install 600 A dead-break elbows to terminate the single conductor
aluminum power cables with copper concentric neutrals at Contractor furnished and installed 4-
way and 3-way junction boxes. These elbow connectors shall be 600 A, dead-break with a phase to
ground rating of 21.1 kV. They shall meet the full requirements of ANSI/IEEE Standard 386. These
elbow connectors shall be BOL-T connector system type connectors approved by the owner.
4.14.2.3 MV 2-Way Junction Boxes
The Contractor shall ultimately determine the exact quantity of 2-way junction boxes used as splice
locations required to complete the work. The actual quantity shall vary based on as installed field
conditions.
The Contractor shall furnish and install 600 A dead-break elbows as required. The elbows shall
terminate the single conductor aluminum power cable with copper concentric neutrals when
required, at Contractor furnished and installed splice junction boxes. These elbow connectors shall
be 600 A dead-break with a phase to ground rating of 21.1 kV. They shall meet the full
requirements of ANSI/IEEE Standard 386. Grounding requirements for the shields on each dead-
break elbow shall appear in the drawings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 839 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-25
4.14.3 Installation
4.14.3.1 Cable Splicing (Where Applicable)
Underground power cable splices are permitted where the cable run exceeds manufacturer’s reel
length. In no case may underground runs exceed two reel lengths or a maximum distance of 8,500
feet before cable is spliced in an above ground 2-way junction box. On home runs, only one
underground splice shall be allowed between junction boxes. In-line connections shall be 2-way,
600 A junctions or as specified. The Contractor shall determine quantity and location of junction
boxes based on cable reel lengths, roadways or easement crossing, etc. Junction boxes shall only be
placed near WTGs, access roads, and in road rights-of-way.
Contractor shall only use shear bolt type (no compression splices).
Where cables are to be spliced, an area of sufficient size must be excavated to provide
environmental controls as needed.
After cable is cut, a water-tight protective seal must be applied to exposed ends to prevent
dirt and moisture from entering cable.
A plastic tarp shall be placed under the cable and covering an area of at least 8-feet in
diameter measured from the splicing location.
A protective tent must be erected around the splicing location.
The protective tent shall be large enough to completely cover the tarped area under and
around the splice location.
The protective tent shall have adequate seals to allow no dust or precipitation to blow into
the splicing area.
If the temperature at the splicing location is below 40° F a heat source shall be located at the
splicing location to heat the protective tent to 45° F or more.
The splice shall be installed per manufacturer instructions and training. All personnel
installing splices shall complete manufacturer training for the specific splices to be installed.
Certification documentation for each person installing splices shall be made available to the
Owner upon request.
Personnel installing splices shall have completed training on installing the specific splices
within 6-months of installing the splice.
The Contractor is responsible for replacing terminations, cable or splices that do not pass
quality control testing or meet IEEE and IEC Standards as determined by Owner.
Each installed splice shall be documented/recorded with personnel’s name(s) that installed
the splice and photographed.
A splice locator ball shall be buried directly over every splice location. The splice locators
must be designed to be located using electronic equipment. The splice locator must be
approved by Owner.
GPS coordinates shall be recorded and documented at each splice location. The location
shall be marked on the as-built drawings with coordinates.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 840 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-26
4.14.3.2 Junction Box Pads
All junction and splice boxes shall be deep-set fiberglass boxes and be installed on a level crushed
rock pad at least 4 inches thick. The pad is intended to provide a solid level base for the box
extension.
Cable entry can be through sealed connectors instead of conduits for boxes buried 60 inches. The
bottom of the box must be below the frost line.
4.14.3.3 Junction Box Locations
All junction and splice boxes shall be located whenever possible near roads or turbine access areas
to minimize damage by road maintenance equipment. Under no circumstances shall an
aboveground junction or splice box be located in a cultivated field. All junction and splice boxes
shall have four concrete barrier posts located around the boxes to minimize damage. Posts shall be
set with concrete to provide additional impact resistance. All junction box locations shall be
reviewed by the Owner prior to construction.
4.14.4 Grounding
4.14.4.1 Junction Box Grounding
General
The grounding system for the MV junction and splice boxes is designed to achieve a maximum of
10.0 ohms resistance or other maximum resistance specified by the engineer of record. Four point
fall-of-potential measurements shall be made after installation. If ground resistance is found to
exceed the design resistance, then radial ground leads can be extended from the ground loop and
additional ground rods installed. Contractor is responsible for supplying and installing additional
materials as required.
Specific Requirements
The grounding system consists of a ground loop and ground rods. All ground loop wire to ground
loop wire, and ground rod to ground loop wire connections must be done using exothermic process
or using an Owner approved mechanical compression type connection only. The ground loop shall
consist of a minimum 2/0 AWG stranded copper ground conductor installed in a 4 inch wide, 3 foot
deep trench around each MV junction box. The trench shall be in undisturbed soil approximately 3
feet from the junction box base, under 4 inches of well compacted select native fill. No rocks larger
than what would pass through a Number 4 screen shall surround the ground conductor.
At least one 3/4 inch diameter, 10 foot long copper ground rod shall be driven near the ground loop
on opposite sides (minimum 10 foot between rods) and connected to the loop. Two 2/0 AWG
stranded copper pigtails from the ground loop shall be brought into the junction box and connected
to the ground bus.
The Contractor shall verify the adequacy of the above sizes, dimensions and quantities in a
grounding study.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 841 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-27
4.14.5 Testing
4.14.5.1 Junction Box Grounding Test
The Contractor shall use the four point fall of potential method per IEEE STD 81 for measuring and
testing the ground resistance of the junction boxes.
The grounding point shall be connected to any bare copper grounding conductor (e.g. grounding
point inside junction box) as the system reference point (E). The minimum distance from E to the
current electrode (CE) should be 5-6.5 times the diagonal distance of the grounding system being
measured. Resistance measurements shall be taken with the potential electrode (PE) at 1%, 10%,
20%, 30%, 40%, 50%, 60%, 61.8%, 70%, 80%, 90%, and 99% of the diagonal distance. The
Contractor shall compare the reading at point (E) to the theoretical value from the step and touch
analysis. The test shall be performed with all phase and ground connections lifted so that the
equipment being tested is isolated from the rest of the grounding system. Testing direction shall be
perpendicular to any parallel conductive path (i.e., trench, conduit, fence, overhead, or below-grade
lines) A sketch of the testing route shall be provided for each test. Contractor shall ensure that this
testing is done in accordance with Engineer of Record’s requirements and recommendations.
4.14.6 Numbering and Labeling
4.14.6.1 General
The Contractor shall provide identification nameplates approved by Owner. Edges shall be
chamfered. Nameplates shall be mounted to the equipment by using one adhesive and stainless
steel screws. These screws can be either the self-drilling or drilled and tapped type. Pop rivets are
not acceptable.
4.14.6.2 MV 4-Way, 3-Way, and 2-Way Cable Junction Boxes
Each of the 4-way, 3-way, and 2-way cable junction and splice boxes shall be labeled with an
Owner-approved reflective numbering system identifying the junction or splice box number. These
labels and an Owner-approved “Danger High Voltage” sign shall be installed on the side of the
enclosure that will be opened for access to the terminals inside.
Junction boxes shall be identified. For example, the J-Box on Feeder 5 furthest from the Project
Collector Substation shall be labelled “JB5-1”. Labeling is to be located on the access cover of the
junction or splice box and on the side facing the road access.
4.15 MISCELLANEOUS EQUIPMENT
4.15.1 General
The miscellaneous power equipment required for the collection system is described in this section.
4.15.2 Equipment Requirements
4.15.2.1 Fault Indicators
Contractor shall install directional fault indicators (DFIs) at all junction boxes and every third
turbine, to ensure that a single DFI does not monitor more than three cable segments. The DFIs
shall not use LEDs (light-emitting diode) and shall utilize a 24 hour reset time or voltage
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 842 of 1056
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IDAHO POWER CO.| Collection System 4-28
restoration. DFIs shall be rated to prevent false tripping (i.e., they shall only trip due to fault
current flowing from the grid). Final equipment selection is subject to Owner approval.
Contractor to supply DFIs required. Contractor shall install DFI remote displays external to
junction boxes and pad mount step-up transformers. DFI remote displays shall be mounted
sufficiently above grade to ensure visibility when snow is on the ground (at least 24-30 inches
above grade is preferred). If the external display needs to be installed in a junction box lid,
Contractor shall properly manage/organize wires to not interfere with maintenance operations.
4.15.2.2 Surge Arresters
The Contractor shall furnish and install, at a minimum, station class 30kV (24.4 kV MCOV) metal
oxide varistor surge arresters in pre-molded rubber elbows for cable terminations and
transformers. This voltage rating assumes a grounded wye on the 34.5 kV side of the main power
transformer winding at the Project Collector Substation. Contractor shall be responsible for final
sizing of the surge arresters. They shall be sized according to insulation coordination and
temporary overvoltage analyses. The arresters shall provide overvoltage system protection in an
insulated, fully shielded, submersible, dead front device. The arrester housing interface shall
conform to ANSI/IEEE Standard 386 with a maximum discharge voltage of 110 kV at 20 kA. The
Contractor shall install arresters at the last pad mount step-up transformer in each turbine string.
Grounding requirements for these arresters shall appear in the construction drawings. These surge
arresters shall be compatible with junction boxes and pad mount step-up transformers. They shall
also be removable with live line tools. Once surge arresters are removed, they shall accommodate
load-break ground adapters.
4.15.3 Installation
N/A
4.15.4 Grounding
N/A
4.15.5 Testing
N/A
4.15.6 Numbering and Labeling
Numbering and labeling of all equipment shall be per Owner requirements and preferences.
4.16 METEOROLOGICAL (MET) TOWER 120V CABLE
4.16.1 General
The Contractor shall size, furnish, and install direct burial cable from MET towers to the nearest
turbine pad mount step-up transformer.
4.16.2 Equipment Requirements
This cable shall provide single-phase power for the MET tower equipment. The cable shall be RHW
600 V, 90° C dry location/75° C wet location, suitable for installation in conduit, underground duct
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 843 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-29
systems, and direct buried. The insulation shall meet or exceed all requirements of applicable ICEA,
NEMA, and UL standards.
4.16.3 Installation
The Contractor shall install the MET tower fiber-optic cable in the same trench as the MET tower’s
power supply cable. This shall be done in accordance with Subsection 4.17.3. The MET tower fiber-
optic cable shall be integrated into the turbine supplier’s network.
4.16.4 Grounding
MET tower grounding is to be installed by Contractor.
4.16.5 Testing
Cable shall be tested in the factory to determine its compliance with the requirements of the
referenced codes and standards.
4.16.6 Numbering and Labeling
N/A
4.17 FIBER-OPTIC COMMUNICATION CABLE
4.17.1 General
The Contractor shall install and terminate the fiber-optic network in accordance with this
specification.
The Contractor shall install a fiber-optic network that shall connect individual turbines with the
Project Collector Substation control center. The design of the fiber-optic network will be per WTG
technical specifications and will be such that each feeder will create a complete fiber-optic logical
ring. The Contractor shall design the fiber-optic network so that turbine supplier can provide loop
and termination design. The fiber cable shall be direct buried cable in orange HDPE (high density
polyethylene) innerduct. All splicing shall be made at the turbines, Project Collector Substation
Building, and the splicing hand holes as specified on the drawings. All splices shall be spliced in a
separate location from the electrical conductor splices. Sufficient spare length shall be provided for
maintenance provisions. No running splices shall be made.
4.17.2 Equipment Requirements
Contractor is responsible for verifying the compatibility and acceptability of the Owner-preferred
items mentioned in this document.
4.17.2.1 Cable Specification
The Contractor shall furnish and install all fiber-optic cable required. Contractor shall verify the
fiber cables comply with turbine supplier requirements. Contractor is required to confirm fiber
cable lengths in the field before ordering the cable. The fiber-optic cable shall meet or exceed the
physical characteristics listed in the table below:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 844 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-30
Table 4-2 Required Fiber-Optic Cable Characteristics
Fiber-
Fiber quantity 12, 24, and/or 36 as required by final design
Fiber diameter 9/125 Microns
Maximum attenuation 0.4 @ 1300nm dB/km, 0.3 @ 1550nm dB/km
Minimum bandwidth N/A
Operating temperature range -40 to +70° C
Additional requirements:
o Dual window.
o Single jacket.
o All-dielectric loose tube cable.
o The cable components should be coated with super absorbent polymer (SAP) materials
impregnated within the core to prohibit the migration of water.
Fiber cable construction will be loose tube gel filled color-coding per
TIA/EIA 598B standards. The central strength member will contain no
metallic conductors. The overall strength member will be aramid fiber yarn
or fiberglass, the jacket will be black UV, and moisture resistant PE
(polyethylene) with sequential meter markings.
All fiber equipment (switches, converters, etc.) is operating at 1300nm,
except long-haul equipment which operates at 1550nm.
4.17.2.2 Cable Manufacturer Requirements
The cable manufacturer shall be responsible for all phases of manufacturing, packaging, and the
safe keeping of the fiber-optic cable while at its facility. Prior to shipping, the cable manufacturer
shall test each optical fiber to verify conformance to the specification herein and the optical glass
fiber manufacturer's specifications. Each of the optical fibers in each of the cable reels shall be
completely tested with an optical time domain reflectometer (OTDR) at optical wavelengths
specified on an end-to-end basis. A printed hard copy of the final test data completed prior to
shipment shall be attached in a waterproof envelope or pouch to each reel of cable provided.
4.17.2.3 Required Drawings and Data
All drawings and technical data required to be furnished by the Contractor shall be in English, and
all dimensions on the drawings shall be in feet and inches and all weight in pounds. The drawings
shall be complete and accurate in their content. Originals and all copies shall be legible.
The following table summarizes the drawings and data required under these specifications:

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 845 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-31
Table 4-3 Drawings and Data Schedule for Fiber-Optic Cable
me
Factory Test Results of Cable With Shipment Test Results
Pre-Installation Field Test Results of
Cable
14 Days After Receipt of Cable OTDR Charts and Disk
Post-Installation Field Test Results of
Cable
14 Days After Completion of Tests OTDR Charts and Disk
Certification of Splicing Personnel 14 Days Prior to Fiber Splicing Copy of Certification
4.17.2.4 Connectors
SC connectors will be used to connect to the fiber patch panels in the wind turbines and in the
substation.
4.17.2.5 Innerduct
Fiber shall be installed in orange HDPE 1.25 inch diameter innerduct with wall thickness of 0.151
inches or Owner-approved alternate. The manufacturer shall be Carlon or Owner-approved
equivalent.
4.17.2.6 Innerduct Accessories
All innerduct accessories will consist of the following components or Owner-approved equivalent
components from approved manufacturer:
Commscope - 1163600
Carlon terminating connector part number – TC125
Neptco MULETAPE part number – DT1250P
4.17.2.7 Hand Holes
The hand holes will be precast polymer concrete for underground construction. The hand hole will
consist of the following components or Owner-approved equivalent from an approved
manufacturer:
Box part number – CDR B19304836A
Heavy duty cover part number – C1C304803
4.17.2.8 Above-Ground Splice Housing
The aboveground splice closing will be a Charles multi-purpose housing with fiber-optic bracket or
Owner-approved equivalent component from an approved manufacturer:
Housing part number – CMPH-750FNH
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 846 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-32
4.17.2.9 Fiber-Optic Splice Enclosure
The fiber-optic splice enclosure will be a single-ended mechanical butt gel-sealed thermoplastic
enclosure manufactured by Preformed Line Products or Owner-approved equivalent product from
an approved manufacturer:
Splice enclosure – 8006951
4.17.2.10 Fiber-Optic Patch Panel
Fiber patch panel will be a wall mount enclosure with 4 adapter plate openings with 6 position dual
SC connectors manufactured by Optical Cable Corporation and Uniprise Solutions or Owner-
approved equivalent products from an approved manufacturer:
Patch panel part number – ZDMB6B-ALLIANT1
Adapter panel – Uniprise Solutions - PNL-WH-006-MFA-ST06-BG
4.17.2.11 Fiber-Optic Fan-Out Kit
The fan-out kit will consist of the following components or Owner-approved equivalent component
from an approved manufacturer:
Fan-out cable – Corning FAN-BT25-06
Splice tray kit – Preformed Line Products LGSTS16
4.17.3 Installation
4.17.3.1 General
The fiber cable shall be directly buried in a trench. The fiber cable may be installed in the same
trench as the power cable. The fiber-optic cable configuration shall be shown on the construction
drawings. In addition, Contractor shall install markers at 500 foot intervals and any utility and road
crossings (this is in addition to the power cable markers discussed in Section 4.4 above).
The Contractor shall install underground warning tape and tracer wire over fiber cable if not routed
in the same trench as the power cables.
The Contractor shall install fiber-optic cable between the cable trench and the conduit stub-out at
the turbine tower as shown on the construction drawings. The conduits shall be sealed after the
fiber-optic cables are installed to prevent rodent entry into the tower. The Contractor shall
terminate all fibers into the fiber-optic patch panels.
Contractor shall install hand holes at the field splice locations separate from the electrical
conductors. These locations shall be located around turbines, public right away and not in
landowner fields.
Contractor shall fusion splice all fiber cables.
All fiber-optic cable sheath lengths shall be recorded at each facility and hand hole entry and exit.
The sheath footage recordings shall be considered as part of the as-built drawings upon the
completion of the cable installation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 847 of 1056
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IDAHO POWER CO.| Collection System 4-33
The Contractor shall verify and test the complete fiber-optic network after all connections are
made. See Subsection 4.17.2.
4.17.3.2 Fiber-Optic Cable Crossings
Several crossings under paved roads, power cables, drain tiles, and wetlands may be required for
the fiber-optic communication cables.
In such instances, the fiber-optic cable conduit shall be installed by HDB. The fiber-optic cable shall
be routed through innerduct inside the bore tube with the other cables.
The Contractor shall obtain all necessary permits before commencing work. The Contractor shall
prepare drawings or sketched details of the cable crossing as part of permit application if required.
The Contractor shall be responsible for all permit payments and/or application fees.
Contractor shall obtain Owner approval for boring plan before the work for the bore commences.
4.17.4 Testing
Factory tests shall be performed on each fiber of every reel at the factory. Results shall be
recorded and included in the packaging with the cables. Product data sheets showing the
cable characteristics including dispersion, dimensional quality, and tensile strength shall be
provided by the manufacturer.
The Contractor shall test all fibers of each reel prior to taking delivery. Notify the Owner at
least 7 days prior to all pre-installation field tests to enable the Owner’s representative to
be present. Contractor shall submit OTDR charts at both 1310 nm and 1550 nm showing
launch conditions and all other parameters used in the setup (including the time and date).
A 1 km launch fiber shall be used. These charts shall illustrate and quantify the losses of
each length of fiber and stress points in the fiber. Review the traces carefully and explain
unusual discontinuities in detail. Photographs of OTDR test results will not be accepted. The
OTDR testing and waveforms shall be stored on recordable media and included with the
submittal. If the OTDR testing is performed using equipment other than Wavetek or
Tektronics, the Contractor shall supply the Owner with the software necessary to view the
test results. All pre-installation tests on the fiber-optic cable shall be compared to the
factory test results. If the overall attenuation for a fiber increases by more than 1 dB, the
reel will be rejected.
Contractor shall notify the Owner at least 7 days prior to the post installation field tests to
enable the Owner’s representative to be present. Contractor will perform end to end tests
for each fiber after all splices have been completed and all splice enclosures, except for
those required for fiber access during testing, have been returned to their permanent
position. The test shall include OTDR charts at both 1310 nm and 1550 nm showing launch
conditions and all other parameters used in the setup, time, and date shall be included.
OTDR measurements shall be made in both directions, if possible, and the splice loss results
bi-directionally averaged. These charts shall illustrate and quantify the losses of each length
of fiber and stress points in the fiber. Bi-directional averaged values shall be clearly
displayed on a separate chart that identifies each splice location by tower number and
direction of measurement. Review the traces carefully and explain unusual discontinuities
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 848 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-34
in detail. Photographs of OTDR test results will not be accepted. The OTDR testing and
waveforms shall be stored on recordable media and included with the submittal. If the
OTDR testing is performed using equipment other than Wavetek or Tektronics, the
Contractor shall supply Owner with the software necessary to view the test results. All post-
installation tests on the fiber-optic cable shall be compared to the pre-installation test
results. Bi-directionally averaged splice loss shall not exceed 0.15 dB.
All test equipment shall be calibrated with certification traceable to the National Institute of
Standards and Technology (NIST) relative to their intended use.
The fiber-optic tester shall have a minimum of 1 year testing and operations experience
with the OTDR and optical loss test equipment used for tests required in this specification
and shall be able to use all necessary test equipment without reference to test equipment
instruction books while performing the required tests specified herein. The qualifications of
all personnel performing the testing shall be in accordance with the latest version of NETA
ATS.
4.17.5 Numbering and Labeling
The Contractor shall label the fiber-optic cables at each termination point with identification
numbers to be identified by the Owner.
Each fiber-optic cable pulled into the junction boxes and spliced, terminated at the turbines and
terminated at the Project Collector Substation Buildings shall have a Contractor-provided cable
number label that corresponds to the cable number to be provided by the Owner. All labeling shall
be done in accordance with ANSI/TIA-606-B.
4.18 AMPACITY STUDY
4.18.1 Purpose and Scope
Contractor shall complete ampacity analyses on all Project power cables. These include:
MV collector power cables.
LV collector power cables.
MET tower power cables.
Other power cables in the Project Collector Substation and O&M Facility (if O&M Facility is
in Contractor’s scope).
Justification must be provided for all cable sizing. Most cable sizing will require CYMCAP analysis.
Where applicable, NEC references may also be used to support cable sizing (such as for LV power
cables at the Project Collector Substation and MET tower).
4.18.2 Required Methodology
Contractor shall determine the ampacity for all underground cables using CYMCAP. CYMCAP
analysis shall consider the following parameters:
Accurate soil thermal resistivity (rho) values based on final geothermal and geotechnical
investigations.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 849 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-35
Worst case current experienced by each cable during normal (non-fault) operations.
Cable physical and electrical parameters as defined by the manufacturer.
Accurate worst case soil temperature assumption for the Project region.
Trench and bore depths based on the current design drawings.
Analyses shall ensure that cable temperature does not exceed 90° C (running cables at
105° C may be allowed upon Owner approval).
Heating from circulating currents in the concentric shields.
Any assumptions made in this study must be enforced/noted in the design drawings (burial depth,
compaction, etc.).
At minimum, Contractor shall consider the following configurations in CYMCAP analysis:
Each cable size individually.
Parallel cable runs.
Project Collector Substation entrance(s).
LV WTG conduit entrance.
All crossings and bores including, but not limited to:
o Pipeline (consideration of any mutual heating from the pipeline).
o Railroad.
o Road.
o Stream.
o Drainage.
o Wetland.
o Other feeder cables (consideration of any mutual heating from the cables).
If a different cable burial configuration is required during construction, additional CYMCAP runs
shall be required before Contractor is allowed to proceed with the new configuration.
4.18.3 Required Submittals
4.18.3.1 30% Design
The 30% submittal of this study shall include preliminary CYMCAP analyses to generate initial cable
sizes. Only the basic and limiting cases need to be considered in CYMCAP at this time.
4.18.3.2 60% Design
The 60% submittal should include most or all required cases.
4.18.3.3 90% Design
The 90% submittal shall include all required cases and considerations, such that cable procurement
may follow.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 850 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-36
4.18.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
All underground collection cables shall have appropriate ampacities based on the final geotechnical
and geothermal investigations, while maintaining conductor temperatures at or below 90° C
(except where 105° C has been approved by Owner). A CYMCAP model will be provided showing
that the cable temperature will remain below the rated temperature at maximum output.
4.18.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.19 REACTIVE POWER FLOW STUDY
4.19.1 Purpose and Scope
Contractor shall complete a reactive power flow study to determine whether the Project meets
interconnect requirements, as well as assess the real and reactive capabilities of the Project. This
study must also ensure that the elements of the collector system are not overloaded and that
acceptable voltages are maintained at the WTG terminals.
4.19.2 Required Methodology
Owner-approved power flow software shall be used to perform the reactive power flow analysis.
The power flow model shall include the utility, Project Collector Substation transformer(s),
collection cables, pad mount step-up transformers, grounding transformers (if needed), and the
WTGs. The Project must satisfy the interconnect requirements, including:
0.95 leading to 0.95 lagging power factor at the POI.
0.95 pu to 1.05 pu voltage at the POI.
Voltage schedule at the POI shall be consistent with LGIA.
Maximum no load reactive power injection (if applicable).
WTGs shall not trip off due to undervoltage or overvoltage when the park is operating
within the above parameters.
At minimum, the following cases shall be considered in this study:
0.95 pu voltage at the POI with lagging power factor.
1.02 pu voltage at the POI with leading power factor.
1.02 pu voltage at the POI with lagging power factor.
1.05 pu voltage at the POI with leading power factor.
Zero generation.
Any other cases considered in the LGIA.
Each case (except for zero generation) shall be run with WTG output at 10%, 20%, 30%, 40%, 50%,
60%, 70%, 80%, 90%, and 100%. If any of the requirements stated above are not met, the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 851 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-37
Contractor shall recommend ways to bring the Project into compliance (capacitor banks, reactive
banks, etc.). If capacitor bank(s) are required within the Project Collector Substation, the Contractor
shall furnish the equipment per Section 5.0.
If reactive compensation is required, contractor shall perform flicker analysis in accordance with
IEEE 1036 to verify that the voltage changes experienced during switching will remain within
acceptable levels.
4.19.3 Required Submittals
4.19.3.1 30% Design
The 30% submittal of this study shall include preliminary reactive power analyses to determine
whether reactive compensation or other equipment will be required.
4.19.3.2 60% Design
The 60% submittal shall be updated to reflect any design changes since the 30% submittal.
Simulation results for the majority of the required cases should be available.
4.19.3.3 90% Design
The 90% submittal shall be updated to reflect any design changes since the 60% submittal.
Simulation results for the majority of the required cases should be available.
4.19.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.19.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.20 VAR CONTROL PHILOSOPHY
4.20.1 Purpose and Scope
Contractor shall recommend a reactive power compensation equipment control
algorithm/procedure to be used in switching in and out any capacitor or reactor banks. Contractor
shall also review and approve Turbine Supplier’s final VAR control philosophy.
This study should include detail on the prioritization and operation of the following pieces of
equipment:
Shunt switched devices (capacitors / reactors)
Load Tap Changer (if applicable)
WTG reactive capability
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 852 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-38
4.20.2 Required Methodology
Contractor shall verify that any switching of reactive compensation equipment at this Project is
coordinated with other reactive power equipment on the Transmission Owner’s transmission
system. Contractor shall also coordinate with Turbine Supplier.
The control algorithm shall be designed to avoid excessively switching reactive compensation
equipment on and off. The VAR control philosophy will use voltage control mode and meet voltage
schedule requirements (to be provided by Owner).
Contractor shall verify load tap changer (LTC) requirements for the main power transformer(s)
within the Project Collector Substation. If load tap changers are required within the Project
Collector Substation, the Contractor shall design the LTC location to be on the high side winding and
furnish the equipment. The following cases shall be analyzed as part of the VAR control philosophy:
No load tap changer
Load tap changer on the high voltage winding
4.20.3 Required Submittals
4.20.3.1 30% Design
No 30% submittal of this study is required.
4.20.3.2 60% Design
No 60% submittal of this study is required.
4.20.3.3 90% Design
Contractor shall provide a draft of the control procedure and algorithm for review. This shall
include a detailed description of the algorithm, as well as the basis and assumptions used to design
the algorithm.
4.20.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.20.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.21 SHORT CIRCUIT STUDY
4.21.1 Purpose and Scope
Contractor shall complete a short circuit analysis. The purpose of this analysis is to ensure that the
fault currents on various equipment are within the ratings of that equipment, and that they will not
be damaged during a fault scenario.
4.21.2 Required Methodology
All possible faults shall be analyzed in power flow software. These include 3-phase, single line-to-
ground, double line-to-ground, and line-to-line faults.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 853 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-39
Contractor shall compute the worst-case fault condition (combination of fault current and clearing
time) of the following equipment if applicable. These worst-case fault conditions shall be compared
to the withstand ability of each piece of equipment. ICEA P-32-382 shall be used to determine
withstand ability on insulated cables. Contractor shall also ensure that the following equipment
will withstand breaker failure clearing scenario.
MV cables
LV cables
Concentric shields
o Contractor shall clarify the basis for the amount of current on the concentric shields
during a fault event that is accurate, reasonable, and generally accepted by the industry.
Trench ground conductors
Pad mount step-up transformers (PMT’s)
Main power transformer(s) (MPT(’s))
Switchgear at the Project Collector Substation
MV terminations
MPT fuse
MV breakers
HV breakers
Contractor shall also report the maximum fault current at the Project Collector Substation.
4.21.3 Required Submittals
4.21.3.1 30% Design
The 30% submittal of this study shall include fault assessments of most equipment.
4.21.3.2 60% Design
The 60% submittal should include fault assessments of most equipment and incorporate any design
changes or comments from the 30% submittal.
4.21.3.3 90% Design
The 90% submittal should include fault assessments of all equipment and incorporate any design
changes or comments or from the 90% submittal. The results should be finalized to the point that
procurement can follow soon after this submittal.
4.21.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.21.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 854 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-40
4.22 HARMONICS STUDY
4.22.1 Purpose and Scope
Contractor shall complete a harmonic resonance analysis for the Project’s collection system. The
purpose of this study is to determine the total voltage and current harmonic distortion at various
points in the Project and verify that the Project is compliant with IEEE 519.
4.22.2 Required Methodology
Industry-accepted software shall be used to perform harmonic frequency scans and load flow analyses
under various system configurations. The frequency scans at the following buses/locations shall be
considered:
Point of interconnect (POI)
The MV side of each pad mount step-up transformer
Project Collector Substation MV buses
Capacitor bank buses
At minimum, the following system configurations shall be considered:
Normal operating conditions with:
o Capacitor/reactor bank(s) ON (including all possible combinations if there is more than
one capacitor bank) (if capacitor banks used on Project)
o Capacitor/reactor bank(s) OFF (including all possible combinations if there is more
than one capacitor bank) (if capacitor banks used on Project)
All combinations of capacitor/reactor bank OFF and different numbers of feeders open
All capacitor/reactor banks OFF and one MPT open at the Project Collector Substation
The following harmonic sources shall be considered:
Cables (MV and LV)
PMT’s
MPT
Capacitor banks (if used)
Reactor banks (if used)
WTG’s
Contributions from the transmission system (consideration of ambient harmonic
distortion)
Contractor shall make recommendations with respect to any necessary mitigation or harmonics
monitoring.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 855 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-41
4.22.3 Required Submittals
4.22.3.1 30% Design
A 30% submittal is not required for the harmonics study.
4.22.3.2 60% Design
A 60% submittal is not required for the harmonics study.
4.22.3.3 90% Design
The 90% submittal shall include all required cases and considerations. It will also contain a
recommendation regarding the need for power quality equipment and/or monitoring.
4.22.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.22.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.23 ELECTRICAL LOSSES STUDY
4.23.1 Purpose and Scope
Contractor shall complete an assessment of the electrical losses associated with the Project. The
purpose of this study is to verify that the annualized losses are below the limits required by the
Owner. These limits are indicated below:
Maximum allowable annualized energy loss (from generator terminals to revenue meter):
2.5%
Contractor shall also calculate the energy loss percentage at peak output for informational
purposes.
4.23.2 Required Methodology
Contractor shall assess both the annualized losses on the Project, as well as the maximum
instantaneous losses. Power flow software shall use accurate 8760 wind data to calculate expected
losses for each wind speed.
Losses from the following equipment shall be considered:
Collection cables (MV and LV)
PMT’s
MPT’s
Grounding transformers
Transmission Line (if applicable)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 856 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-42
No load losses of all transformers shall be accounted for in the analysis.
Losses at zero percent generation shall be included in the loss calculation.
4.23.3 Required Submittals
4.23.3.1 30% Design
The 30% submittal shall be as thorough and accurate as possible so that any excessive losses can be
corrected as early as possible (e.g. by increasing cable sizes).
4.23.3.2 60% Design
A 60% submittal is not required for this study.
4.23.3.3 90% Design
The 90% submittal shall include any design changes since the 30% submittal and identify any
excessive losses that need to be corrected.
4.23.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
The loss percentages shall meet the Owner’s requirements.
4.23.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.24 TEMPORARY OVERVOLTAGE (TOV) STUDY
4.24.1 Purpose and Scope
Contractor shall perform TOV analyses to determine the level of temporary overvoltage when the
feeder breakers are opened. This analysis shall inform any surge arrester, grounding transformer,
and grounding switch breaker recommendations.
4.24.2 Required Methodology
Owner-approved software shall be used to complete this analysis. EMTP, ATP, and PSCAD/EMTDC
are approved.
The analysis shall accomplish the following:
Verify that the temporary overvoltage on the feeder during an open feeder breaker
situation stays within acceptable limits (during either a fault scenario or during normal
operation). These limits shall be in accordance with the latest edition of IEEE C62.92.1. To
meet this requirement, contractor shall make any necessary surge arrester, grounding
transformer, or grounding switch breaker recommendations. The study prepared by the
Contractor shall provide results with and without any recommended mitigation.
Verify that the temporary overvoltage does not exceed the TOV withstand capability of the
surge arresters.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 857 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-43
Verify that the temporary overvoltage does not exceed the limits of the TOV withstand
capability curve of the surge arresters based on the anticipated magnitude and duration of
the temporary overvoltage.
Verify that the temporary overvoltage does not exceed the limits of all equipment
associated with the WTG’s, inverters, power supplies, etc.
The energy absorption by the surge arresters shall also be assessed to ensure that they can
absorb the required energy.
4.24.3 Required Submittals
4.24.3.1 30% Design
The 30% submittal shall be thorough and accurate in order to determine whether certain
grounding equipment is necessary.
4.24.3.2 60% Design
A 60% submittal is not required for this study.
4.24.3.3 90% Design
The 90% submittal shall include any design changes since the 60% submittal and allow for
procurement of any necessary grounding equipment.
4.24.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.24.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.25 INSULATION COORDINATION STUDY
4.25.1 Purpose and Scope
Contractor shall perform a study to ensure that the dielectric strength of equipment on the Project
is properly coordinated with the capabilities of the surge arresters.
4.25.2 Required Methodology
Contractor shall verify that the Project is compliant with the requirements of IEEE C62.22.
4.25.3 Required Submittals
4.25.3.1 30% Design
The 30% submittal shall be thorough and accurate in order to determine whether certain
grounding equipment is necessary.
4.25.3.2 60% Design
The 60% submittal shall include any design changes since the 30% submittal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 858 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-44
4.25.3.3 90% Design
The 90% submittal shall include any design changes since the 60% submittal and allow for
procurement of any necessary grounding equipment.
4.25.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.25.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.26 STEP AND TOUCH ANALYSIS
4.26.1 Purpose and Scope
The purpose of the study is to determine the worst-case step and touch potentials that could be
encountered on the Project.
4.26.2 Required Methodology
Contractor shall use CDEGS or owner-approved equivalent software to verify that the step and
touch potentials on the Project are compliant with the latest version of IEEE 80 and NESC. The step
and touch voltages on the Project shall not exceed the maximum allowable voltages required by
IEEE 80. The following requirements shall also be observed:
Contractor shall use the worst-case fault current and fault location (based on soil electrical
resistivity data) in this analysis.
If copper telecom infrastructure is used on this Project, ground potential rise evaluation and
high voltage isolation equipment design must be included.
If necessary, Contractor shall recommend changes to the protection system or surface
material.
Contractor shall verify proper ground resistance has been achieved on the Project using the
four-point fall of potential method per IEEE STD 81.
Contractor shall provide grounding system impedance value to Owner prior to startup.
4.26.3 Required Submittals
4.26.3.1 30% Design
The 30% submittal shall be a preliminary analysis based on available geotechnical data.
4.26.3.2 60% Design
The 60% submittal shall incorporate actual site geotechnical data. Any critical step and touch
voltage concerns shall be identified at this stage.
4.26.3.3 90% Design
The 90% submittal shall include any design changes since the 60% submittal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 859 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-45
4.26.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.26.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.27 EFFECTIVE GROUNDING STUDY
4.27.1 Purpose and Scope
The purpose of this study is to verify that the collection system is effectively grounded per IEEE
requirements.
4.27.2 Required Methodology
Contractor shall use EMTP software to verify that the collection system is effectively grounded per
IEEE C62.92.1. This shall be done by simulating a single line-to-ground fault and verifying that the
maximum steady-state peak line-to-ground voltage on the non-faulted phases does not exceed IEEE
requirements.
4.27.3 Required Submittals
4.27.3.1 30% Design
The 30% submittal shall be a preliminary analysis and determine whether any critical design
changes are needed.
4.27.3.2 60% Design
A 60% submittal is not required for the effective grounding study.
4.27.3.3 90% Design
The 90% submittal shall include any design changes since the 60% submittal.
4.27.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
4.27.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.28 RELAY SETTINGS PHILOSOPHY
4.28.1 Purpose and Scope
Contractor shall prepare a relay protection settings and philosophy document for the Project. This
document shall describe the relays used, the protection philosophy, and convey all relay settings.
4.28.2 Required Methodology
This study will be reviewed with Owner prior to implementation of relay settings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 860 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-46
Contractor shall use an industry-accepted short circuit and relay coordination software (e.g. Aspen,
ETAP, etc.) to develop relay protection settings, as well as any necessary software outputs such as
time current curves (TCC’s). Any calculations required to determine relay settings shall be included
in the report. Schweitzer relays shall be used on this Project. All transmission line relay protection
shall be coordinated with the standards from the Transmission Owner as outlined in the GIA.
Contractor shall coordinate transmission line protection settings with the Transmission Owner.
Separate zones of protection will be required in accordance with Project Collector Substation
drawings. The design of the Project will balance minimization of fault clearing times with system
coordination. Contractor shall verify the adequacy of the relay design philosophy during the
detailed design.
Relay settings and philosophy shall be assessed for all major equipment including but not limited
to:
WTG’s
Collection System circuits
Substation circuit breakers
Capacitor/reactor banks
MPT’s
MPT high side bus
MPT low side bus
MPT high side breaker
MPT low side breaker
Transmission line
Other requirements:
Contractor shall implement an “Arc Flash Protection” mode on the feeder relays. This mode
is intended to be in service under normal operating conditions and must include a more
sensitive directional-overcurrent element. A pushbutton on the front of the relay will allow
disabling of the mode to accommodate Wind Turbine pad mount transformer inrush during
switching. Only those buses which have a PPE rating greater than hazard risk category 4
shall have the mode available.
Contractor shall address primary and secondary protections in this philosophy document.
Contractor shall provide fault locator settings for locating faults on home runs up to the first
turbine or 3-way or 4-way junction box on each circuit.
Contractor shall comply with all applicable NERC standards and requirements.
4.28.3 Required Submittals
4.28.3.1 30% Design
No 30% submittal shall be required.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 861 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-47
4.28.3.2 60% Design
The 60% submittal shall include preliminary analyses of all major equipment.
4.28.3.3 90% Design
The 90% submittal shall include analyses of all major equipment and incorporate any comments
from the 60% submission.
4.28.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
This final submittal shall be suitable for use in the final arc flash analysis.
4.28.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.29 ARC FLASH STUDY
4.29.1 Purpose and Scope
Contractor shall perform an assessment of the arc flash risk at each bus in the Project. The purpose
of this assessment is to classify the arc flash risk level at each bus based on the worst case incident
energy that could occur. Contractor shall also provide all equipment arc flash labels. Prior to
equipment purchase, Contractor shall within reason purchase equipment that meets category 4 or
less (for example, accessing and operating pad mount transformer low voltage disconnect using
category 4 PPE).
4.29.2 Required Methodology
Contractor shall perform the analysis in accordance with the latest adopted version of NFPA 70-E,
IEEE 1584 and NESC, as well as Owner’s arc flash standards. Where conflicts exist between the
above standards, the more stringent shall apply. Contractor shall adhere to the following
requirements:
Contractor shall acquire the following from the Owner:
o Preferred working distance assumptions for the different voltage levels. Contractor
shall also ensure that these assumptions are based on actual and/or practical working
distances that will be needed on this Project.
o Site-specific arc flash hazard classification levels (with PPE (Personal Protective
Equipment) requirements).
o Arc flash label standards, formats, and preferences
Contractor shall determine the worst case incident energy at every AC and DC bus within
the Contractor’s design scope (including the low voltage distribution panels (LVDP) in the
WTG’s if not in Turbine Supplier’s or Owner’s scope and the AC/DC panels/buses in the
Project Collector Substation control building).
Contractor shall classify each bus based on the above-mentioned site-specific arc flash
hazard classification levels.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 862 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-48
Contractor shall perform these analyses in accordance with the latest relay settings that are
available when performing each iteration of the study.
Contractor shall develop maintenance relay settings for the LVDPs in order to reduce the
incident energy to hazard category 2. This shall be done in coordination with the “Relay
Settings Philosophy” document.
The design will seek to limit arc flash energy to Hazard/Risk Category 2 at all 690V buses in
accordance with the “Relay Settings Philosophy” document. There may be some instances
where Hazard/Risk Category 2 is not achievable. The primary acceptable methods for
minimizing fault clearing times are to utilize bus differential relay, alternate mode switches
and coordination between main and feeder breakers. Fiber-optic arc sensors may be used,
only upon approval by Owner, when the primary methods have been exhausted.
Contractor shall perform an incident energy analysis using ETAP version 12.5.0 or later.
Contractor shall provide a summary report which includes tables listing Hazard/Risk
category, arc flash boundary distance and incident energy levels for each piece of
equipment analyzed. If alternate mode switches are used, the analysis and report must
include incident energy levels with the maintenance switches in both the ON and OFF
positions. ETAP generated reports should be included as attachments to the Incident Energy
Analysis report. Additionally, Contractor shall provide the Buyer with the final ETAP model
(.oti and associated .mdb & .lib files) upon completion of the report/project.
Contractor will perform calculations and provide labeling for all electrical Equipment, as
required, to ensure compliance with NFPA 70E. Arc Flash labels will be provided per NFPA
70E.
4.29.3 Required Submittals
4.29.3.1 30% Design
A 30% submittal shall not be required.
4.29.3.2 60% Design
A 60% submittal shall not be required.
4.29.3.3 90% Design
The 90% submittal shall be the first submittal and be based on the latest data and information
available at that time.
4.29.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
This version will be updated with as-built changes from the field.
4.29.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 863 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-49
4.30 MINIMUM APPROACH DISTANCE (MAD) STUDY
4.30.1 Purpose and Scope
Contractor shall perform an assessment of the Minimum Approach Distance (MAD) for the Project
Collector Substation. The purpose of this assessment is to determine minimum approach distance
for use by the Owner during maintenance activities as per the OSHA Standard 1910.269(I)(3) and
(q)(3). Contractor shall also provide all equipment minimum approach distance labels.
Contractor shall perform a Transient Overvoltage study to determine the expected overvoltage
factor (per-unit) to calculate the MAD for the Project Collector Substation.
4.30.2 Required Methodology
The study shall use EMTP type software program for modeling the transmission network
and calculating the per unit Transient Overvoltage.
For the purpose for the Transient Overvoltage study, the “study area” shall include the
system within the radius of up to two (2) substations from Project Collector Substation.
To accurately capture the switching transient travelling waves, frequency dependent
models of the transmission lines in the study area shall be included in the study model.
This model shall include transmission line tower configuration and conductor and ground
wire parameters to calculate the frequency dependent impedance parameters of the
transmission circuit. The EMTP software program used should be able to calculate the surge
impedance and the travel time of the transient waves.
Detailed substation data such as transformer data with winding impedances and nameplate
rating, shunt connected equipment data, circuit breaker data, surge arrester information are
to be included in the Transient Overvoltage study model.
The rest of the system shall be represented by an equivalent network model.
The EMTP model built shall be validated against the obtained transmission load flow and
short circuit models for power flow, voltage and short circuit parameters.
The Transient Overvoltage study is to be performed under study under various network
configurations (system intact vs. contingency scenarios).
The Transient Overvoltage must be calculated for the worst case switching transient among
the multiple point-on-wave (POW) switching simulations performed via statistically control
circuit breaker operation as per OSHA 1910.269.
The Minimum Approach Distance (MAD) shall be determined based on the worst observed
Transient Overvoltage in per unit using the OSHA online calculator available at:
https://www.osha.gov/dsg/mad_calculator/mad_calculator.html
4.30.3 Required Submittals
4.30.3.1 30% Design
A 30% submittal shall not be required.
4.30.3.2 60% Design
A 60% submittal shall not be required.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 864 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-50
4.30.3.3 90% Design
The 90% submittal shall be the first submittal and be based on the latest data and information
available at that time.
4.30.3.4 IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
This version will be updated with as-built changes from the field.
4.30.3.5 As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.31 PROJECT COLLECTOR SUBSTATION-SPECIFIC STUDIES
4.31.1 AC Station Service Study
4.31.1.1 Purpose and Scope
Contractor shall perform an AC station service study in order to determine the appropriate ratings
for the AC auxiliary power system components installed in the Project Collector Substation.
4.31.1.2 Required Methodology
Contractor shall perform the analysis in accordance with the latest version of the National Electrical
Code (NEC), National Electrical Safety Code (NESC) and IEEE-141. Contractor shall adhere to the
following requirements:
Voltage drop will be calculated in order to minimize electrical losses and to determine the
size of cables required for the auxiliary power system.
The minimum kVA rating of the auxiliary power transformer will be calculated based on the
AC panel loads. The automatic transfer switch (ATS) will be sized according to the
maximum amps per phase of the proposed transformer.
The equipment and material components of station service systems are specified according
to manufacturer and industry standards.
The components are sized and selected for application by manufacturer’s data and by
industry design guides and standard practices.
4.31.1.3 Required Submittals
30% Design
The 30% submittal shall be thorough and accurate in order to determine the appropriate rating of
the required station service transformer and components.
60% Design
A 60% submittal is not required for the AC station service study.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 865 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-51
90% Design
The 90% submittal shall include any design changes since the 30% submittal, and allow for
procurement of the required station service transformer and components.
IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.31.2 DC Station Service Study
4.31.2.1 Purpose and Scope
Contractor shall perform a DC station service study in order to ensure appropriate ratings for the
battery and battery charger installed in the control building of the Project Collector Substation.
4.31.2.2 Required Methodology
Contractor shall perform the analysis in accordance with the latest version of IEEE-485 and IEEE-
946. Contractor shall adhere to the following requirements:
The continuous and momentary DC loads will be calculated in accordance with the Project
Collector Substation one line diagrams and ancillary loads that will be connected to the
battery.
The battery charger shall provide a constant DC load and recharge the battery in a 12 hour
period.
The equipment and material components of station service systems are specified according
to manufacturer and industry standards.
The components are sized and selected for application by manufacturer’s data and by
industry design guides and standard practices.
4.31.2.3 Required Submittals
30% Design
The 30% submittal shall be thorough and accurate in order to determine the appropriate ratings of
the DC battery and charger.
60% Design
A 60% submittal is not required for the DC station service study.
90% Design
The 90% submittal shall include any design changes since the 30% submittal, and allow for
procurement of the required battery and battery charger.
IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 866 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-52
As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.31.3 Lighting Study
4.31.3.1 Purpose and Scope
Contractor shall perform a lighting study in order to properly design the Project Collector
Substation exterior area lighting systems.
4.31.3.2 Required Methodology
Contractor shall perform the analysis in accordance with the latest version of the National Electric
Safety Code (NESC). Contractor shall adhere to the following requirements:
Lighting illumination calculations should be performed (on the basis of the selected
luminaires and dimensions of the illuminated area) by one of the following methods:
computer program (preferred), manual, or spreadsheet. The preferred and verified
computer software programs are Visual and Lighting Analysts, Inc., AGI32.
Two kinds of lighting are required: general illumination for the movement of occupants and
directed illumination for viewing fans, bushings, oil gauges, panels, disconnect switch jaws,
station bus, and other live parts.
The IESNA recommends 20 lux (2.0 footcandles) be maintained for general or area
illumination and 50 lux (5.0 footcandles) be maintained for directed or task illumination.
Depending on the Project Collector Substation size and projected future layout (if large
unused areas exist), maintaining 20 lux (2.0 footcandles) for general illumination
throughout the Project Collector Substation yard may be an unreasonably high overall
illumination level.
Outdoor control building lights shall remain on during the night. All other Project Collector
Substation yard lighting shall be operated by a switch or switches installed in the control
building.
4.31.3.3 Required Submittals
30% Design
A 30% submittal is not required for the lighting study.
60% Design
The 60% submittal shall include preliminary analyses of Project Collector Substation exterior area.
90% Design
The 90% submittal shall include analyses of the Project Collector Substation exterior area and
incorporate any comments from the 60% submission.
IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 867 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Collection System 4-53
As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
4.31.4 Lightning Study
4.31.4.1 Purpose and Scope
Contractor shall perform a lightning study in order to determine the effective striking distance that
provides direct stroke shielding for the Project Collector Substation. The effective lightning
protection design shall utilize shield masts and/or shield wires.
4.31.4.2 Required Methodology
Contractor shall perform the analysis in accordance with the latest version of IEEE-998. Contractor
shall adhere to the following requirements:
The effective lightning protection design shall utilize shield masts and/or shield wires.
The resulting shielding system failure rate is calculated to confirm the design adequacy per
the rolling sphere method, based on the electro-geometric model.
The fixed angle method per IEEE-998 may be used to confirm design adequacy.
These methods apply to electrical switchyard equipment and structures. The protection of
transmission lines and buildings is outside the scope of this study.
4.31.4.3 Required Submittals
30% Design
The 30% submittal shall include preliminary analyses of Project Collector Substation lightning
protection.
60% Design
A 60% submittal is not required for this study.
90% Design
The 90% submittal shall include any design changes since the 30% submittal, and allow for
procurement of required lightning masts and/or shield wires.
IFC Design
Any corrections or additions from the 90% submittal shall be incorporated in the IFC submittal.
As-Built
Contractor shall provide an as-built submittal which has taken any as-built changes since IFC into
account.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 868 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-1
5.0 Substation
5.1 GENERAL
These general equipment specifications apply in general to all equipment and materials and are
supplementary to the detailed specifications. If requirements specified herein are in conflict with
requirements specified in the detailed specifications, the more stringent specification shall govern
to the extent of such conflict. The Contractor shall furnish all major substation equipment per the
Owner’s specification data sheet(s) and determine necessary quantities and ratings where
applicable.
The Contract shall be based upon the use of equipment and materials complying fully with the
requirements specified in this Exhibit. For 345kV equipment, Contractor shall follow Transmission
Owner’s specifications if specified by Owner and/or Transmission Owner during detailed design. It
is recognized that the Contractor may have standardized on the use of certain components,
materials, processes, or procedures different than those specified herein. Alternates on the basis of
supplying the Contractor's standard components, materials, processes, or procedures will be
considered by the Owner. The alternate proposal shall clearly stipulate the alternate proposed, the
specific exceptions to the specifications, and the price change applicable for supplying such
alternate.
5.1.1 Identification
All correspondence, shipping notices, specifications, engineering data, and other documents
pertaining to the equipment and materials furnished under these specifications shall be identified
by the Owner's name, the project name, the unit number, and the specification number.
5.1.2 Numbering System
The Owner shall establish an identification numbering system to provide consistent numbering
throughout the generating unit. All electrical devices, control and instrumentation equipment, and
other items of similar nature shall be permanently identified with the identification number
specified on the Contractor’s drawings. Except as specified otherwise in these specifications, the
identification shall be engraved on stainless steel or laminated phenolic tags or nameplates at the
option of, and as acceptable to, the Owner and permanently affixed to the device. The Owner’s
identification numbers shall be included on the drawings prepared by the Contractor.
5.1.3 Equipment Testing
The Owner reserves the right to witness any or all of the Project Collector Substation equipment
testing.
The Contractor shall notify the Owner of the scheduled start date of the factory tests not less than
two weeks prior to the start of testing.
A copy of the test report shall also be included in each copy of the instruction manual for substation
equipment.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 869 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-2
5.1.4 Preshipment Inspection
The Owner reserves the right to inspect the equipment prior to shipment.
The Contractor shall notify the Owner of all shipments not less than 72 hours prior to the date of
shipment to allow the Owner to inspect the equipment if so desired, given appropriate notice.
5.1.5 Shipments
Shipments to the Project Collector Substation site shall be consigned to the following locations.
The Contractor shall discuss with the Owner the routing of shipments and shall route the shipments
as indicated by the Owner, provided freight rates are no greater than by other routes.
5.1.6 Shipping Notice
The Contractor shall submit to the Owner two copies of shipping notices describing each shipment
of material or equipment. The shipping notices shall be faxes or e-mails to arrive approximately 3
business days ahead of the estimated shipment arrival. The addressee for each shipping notice will
be determined later.
5.1.7 Recommended Spare Parts
The Contractor shall provide a complete listing of recommended spare parts with unit prices FOB
Project Collector Substation site. The listing shall include the manufacturer of each part, a
description of each part (including industry standard part number if available), the assembly or
equipment in which each part will be used, and recommended quantities to be stocked; shall
classify the relative criticality of parts based on manufacturer’s experience; and shall list the lead
time required for manufacture and delivery of each part.
Owner will retain the option of purchasing any one or any combination of spare parts listed at the
prices quoted until 6 months after the date of commercial operation.
5.1.8 Electronic Material List
Contractor shall provide an electronic material list for their entire scope of work by means of an
electronic file in the Excel spreadsheet format. Scanned files or documents are not acceptable. The
Excel spreadsheet must list all "receivables", which are items to be shipped as separate
components, assemblies, sub-assemblies or spares. For Change Orders/Revisions, the entire
original Electronic File does NOT need to be resent; only the changes need to be provided.
As a minimum, the following fields must be provided on the Electronic Material List:
PO NO. - Owner's Contract Number (15 AN)
Contractor Name - Contractor's name as shown on Contract (50 AN)
Current Promise Delivery Date – This is the date Contractor is currently promising delivery
by. This must be provided for each deliverable item (10 character N – Date Format is
mm/dd/yyyy)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 870 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-3
Field Required Date – This is the delivery date required per the Contract. This must be
provided for each deliverable item. (10 character N – Date Format is mm/dd/yyyy)
Contractor's Tag Number – Enter tag number. Contractor shall use Contractor's or
Subcontractor’s identification number (i.e. mark, piece, part or serial number, must be
shown). Each tag, mark, piece, part, or serial number shall be listed individually. Do not
combine them. (30 character AN)
Quantity – Provide the quantity of each item. (10 character N)
Size and Description – Provide the description (I.e. nameplate description) and size for all
items. (200 character AN)
Advise if preventative maintenance or storage requirements are required prior to
installation – Contractor shall identify the item numbers or specific component types which
are to be stored indoors and/or require special storage provisions or require preventative
maintenance prior to installation. If Contractor specifies Yes (Y), Contractor shall provide
specific details of the requirements. (1 Character A, either Y for Yes or N for No for each
deliverable item).
Unit of Measure – Provide applicable unit of measure
Additional Fields - Additional fields are required for pre-fabricated materials, such as
structural steel. The area, drawing number, sequence or volume, and shop order number
are required for all pre-fabricated materials. For structural steel the weight is required.
5.1.9 Codes and Standards
Latest version of all codes and standards listed in this Exhibit shall govern unless otherwise
indicated.
5.2 TECHNICAL SCOPE AND SYSTEM PERFORMANCE REQUIREMENTS
5.2.1 Technical Scope of Work
The work under these specifications shall include furnishing all materials listed in this section in
accordance with their respective specifications.
5.2.2 Quantity of Supply
Contractor shall supply all structures and materials in sufficient quantity to ensure the Project
Collector Substation achieves the operating characteristics described in these specifications.
Contractor shall design and build an open (future) bay on each 34.5 kV bus.
The included conceptual design for the Project Collector Substation is not a final design nor are the
quantities thereof accepted to be correct, whether or not such quantities are expressed or implied.
All of the conceptual design drawings are for reference only and shall be taken as a guide showing
the desired design approach.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 871 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-4
5.3 CIVIL REQUIREMENTS
5.3.1 General
The Project Collector Substation civil works shall be developed as required to support the
construction of the electrical components of the Project. The earthwork services shall be performed
based on the results of the geotechnical investigations and topographical surveys and shall meet all
minimum requirements of these technical specifications and as required by the detailed Project
layout. Site preparation shall consist of clearing and grubbing and the placing and compaction of fill
with slopes and embankments designed in such a fashion as to be stable and capable of carrying
anticipated loads from equipment or structures. The Project Collector Substation site shall be
graded such that runoff water will drain away from the site. The top of all permanent foundations
shall be placed a minimum of 12 inches above the 100-year flood elevations.
5.3.2 Site Preparation
Site preparation requirements shall comply with the specification data sheet(s) completed by
Contractor during detailed design.
5.3.3 Fencing
Fencing shall be furnished in accordance with the specification data sheet(s) completed by
Contractor during detailed design.
5.3.4 Camera Conduits
The Contractor will design, procure, and install conduits for operating cameras in the substation.
The locations will be agreed upon with Owner during design. The Contractor will run (2) 1-inch
conduits from the control building to each of the camera locations. At each camera location, will be
a hand-hold box installed with the conduit appropriately connected to the hand-hold box.
Generally, the locations will be at each corner and next to each gate .
5.4 STRUCTURAL REQUIREMENTS
5.4.1 General
The Contractor shall be responsible for the design, detailing, material procurement, layout,
erection, and construction of substation foundations and structures, as required for the installation
and operation of the substation.
5.4.2 Codes and Standards
The design and construction of all substation foundations and structures shall be in accordance
with all Federal, State, and Municipal codes and regulations, as well the Codes and Standards listed
below.
International Building Code 2015 (IBC 2015).
Building Code Requirements for Structural Concrete, American Concrete Institute
(ACI 318-14).
Manual of Steel Construction, American Institute of Steel Construction (AISC, 14th Edition).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 872 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-5
Minimum Design Loads for Buildings and Other Structures, American Society of Civil
Engineers (ASCE 7-16).
International Standard, Wind Turbines-Part 1: Design Requirements (IEC 61400-1, Edition
3.1, 2014-04).
ASCE Manuals and Reports on Engineering Practice No. 113, Substation Structure Design
Guide.
5.4.3 Concrete Foundations
All concrete and grout material used for substation foundations shall be in accordance with the
requirements specified in Section 3.0.
Anchor bolts, concrete piers, and flat slabs shall be set carefully and maintained at the lines and
elevations shown on the drawings within the following tolerances:
Location of foundation center: ±1/2”
Distances between bolt centers in the same foundation: ±1/16”
Elevation at top of anchor bolts and flat slabs: minus 0” to plus 1/4”
Angular deviation from vertical (out of plumb): 1/16” in 1’
Distance between anchor bolt centers between adjacent foundations for a structure: ±1/4”
Horizontal angular alignment (rotation) of anchor bolt group: ±1°
Flat slab deviation from level: 1/16” in 4’
5.4.4 Miscellaneous Concrete Embedments
The Contractor shall coordinate the location and placement of grounding grids, control conduit, and
electrical conduit, as needed. Conduit placement details shall be submitted to the Owner for
approval.
Miscellaneous embedments and conduit will be located as not to interfere with a foundation’s
structural reinforcing steel.
Miscellaneous embedments will be properly secured to prevent movement during concrete
placement.
5.4.5 Structural Steel
Dead-end steel structures shall be single-bay h-frame structures made of tubular steel. Overload
factors and shape factors shall be accounted for in the design of these structures. Lightning masts,
static wire vangs, grounding lugs, and other lightning-protection design considerations shall be
accounted for.
All small substation steel supports shall be made of structural steel members. Seal welds shall be
provided between strength welds before galvanizing per ASTM A123. Welding electrodes shall be
E70XX per AWS A5.1.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 873 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-6
Structural steel design documentation shall be submitted to the Owner as specified in Specification
WED 0142 and specification data sheet(s) completed by Contractor during detailed design.
5.5 OUTDOOR DISCONNECT SWITCHES
5.5.1 General
Outdoor Disconnect Switches shall be furnished in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
Owner reserves the right to be present during factory testing. Contractor shall give Owner a
minimum thirty (30) days’ notice so that personnel can make proper arrangements. Presence at
factory testing shall be made available to Owner at no additional cost to Owner.
5.5.2 Codes And Standards
Outdoor disconnect switches furnished under these specifications shall be in accordance with the
requirements of applicable to ANSI, IEEE, and NEMA standards. All materials and devices shall be in
accordance with the applicable requirements of state and local safety standards.
5.5.3 Equipment Required
The Contractor shall furnish disconnect switches and accessories as indicated on the drawings and
specified herein.
The quantities of disconnect switches furnished shall be indicated on the drawings.
Per Owner, the following outdoor disconnect switches shall be furnished by the Contractor for the
Project Collector Substation:
Table 5-1 Outdoor Disconnect Switches
M Description
345 kV Double Break Southern States. LLC
blade option.
5.5.4 Insulators
Disconnect switch insulators shall be furnished.
5.5.5 Ratings
Disconnect switch ratings shall be furnished in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
If Contractor recommends altitude correction, a clear indication should be made to the Owner.
5.5.6 Switch Construction (If Applicable)
Switches shall be complete with switch blades, contacts, terminals, bases, and leveling devices, and
with all bolts, nuts, and other hardware required to assemble the switches, mount the insulators,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 874 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-7
and mount the switches on steel structures. Switch bases shall be designed to resist all dynamic and
static loads imposed by the switch. Switch bases shall be steel channel, hot-dip galvanized after
fabrication.
All switch components fabricated of ferrous materials shall be hot-dip galvanized after fabrication
or shall be stainless steel.
Switch parts shall be capable of carrying the continuous current required in an ambient
temperature of 40ºC without exceeding the temperature rises listed in ANSI C37.30, and shall have
sufficient strength for all mechanical requirements.
All switches shall be furnished with copper or aluminum alloy live parts. Copper switch blades shall
be hard drawn and tinned after fabrication; aluminum switch blades shall be extruded 6063, T6
alloy. Where disconnect switch terminals are fabricated of copper, the copper shall be tinned. All
other switch components which are fabricated of copper and are in contact with aluminum shall
have the copper tinned, and shall be provided with electrical joint compound between the contact
surfaces.
Switch bearings shall be maintenance free of the sealed, greaseless type.
Switch contacts shall be high-pressure, silver insert, wiping action type. The jaw contact fingers of
switches so equipped shall be designed to increase contact pressure with increasing current.
Contact finger pressure springs shall be outside of the load current path.
Disconnect switches shall be furnished with terminal pads with 9/16 in. (14.3 mm) diameter bolt
holes on 1-3/4 in. (44.45 mm) centers. Both sides of each terminal pad shall be suitable for
electrical connection to the bus system. The quantity and arrangement of bolt holes in each
terminal pad shall be coordinated with the switch continuous current rating and shall be in
accordance with the following table. Contractor shall verify with manufacturer the required bolt
size, diameter, and installation torque that ensure these ampere ratings.
Table 5-2 Switch Continuous Current Ratings
Arrangement
600 2 Parallel to center line of switch
601 through 2,000 4 Square
2,001 through 4,000 6 Rectangular, with longer dimension
perpendicular to center line of switch
All bolts, nuts, and other hardware required to attach the disconnect switch bases to the steel
structures and the station post insulators, and make the electrical connections to the bus system
shall be provided. The quantity of bolts, nuts, and other hardware provided shall include an overage
of 5 percent plus ten bolts of each type, size, and length.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 875 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-8
5.5.7 Hookstick Operated Switches
Standard blade stops for all hookstick switches shall be set to 90 degrees. Operators shall be able to
operate hookstick switches at a 45 degree angle from the switch.
5.5.8 Group Operators (If Applicable)
Group operators shall be complete with interphase shafts, operating rods, couplings, guide
bearings, mounting brackets, offsets, manual or motor operators, and all bolts, nuts, and other
hardware required to assemble the operators and mount the operators on steel structures.
Operators shall be furnished with multi-revolution grounding devices or braids and with provisions
for padlocking in the open and closed positions. Braids shall be tinned copper.
All levers, interphase shafts, and operating rods shall be cut to length and threaded at the factory.
All group operator components fabricated of ferrous materials shall be hot-dip galvanized after
fabrication or shall be stainless steel.
5.5.8.1 Manual Operators (If Applicable)
Manual operators for switches shall be swing handle type and indicated on the specification data
sheet(s) by Contractor during detailed design. Manual operators shall not require an operating
force greater than 50 lb (220 N).
Each disconnect switch manual operator shall be provided with an auxiliary switch, with contacts
in accordance with the specification data sheet(s), enclosed in a NEMA 4 weatherproof housing
equipped for threaded rigid steel conduit connection. The auxiliary switch housing shall contain a
120 VAC space heater. Auxiliary switch contacts shall be field convertible. The auxiliary switch shall
be for field mounting on the operating pipe where the operating pipe shall be at 3’6” from top of
grade to ensure ease of operating and closing.
5.5.9 Tightening of Connections
The Contractor shall include on the erection and assembly drawings complete information for
tightening of all electrical connections secured with bolts or studs. The information furnished shall
include torque wrench settings or complete details of other tightening procedures recommended
for bus joints, connector attachments, and contact attachments.
5.5.10 Manufacturers
All disconnect switches shall be of a common brand. See Appendix for approved vendors.
5.6 INSULATORS
5.6.1 General
Insulators for use on the substation structures shall be furnished in accordance with this section
and indicated on the specification data sheet(s) by Contractor during detailed design.
Owner reserves the right to be present during factory testing. Contractor shall give Owner a
minimum thirty (30) days’ notice so that personnel can make proper arrangements. Presence at
factory testing shall be made available to Owner at no additional cost to Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 876 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-9
5.6.2 Codes and Standards
All insulators furnished under these specifications shall conform to the requirements of the latest
applicable standards of ANSI, IEEE, and NEMA.
5.6.3 Equipment Required
Insulators furnished shall be complete with all accessories ready for mounting, assembly,
connection, and immediate service.
The quantity and types of insulators furnished shall be indicated on the drawings.
5.6.4 Design Requirements
Insulator design requirements are covered in the following sections. Fittings and clamps shall be
hot-dip galvanized, malleable iron or bronze. Aluminum fittings and clamps shall not be used.
5.6.5 Station Post Insulators (If Applicable)
These station post insulators shall be used as rigid bus supports. All mounting hardware for
insulator field assembly and mounting to equipment and steel structures shall be furnished with an
average of 5 percent plus 10 bolts of each type, size, and length.
5.6.6 Manufacturers
Insulators shall be as manufactured by Lapp Insulator Company, Newell Porcelain, PPC Insulators,
and/or NGK Locke unless otherwise approved by the Owner.
5.7 VOLTAGE TRANSFORMERS
5.7.1 General
Voltage transformers shall be furnished in accordance with this section and as indicated on the
drawings. For 34.5 kV voltage transformers, see Owner’s Specification 0168 included with this
Exhibit.
Voltage transformers shall be furnished in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
5.7.2 Codes and Standards
Voltage transformers furnished under these specifications shall be in accordance with applicable
standards of ANSI, IEEE and NEMA.
All materials and devices shall be in accordance with the applicable requirements of the Federal
"Occupational Safety and Health Standards."
5.7.3 Equipment Required
Voltage transformers furnished shall be complete with all accessories ready for mounting,
assembly, connection, and immediate service.
The quantity and types of voltage transformers furnished shall be as indicated on the drawings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 877 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-10
5.7.4 Ratings
The voltage transformers shall be rated as indicated in Section 5.0 of Owner’s Specification 0168.
Additional voltage transformer ratings for 34.5 kV are provided in the table below.
Table 5-3 Voltage Transformer Ratings
Maximum Continuous Voltage, Vpp 36.5 kV
Continuous Overvoltage, V’pp
(1.1 x Vpp)
38 kV
Nominal Circuit Voltage (phase to ground),
Vpg
19.9 kV
BIL and Full Wave, (Minimum)
1.2 x 50µs
200 kV
Bushing
Minimum Creepage Distance

60 Hz Wet, 10-sec.
Withstand
70 kV
Minimum strike distance 16 inches
Windings
Primary Voltage 20.125 kV
Secondary Voltages (rms) 115/67.08 V
Winding Ratio 175/300:1
Secondary Windings 2
Taps per Winding 3
ANSI Accuracy Class @ Burden 0.15
Thermal Burden
(Per Winding)
1000
Where indicated on the drawings, voltage transformer(s) shall be provided. Primary and secondary
ratings shall be indicated on the specification data sheet(s).
The voltage transformers shall be suitable for operation at the altitude specified on the specification
data sheet(s).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 878 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-11
5.7.5 Construction Details
Each voltage transformer shall be designed and fabricated in accordance with the latest revisions of
the applicable codes and standards.
Voltage transformers shall be furnished with all field connection hardware for field mounting on
supports described in these specifications. All hardware shall be hot-dip galvanized.
Each voltage transformer assembly shall include line connectors and base support assembly.
Voltage transformers rated 230 kV and above shall be equipped with corona shields as required.
The voltage transformers shall be furnished with the following accessories:
Primary terminal - tin-plated bronze
Oil level indicator
Oil drain and filling valves
Four lifting eyes in base
Porcelain color shall be indicated in the specification data sheet(s).
The number of bushings shall be indicated in the specification data sheet(s).
5.7.6 Base Support Assembly
The base support assembly shall be an outdoor, weatherproof enclosure designed and fabricated to
support and house the following equipment:
1 Space heater sized to prevent moisture from condensing on internal components,
with the voltage rating specified in the specification data sheet(s)
1 Grounding terminal, bolted clamp type, for up to 127 mm2 (250 kcmil) copper
ground cable size
1 Terminal box, weatherproof with threaded conduit hubs
1 Voltage transformer network factory adjusted, with main and auxiliary secondary
windings, each rated in accordance with the specification data sheet(s)
5.7.7 Manufacturers
Voltage transformers manufacturer and type shall be indicated on the specification data sheet(s).
5.8 CAPACITOR VOLTAGE TRANSFORMERS
5.8.1 General
Capacitor voltage transformers (CVTs) shall be furnished in accordance with this section, as
indicated on the drawings, and specification data sheet(s) completed by Contractor during detailed
design.
5.8.2 Codes and Standards
All equipment furnished under these specifications shall conform to the applicable standards of
ANSI, IEEE, and NEMA.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 879 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-12
All materials and devices shall be in accordance with the applicable requirements of the Federal
"Occupational Safety and Health Standards."
5.8.3 Equipment Required
CVTs furnished shall be complete with all accessories ready for mounting, assembly, connection,
and immediate service.
The quantity and types of CVTs furnished shall be as indicated on the drawings.
Per Owner, the following CVTs shall be furnished by the Contractor for the Project Collector
Substation:
CVT, Stn Post, 345 kV, 1550 kV
BIL
ABB
5.8.4 Ratings
All CVTs shall be suitable for operation at the altitude and ratings indicated on the specification
data sheet(s).
5.8.5 Details of Construction
Each CVT shall be designed and fabricated in accordance with the latest revisions of the applicable
Codes and Standards.
Each CVT assembly shall include line connectors, coupling capacitor units, and base support
assembly. Each CVT shall be factory adjusted and designed and fabricated in accordance with
NEMA.
Porcelain color shall be indicated in the specification data sheet(s).
Each CVT shall be furnished with a 100 mm (4 in.) wide NEMA 4-hole line terminal pad, unless
otherwise indicated by Owner.
CVTs rated 230 kV and above shall be equipped with corona shields as required.
CVTs shall be furnished with all field connection hardware for field mounting on steel supports
described in these specifications. All hardware shall be hot-dip galvanized.
If required, carrier accessories and wide band filters shall be provided for the CVTs.
The CVTs shall be furnished with the following accessories:
Primary terminal in accordance with the specification data sheet(s).
Four lifting eyes in base.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 880 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-13
5.8.6 Capacitor Units
The coupling capacitor shall be a standard assembly of capacitor units including a lower coupling
unit with such additional upper coupling units as are required to provide the necessary series
capacitance between line and ground.
The lower coupling unit shall include one or more insulating bushings projecting through the
bottom for connection to the voltage transformer and carrier current networks (if required) and
shall be mounted on the base support assembly.
The upper coupling unit shall be standard, arranged for bolting to the lower unit and for supporting
other upper bolt-secured units.
5.8.7 Base Support Assembly
The base support assembly shall be an outdoor, weatherproof welded enclosure designed and
fabricated to support and mount the coupling capacitors specified above and house the following
equipment:
1 CVT factory adjusted, including protective gaps, reactors, potential grounding switch
with external hookswitch operator, carrier grounding switch with external
hookswitch operator (carrier equipped units only), and a transformer with main and
auxiliary secondary windings, each rated in accordance with ANSI C93.2.
1 Space heater sized to prevent moisture from condensing on internal components,
with the voltage rating specified on the specification data sheet(s).
1 Carrier lead-in bushing (carrier equipped CVTs only).
1 Grounding terminal, NEMA 2-hole pad, tinned bronze, bolted clamp type, for up to
127 mm2 (250 kcmil) copper ground cable size.
1 Terminal box, weatherproof with threaded conduit hubs.
5.8.8 Manufacturers
CVTs manufacturer and type shall be indicated on the specification data sheet(s).
5.9 REVENUE METERING
5.9.1 General
Metering units, specifically described as single-phase, oil-filled, combination current/voltage
instrument transformers for revenue metering and outdoor use, shall be furnished in accordance
with this section.
See Owner’s Specification 0167, 0168 and Guideline for Substation Metering Applications included
with this Exhibit for metering instructions. The requirements of the specification data sheet(s) and
drawings shall govern should conflicts occur between them and the written text of these
specifications.
The Contractor shall furnish the metering unit in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 881 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-14
5.9.2 Codes and Standards
All equipment furnished under these specifications shall conform to the latest applicable standards
of ANSI, IEEE, and NEMA, especially those listed below, with exceptions as may be contained in
these specifications:
ANSI C57.13 IEEE Standard Requirements for Instrument Transformers.
NEMA 107 Methods of Measurement of Radio Influence Voltage (RIV) of High
Voltage Apparatus.
ANSI C12.11
American National Standard for Instrument Transformers for
Revenue Metering 10 kV BIL through 1050 kV BIL (0.6 kV NSV
Through 230 kV NSV).
All materials and devices shall be in accordance with the applicable requirements of the Federal
"Occupational Safety and Health Standards."
5.9.3 Equipment Required
The metering units furnished shall be complete with all accessories ready for mounting, assembly,
connection, and immediate service.
The quantity and types of metering units furnished shall be indicated on the drawings, and on the
specification data sheet(s).
5.9.4 Ratings and Metering Requirements
The metering units shall be suitable for operation at the altitude and ratings indicated on the
specification data sheet(s).
The metering requirements shall be:
Balance Area metering – SEL 735
Customer Billing metering – SEL 735
Feeder metering – metering data from relay/control metering functions (preferred) or SEL
735
5.9.5 Construction Details
Each metering unit shall be designed and fabricated in accordance with the latest revisions of the
applicable Codes and Standards.
Metering units shall be single-pole type and a hermetically sealed, oil-filled wound device. Metering
unit assemblies shall include line connectors and base support assemblies.
Metering units shall be furnished with all hot-dip galvanized hardware to accommodate field
mounting on steel supports with a ½ inch thick plate.
Metering units rated 230 kV and above shall be equipped with corona shields as required.
Porcelain color shall be indicted in the specification data sheet(s).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 882 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-15
The metering units shall be furnished with the following accessories:
Primary terminals
Four lifting eyes in base.
Oil level indicator.
Oil drain and filling valves.
Lifting Sling(s) (one set per order)
5.9.6 Base Support Assembly
The base support assembly shall be an outdoor, weatherproof welded steel enclosure designed and
fabricated to support and mount the metering units specified above and house the following
equipment:
1 Space heater sized to prevent moisture from condensing on internal components,
with the voltage rating specified in the specification data sheet(s).
1 Grounding terminal, NEMA 2-hole pad, bolted clamp type, for up to 127 mm2
(250 kcmil) copper ground cable size.
1 Voltage transformer network factory adjusted, with main and auxiliary secondary
windings, each rated in accordance with the specification data sheet(s).
1 PT terminal box, weatherproof with (3) 1-1/2 inch standard threaded conduit hubs.
1 CT terminal box, weatherproof with (3) 1-1/2 inch standard threaded conduit hubs.
4 1” lifting eyebolts for a four-point lifting sling arrangement.
5.9.7 Grounding
The neutral terminal of the voltage transformer shall exit the tank via a 5kV insulated bushing and
be grounded by means of a removable copper strap to a NEMA 2-hole pad.
5.9.8 Terminals
The primary terminals shall be aluminum or tin-plated copper in a NEMA hole-pattern that meets
the continuous current carrying requirements. The secondary terminals shall be #10-32 threaded
studs. The CT secondary terminals shall be a sliding CT shorting link type.
5.9.9 Paint
Exterior metallic non-current carrying surfaces and parts shall be either corrosion resistant
material or painted with a weather-resistant paint system consisting of one primer and two ANSI-
70 gray finish coats. As an option, for high-corrosion areas, special corrosion-resistant finishes
(e.g., zinc-rich, paint, or stainless steel tank) shall be available.
5.9.10 Insulating Oil
The nameplate shall be of stainless steel material and shall indicate that the dielectric fluid is free of
polychlorinated biphenyls by the inscription: “CONTAINS NO PCB AT TIME OF MANUFACTURE”.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 883 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-16
5.9.11 Lead Markings
Metering unit primary and secondary lead markings shall meet established IEEE, ANSI, industry
standard, and/or Owner conventions.
5.9.12 Accessories
Metering units shall be furnished with a magnetic oil level gauge readable from ground level. The
oil drain and filling provisions shall be provided with a ½” brass ball drain valve with plug and a 1-
inch oil filling opening with nitrogen valve.
Metering units shall be furnished with a primary bypass protector, and four 7/8” x 2-3/8” base
mounting slots.
5.9.13 Testing
Before shipment, each transformer shall be subjected to testing as prescribed by NEMA Standard
107 and ANSI C57.13 and other tests as follows:
Applied voltage test for primary and secondary winding withstand to ground.
Induced voltage test for proper turn-to-turn insulation.
Accuracy test for ratio correction factor and phase-angle verification to
confirm required metering accuracy per ANSI C57.13.
Leak test to assure integrity of gaskets and seals.
Partial discharge test may be done in conjunction with applied voltage testing to
assure proper line-to-ground withstand.
Turns ratio test
Insulation power factor test
Polarity test
CT secondary excitation test
These tests shall be submitted on a formal certified test report, with the required number of copies
to be submitted to the Owner at the time of delivery of the units.
5.9.14 Manufacturers
Metering units manufacturer and type shall be indicated on the specification data sheet(s).
5.10 SURGE ARRESTERS
5.10.1 General
Surge arresters for outdoor use shall be furnished in accordance with this section.
The Contractor shall furnish surge arresters in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
Owner reserves the right to be present during factory testing. Contractor shall give Owner a
minimum thirty (30) days’ notice so that personnel can make proper arrangements. Presence at
factory testing shall be made available to Owner at no additional cost to Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 884 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-17
5.10.2 Codes and Standards
All equipment furnished under these specifications shall conform to the applicable standards of
ANSI, IEEE, and NEMA.
The surge arresters shall be designed, fabricated, and tested in accordance with ANSI C62.11 and
these specifications
5.10.3 Equipment Required
Surge arresters furnished shall be complete with all accessories ready for immediate service.
The quantity and types of surge arresters furnished shall be indicated on the specification data
sheet(s). Per Owner, the following surge arresters shall be furnished by the Contractor for the
Project Collector Substation:
Table 5-4 Surge Arresters
Description Vendors
345kV Arrester, Stn Cl, 220kV MCOV,
Polymer, MOV, 276kV Duty Rating
Hubbell Power Systems, Inc.
34.5kV Arrester, Stn Cl, 24.4kV
MCOV, Polymer, MOV, 30kV Duty
Rating, Std Base Mtg, Metal Top
Cooper Industries
Hubbell Power Systems, Inc.
34.5 Arrester, Stn Cl, 29kV MCOV,
Polymer, MOV, 36kV Duty Rating,
10 in. B.C., Sky Gray, Metal Top,
Without Brackets
ABB Power T&D Company,
Inc.
ABB Power T&D Company,
Inc.
ABB Power T&D Company,
Inc.
Cooper Industries
General Electric
Magnetek
Hubbell Power Systems, Inc.
5.10.4 Ratings
Surge arresters shall conform to the requirements indicated by the temporary overvoltage (TOV)
study per Exhibit A-3.4.
The arresters shall be suitable for operation at the altitude indicated on the specification data
sheet(s).
5.10.5 Construction Details
The surge arresters shall be metal oxide type with polymer housing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 885 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-18
The line terminal shall be indicated on the specification data sheet(s).
Surge arresters shall be corona free when energized at the specified maximum operating system
voltage.
Surge arresters shall be furnished with all hot-dip galvanized hardware for field mounting on steel
supports.
The arresters shall have a NEMA 2-hole ground connector suitable for connection up to a 250 kcmil
(127 mm2) copper conductor.
The surge arresters shall be furnished with all mounting and connection hardware and be installed
ready for service.
5.11 POWER CIRCUIT BREAKERS
5.11.1 General
These specifications cover furnishing of outdoor circuit breaker equipment, materials, and
accessories indicated on the specification data sheet(s) completed by Contractor during detailed
design. Circuit breakers furnished shall be complete with all accessories ready for mounting,
assembly, connection, and immediate service.
The requirements of the Owner’s Specification 0135 and 0141, the electrical control scheme, and
specification data sheet(s) completed by Contractor during detailed design shall govern should
conflicts occur between them and the written text of these specifications.
5.11.2 Codes and Standards
All equipment provided under this specification shall conform to the applicable standards of ANSI,
ASME, ASTM, IEC, IEEE, and NEMA. All materials and devices shall be in accordance with the
applicable requirements of the Federal "Occupational Safety and Health Standards."
The circuit breakers shall be designed, fabricated, and tested in accordance with ANSI C37 Series,
NEMA SG 4, and these specifications.
5.11.3 Equipment Required
The Contractor shall furnish circuit breakers and accessories as indicated on the drawings and
specified herein.
The quantities of circuit breakers furnished shall be as indicated on the drawings. See Appendix for
Approved Vendor List.
5.11.4 Construction Details
Circuit breakers shall include preinsertion closing resistors, if applicable, current transformers,
grading capacitors, puffer interrupters, operating mechanisms, cabinets, support framework, and
other components to be erected and tested as a complete breaker at the jobsite. EHV circuit
breaker(s) shall be single pressure SF6 gas type.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 886 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-19
Each circuit breaker pole shall include separate stored energy operating mechanisms. Each breaker
shall be mechanically and electrically suitable for single-pole tripping and reclosing, and electrically
ganged 3-pole tripping and reclosing.
5.11.5 Enclosures
The operating mechanism and necessary auxiliary devices shall be furnished in weatherproof, dust
resistant enclosures, mounted on the breaker frame.
One breaker control cabinet will provide the internal wiring for the breaker system and the
interface between the Owner's control and power circuits to the breaker. The control cabinet shall
allow sufficient space for termination of control and power circuits.
Enclosure door handles shall include provisions for padlocking.
All control switches, push buttons, fuses, shorting type terminal blocks, and other devices requiring
Owner interface shall be mounted at a height and location to be easily accessible. Such devices shall
be located less than 1,500 mm (5 feet) but more than 600 mm (2 feet) above the top of the
foundation.
5.11.6 Operating Mechanism
Each operating mechanism shall consist of a pneumatic, hydraulic, or spring charged stored energy
mechanism. Each operating mechanism shall include all auxiliary devices and other accessories for
the operating mechanism furnished. Each mechanism, regardless of the operating medium utilized,
shall be electrically trip-free and shall include anti-pump auxiliary relays and devices.
Each operating mechanism shall include a mechanical position indicator. The indicator shall
provide a positive indication of the breaker or breaker pole position by direct mechanical coupling
to the operating rod. The indicator shall consist of a suitable sign utilizing green with the word
"OPEN" when in the open position, and red with the word "CLOSED" when in the closed position.
Each operating mechanism shall include dual trip coils. The trip coils shall be electrically and
magnetically independent. The trip coils shall be located such that heat or fire damage to one trip
coil shall not preclude the proper operation of the other trip coil. The trip coils shall be suitable for
parallel trip coil operation. Trip coils shall not operate with currents less than 1 ampere DC. Each
trip coil shall be wired to allow independent activation and test.
Each separate pneumatic or hydraulic operating mechanism shall include two alarm contacts which
close to alarm low air or oil/nitrogen gas pressure. A low-pressure cutout (with two alarm
contacts) shall be provided to prevent initiating a close signal should the operating pressure be
below the minimum required for a complete close-open operation. The low-pressure cutout device
shall not prevent a complete close-open operation should pressure drop after the close-open
operation is initiated.
Each stored energy operating mechanism shall operate according to the duty cycle specified on the
specification data sheet(s) without auxiliary power available. Each operating mechanism shall store
sufficient energy for three close-open operations without the need for running pumps or
compressors. If this requirement cannot be met, the breaker shall include an automatic throwover
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 887 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-20
scheme to alternately supply each mechanism motor from the Owner's DC station service system
should normal auxiliary power be lost. The Contractor, in such case, shall clearly state the
requirement for emergency DC control power and the duty cycle available without auxiliary power.
The stored energy mechanism recharging time to full operating pressure or condition from a
completely discharged condition shall not exceed 1 hour.
Each operating mechanism shall include spare auxiliary switch contacts for use by the Owner. The
spare auxiliary switch contacts shall be mechanically linked to the mechanism operating rod and
shall be field adjustable as either "a" or "b" contacts.
One permissive control switch (69 device) per breaker pole shall be furnished. It shall be a two-
position, manually operated switch that in one position permits the closing of the pole and in the
other position prevents the circuit breaker pole from being operated. It shall be mechanically
interlocked with a manual trip lever that is accessible from outside the pole operator housing so
that, if the breaker is tripped by this lever, the 69 device must be manually reset before the breaker
pole can again be operated. The manual trip device on each pole shall electrically trip all three
poles, with the 69 device on all three poles being moved to the lockout position. The manual trip
lever shall be painted red, shall have a guard to prevent accidental activation, and shall have a
plastic engraved label worded "Emergency Trip".
Each breaker close control scheme shall include a field adjustable 0.1 to 1 second time delay pickup
close relay, factory preset to provide a 20 cycle automatic reclose time (including breaker close
time) after energization of the close circuit.
5.11.7 Auxiliary Power Supply
The Contractor will furnish one auxiliary power supply to each circuit breaker at the voltage
specified on the specification data sheet(s). If the Contractor chooses to furnish motors or other
auxiliary equipment designed to operate at a different voltage from the specified auxiliary power
supply, they shall furnish all equipment required to transform the voltage of auxiliary power to the
design voltage of the equipment furnished. The Contractor shall provide suitable branch circuit
protection.
5.11.8 Auxiliary Power and Control Power Disconnects
Two power supply disconnects and four knife switches per breaker shall be provided. The close
circuit and auxiliary power supply shall be fed from individual disconnects. One knife switch shall
be wired in series with each of the disconnects feeding the auxiliary power supply and close coil.
The two remaining knife switches shall feed trip coils one and two.
5.11.9 SF6 Gas System
Temperature compensated pressure switches or gas density switches shall be provided to monitor
the SF6 gas density in each breaker pole. Alternately, pressure differential switches may be used to
measure the differential pressure of the SF6 gas between poles.
A drop in SF6 gas density, in any pole, shall initiate a low SF6 gas density alarm. A further drop in
density shall initiate a trip or block any further breaker operation.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 888 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-21
The breaker shall be furnished with sufficient SF6 gas to fill, test, and energize each breaker. The
SF6 shall be free of moisture and impurities. SF6/nitrogen gas mixtures shall not be supplied.
The SF6 to air seals and gaskets shall prevent SF6 gas leakage in excess of 2 percent per year of gas
weight, through the duration of the guarantee period. Corrosive arc products due to moisture
infiltration shall be prevented to the maximum extent possible through the use of desiccant
moisture absorbing chambers and an arc product filter.
5.11.10 Arc Containment Chamber
The arc containment chamber (the breaker tank on dead-tank breakers or the puffer interrupter on
live-tank breakers) shall be designed to withstand pressure buildup if the breaker fails to interrupt
full rated fault current. The use of a pressure relief device is acceptable and shall be so stated in the
specification data sheet(s).
5.11.11 Space Heaters
Each operating mechanism and control enclosure shall be provided with space heaters to prevent
condensation of moisture within the enclosure. Space heater capacity shall be as required to
maintain the enclosure internal temperature above the dew point. The heaters shall be spaced
away and thermally insulated from any devices or painted surfaces.
Space heaters shall be sized to provide adequate heating when energized at the applied voltage
indicated on the specification data sheet(s). The Contractor shall provide all space heater wiring
integral to the breaker and suitable branch circuit protection.
Space heaters shall be controlled by an adjustable thermostat, factory set to close (ON) at 29° C
(85° F) and open (OFF) at 35° C (95° F).
5.11.12 Current Transformers
Current transformers shall be provided as specified in accordance with NEMA SG 4 - Section 3.
Current transformers shall be bushing type for dead-tank breakers or free-standing for live-tank
breakers, with fully distributed windings for relaying service. They shall be five lead multi-ratio
unless otherwise indicated by Owner.
The energized parts of current transformers furnished separately with live tank circuit breakers
shall be made of corrosion-resistant material, such as galvanized or stainless steel.
5.11.13 Insulating Oil
Free-standing current transformers supplied with live-tank circuit breakers shall be shipped
completely filled with insulating oil. Insulating oil supplied shall be polychlorinated biphenyls
(PCBs) free oil and is not to be FR3 fluid. Insulating oil sampling and test procedures at the factory
shall conform to the requirements of ASTM D117.
The insulating oil shall meet all the requirements as defined by ANSI/ASTM standards, shall be
chemically stable, free from acidity or other corrosive ingredients, shall possess high dielectric
strength, and shall test at least 28 kV when tested upon receipt at the job delivery point. The Owner
will test samples of the oil furnished. If the dielectric test strength of the oil tests less than 28 kV
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 889 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-22
when tested in accordance with the procedures of ASTM D1816 using a 1 mm (0.040 inch) gap or
the oil contains more than 10 ppm water when tested in accordance with the procedures of ASTM
D1533 (Karl Fischer method), then the current transformer insulation system shall be
unacceptable. The Contractor shall provide all labor, supervision, material, and equipment to
restore the oil to the quality specified.
5.11.14 Oil Preservation System
Separate oil-filled current transformers shall be supplied with a sealed oil preservation system
using a bladder to absorb oil volume changes due to temperature. Each current transformer shall
include an oil sampling valve to allow small oil samples to be taken for test.
5.11.15 Ground Fault Current Transformers
If required, ground fault current transformers shall be provided and specified on the specification
data sheet(s). Each separate live-tank breaker interrupter support insulator stack and each
insulator stack for oil-filled current transformers shall be supplied with ground fault current
transformers encompassing the insulator stack. The ground fault current transformer shall be five
lead, multi-ratio type with ratios and relaying accuracy as specified.
5.11.16 Current Transformer Secondary Terminations
All secondary leads of each current transformer and ground fault current transformer, including all
taps of each transformer, shall be wired to shorting type terminal blocks located in either the circuit
breaker control cabinet (dead-tank type), or for live-tank breakers, a weatherproof current
transformer terminal cabinet located on the center current transformer support structure. Each set
of secondary winding taps shall terminate on a 6-pole shorting block, with the sixth pole
permanently connected to the shorting bar and to ground. Shorting terminal blocks shall be
arranged such that the three shorting terminal blocks associated with three secondary windings, on
different poles, but comparably located, shall be grouped together. There shall be no splices in the
current transformer leads. All current transformer secondary wiring shall be furnished by the
Contractor, cut to length and pre-terminated. All current transformer secondary wiring shall be
shielded copper cable, 6 mm2 (10 AWG) minimum. Complete wiring and connection diagrams shall
be furnished, with terminal blocks arranged in the same configuration as physically arranged in
cabinets or terminal boxes.
5.11.17 Assembly and Configuration
The circuit breakers shall be factory assembled into integral shipping sections as complete as
possible to minimize assembly requirements at the site. A structural steel frame, common to all
breaker components on a pole except free-standing current transformers, shall be furnished. Each
free-standing current transformer shall include a structural steel support frame. The frames
furnished shall maintain a 2,750 mm (9'-0") minimum height from the bottom of porcelain to grade.
Each pole shall include an integral frame mounted operator mechanism enclosure. All wiring,
conduit, and pneumatic or hydraulic piping from individual interrupter units to the operator
mechanism enclosure on a pole shall be furnished by the Contractor.
All wiring, raceway, and pneumatic or hydraulic piping from individual pole operator mechanism
enclosures to the breaker control cabinet, or from separately mounted current transformers to the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 890 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-23
current transformer terminal cabinet shall be furnished by the Contractor. The piping and wiring
shall be enclosed in Contractor-furnished aboveground metal raceway. The bottom of the raceway,
between poles, shall be a minimum of 2,450 mm (8'-0") above top of foundation.
5.11.18 Bushings
All bushings shall be rated in accordance with ANSI and NEMA standards and as specified.
Condenser type bushings shall have a capacitance tap suitable for use with a potential device. The
tap shall also be suitable for power factor testing.
5.11.19 Auxiliary Power and Control Circuits
Breaker auxiliary power, control, and alarm circuits shall be provided with terminal blocks for
connection to external circuits. The terminal blocks shall have circuit identification and shall be
located in the control cabinet to provide external circuit connections from a common raceway
entrance.
5.11.20 Pre-insertion Closing Resistors (If Applicable)
The circuit breakers shall include pre-insertion closing resistors as necessary to limit the line
closing switching surge factor in accordance with the standard conditions defined in ANSI/IEEE
C37.04 and ANSI C37.06. Pre-insertion time shall be approximately 8 milliseconds. Closing resistor
heating shall not limit the duty cycle specified.
5.11.21 Grading Capacitors
Grading capacitors shall be furnished as required to limit switching surge voltage across the
breaker contacts during interruption.
5.11.22 Spare Parts
The Contractor shall include a list of spare parts for each circuit breaker and an itemized list of
spare parts that are recommended, but not included for each circuit breaker. The second list shall
indicate the quantity recommended per circuit breaker, and the unit price each.
One complete set of spare gaskets and O-rings shall be furnished. The set shall contain all gaskets
and O-rings needed for one complete 3-pole breaker including operating mechanism seals, SF6 gas-
to-air seals, and seals used in separately mounted current transformers.
5.11.23 Factory Tests
Each circuit breaker shall undergo the production tests as listed and described in ANSI C37.09. The
Owner may require that each circuit breaker be fully assembled at the factory, and remain fully
assembled during production testing.
Certified production test reports for each circuit breaker furnished shall be submitted to the Owner
within 10 days after completion of the tests. Testing shall include accuracy tests of all current
transformers in accordance with ANSI C57.13.
In addition, representative design test reports for the circuit breakers proposed shall be furnished.
Design tests shall have been conducted for the specific rated circuit breakers proposed.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 891 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-24
5.11.24 Preparation for Breakers for Shipment
Circuit breaker components shall be clean, dry, and sealed when shipped from the factory. Each
component not shipped with SF6 gas shall contain a packaged moisture absorbing chemical as
required to keep it moisture free during shipment. Tanks, interrupters, support insulators, or other
SF6 containers which are found to contain moisture when received at the jobsite shall be dried, and
moisture damage shall be repaired at the Contractor's expense.
Complete instructions outlining the Contractor’s recommended procedures for inspection upon
receipt at the Project Collector Substation site, moisture free maintenance during storage, and
preparation for SF6 filling shall accompany each breaker. These instructions shall be shipped inside
the breaker control cabinet.
Manufacturer shall test each pole/pole section for moisture content prior to shipment and shall
record and attach label to each tested item.
5.12 MAIN POWER TRANSFORMER (SECTIONS AS APPLICABLE)
5.12.1 General
5.12.1.1 Scope of Supply
The 345/34.5 kV main power transformer(s) to be used in the Project Collector Substation shall be
in accordance with this specification. The Subcontractors quoting for the transformer must provide
a quote which is in strict conformance with this specification. Contractor is responsible for final
transformer sizing (MVA ratings). If two main power transformers are used, they shall be of like
construction and brand.
5.12.1.2 Performance and Design Requirements
Performance and design requirements for the power transformers shall be indicated on the
specification data sheet(s) completed by Contractor during detailed design.
5.12.2 Codes and Standards
Work performed under these specifications shall be done in accordance with the following codes
and standards. Unless otherwise specified, the applicable governing edition and addenda to be used
for all references to codes or standards specified herein shall be interpreted to be the
jurisdictionally approved edition and addenda. If a code or standard is not jurisdictionally
mandated, then the current edition and addenda in effect at the date of this document shall apply.
These references shall govern the work except where they conflict with the Owner’s specification.
In case of conflict, the latter shall govern to the extent of such difference:
Work
Transformer IEEE C57 Series and all reference documents
All materials and devices shall be in accordance with the applicable requirements of state and local
safety standards. ANSI, ASTM, NEC, NESC and NEMA standards shall be applicable as well.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 892 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-25
5.12.3 Products
5.12.3.1 General
This specification is intended for procurement of outdoor oil-immersed power transformers. The
standard design shall be in accordance with accepted industry practices for electrical power
generation.
5.12.3.2 Loading and Ratings
The current carrying capability shall be limited only by the capacity of the core and coils and not by
other components such as winding leads, bushings, and tap changers.
The transformer ratings and operating conditions shall be indicated in the specification data
sheet(s) completed by Contractor during detailed design.
5.12.3.3 Load Rejection
The main power transformer may be subjected to load rejection conditions that result in an
abnormally high voltage from the collection system. Therefore, it shall be designed to withstand, as
a minimum, the resulting stresses with 1.4 times the rated voltage for 5 seconds, applied at the
transformer terminals to which the collection system is to be connected.
5.12.3.4 Through-Fault Withstand
Transformers furnished under these specifications shall be capable of withstanding, without
damage, the mechanical and thermal stresses caused by short-circuit currents limited only by the
impedance of the transformer. System impedance shall be considered equal to zero. System prefault
voltage shall be equal to the voltage rating of the maximum tap or 1.05 times the principal tap,
whichever is greater.
5.12.4 Mechanical Construction
5.12.4.1 Tank
Tank shall be of welded steel plate construction. The complete tank shall be designed to withstand
vacuum and pressure in accordance with IEC 60076 or full vacuum and at least 125 percent of the
maximum operating pressure of the oil preservation system furnished. The tank cover shall be
sloped to assist with the flow of gas bubbles to the gas detector piping and/or relay. Field
installation shall not require any welding. The base shall allow skidding or moving on rollers in any
direction. Lifting lugs and jacking pads shall be provided for lifting and jacking the completely
assembled transformer. The jacking pads must be located near each of the four corners. The tank
shall be designed so that all current transformers can be removed easily without removing the main
transformer tank cover. Holes with automatic drain valves shall be provided at the low point of the
bus duct flange enclosures so that condensate and water will not accumulate. The transformer tank
base shall be engraved or a placard shall be installed to clearly identify the dimensional centerline
near the base of the tank on all four sides. If abbreviated, “C.L.” shall be used to signify dimensional
centerline. The tank shall be marked on a minimum of two adjacent sides to show center of gravity.
If abbreviated, “C.G.” shall be used to signify center of gravity.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 893 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-26
5.12.4.2 Drawings, Nameplates and Test Reports
Drawings, nameplates, test reports, and correspondence must use the English language and English
units of measure with the metric equivalent in parentheses. The following minimum information
must be shown on the transformer outline drawing:
All multiple quantities.
Weights.
Paint color.
Footprint of base.
Dimensional centerline. Location of Owner connections (bus duct, etc.) shall be referenced
to centerline on all outline drawings.
Center of gravity (shown on two views).
o Valve sizes and types.
o 77° F (25º C) oil level and low oil level.
o Location and detail sketch of ground pads.
o Location, cutout size, and open door dimensions of all cabinets.
o Bushing and arrester ratings, stud diameters with thread information, and space
arrangements with hole patterns.
o Location, hole sizes, and detail sketch of jacking, lifting, and pulling facilities. A
statement should be made describing which lugs are for lifting the transformer when
completely assembled and full of oil.
o Distance clearances around the envelope of the transformer that the Owner must meet
so as not to interfere with operation or maintenance of the transformer and its
accessories. Some examples are cooling control cabinet swing door distance, pullout of
radiator banks maintenance distances, etc.
5.12.4.3 Core and Coils
Nuts, bolts, and clamps of the core assembly shall be provided with positive locking devices to
prevent loosening. For core form transformers, the complete core and coil assembly shall be
removable from the tank for repairs. The core shall be securely grounded to the tank. For core form
transformers, the core ground connection shall be detachable and made in an externally located
terminal box, accessible without requiring entry into the main tank.
The outermost core steel packets and tie bars/plates (if located internal to the windings) shall be
divided as needed so that the maximum operating temperature does not exceed the manufacturer’s
standard practice. In no case shall tie bar sections be wider than 3 inches (75 mm) or core packet
sections wider than 4-1/2 inches (115 mm). If slit core packets and/or tie bars/plates are used as
described above, and tie bars/plates located adjacent to the core packet, insulation material
provided between the bars/plates and the core packets shall be a high temperature, non-cellulosic
material such as Nomex.
Windings shall be fixed under pressure with single piece clamping plate, located at the top of the
winding and either a single piece or multi-piece clamp located at the bottom of each set of windings.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 894 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-27
These clamping plates shall be properly sized and braced for short circuit forces, made from
suitable materials, and locked into place with suitable means. Core form windings shall be circular.
All windings shall be copper. When a continuously transposed conductor is used, it shall be epoxy
bonded.
All windings shall be self-supporting for inward (buckling) and outward (hoop) forces. Windings
shall not rely on the core assembly for support to resist inward radial short-circuit forces. Winding
capability to resist inward radial forces shall be based on the ability of the conductor to resist forces
in a "free-buckling" mode. When the coils use paper insulation, it shall be thermally upgraded paper
insulation. Proof of paper quality, testing and specifications shall be furnished upon request and
shall be subject to acceptance/approval by the Owner.
Geomagnetic Disturbance Withstand
Transformers supplied under this specification shall be designed and evaluated to withstand a
geomagnetic disturbance in accordance with the latest revision of C57.163, “IEEE Guide for
Establishing Power Transformer Capability while under Geomagnetic Disturbances”. Unless specific
user data is supplied herein, the Geomagnetically Induced Current (GIC) signature included within
C57.163, shall be used. The manufacturer shall demonstrate by calculation that recommended
temperature limits for winding hot spots and tie-plate hotspots shown in the guide are not
exceeded under the GIC signature specified (plot temperature rise response verses time during the
GIC event). Such calculations shall be produced and submitted in a format acceptable for submittal
to NERC.
5.12.4.4 De-energized Tap Changer (If Applicable)
The operating handle shall have provisions for padlocking and shall be located no more than 60
inches (1,500 mm) above ground level. The tap position indicator shall be clearly visible from
ground level.
5.12.4.5 On Load Tap Changer (OLTC) (If Applicable)
The on load tap changer shall be furnished in accordance with Owner’s Specification 0138 included
with this Exhibit and the additional specifications below. If conflicts exist, the Owner’s
specifications shall govern. Acceptable Contractor alternatives to Specification 0138 and the
additional specifications below shall be submitted to the Owner for approval.
When an on load tap changer is specified, it shall be furnished with the arcing contacts housed in
separate compartments, designed to prevent any interchange of oil between the compartment and
the main tank. Removable bolted covers shall be provided for access to the switch compartment
without opening the main tank or lowering the oil in the main tank. A drain valve with sampling
device shall be located in the bottom of each oil-filled compartment to provide complete oil
drainage.
A magnetic liquid level gauge with a vertical face shall be mounted on the side of the oil-filled
compartment. A mechanical pressure relief device shall be mounted on the top of the oil-filled
compartment. The tap changer shall provide full rated kVA on taps above and below rated voltage.
The tap changer shall be designed to provide at least 500,000 operations at the maximum
nameplate current rating before contact replacement.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 895 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-28
When a current limiting series transformer is provided, it must have circular windings and meet all
the same criteria as the main core and coil. Series transformers and any internal surge suppression
devices must be identified to the Owner. Equipment for the automatic and manual control of the
LTC shall be furnished in a weatherproof compartment mounted adjacent to the tap changer
compartment. Access and operation at ground level shall be provided. The following equipment
shall be furnished, as necessary, to provide the specified LTC controls:
Operating mechanism with motor drive.
Weatherproof compartment with convenience outlet, anti-condensation heater, and light
with switches.
Mechanically operated limit switches and stops to prevent overtravel of the drive
mechanism beyond the maximum raise and lower positions.
Local position indicator.
Operations counter.
RAISE-LOWER selector switch for manual control.
AUTOMATIC-OFF-MANUAL selector switch.
Voltage testing terminals.
Line drop compensator with adjustable resistance and reactive elements.
Current transformers for line drop compensation.
Voltage regulating relay.
Time-delay relays for first step of a tap position change.
A hand crank for manual operation, with electrical interlock to prevent operation of the
motor while the hand crank is being used.
REMOTE-LOCAL selector switch.
Remote tap position indicator, selsyn type, for mounting on Owner’s remote control panel.
Any additional equipment needed for remote/local or automatic/manual control
5.12.4.6 Insulating Oil
Unless otherwise specified, insulating oil for complete filling shall be furnished with each
transformer in accordance with Owner’s Specification 0100 included with this Exhibit and the
additional specifications below. The oil shall be polychlorinated biphenyls (PCBs) free, cannot be
FR3 fluid, and shall be Type II, inhibited with 0.15 percent to 0.30 percent by weight of DBPC
(2-6 ditertiary butyl paracresol). The transformer main nameplate shall state that the oil is
inhibited and PCB-free at the time of manufacture.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 896 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-29
The electrical insulating mineral oil to be permanently installed in all transformers furnished under
these specifications shall be new, unused oil. The oil shall be tested in accordance with ASTM D-
1275, Method B and to Doble CCD or IEC/CIGRE CCD, and shall be deemed "non-corrosive"
according to criteria stated in these documents. Also, a Dibenzyl Disulfide (DBDS) test shall be
performed and shall yield results less than 20 mg/kg by weight. Results of these oil tests shall be
submitted to the Owner at least 15 days before the oil is dispatched to the Project Collector
Substation site (whether in the transformer body or by separate transport means). In addition to
meeting the requirements of the applicable national and international industry standards, the oil
shall contain less than 25 ppm water and shall test at least 30 kV breakdown strength upon receipt
at the delivery point.
Oil shall be shipped by bulk container, such as a tanker or large flexible tank, designed specifically
for such use. Shipment in drums is not allowed unless approved by the Owner. Each shipping
container shall have its oil tested for dielectric integrity prior to being installed in the transformer.
When shipping weight permits, the transformer shall be shipped oil-filled. If the transformer is
shipped without oil, then it shall be shipped pressurized with nitrogen. A pressure vacuum gauge
and suitable shutoff valve shall be provided to monitor or add nitrogen during shipment.
Each transformer and its associated equipment shall be designed and delivered capable of full
vacuum filling in the field. The manufacturer's recommended assembly and filling procedures shall
be submitted for Owner’s review prior to shipment.
5.12.4.7 Oil Preservation System
The system shall be designed with an oil temperature alarm range of -13° F to 248° F (-25° C to
120° C). Unless specified, the Contractor will have the option of furnishing a sealed tank system, an
automatically maintained inert gas pressure system, or a sealed bladder conservator system. Based
on this choice, the appropriate following paragraph shall be applied:
Sealed Tank System
The system shall include a pressure vacuum gauge and a pressure relief device designed to seal the
interior of the transformer from the atmosphere and hold the gas plus oil volume constant within
the range of 10 psi (0.70 kg/cm2) positive to 8 psi (56 kg/cm2) negative.
Inert Gas Pressure System
An alarm device with alarm contacts for remote indication of low gas supply shall be furnished.
Valves shall be provided to permit purging the gas space and testing the seal on the tank by
admitting dry nitrogen under pressure. The gas control equipment, including adequate space for
nitrogen bottles, shall be protected by an easily accessible weatherproof enclosure mounted on the
transformer. Sufficient nitrogen gas shall be furnished for the initial flushing, filling, and operation.
If necessary, used gas cylinders may be returned to the manufacturer at their expense.
Sealed Bladder Conservator System
The system shall prevent air and moisture from coming in contact with the oil through the use of a
flexible rubber air cell in the conservator tank. A positive oil pressure must be maintained on all
gaskets above the tank cover. A gas detector relay system shall be provided that collects
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 897 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-30
accumulated gases at the high point of the cover. The system shall include a gauge alarm contact
and a gas sampling valve at ground level. When possible, the conservator tank shall be located so as
to not be in proximity to isolated phase bus duct, such as in segments where LV bushings are not
located. If such a location is not practical, then the conservator tank and its various piping and
conduit connections shall be electrically insulated from the main tank, except the main oil pipe from
the conservator to the main tank shall be securely grounded and bonded to the main tank to
provide a single point of ground for the conservator tank. The intent of this single point ground
system is to prevent circulating currents in the conservator tank and mount brackets induced by
stray flux from the isolated phase bus system.
5.12.4.8 Oil Containment
The Project Collector Substation will need to be designed and constructed to ensure compliance
with the regulations in 40 CFR Part 112- Oil Pollution Prevention. With respect to minimum design
requirements for meeting 40 CFR 112, Owner specifies a concrete containment structure/pit for
meeting Spill Prevention, Control and Countermeasure (SPCC) secondary containment
requirements for the main power transformer(s) specified in section 12.1.1 of this document. The
concrete secondary containment structures need to be designed to meet SPCC requirements,
including allowing necessary freeboard for precipitation. The minimum containment volume shall
be equivalent to 110% of the total transformer oil volume plus the total volume of water entering
the containment basin from a 6-inch storm event. If any of the above requirements or regulations
differ, the more stringent shall apply. The concrete containment structure’s dimensions and
orientation must be such to ensure a breach in oil from the transformer will be completely held
inside the containment.
5.12.4.9 Bushings
Transformer bushings above 15 kV class shall be oil-filled, using either the transformer's oil as the
cooling and insulating fluid or the bushing's own self-contained supply of oil. Bushings mounted in
a vertical position shall have a self-contained oil supply. Oil-filled bushings shall have a sight gauge
or other means to indicate oil level.
Bushings above 150 kV BIL shall be PCORE or ABB condenser type, with capacitance graded layers
of insulating material for the purpose of controlling the distribution of the electric field, and shall be
equipped with a capacitance or power factor test tap. If the bushing is mounted in a metal enclosed
bus duct, the external terminal shall be designed for connection to a bus operating at 221° F
(105° C).
Gaskets, oil expansion areas, and paper insulation used in the assembly of the bushings shall be
suitable for the required operating temperatures. All bushings shall be constructed by using wet
process porcelain materials with a homogeneous surface. Porcelain parts of each bushing rated
below 450 kV BIL shall be one piece. For "draw lead" type bushings, the transformer outline
drawing shall indicate the size, number of strands, and material of the bushing draw lead. Minimum
creep distances shall be as specified using millimeters per rated system voltage, mm/kVL-L.
Outline drawings of each bushing shall be included with the approved transformer vendor
drawings. Instruction manuals for each style of bushing shall be included with the transformer
instruction manuals.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 898 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-31
5.12.4.10 Terminals
Each bushing with a stud type connection shall be furnished with a removable stud-to-pad four-
hole terminal of sufficient size to continuously carry the maximum current. Aluminum-to-copper
bimetallic transition plates shall be furnished. At 230 kV and above, the terminals shall be corona
free. System line connections will first connect to the associated surge arrester, if specified.
5.12.4.11 Terminations to the Transformer
If a termination compartment is specified, then an air termination compartment should be provided
on the tank wall to allow for cable entry from below. If a termination flange is specified, then a
bolted flange connection to cable, non-segregated, segregated, or isolated phase bus duct shall be
provided as specified. A short flange should be located close to the tank, and a long flange should be
located, via a throat, at the end of the bushing top terminal.
Termination flanges shall be installed to within +/- 1/8” (3 mm) tolerance of the location indicated
on the transformer outline drawing. Horizontal flange surfaces shall be level to within 1/8” (3 mm)
tolerance side-to-side across the face of the flange. Vertical flange surfaces shall be installed
“plumb” and oriented perpendicular to the centerline of the mating bus within 1/8” (3 mm)
tolerance side-to-side across the face of the flange.
5.12.5 Additional Equipment
5.12.5.1 Surge Arresters
High capacity, station class metal oxide type surge arresters, along with all the mounting equipment
and grounding connectors shall be furnished and mounted next to the high and low-side bushings.
Provisions shall be made to locate surge arresters as close to transformer as possible. Each arrester
shall have a copper connection to a transformer ground pad. Arresters shall have full-capacity
copper connections to the bushing terminals to allow for transmission line connection to the
arresters.
5.12.5.2 Current Transformers
CTs shall be of the bushing type and shall be mounted internal to the transformer tank. Multi-ratio
CTs must have five leads. All current transformer secondary leads shall be wired to the transformer
control cabinet. The continuous current thermal rating factor (TRF) shall be 2.0 minimum. The
continuous current thermal rating factor shall be 1.0 minimum. The CT secondary leads shall be fed
through the tank to a CT junction block and then brought down to the transformer control cabinet.
CT excitation and overcurrent curves shall be submitted for approval.
5.12.5.3 Neutral Grounding Resistor/Reactor (If Applicable)
Contractor shall appropriately size the neutral grounding reactor/resistor (NGR) to limit fault
current. Contractor shall place NGR with sufficient clearance from other neighboring metallic parts
per manufacturer’s recommendations.
The heavy-duty, outdoor, stainless steel strip type NGR with aluminum enclosure shall be mounted
on the transformer. The resistor/reactor assembly shall rest on cap and pin or post type porcelain
insulators. Electrical terminals on the resistor/reactor shall be insulated bushings. One
resistor/reactor terminal shall be connected by copper bar bus to the transformer neutral and the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 899 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-32
other resistor/reactor terminal shall be connected by copper bar bus to the transformer ground
pad. Arresters shall have full-capacity copper connections to associated bushing terminals, with all
associated hardware, to allow for transmission line connection to the arresters. The grounding
resistor/reactor enclosure shall be painted the same color as the transformer tank.
5.12.5.4 Cooling Equipment
The transformer’s cooling class shall be ONAN/ONAF/ONAF. Cooling equipment including
radiators, fans and mounting hardware shall be furnished in accordance with specified transformer
rating. Manual control switches shall be provided in the control cabinet to allow testing and
maintenance of the cooling fans, and for selecting automatic or manual control. Controls shall
provide for changing the sequence of cooler groups. If any of the manufacturer’s control switches
include an off position that prevents operation of any of the cooling equipment, a Form C alarm
contact shall be provided for the Owner’s use. The cooling equipment control system shall have
terminal points for incorporating a normally closed contact from the Owner’s protective relaying
equipment. The open status of this contact shall stop the operation of all cooling equipment.
Multiple contact points shall be provided for cooling systems that have redundant, separate power
supplies. Cooling fans shall be located a minimum of 24 inches (610 mm) above the base of the
transformer. Personnel protection guards shall be placed over fan blades.
Cooling equipment shall be capable to withstand, without any damage or deformation, the pressure
conditions specified for the tank assembly. If a future forced cooled rating is specified, provisions
shall be made on both the transformer and in the control cabinet. The outline, wiring, and
nameplate drawings must give sufficient details so that the future equipment can be added in the
field. These details include information for the fans, breakers, relays, and wiring.
5.12.5.5 Cooling Equipment Maintenance
To support the removal and maintenance of the equipment without draining oil or removing the
transformer from service, the following shall be provided:
Flange mounted, manually operated shutoff valves with bolts and provisions for padlocking
in the open or closed position.
Oil tight covers for each connection to be used when cooling equipment is detached.
Lifting eyes, oil drain, and vents for each cooling unit piping.
In addition, supports for arresters, conservator tanks, etc., mounted above the cooling equipment
must be designed in such a way that no disassembly is required to access the cooling equipment for
removal.
5.12.5.6 Alarms and Indicators
Alarm indication contacts shall be of the dry type, electrically separate and insulated from the
ground, for operation on the specified DC control power system. All alarm and spare contacts and
indication leads shall be wired to terminal blocks in the control cabinet for use by the Owner. These
contacts shall be Form C, one normally open and one normally closed contact, which change status
on an alarm condition. The functional description and actuation state of all alarm (and trip)
contacts shall be clearly indicated with recommended set points, as applicable, on the
manufacturer’s electrical schematics and interconnection wiring diagrams.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 900 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-33
A dial type liquid temperature indicator relay shall be furnished to indicate top oil temperature. In
addition to providing visible indication, it shall be equipped with separate high alarm and high-high
alarm contacts, and with a manually resettable maximum temperature indicating hand. A dial type,
hot spot winding temperature indicator relay shall be furnished for the hottest winding. In addition
to providing visible indication of the temperature of the winding, each indicator relay shall be
equipped with separate alarm and control contacts for the cooling equipment. Each winding
temperature indicator relay shall incorporate a current transformer responsive to its associated
phase winding current, calibrating resistor, temperature detector element, and heater, all mounted
and connected to simulate the hot spot temperature of the winding.
A fault pressure relay and gas detector relay or Buchholz type system (combination gas detector
and oil surge) shall be provided that will operate upon gas accumulation and for abnormal rates of
pressure rise in the main tank and LTC compartment, if provided. The system shall not be affected
by mechanical shock, inrush currents, or impulse voltages. The system shall be ground or ladder
accessible. The fault pressure relay system shall provide an auxiliary seal-in relay and reset switch
arranged and connected to provide manually resettable lockout function on operation of the
primary element. The auxiliary seal-in relay shall be designed for operation on a DC protection
scheme, shall include four electrically separate, field convertible contacts for use with remote
equipment, and shall be mounted inside the main control cabinet. A local DC indicating light shall
be furnished to indicate relay reset required. Units not having oil conservator tanks do not require
gas detection relays.
A Qualitrol (SEVERON), an Online Dissolved Gas Analyzer (DGA), TM-8 type, shall be installed by
manufacturer. The DGA shall provide, at a minimum, typical 8 major fault gases, moisture in oil, oil
temperature and ambient temperature. Gas data shall be provided through station RTU to SCADA
EMS for remote indication and analysis. The fault gas sensor shall be positioned in the tank as
recommended by the manufacturer
Transformer gauges shall be tilted as needed for ease of reading from ground level.
5.12.5.7 Additional Accessories
The following accessories shall be provided and clearly identified by the Contractor:
Resetting mechanical pressure relief device with alarm contact and visual indicator.
Associated piping, fittings, and attachments shall be provided to route the discharge from
the pressure relief device to grade.
A Y-D buried tertiary winding designed by the manufacturer at a capacity of 35% of MVA
rating of the transformer.
Valve for drainage of the oil to within 1 inch (25 mm) of the bottom of the tank, including
built-in, capped sampling connection on the discharge side.
Upper filter valve located below the 77° F (25° C) liquid level and on the diagonally opposite
wall as the drain valve for the return of filtered oil to the transformer.
One set of single-pole, double-throw (spdt) alarm contacts for liquid level indicator and
mechanical pressure relief device.
Two grounding pads on each transformer tank, on diagonally opposite corners.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 901 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-34
One bolted clamp type connector for 1/0 AWG (50 mm2) to 300 kcmil (150 mm2) copper
conductor for each tank grounding pad.
0.25 inch (6 mm) by 4 inch (100 mm) copper bar ground bus connecting each surge
arrester and neutral bushing to the ground pads at base level. Exposed copper shall be
painted the same color as the transformer.
Nameplates for each major item of equipment and each terminal block in the control
cabinet.
One set of special tools for installation, maintenance, and dismantling of the equipment.
Tools shall be new and unused and become the property of the Owner.
One additional gasket for each gasket located on the transformer, sealed for long-term
storage.
5.12.5.8 Control Cabinet
The control cabinet for each transformer shall be intended for outdoor use and shall be dust-tight,
raintight, sleet resistant, undamaged by external ice formation, and shall have suitable corrosion
protection. All ventilating openings shall be louvered to prevent entrance of rain and shall be
equipped with fine mesh dust filters and stainless steel insect screens. The cabinet shall be
provided with a gasketed, removable, blank bottom plate that can be drilled or punched in the field.
There must be no obstructions beneath the cabinet so that the Owner has clear access to connect
the incoming cables or conduits. Control cabinet doors shall have a three-point cabinet type latch
with a single handle and shall include provisions for padlocking. Mechanical stops shall be provided
for doors and hinged panels. The control cabinet shall be mounted a minimum of 30 inches (760
mm) and a maximum of 78 inches (1,980 mm) above ground. The cabinet and all devices shall be
easily accessible from the ground. The cabinet shall not be mounted on the radiators.
Copper grounding bar with terminal screws shall be located in a convenient position in the cabinet
near the terminal blocks for grounding of incoming control and power cables. Indicators, control
devices, and terminal blocks mounted in the control cabinet shall have device nameplates. The
control cabinet shall be provided with space heaters capable of preventing condensation of
moisture within the cabinet. Space heaters shall receive power from the transformer's internal
control power source and shall have a voltage rating twice the energization voltage. Space heaters
shall be controlled by an adjustable thermostat, factory set to close on falling temperature at 80.6° F
(27° C) (ON) and open on rising temperature at 95° F (35° C) (OFF).
If required, a single-phase 15 ampere, grounded convenience outlet shall be mounted inside the
control cabinet, including ground fault protection with a test button and separate circuit breaker or
fused protection.
5.12.5.9 DC Control Power
Electrical devices served from this supply shall not impose any ground connections on the battery.
For each DC supply specified, pull-out fuses shall be provided at the incoming terminals to protect
downstream devices. A voltage failure relay and a red indicating light shall be provided to monitor
each DC supply (downstream of the fuses).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 902 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-35
The voltage failure relay shall be provided with one set of Form C alarm contacts wired to field
terminals for remote indication of loss of DC power. The red indicating light shall be provided with
a nameplate engraved to read: “DC POWER AVAILABLE”.
5.12.5.10 Auxiliary Power
Auxiliary power will be furnished from external sources as per this specification. Main
compression type terminals shall be provided for terminating the auxiliary power circuits. Main
circuit protective devices shall be supplied between the main terminals and the auxiliary
equipment. Additional branch circuit protective devices shall be supplied on branch circuits.
If two sources of auxiliary power are to be provided, automatic transfer equipment, including an
automatic throwover contactor, or automatic transfer switch shall be furnished to transfer load
from the normal source to the emergency source upon failure of the normal source. AC control
power shall be derived from the auxiliary power source(s). The availability of each auxiliary power
source shall be monitored by a red indicating light. Each indicating light shall be provided with a
descriptive nameplate. The indicating light associated with the normal power source shall be
engraved to read: “NORMAL SOURCE AVAILABLE”. The indicating light associated with the
emergency power source shall be engraved to read: “EMERGENCY SOURCE AVAILABLE”.
Transformation equipment shall be provided as necessary within the control cabinet to supply the
specified control power, which includes the space heater and convenience outlet circuits. All
ungrounded legs of control power transformers shall be fused. A voltage failure relay shall be
supplied to monitor and alarm on the loss of each auxiliary power source voltage and each control
circuit power source voltage including the space heater control voltage. The manufacturer shall
provide Form C alarm contacts for the Owner’s use to indicate when any cooling equipment branch
circuit protective device is open, unless a voltage failure relay downstream of the branch circuit
protective device is provided with Form C alarm contacts.
If a voltage failure relay downstream of the branch circuit protective device is not provided, and an
automatic transfer scheme is used with two sources of auxiliary power, the auxiliary power/control
power immediately downstream of the transfer scheme shall be monitored with a voltage failure
relay. That relay shall be designed with enough time delay to prevent a nuisance alarm whenever
the transfer scheme switches either from normal source to emergency source or from emergency
source to normal source. If the Contractor chooses to furnish motors or other auxiliary equipment
designed to operate at a different voltage from the auxiliary power supply, the equipment required
to transform the voltage of auxiliary power as supplied to the design voltage of the equipment shall
be furnished.
5.12.5.11 Wiring
Current transformer leads shall be extended into the control cabinet and shall be terminated on
shorting type terminal blocks with pre-insulated ring type connectors. The secondary leads of the
current transformers shall be 100 percent copper wire and 10 AWG as a minimum. Control cabinet
wiring shall be Class B, stranded copper, 14 AWG or larger, with flame retardant, cross-linked
polyethylene insulation rated at 600 volts.
Splices will not be permitted in control wiring, current transformer leads, or instrument leads,
unless screw terminals are provided within a splice box or where current transformer leads must
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 903 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-36
pass through the tank wall. Terminal blocks, except those used for current transformer circuits,
shall be rated at 600 volts as a minimum and shall have screw terminals. Step type terminal blocks
are not acceptable. Terminal blocks shall be furnished with white marking strips and without
covers. Terminal blocks for circuits above 240 volts AC shall have guards to prevent accidental
contact. For every ten terminals used, two or more spare unused terminals shall be furnished on
each terminal block for circuit modifications.
Terminal blocks for external connections shall be grouped in the control cabinet for easy
accessibility and shall be unrestricted by interference from structural members and instruments.
Sufficient space shall be provided on each side of each terminal block to allow an orderly
arrangement of all leads to be terminated on the block. On terminal blocks with electrical
connections by both the manufacturer and the Owner, the manufacturer‘s connections shall be
made on one side of the block and the Owner's connections shall be made on the opposite side.
Cables between the current transformers and accessories and the control cabinet shall be
completely enclosed in rigid metallic conduit or tank braces or utilize steel wire armor construction
with suitable supports. Exposed non-armored cables are not acceptable.
5.12.5.12 Paint
Metallic surfaces subject to corrosion shall be cleaned and painted with the manufacturer's
premium standard cleaning system, paint system, and colors.
The entire interior of the main tank and the control cabinet shall be painted white for improved
inspection visibility. Exposed unpainted parts shall be fabricated of corrosion-resistant materials.
Touchup paint shall be compatible with, and the same color as, the factory applied paint. This
additional paint shall be supplied in two separate 1 US gallon (4 liter) containers, properly
identified, carefully packed with the accessories, and protected to avoid damage during shipment.
A material safety data sheet shall be furnished with the shipping documents.
5.12.6 Factory Tests
Each transformer shall be completely assembled and tested at the factory in accordance with
applicable standards using materials and equipment that will be a part of the final assembled unit,
specifically, bushings, cooling, and control equipment. At some time during the manufacturing
process, all equipment must be mounted to ensure proper fit. This includes, but is not limited to,
bushings, the oil preservation system, arresters, neutral grounding equipment, control cabinets,
and all cooling equipment. The Owner reserves the right to witness factory testing and shall be
informed in writing at least 30 days prior to the scheduled start date of factory tests so that
arrangements can be made for a representative to be present. The Owner shall also be notified of
the sequence of tests, not less than 10 days prior to testing. Testing procedures and techniques are
to be in accordance with normal accepted industry practice and the appropriate standards.
The transformer shall not be released from the test area until the dielectric, temperature rise, loss
measurements, and gas-in-oil test data have been approved by the Owner. The Owner shall be
notified of any unusual event or damage occurring during the fabrication of each transformer and of
all tests that do not meet the applicable standard values, manufacturer's standard values, and
guaranteed values. The Owner reserves the right to inspect such damages or test failures.
Corrective measures to overcome such damage or failure shall be subject to acceptance by the
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 904 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-37
Owner. Tested and calculated data shall be included in the certified test report. In particular, the
calculated hottest spot temperature rises of the windings shall be shown.
To minimize potential damage to the transformer during testing, the resistance, polarity, phase
relation, turn ratio, no-load loss, percent impedance, temperature rise (when applicable), and load
loss tests should precede dielectric tests. In this sequence, the beginning tests involve voltages and
currents, which are usually reduced as compared to rated values, thus tending to minimize
damaging effects to the transformer. The dielectric test sequence shall be arranged so that lightning
and switching impulse tests precede the power frequency tests, and the final dielectric test
performed shall be the induced overvoltage test. In addition to all tests dictated by and described in
the appropriate standards, the following tests and calculations are also required:
5.12.6.1 Design and Routine Testing
Regulation:The regulation of transformer shall be calculated for unity (1.0), nine-tenths (0.9), and
eight-tenths (0.8) power factor lagging.
Insulation resistance and core megger tests shall be performed, with resistance
measurements corrected to 68° F (20° C).
The maximum acceptable value for insulation power factor is 0.5
percent when corrected to 68° F (20° C). Capacitance measurements shall also be made between
windings and from windings to ground.
Gas-in-Oil: Dissolved gas-in-oil analysis shall be made before testing begins, before and after
temperature rise tests, and after over excitation tests (totaling four times).
Impedance: The positive and zero sequence impedances shall be measured on all tap positions for
units fitted with de-energized tap changers and at both tap extremes, nominal tap, and two other
positions (selected by the Owner at a later date) for units fitted with LTCs.
A full temperature rise test shall be performed. Transformers having only
a single force cooled nameplate capacity rating (ONAF) shall include a temperature rise test at 60
percent of nameplate MVA rating (in addition to the test at 100 percent rating) with all the fans
operating, so that temperature rises and gradients needed for the hot spot calculations can be
determined. The hottest spot temperature rise calculation shall be performed using the "maximum
eddy-current watt loss method." Use of empirical hot spot gradient factors to estimate hot spot
temperature rises is not acceptable. Infrared thermographic photos shall be taken of the unit from
all sides and top during the hottest part of this test to record hot spot temperature data. Color
copies of these photos shall be included in the test report.
Lightning impulse and chopped wave tests are required as routine tests on line and
neutral terminals of all transformers, except that the chopped wave test is not required on the
neutral terminals. Switching impulse tests are required as a routine test on transformer windings
rated 300 kV and above, using a test voltage that is approximately 83 percent of the full wave
lightning impulse level. Transformers with protective devices that are an integral part of the design
shall be tested in the following sequence.
One reduced full wave between 50% and 70% of the required full-wave impulse level
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 905 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-38
One or more intermediate reduced full waves between 75% and 100% of the required full-
wave impulse level
One full wave at 100% of the required full-wave impulse level
Two chopped waves at 100% of the required chopped-wave impulse level
Two full waves at 100% of the required full-wave impulse level
One or more intermediate reduced full waves at the same voltage levels as used before the
first full-wave test
One reduced full wave between 50% and 70% of the required full-wave impulse level
Transformer with reactive type LTC shall be tested as per below tap settings.
Impulse on HV winding phase A: HV: max. tap; LV min. tap (maximum ratio);
Impulse on HV winding phase B: HV: nom. tap; LV nom. tap (nominal ratio);
Impulse on HV winding phase C: HV: min. tap; LV max. tap (minimum ratio);
Impulse on LV winding phase A: LV: max. tap; HV min. tap (minimum ratio);
Impulse on LV winding phase B: LV: nom. tap; HV nom. tap (nominal ratio);
Impulse on LV winding phase C: LV: min. tap; HV max. tap (maximum ratio).
A Class II, 1 hour, induced overvoltage withstand test with partial
discharge measurements shall be performed as a routine test on all transformers regardless of
voltage class. The apparent charge shall not exceed 300 picoCoulombs (pC) at 1.5 times maximum
line-ground voltage and the Radio Induced Voltage (RIV) measurement shall not exceed 100
microvolts during this test. Factory tested bushings shall be part of the final assembled unit and
results will be compared to the results made during preoperational site testing.
A short duration (1 minute) power frequency voltage test shall be
performed as a routine test on all line and neutral terminals.
An oil leak test shall be performed on each completely assembled transformer, using a
test pressure that is 25 percent greater than the normal operating pressure.
The average audible sound level test is required as a design (type) test.
Contr All auxiliary equipment, CT circuits, and control wiring must be tested to verify
proper connections. CT ratio and polarity must be checked. The insulation of the control circuits
must be verified by applying a power frequency test voltage of 1500 volts for 1 minute or 1800
volts for 1 second with all of the circuits tied together.
Fan auxiliary power requirements shall be measured and recorded.
A complete dimensional check shall be performed on each transformer
specified herein to confirm that the actual dimensions match the dimensions shown on the
drawings. The purpose of this check is to confirm that dimensions shown for isophase bus, non-
segregated phase bus/cable bus, or other Owner’s interfaces shall be identical to the information
shown on the manufacturer’s drawings. The bus connection dimensional check shall confirm that
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 906 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-39
all bus connections have been installed in a manner that makes the connections level when the
transformer is level.
Each transformer supplied under these
specifications shall undergo an SFRA test using a Doble SFRA test set and leads and be performed in
accordance with Doble’s instructions and recommendations. A test shall be performed after all
electrical tests specified herein are complete, but prior to draining the oil. Also, the manufacturer
shall furnish a small temporary test bushing mounted in each bushing cover plate to be used for
performing an SFRA after the insulating fluid has been drained and the unit prepared for shipping.
One dry SFRA test shall be performed at the factory and the manufacturer shall make arrangements
to perform a dry SFRA test as part of the receipt inspection procedures. If the transformer is
delivered by railcar, the SFRA test shall be performed before the unit is untied/removed from the
railcar. Software data from all tests shall be provided to the Owner.
On- All transformers equipped with on-load tap
changers shall undergo the following special tests in addition to routine tests specified by the latest
revision of IEEE C57.12.90.
Load loss measurements shall also be taken with the DETC (if so equipped) in positions 1, 3,
and 5 and the OLTC in extreme raise and lower positions and neutral position. Also with
DETC in the lowest position and OLTC in the lowest non-bridging position and the lowest
bridging position (if equipped with preventative auto transformer). Losses for the worst
case of all tested positions shall be used to adjust the temperature rise test.
With transformer de-energized, 4 complete cycles of operation.
With transformer energized at rated voltage and at no load, 1 complete cycle of operation.
With one winding short circuited and as high as possible rated current flowing in the tapped
winding, 4 tap OLTC operations from 2R to 2L or otherwise across the coarse or changeover
selector switch operates.
For all of the above tests, there shall be no abnormal deflections of current or abnormal noises
coming from the transformer.
5.12.6.2 Accessory Testing
All the accessories shall be tested for continuity, ground and correct connections.
Tests shall be conducted for proper operation of all relays, indicators, switches, lights and
interlocks.
5.12.7 Photographs
Three sets of color photographs of each core and coil assembly shall be furnished with the
instruction books. The photographs shall be taken just prior to placing the completed core and coil
assembly into the tank. All photographs shall be 8 inch by 10 inch (200 mm by 250 mm) glossy
prints labeled with the transformer manufacturer's name and serial number. Five different views
shall be provided as follows: top view, front view, left side view, right side view, and rear view.
Digital photographs in JPEG format may be supplied in lieu of glossy prints.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 907 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-40
5.12.8 Shipping - Impact Recorders, Dew Point Temperature, and Receipt Inspection
The manufacturer shall supply and mount impact recorders (in suitable weatherproof enclosures)
directly on each transformer prior to shipment. The impact recorder shall provide a permanent
record of the magnitude of axial, transverse, and vertical forces to which the transformer is
subjected while in transit.
For units shipped under dry gas, the moisture content of the insulation shall be estimated by the
following method immediately prior to shipment. Dry gas shall be installed in the main tank and
held at a pressure of 0-5 psig (0-0.35 kg/cm2) for at least 18 hours. The dew point temperature and
ambient temperature of the gas shall be measured with a suitable device, and the results used in
conjunction with the vapor pressure and percent moisture by weight graphs found in IEEE C57.93
or other graphs agreed upon between manufacturer and the Owner. If the percent moisture by
weight of the paper exceeds 0.5 percent, the unit shall undergo further processing until this level is
achieved. If the pressure in the main tank is between 0-5 psig (0-0.35 kg/cm2) at the time the dew
point is measured, it is not necessary to make any adjustments to the readings taken from the
aforementioned graphs.
5.12.9 Assembly and Field Testing
Contractor shall install, assemble, vacuum fill, and test transformer. Owner is responsible for
delivery of transformer to pad. Contractor is responsible for install of all auxiliary equipment,
which includes radiators, pumps, conservator tank (if necessary), NGR, etc. Contractor is
responsible for vacuum filling transformer and doing field test in accordance with operating
manual of unit.
5.13 SHUNT CAPACITOR BANK (IF APPLICABLE)
5.13.1 General
See Owner’s Specification WED 0021 included with this Exhibit for capacitor bank specifications.
5.13.2 Equipment Required
If required, capacitor banks shall be furnished in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
If Contractor recommends altitude correction, a clear indication should be made to the Owner.
5.14 CONTROL EQUIPMENT ENCLOSURE
5.14.1 General
See Owner’s specification WED 0148P included with this Exhibit for control equipment enclosure
specification. If there is any contradiction between this Exhibit and the included Owner’s
specifications, the more stringent shall apply.
5.14.2 Equipment Required
The Contractor shall furnish control equipment enclosure in accordance with the specification data
sheet(s) completed by Contractor during detailed design.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 908 of 1056
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IDAHO POWER CO.| Substation 5-41
5.15 CONTROL, PROTECTION AND MEASUREMENT PANELS
5.15.1 General
5.15.1.1 Scope of Supply
Scope of supply shall include furnishing the protective relaying panels as specified herein and on
the specification data sheet(s) to be completed by the Contractor during detailed design.
5.15.1.2 Performance and Design Requirements
Performance and design requirements for the protective relaying panels shall be indicated by the
Contractor on the specification data sheet(s).
5.15.2 Codes and Standards
Work performed under these specifications shall be done in accordance with the following codes
and standards. Unless otherwise specified, the applicable governing edition and addenda to be used
for all references to codes or standards specified herein shall be interpreted to be the
jurisdictionally approved edition and addenda. If a code or standard is not jurisdictionally
mandated, then the current edition and addenda in effect at the date of this document shall apply.
These references shall govern the work except where they conflict with the Owner's specifications.
In case of conflict, the latter shall govern to the extent of such difference:
Work
Protective relaying panels The applicable ANSI, NEMA, UL and/or IEC standards.
5.15.3 Products
5.15.3.1 General
This section covers the furnishing of protective relaying panels as specified herein and on the
drawings provided by the Contractor.
5.15.3.2 Arrangement
Protective relaying panels shall be arranged in accordance with the arrangement drawing(s)
provided by the contractor and as specified herein.
5.15.3.3 Vertical Panel Structures
The vertical panel structure shall be an assembly of standard fixed vertical panels. Panels shall be
fabricated from not less than 11 USS gauge (minimum 3.06 mm) leveled steel sheets and reinforced
as required to form a rigid structure.
An open vertical panel will be supported by wall braces. An enclosed vertical switchboard shall
have an overall sheet metal enclosure (not grille) covering the back, top, and ends of the entire
assembly. Access to the interior of the enclosure shall be provided by doors or by removable covers.
Each panel shall be formed with edges bent back and joints welded and ground smooth and shall be
designed to be readily removable from the structure without disturbing the remaining panel
assembly or existing control or cross panel wiring. Finished panel surfaces shall be free of waves,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 909 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-42
bellies, and other imperfections. Exterior panel surfaces shall be sandblasted, ground smooth,
filled, primed, and enamel finished.
Instruments, meters, lockout relays, and protective relays shall be mounted on the front of the
panels. Panel cutouts, mounting studs, and support brackets shall be accurately located and
indicated on the drawings.
Mounting brackets, as required, shall be arranged for mounting and wiring auxiliary equipment and
devices and terminal blocks. Where required, brackets shall be hinged and located to allow access
to the back of the equipment mounted on the front of the panels.
Panel space not used by equipment shall remain clear for the addition of possible future equipment.
Blank panels shall be provided with standard wiring gutters for future wiring.
The interior of each panel shall be illuminated with a light, mounted inside the top of the panels and
controlled from a switch mounted inside the door.
Wiring for lights and receptacles shall be run to one common 15 ampere fuse or circuit breaker for
the voltage specified on the specification data sheet(s) as an external connection.
5.15.3.4 Dual Panel Structures
The dual panel structure shall be completely enclosed at the front, rear, top, and both sides.
Standard dual switchboard construction shall be used, having the front or rear panels hinged with
concealed hinges that are not visible from the outside of the panel. Leveled 11 USS gauge
(minimum 3.06 mm) steel sheets and formed steel members shall be welded together to form a
rigid structure. Equipment cutouts, mounting studs, and brackets shall be accurately located and
indicated on the drawings. Welds on exposed surfaces of the structure shall be ground smooth.
Finished panel surfaces shall be free of waves, bellies, and other imperfections. Exterior panel
surfaces shall be sandblasted, ground smooth, filled, primed, and enamel finished. Interior surfaces
shall be sandblasted, primed, and finished with gloss white enamel.
Mounting brackets, as required, shall be arranged inside the switchboard for mounting and wiring
auxiliary devices and terminal blocks. They shall be located to allow access to the back of the
equipment mounted on the front of the fixed panel.
Panel space not used by equipment shall remain clear for the addition of possible future equipment.
Blank panels shall be provided with standard wiring gutters for future wiring.
The interior of each panel shall be illuminated with a light, mounted inside the top of the panel and
controlled from a switch mounted inside the door.
Wiring for lights and receptacles shall be run to one common 15 ampere fuse or circuit breaker for
the voltage shall be specified on the specification data sheet(s) as an external connection.
5.15.3.5 Duplex Panel Structures
The duplex panel structure shall be an assembly of standard fixed vertical front and rear panels.
Standard dual switchboard construction shall be fabricated from not less than 11 USS gauge
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 910 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-43
(minimum 3.06 mm) leveled steel sheets. Leveled steel sheets and formed steel members shall be
welded together to form a rigid structure.
Each panel shall be formed with edges bent back and shall be designed to be readily removable
from the structure without disturbing the remaining switchboard assembly or existing control or
cross panel wiring. All joints shall be welded and ground smooth.
Mounting brackets, as required, shall be arranged inside the switchboard for mounting and wiring
auxiliary devices and terminal blocks. Final arrangement of devices on the panels and inside the
panel shall be submitted to the Owner for acceptance.
Instruments, meters, lockout relays, and protective relays shall be mounted on the fixed front and
rear panels. Panel cutouts, mounting studs, and support brackets shall be accurately located.
Auxiliary equipment may be mounted on interior panels, hinged and located to allow access to the
back of equipment mounted on the front panels. Intermediate barriers between adjacent panels
shall not be provided. Equipment shall not be mounted on end closure sheets.
Panel space not used by equipment shall remain clear for the addition of possible future equipment.
Blank panels shall be provided with standard wiring gutters for future wiring.
Finished panel surfaces shall be free of waves, bellies, and other imperfections. Exterior panel
surfaces shall be sandblasted, ground smooth, filled, primed, and enamel finished. Interior surfaces
shall be sandblasted, primed, and finished with gloss white enamel.
The distance between the front and rear panels shall be 72 inches (1,829 mm). The height above
the floor or base surface shall be 90 inches (2,286 mm) plus 2 inches (50.8 mm) allowed for base
channel. The panel sections shall be mounted on a 2 inch (50.8 mm) by 6 inch (152.4 mm),
8.2 pounds per foot (12.20 kg per meter) steel channel. The panel shall be designed to have the
bottom open and without permanent bottom braces.
The panel shall be furnished without top panel sheets to allow control room illumination and
ventilation to serve the interior.
The panel shall be provided with removable end closures designed to permit future extension from
either or both ends. End closures shall be equipped with hinged formed doors. The doors shall be
rigid, nonsag, and reinforced and shall be equipped with three-point latches.
Internally mounted equipment and auxiliary devices shall be arranged to provide not less than
24 inches (61 cm) of unobstructed walkway between completed front and rear panels.
The interior of the switchboard shall be illuminated with two-lamp fluorescent fixtures, arranged in
a continuous strip along the top, and controlled by three-way switches provided on the end
closures, inside and near the doors.
5.15.3.6 Nameplates
Engraved nameplates shall be furnished on laminated plastic tags at least 1.5 inches (40 mm) by
4 inches (100 mm). Nameplates shall have black letters with a white background. Inscriptions on
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 911 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-44
these tags shall coincide with those used on the drawings. Nameplate inscriptions will be furnished
by the Contractor and approved by the Owner at a later date.
5.15.3.7 Wiring and Wiring Diagrams
The Contractor shall provide internal panel wiring, connections, and diagrams to the manufacturer
in accordance with the following requirements.
Panel Wiring
All wiring used within the panel shall be installed and tested at the factory.
All wiring shall be neatly and carefully installed in wiring gutters or raceway. Wiring to and from
devices mounted inside or on the panels shall be in accordance with wiring diagrams.
Except as otherwise specified, the size of wire used in the panel shall conform to the following
requirements:
Service
Power supplies and packaged control systems As required
Ammeter and current transformer circuits 12 AWG (4 mm2)
Control wiring 14 AWG (2.5 mm2)
Indicating lights and annunciators 16 AWG (1.5 mm2)
Diagrams
The Contractor’s wiring diagrams shall be in accordance with the requirements specified herein.
Sufficient space shall be left on the Owner's side of outgoing terminal blocks for adding cable color
codes and circuit numbers.
The complete connection diagram of each panel shall be on an individual sheet. Information on
each connection diagram sheet shall include point-to-point wiring of the entire unit as it would
appear to a person wiring the panel. Elementary diagrams of control and instrument circuits,
contact arrangement of switches, and internal wiring of relays and instruments for each panel shall
be on additional sheets as required. Interconnection diagrams shall be on separate sheets. All
sheets shall be the same size.
Terminal Blocks
Furnish and install spare control terminal blocks in each panel per Owner’s requirements. In
addition, one lot of terminal blocks (with 20 percent spares) shall be provided for the current
transformers, potential transformers, and analog wiring interface circuits as shown on the
schematic diagrams.
5.15.3.8 Buses
Control, potential, and alarm buses of 12 AWG (4 mm2) or larger panel wire shall be furnished and
installed as required.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 912 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-45
A continuous 1/4 inch (6.35 mm) by 1 inch (25.4 mm) cross-section bare copper ground bus, with
copper/bronze compression or clamp type connectors at each end, shall be provided in the panel.
All panel equipment requiring grounding shall be connected to this ground bus with copper/bronze
compression or clamp type connectors.
5.15.3.9 Power Supply Disconnects
Each panel mounted device requiring AC or DC supply, as indicated on the Contractor’s schematic
diagrams, shall have in its supply circuit a panel mounted fuse or disconnecting link to allow
isolation of the device from the power supply. Disconnecting links shall be sliding link type.
When required by the schematic diagrams, power supplies for special devices shall be wired to a
separate supply circuit for connection to the Owner's preferred AC power supply. Isolation fuses
shall be furnished for each power supply branch circuit.
5.15.3.10 Relays, Meters, Controls, and Instruments
Meters, relays, instruments, and controls shall be installed and wired on the front panels with the
exception of auxiliary relays, transducers, and instrument transformers that may be mounted
inside of the panel or on sub-panels. Unless otherwise noted, instruments and meters including
transducers shall be suitable for operation from instrument transformers with nominal 5 ampere
and 120 volt secondary. Scale ranges and dial constants shall be provided to match the primary
current and voltage ratings.
Indicating Lights
Unless otherwise noted, indicating lights shall be light-emitting diode (LED) type sized for the
supply voltage. The manufacturer shall supply General Electric Type ET-16 LED indicating lights or
Owner-approved equal. Lamps and lenses shall be replaceable from the front of the panel. Shields
shall be provided to prevent short circuits. Indicating lights in outdoor panels shall be
weatherproof.
Potential Transformer Circuit Fuses
Unless otherwise noted, each potential transformer (PT) circuit entering the panel shall be
provided with incoming fuses provided by the manufacturer in accordance with the Owner-
approved diagrams.
5.15.3.11 Raceway
An adequate raceway system shall be provided for all wiring on each side of each panel and
between panels. The horizontal raceway for interpanel wiring shall be furnished complete per
Owner’s specification WED 0148P and as specified herein.
A complete system of separate vertical wiring raceways shall be provided for all factory and field
wiring. This shall include vertical raceways along both sides of each panel.
The raceways for factory wiring shall be sized so that fill does not exceed 30 percent. Vertical
raceways for field wiring shall be twice as large as those provided for factory wiring or shall have a
minimum cross-sectional area of 20 in2 (508 mm2), whichever is larger.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 913 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-46
Vertical raceways for field wiring shall be constructed as to be accessible to conductors entering
from the bottom or the top of the panel.
The manufacturer's standard raceway may be considered, provided the Contractor provides
sufficient information to evaluate the raceway system offered.
5.15.3.12 Space Heater
If a space heater is specified on the specification data sheet(s), a thermostatically controlled space
heater shall be furnished and installed in the panel. The space heater shall be capable of
maintaining the enclosure interior at a temperature above the dew point, based on ambient
conditions specified in the specification data sheet(s). Space heaters shall be controlled by an
adjustable thermostat or fixed humidistat.
5.15.3.13 Receptacles
If a receptacle is specified on the specification data sheet(s), the receptacles shall be furnished,
mounted, and wired in a convenient location at each end of the panel. The receptacles for portable
tools and droplights will be supplied from a single-phase AC source furnished by the Contractor.
5.15.4 Factory Tests
After the panel has been fabricated and all parts assembled, the complete gear, including
instruments and devices, shall be factory tested. Factory tests shall include the following:
Tests that verify correct assembly and operation.
High potential tests.
Applicable standard tests.
5.15.4.1 Test Requirements
The following testing shall be conducted in accordance with the specified source. This testing is to
be considered part of the Contractor’s scope, and all associated costs are the responsibility of the
Contractor. However, the manufacturer is responsible for all costs associated with correcting
deficiencies and retesting in the event of a test failure:
Tests
Production test NEMA, IEEE, UL, IEC Manufacturer
Type test/Functional test Manufacturer standard Manufacturer
Point-to-point wiring checking Manufacturer standard Manufacturer
5.15.4.2 Type Tests and Certification
The manufacturer shall perform the type tests for major components if specified by the Owner and
will be in accordance with all the applicable standards.
Type test certificates from identified components are acceptable in lieu of the individual type test.
Type test certificates shall be made available to the Owner at no extra charge upon request.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 914 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-47
5.15.5 Special Shipping Requirements
The equipment shall be shipped with the control equipment enclosure in accordance with Owner’s
Specification WED 0148P.
5.16 RELAY PROTECTION & CONTROL
5.16.1 General
The Project Collector Substation will employ multiple protective relaying schemes within the power
transformers, transmission, and auxiliary power systems on site, and the protection will also
interface with protective relaying applied within the Project Interconnect Substation. The Owner
requests Contractor acceptance of existing Owner protective relaying standards in the Project
Collector Substation design and construction as indicated herein. These standards apply to the
transformer, WTG collector and bus protection; the Owner recognizes that Subcontractor standards
may differ and will require review by Contractor and Owner as part of incorporation into the
Project. Select protective relaying is shown in the electrical single line diagrams included in Exhibit
CC-9 which shall be integrated in Contractor’s design.
A key activity and formal Contractor Submittal is the relay protection settings that will include
transformer protection relays, collector bus protection relays, and 345 kV bus protection relays.
5.16.2 General Protective Relaying Requirements
The Contractor shall also incorporate the following general requirements. Project Collector
Substation protective relaying shall be designed such that, in the event of a fault occurrence, the
faulty system/equipment is safely disconnected, while continuity of supply consistent with system
stability is maintained. The selection and setting of protection devices for the Project Collector
Substation electric power and auxiliary power systems shall be based upon the following major
requirements:
Faults on systems/equipment items shall be interrupted as quickly as possible to minimize
damage.
Faults external to major power sources (e.g. Unit Auxiliary Transformers) shall only open
the circuit breaker controlling these power sources after any other protection nearest the
fault has failed.
Faults internal to major power sources shall cause their circuit breakers to open as fast as
possible to ensure that the transmission system can restore itself within the limits of
stability.
The protection shall be designed to be stable in transient conditions such as closing one
collector breaker.
Protection of systems and equipment shall be designed to match the specific
systems/equipment operating characteristics as procured and to provide discrimination
with other systems and equipment.
Contractor design and implementation of system protection will be in accordance with
applicable NERC requirements. For example, but not limited to NERC PRC standards.
Contractor will procure equipment from the Owner’s preferred manufacturer of relay and
GPS clock, which is Schweitzer Engineering Laboratories (SEL), unless otherwise indicated
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 915 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-48
in the Contract. Reference Appendix A for Owner’s preferred SEL product codes. The
Contractor shall procure the Owner-preferred equipment, except where one has been made
obsolete, in which case the Contractor will work with the Owner to determine the proper
replacement.
Collector circuits shall include directional elements that are intended to reduce the arc fault
energy in the direction towards the WTGs and the ability to be enabled/disabled locally
(‘Maintenance Mode’ or ‘Arc Flash-Protection’).
Protective relays shall be microprocessor-based digital type. Protective relays shall be time
synchronized to the sequence of event recorders and digital fault recorders by the use of an IRIGB
signal and dedicated GPS time clock.
Protective relay voltage elements shall be coordinated with WTG LVRT and HVRT requirements
and capabilities. The Contractor design shall not reduce the LVRT and HVRT capabilities of the
WTG system.
All Voltage and Current measurements by relays are data points to be available in the RTUs.
Protective relaying devices shall be coordinated so that electrical disturbances (fault, overload, etc.)
are interrupted at the point nearest the fault, with the next upstream protective device providing
backup protection. Phase and ground fault protective devices shall trip the respective breaker.
Protective devices on medium voltage circuits shall operate through a lockout relay (86) or
equivalent device or circuit to prevent automatic equipment restart or reclose.
Protective devices shall be rated for the maximum available fault current. Each current operated
protective relay requires dedicated current transformers not shared with other protection or
metering devices.
An IRIG-B signal shall be distributed to protective relaying devices for the GSU and auxiliary
transformer protection, Unit protection, Generator protection, and medium voltage breaker
protection – to provide event time stamping.
For requirements regarding Project Collector Substation SCADA System reference Section 6.0.
5.16.3 Component Protective Relaying Requirements
The Contractor will design at a minimum, the following protection
for each WTG collector circuit, using a 351S relay, overcurrent protection (50/51/BF), directional
overcurrent (67) for arc flash mitigation, to be coordinated with the arc flash study (performed by
Contractor) and with the Owner’s Engineer.
The Contractor will design, at a minimum, the following protection for
each 34.5 kV Bus, using a 587Z relay, differential current (87), to include all collector circuits and
the bus tie breaker. Tripping due to differential current will trigger a primary electromechanical
lockout (86) on the 34.5 kV bus. A secondary electromechanical lockout (86) will be tripped by a
SEL-351S (overcurrent) relay.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 916 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-49
:The Contractor will design, at a minimum, the
following protection for each bus tie circuit breaker, using a 351S relay and overcurrent protection
(50/51/BF).
The Contractor shall design, at a minimum, the following protection for
each the main power transformer, using a SEL-487E relay and differential current protection (87).
Additional protections shall include sudden pressure (63) and under voltage (27). Contractor shall
specify and provide a SEL-2414 relay for use with the transformer(s). The design shall have
overcurrent protection (50/51/BF) on both the high voltage side (345kV) and low voltage side
(34.5kV) of the main power transformer(s) (using two SEL-351S relays). The design shall have a
primary and secondary (high and low voltage side) electromechanical lockouts (86). The design
shall have dedicated CTs on the neutral connection of the main power transformer(s)’s high and
low side windings. Adequate alarms shall allow operator to quickly identify any abnormal
conditions. Alarms such as high/low level, high/low pressure, and winding or top oil temperature
shall only provide alarms and not trip the main power transformer(s). The design shall have
adequate number of visual disconnect switches on both high and low voltage side.
The Contractor shall design, at a minimum, the 345kV bus protection in
accordance with Transmission Owner’s specifications.
Capacitor banks shall be protected by SEL-487V (one
relay per bay). This relay shall trip and lock out the capacitor bank breaker in the event of a fault.
This relay shall block closing for an appropriate amount of time after opening to prevent closing
into a partially discharged capacitor bank. The relay should also detect and alarm if an unbalance is
detected due to failed capacitor can fuses.
345 kV line between Project Collector Substation and Project
Interconnect Substation should be assumed to be protected by two SEL-411L (or SEL-311L) relays
(primary and secondary). Transmission Owner shall determine final relay requirements.
Voltage measurements shall coordinate the protective relay settings
with turbine breaker settings.
Metering: The placement of CTs and PTs for the meter shall be per the GIA. Any line loss
compensation shall be programmed as needed. Communications to 3rd parties programmed as
needed.
5.16.4 Protective Relay Settings and Implementation
As part of the relay protection settings, Contractor shall calculate and submit relay settings for all
Project Collector Substation relays protecting equipment through the high voltage distance relays
associated with 345kV circuits routed between the Project Collector Substation into the Project
Interconnect Substation. Transmission system electrical information required for the completion of
relay settings shall be provided by Transmission Owner, via the Owner.
Also as part of the relay protection settings, AC and DC protection circuit diagrams and calculations
showing how the proposed protection settings were derived shall be submitted to the Owner (with
a copy of the ETAP or CAPE software files used to develop and install the relay settings provided).
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 917 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-50
In addition, overall protection coordination diagram(s) shall be submitted to demonstrate that the
relay settings proposed offer satisfactory discrimination between the various protective devices.
During construction and Start-up and Commissioning phases, the Contractor shall provide site
testing and functional checks. Test plans shall be created and performed using the Doble Protection
Suite Software for all relays and associated instrument transformers to verify proper operation of
protection circuits. These tests and data reporting shall confirm to NERC requirements.
5.17 BATTERY BANK AND CHARGER
5.17.1 Equipment Required
The Contractor shall furnish battery charger, battery and rack in accordance with the specification
data sheet(s) completed by Contractor during detailed design.
5.18 STATION SERVICE TRANSFORMER
5.18.1 Equipment Required
The station service transformer shall be furnished in accordance with the specification data
sheet(s) completed by Contractor during detailed design.
5.19 GROUNDING TRANSFORMERS
5.19.1 General
Each feeder shall have at least one grounding transformer to ensure that the feeders are effectively
grounded. The grounding transformers must provide effective grounding as defined by IEEE
C62.92.1 at all points on the Collection System. The use of a particular grounding transformer shall
be validated in accordance with the Electrical Studies and Analyses.
5.19.2 Equipment Required
Grounding transformers shall be furnished in accordance with the specification data sheet(s)
completed by Contractor during detailed design.
5.20 GROUNDING SYSTEM
5.20.1 General
The grounding system shall protect all equipment and personnel inside and including the
substation fence against power grid surges and lightning strikes. This includes excavation,
placement of ground conductors and associated equipment, and backfill and compaction of the in-
situ soil. Contractor shall conduct any and all studies and calculations necessary to determine a safe
grounding design.
5.20.2 Codes And Standards
Grounding systems and components furnished with these specifications shall be manufactured in
accordance with applicable standards of the Institute of Electrical and Electronics Engineers, Inc.
(IEEE), the National Electrical Manufacturers Association (NEMA), the American Society for Testing
and Materials (ASTM), and Underwriters' Laboratories, Inc. (UL). Grounding systems and
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 918 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-51
components shall be installed in accordance with the applicable requirements of the National
Electrical Code (NEC) and the Occupational Safety and Health Administration (OSHA) standards.
5.20.3 Materials Required
Grounding component materials shall be furnished new and undamaged.
5.20.4 Execution
5.20.4.1 Grounding Components
An electrical grounding system shall be furnished and installed in accordance with the following
specifications. Grounding components shall include ground rods, ground conductor, ground bus,
above and below grade grounding connections, grounding lugs, and hardware required for a
complete system.
5.20.4.2 Ground Rods
Ground rods shall be copper clad, cold drawn carbon steel manufactured in accordance with UL
467. The copper cladding shall be electrolytically bonded to the steel rod or bonded by a molten
welding process. Cold rolled copper cladding will not be acceptable. Ground rods shall have a
conical taper on one end to facilitate soil penetration. Individual ground rods shall be 3/4 inch (19
mm) diameter and 10 feet (3 m) long. Ground rods shall be similar to Type ERITECH as
manufactured by Erico, or an Owner acceptable equal.
5.20.4.3 Conductors
Bare ground conductor shall be soft drawn, stranded copper conforming to the requirements of
ASTM B-8. Insulated ground conductor shall be soft drawn, stranded copper conforming to the
requirements of UL 83. Insulated ground conductor shall be Type TW or THW having green colored
PVC insulation. Ground conductors shall be as manufactured by Rome Cable Corporation, or an
Owner acceptable equal.
5.20.4.4 Bus Bar
Ground bus bar shall be soft drawn, uncoated copper conforming to the requirements of ASTM B-
187. Bus bar shall be a minimum 1/8 inch (3 mm) thick and 1 inch (25 mm) wide. Where required,
bus bar shall be provided with predrilled holes measuring 9/16 inch (14 mm) in diameter with
NEMA center line hole spacings. Bus bar shall be as manufactured by Erico, or an Owner acceptable
equal.
5.20.4.5 Exothermal Connections
Exothermal connections shall be made for below grade electrical connections with a standard duty
copper molten weld conforming to the requirements of IEEE 837, IEEE 80 Section 11, and UL 467.
Molds and powder cartridges used for making exothermal connections shall be furnished by the
same manufacturer. Exothermal connections shall be similar to Type CADWELD as manufactured
by Erico, or an Owner acceptable equal.
5.20.4.6 Compression Connections
Compression connections shall be made for above grade electrical connections and be irreversible,
heavy-duty, copper crimps conforming to the requirements of IEEE 837 and UL 467. Compression
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 919 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-52
fittings and compression tools and dies shall be furnished by the same manufacturer. Compression
connections shall be similar to Type HYGROUND as manufactured by Burndy Electrical, or an
Owner acceptable equal.
5.20.4.7 Ground Lugs
Ground lugs shall be single hole or two hole, copper bars conforming to the requirements of UL 467.
Two hole ground lugs shall have NEMA center line hole spacings. Ground lugs used with the
exothermal weld process shall be similar to Type LA as manufactured by Erico, or an Owner
acceptable equal. Ground lugs used with the compression process shall be similar to Type YGA as
manufactured by Burndy Electrical, or an Owner acceptable equal.
5.20.4.8 Ground Plates
Ground plates shall be high strength, four hole copper bodies conforming to the requirements of
IEEE 837 and UL 467. Ground plates shall have NEMA center line hole spacings and shall be
provided with hole plugs on the mating side of the plate. Ground plates used with the exothermal
weld process shall be similar to Type B164 as manufactured by Erico, or an Owner acceptable
equal. Ground plates used with the compression process shall be similar to Type YGF as
manufactured by Burndy Electrical, or an Owner acceptable equal.
5.20.4.9 Hardware
Clamps, connectors, bolts, washers, nuts, and other hardware used with the grounding system shall
be of copper, copper alloy, or stainless steel.
5.20.5 Grounding Installation
Grounding system components shall be installed as described in these specifications.
5.20.5.1 Conductors
Exposed conductors shall be installed inconspicuously in vertical or horizontal positions on
supporting structures. When located on irregular supporting surfaces or equipment, the conductors
shall run parallel to or normal to dominant surfaces.
All below grade ground conductors shall be buried a minimum of 18 inches (450 mm) and a
maximum of 30 inches (750 mm) below finished grade unless installed under a concrete
foundation. Ground grid conductors under foundations shall have 6 inches of earth cover between
conductor and bottom of foundation.
Conductors routed over concrete, steel, or equipment surfaces shall be kept in close contact with
those surfaces by using fasteners located at intervals not to exceed 3 feet. Conductors routed
around 90 degree corners shall be kept in close contact with the perpendicular surfaces and shall
not be physically damaged due to an insufficient bending radius.
Damaged ground system conductors shall be repaired or replaced.
5.20.5.2 Ground Rods
Where the required ground rod length exceeds 10 feet (3 m), ground rod standard sections shall be
welded together to provide an extended rod with one true centerline a minimum of joint resistance.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 920 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-53
During welding, the ground rod sections being welded shall be supported by a guide to ensure
proper alignment.
5.20.5.3 Ground Plates
Ground plates embedded in concrete shall be carefully located as indicated on the drawings and
firmly secured to the concrete forms. The threaded holes in the mating surface of round plates shall
be plugged prior to pouring concrete. The grounding conductor attached to the ground plates shall
be inspected prior to the pouring of concrete to ensure a good solid connection in accordance with
industry standards.
5.20.5.4 Column Grounding
Structural steel columns shall be grounded by use of a servit post installed in a pre-drilled hole in
the web of the column near the base as indicate on the drawings. The Contractor shall provide a
hole in the web of structural steel columns not so equipped for grounding provisions. The hole shall
be 9/16 inch (14 mm) in diameter and located approximately 8 inches (200 mm) up from the base.
Prior to the installation of the servit post, paint, scale, and other non-conductive substances shall be
removed from surfaces of ungalvanized structural steel members by grinding. Galvanized steel
surfaces shall be leaned with emery paper.
5.20.5.5 Conduit Grounding
All conduit grounding bushings within all enclosures, including equipment enclosures, shall be
wired together and connected internally to the enclosure grounding lug grounding bus with a bare
copper conductor. Grounding bushings shall be grounded with conductor sized in accordance with
the NEC, but not smaller than 8 AWG.
All grounding bushings on conduit runs which are terminated at tray shall be connected to the tray
grounding cable or tray side rail with bare copper conductor as indicated on the drawings.
Where a conduit run is terminated at tray and the conduit carries a separate insulated grounding
conductor, this grounding conductor shall be terminated on the tray grounding cable. If the conduit
run is terminated with a grounding bushing and the separate ground conductor it carries is sized in
accordance with the requirements of the preceding paragraphs for conduit bushing grounding, the
ground conductor in the conduit run may be continued through the conduit bushing ground
connection and terminated on the tray grounding cable making unnecessary the installation of a
separate conduit bushing grounding cable.
Conduit bushing ground conductors shall be connected to the tray ground cable using split bolt
connectors or an Owner acceptable equal mechanical connector.
Conduit terminated at equipment and device in threaded hubs shall not require additional
grounding provisions.
5.20.5.6 Tray Grounding
A bare copper grounding conductor shall be installed on all power level cable trays containing
single conductor power cables. The tray grounding conductor shall be installed on the outside of
the tray side rails, along the entire length of the trays, attaching to each tray fitting and to each
straight section of tray at 6 foot (1.8 m) maximum intervals. The tray grounding conductor shall be
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 921 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-54
attached to the trays using bolted ground clamps, and shall be connected to the ground grid at
locations indicated on the drawings. Splices for the tray grounding conductor shall be made using
compression connectors.
Cable trays containing multi-conductor power cables, control, or instrument circuits shall not
require a continuous ground conductor installed along the tray. Instead, these tray levels shall be
grounded by means of a ground jumper extended from the tray side rail to the continuous ground
conductor installed along a power level cable tray, to building steel, or to the ground grid.
Grounding intervals shall not exceed 100 feet (30 m).
Grounding jumpers shall be required across all expansion splice plates, dropouts and adjustable
splice plates where a continuous ground conductor is not installed along the tray level.
5.20.5.7 Equipment Grounding
Electrical equipment that requires a ground grid extension stinger shall be connected to the ground
grid with copper grounding conductor. The term "electrical equipment," as used in this section,
shall include all enclosures containing electrical connections or bare conductors except that
individual devices such as solenoids, pressure switches, and limit switches shall be exempt from
this requirement unless the device requires grounding for proper operation. Equipment will be
furnished with grounding pads and/or ground lugs which the Contractor shall connect to the
ground grid. All ground connection surfaces shall be cleaned immediately prior to connection.
Where ground grid extension stingers are used for connection to electrical equipment, the
Contractor shall connect the grounding conductor to the equipment ground bus, pad, or lug.
Where a ground conductor is included with the phase conductors of power circuits, the ground
conductor shall be connected to the equipment grounding facilities and to the source ground bus.
Where a ground conductor is not included with the phase conductors, the equipment shall be
grounded by connecting a separate ground cable to the equipment grounding facilities and to the
tray ground cable or source ground bus. All equipment ground conductors which are not an
integral part of a cable assembly shall be sized in accordance with the requirements of NEC. All
ground conductors installed in conduit shall be insulated.
Circuits include an insulated ground conductor to all 6,900 volt, 4,160 volt, 480 volt, and 208 volt
loads to satisfy the requirements of the preceding paragraph. This ground conductor is either a
separate cable, Type GI, or is contained within the multi-conductor power cable. Power circuits
from 120/208 volt power panels contain one additional conductor which is used for grounding
smaller devices which require 120-volt power.
The Contractor shall design, furnish, and install all equipment grounding cables required in
addition to the ground cables to devices which have electrical connections but do not require a
power circuit such as junction boxes and control equipment enclosure.
Suitable grounding facilities shall be furnished on electrical equipment not so equipped. The
grounding facilities shall consist of compression type terminal connectors bolted to the equipment
frame or enclosure and providing a minimum of joint resistance.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 922 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-55
Suitable grounding facilities for electrical equipment not so equipped, but requiring multiple
grounding connections, shall include the installation of a bare copper ground bus for the connection
of several grounding conductors. This ground bus shall be connected to the equipment frame or
enclosure, providing a minimum of joint resistance.
The conduit system is not considered to be a grounding conductor except for itself and for lighting
fixtures. No equipment grounding conductor shall be smaller in size than 12 AWG unless it is a part
of an acceptable cable assembly.
5.20.6 Grounding Measurements
All ground resistance measurements shall be made with the Four-Point Fall of Potential method as
defined in IEEE 81. Some of the acceptable instruments are as follows:
Advanced Geosciences, Inc., Sting R1, Mini Sting, Super Sting R1, or Super Sting R8
Iris Instruments, SYSCAL R1 Plus, SYSCAL R2, or SYSCAL Pro
The grounding point shall be connected to any bare copper grounding conductor (e.g. fence ground)
as the system reference point (E). The minimum distance from E to the current electrode (CE)
should be 5-6.5 times the diagonal distance of the grounding system being measured. Resistance
measurements shall be taken with the potential electrode (PE) at 1%, 10%, 20%, 30%, 40%, 50%,
60%, 61.8%, 70%, 80%, 90%, and 99% of the diagonal distance. The Contractor shall compare the
reading at point (E) to the theoretical value from the step and touch analysis. The test shall be
performed with all phase and ground connections lifted so that the equipment being tested is
isolated from the rest of the grounding system. Testing direction shall be perpendicular to any
parallel conductive path (trench, conduit, fence, overhead or below-grade lines, etc.) A sketch of the
testing route shall be provided for each test. Contractor shall ensure that this testing is done in
accordance with Engineer of Record’s requirements from the step and touch analysis.
5.21 ELECTRICAL STARTUP, TESTING, AND CHECKOUT
5.21.1 General
This section describes and defines general criteria which pertain to the startup, testing, and
checkout work covered by these specifications. This work is in addition to testing activities
required in other sections of this specification. The Contractor shall be responsible, as part of the
base scope, for all labor and materials required to demonstrate that the electrical equipment has
been installed correctly and functions properly. Functional testing shall include a demonstration
that all major equipment installed can be operated in accordance with the design from local and
remote stations, control loops and protective devices perform as designed and other equipment
operates in accordance with their specification. After such demonstration, the systems and
components shall be turned over to the Owner. Upon acceptance of completion, the Contractor shall
provide standby craft labor to correct discrepancies found during initial operation on a time and
material basis when requested by the Owner. Such standby craft labor shall not be utilized for
completion of Contractor Punch List items for work later identified as resulting from Contractor's
lack of construction completion or Contractor's warranty work. Construction checkout of all elec-
trical systems shall be provided by the Contractor subject to approval by the Owner. The scope of
work extends to all equipment connected and/or installed under these specifications.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 923 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-56
The Contractor shall supply to the Owner their proposed electrical and instrumentation testing
procedures for review and document all testing and inspections.
5.21.2 Codes and Standards
The Contractor test procedures and plans must meet NETA and IEEE standards for testing
substation equipment including, but not limited to transformers, relay protection, surge arresters,
disconnect switches, cables, station batteries, circuit breakers and capacitor banks (if applicable),
as well as circuit loop checks and control loop checks.
Documentation of all necessary equipment capabilities, settings, testing and commissioning shall be
provided in sufficiency to meet NERC (PRC & FAC) standards requirements.
5.21.3 Execution
5.21.3.1 Inspection
The Contractor shall inspect the installed instrument systems and the installed equipment specified
herein prior to starting calibration and checkout and shall report in writing to the Owner all
deficiencies that could prevent proper checkout of such equipment and systems. Such deficiencies,
if caused by or during installation by the Contractor, shall immediately be corrected. All equipment
inspections shall be prepared for operation as recommended by the equipment manufacturer, as
outlined in the Exhibit Y, and as directed by the Owner.
The Contractor shall perform an infrared inspection after energization to all substation critical
equipment and parts in order to determine connection issues and eliminate heat related damage
and failure. Critical equipment and parts include, but are not limited to transformers, circuit
breakers, disconnect switches, bushings, surge arresters, cooling systems, and tap changer tanks.
5.21.3.2 Discrepancy Procedure
The Contractor shall endeavor to promptly discover major discrepancies in equipment, materials,
and installation so that corrective procedures can be initiated without delay. When the Contractor
discovers equipment with an incorrect rating, damage, not being as specified, or is otherwise
unsatisfactory, arrangements will be made for replacement of the equipment. The Contractor shall
promptly report to the Owner any improper field installations or material usage which the
Contractor believes should be corrected. The Owner will arrange for corrective action.
5.21.3.3 Calibration in-Place
All equipment furnished and installed by the Contractor shall be calibrated at the site after
installation. The Contractor's technicians performing the calibration shall be experienced in the
calibration and adjustment of mechanical equipment and final drive devices. Technicians shall be
experienced in working with the necessary diagrams and documents in accordance with the
calibration and checkout work assigned to each technician.
Devices and equipment shall be adjusted and calibrated with the equipment normally installed in
place. Exceptions to this procedure will be permitted with the concurrence of the Owner for the
specific device categories for which in-place calibration is not practical.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 924 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-57
5.21.3.4 Calibration Range
Analog devices shall be calibrated to be accurate within the manufacturers' specified tolerances
over a range of 0 to 100 percent full range, with check readings for accuracy and hysteresis at 0, 25,
50, 75, and 100 percent. Digital or switch contact devices shall be set to actuate or change state at
the required process condition, and shall be checked for accuracy and hysteresis (deadband) at this
condition. Both accuracy and hysteresis for both analog and digital devices shall be certified to be
within the manufacturers' stated tolerances.
5.21.3.5 Minor Corrections
Equipment and devices furnished by others may require minor correction to ensure correct
operation following calibration and checkout. These minor corrections may include the following:
Minor assembly operations within instruments.
Removal of factory shunts or jumpers.
Minor wiring corrections.
The Contractor shall perform minor corrections as part of the work defined by these specifications.
In exceptional cases, the Contractor may judge that timely completion of the work requires
discrepancies to be repaired by the Contractor. In such cases, the Contractor shall include repair of
these discrepancies as part of this work.
5.21.3.6 Contractor-Caused Defects
The Contractor shall promptly repair at no additional cost to the Owner any equipment or devices
which are damaged by the Contractor's personnel in the course of performing the work. Such
defects shall be promptly reported to the Owner.
5.21.3.7 Manufacturers' Procedures
Drawings and installation and operating instructions from manufacturers of the equipment
appropriate to the work described in these specifications will be made available to the Contractor
as required. The Contractor shall follow the manufacturers' instructions in the performance of this
work and perform all required and recommended tests, calibrations, and settings identified in these
instructions.
5.21.4 Equipment Testing
The Contractor shall provide all required tools and test equipment to perform the work in
accordance with these specifications and the Project Schedule. The test equipment shall be
periodically certified. Any test equipment found out of tolerance during certification shall be
replaced or repaired.
The Contractor shall include a list of test equipment provided, including manufacturer and model.
The Contractor shall provide as many items of each category as are required to perform the work in
accordance with the project schedule. The Contractor shall provide the Owner with a copy of all
certifications for test equipment used on the project including any recertifications or replacement
certifications.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 925 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-58
5.21.4.1 Test Instrument Certification
Test instruments subject to drift or nonobvious miscalibration shall be certified at least weekly. The
Contractor's QA/QC Program shall be capable of providing verification that the certification is being
performed.
Certification methods shall follow recommendations of the test instrument manufacturers.
The Contractor's personnel performing certification shall be specially trained in the methods and
procedures for carrying out these calibration certifications.
5.21.4.2 Calibration or Testing Certification Sticker
The Contractor shall furnish and affix a self-adhesive label to each device calibrated or adjusted.
The label shall indicate the date and the name of the person performing the calibration or
adjustment.
5.21.4.3 Startup
Startup will be under the jurisdiction of the Owner throughout the startup period.
Except as stated elsewhere, the Contractor shall render all services and do all work required to
place each item of equipment installed, including all auxiliaries, in operating condition to the
satisfaction of the Owner. All equipment shall be prepared for operation as recommended by the
equipment manufacturer.
Individual systems and items of equipment shall be completed in a sequence that will permit
systematic checkout and trial operation of each such component before it is incorporated in the
initial operation.
Operating interconnection procedure between Owner and Transmission Owner shall be in
accordance with document EEI-073.
5.21.4.4 Equipment Checks and Calibration
Preoperational checks and inspections shall be performed on all equipment as specified herein, and
in accordance with the equipment manufacturer's recommendations. A representative of the
Contractor shall be present during the equipment checks.
The Contractor shall verify in writing that all work and preoperational checkouts have been
completed and, when the services of equipment manufacturers' field service representatives are
specified, the Contractor shall include verification by such representatives that the equipment is
ready for trial operation.
5.21.4.5 Electrical and Instrumentation Checkout
This section defines the scope of electrical and all instrumentation devices and equipment which
shall be calibrated in-place, adjusted, or checked out by the Contractor as part of the work covered
by these specifications.
The Contractor shall provide all temporary instrumentation and gauging devices required during
checkout and trial operation of the equipment and systems.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 926 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-59
5.21.4.6 Preoperational Equipment Checks and Testing
Preoperational checks and testing shall be performed on all equipment as specified herein and in
accordance with the equipment manufacturer's recommendations. A representative of the
Contractor shall be present during the equipment checks. All field tests shall be witnessed by the
Owner at the Owner's discretion.
The Contractor shall verify in writing that all work and checkouts have been completed, and when
the services of equipment manufacturer's field service representatives are specified, the Contractor
shall include verification by such representatives that the equipment is ready for trial operation.
Preoperational checks and testing shall include, but not necessarily be limited to, the following:
Safety Equipment
All coupling guards, belt guards, and other personnel safety items shall be installed. All bolting shall
be securely tightened to the correct torque as recommended by the equipment manufacturer.
Fire Protection
All fire protection systems and equipment shall be installed and operative.
Shipping
All temporary shipping braces, blocks, or tie rods shall be removed.
Lighting and Receptacle Checkout
The Contractor shall test, check out, and energize the lights and receptacles furnished and installed
under this Contract. Lights shall be energized as soon as circuits are complete to increase the
lighting level for construction and checkout. Immediately before energizing a lighting or receptacle
circuit, the Contractor shall make the following checks:
The transformer neutral supplying the source panelboard is solidly connected to ground.
The phase and neutral conductors to be energized are free from grounds.
All covers are on lighting fixtures, pull boxes, and junction boxes so exposed conductors will
not be energized.
The ground conductor (if required) is solidly grounded.
After completing the pre-energization checks, the Contractor may energize the circuit under the
direction of the Owner.
Metering
All metering, including panel meters and transducers, shall be calibrated to within the manu-
facturer's accuracy.
Unless specified otherwise, all meters shall be tested and calibrated with equipment of no more
than 50 percent of the manufacturer's stated accuracy instrument being tested.
All meters shall be visually inspected for damage, and wiring connections shall be verified in
accordance with the three-line diagrams.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 927 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-60
Panels
Panel instrumentation indicating lights, switches, and relays shall be adjusted and checked out as
part of the checkout of the Contractor-installed electrical equipment. Electric metering for volts,
watts, amperes, and other electrical quantity functions shall be checked out as described in this
section and the following section.
Panel indicators shall initially be calibrated by simulating the electronic signal normally received by
the indicator. The final calibration shall be performed using the actual transmitter, signal
converter, or system output to be connected to the indicator. The transmitter-receiver combination
shall be calibrated to read out accuracy tolerance no greater than twice the average tolerance of the
individual devices throughout the range from 0 percent to 100 percent of total scale. In certain
instances for specific equipment, the Owner will specify a range of interest. In these cases, the
Contractor shall calibrate the transmitter-receiver combination to read exactly correct with the
calibration standard being utilized, within the range of interest.
Electrical panel instrumentation shall be calibrated.
Every instrument utilizing a plastic lens or window shall be given a static effect check. The static
check shall consist of wiping the lens or window vigorously with a dry cloth of a type recommended
by the manufacturer which will not harm the surface. If the needle or pointer holds up-scale or
below zero set for more than 15 seconds, the surface of the lens or window shall be treated with a
clear antistatic compound recommended by the manufacturer.
Cables
All 5 kV and above power cable shall be very low frequency (VLF) hi-pot tested in accordance with
IEEE and ICEA standards.
Shielded cable ground checks should be made after termination is complete using a volt-ohm meter
to determine that each is grounded only at the points according to the drawings.
Additional cable testing shall include, but is not limited to conductor phasing, resistance of neutral
wires, and DC insulation (“megger”) tests. Optional cable testing may include, but is not limited to a
partial discharge (PD) test.
Main Power Transformer(s)
For each main power transformer, measurement of resistance to ground and polarization index of
each winding with all other windings grounded shall be made. Measurements shall be with a
winding tester. Measurements for each transformer shall be made immediately prior to placing in
service. If a transformer winding has a resistance to ground or polarization index less than
recommended by the manufacturer, the transformer will not be placed in service.
Complete check of all field wiring shall be made after installation and connection to verify that field
wiring is as indicated on the drawings and schematic wiring diagrams. Equipment jumpers as
indicated on the schematics shall be checked.
Additional main power transformer testing shall include, but is not limited to testing of insulation,
oil, CTs, ratio test for all tap positions, bushings, sudden pressure relays, pressure relief devices,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 928 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| Substation 5-61
controls (cooling fans, LTC, etc.), alarms and power factor. Site tested bushing results will be
compared to the results made during transformer factory testing.
Instrument Transformers
All instrument transformers, including bushing current transformers, shall be tested.
Ratio and polarity tests shall be performed on all instrument transformers. Current transformer
ratio and polarity tests shall be voltage ratio tests using a digital voltmeter or current ratio tests
using high current injection test equipment, as directed by the Owner.
Additional instrument transformer testing shall include, but is not limited to testing of insulation
resistance, ground, and continuity and phasing checks.
Surge Arresters
Surge arrester testing shall include, but is not limited to insulation resistance, low impedance path
to ground, power factor, and lead length and nameplate checks.
Circuit Breakers
Circuit breaker testing shall include, but is not limited to power factor, contact resistance, dielectric
withstand, timing, and SF6 (moisture, purity, and reactive gasses).
Disconnect Switches
Disconnect switch testing may include, but is not limited to contact alignment, closed contact
resistance, and orientation, clearances, and label checks.
Station Batteries
Station battery testing shall include, but is not limited to cell voltage, internal ohmic and load tests.
5.21.5 As-Built Drawings
The Contractor will furnish three sets of the following drawing categories to the Contractor for
markup purposes:
Electrical one-line and three-line diagrams
Electrical schematic and wiring diagrams
Interior and exterior cable schedules
The Contractor shall neatly and legibly mark each set, in triplicate, including all field corrections
performed during calibration and checkout. One copy of each drawing shall be submitted to the
Owner’s Engineer as a part of the completed forms returned with each subsystem startup or
turnover package. A second set will be turned over to the Owner for use during Start-up and
Commissioning. Submittal of these two sets to the Owner’s Engineer and Owner shall be concurrent
with completion of the startup or turnover package. The third copy shall be retained by the
Contractor until the conclusion of the project. The Contractor's copies shall be turned over to the
Owner at the conclusion of the project.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 929 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-1
6.0 SCADA and Communication Systems
The Contractor shall furnish and install the network, communication, and Project Collector
Substation SCADA System in accordance with this specification. This specification will convey the
scope of the Contractor.
Contractor shall provide the following deliverables including but not limited to: communication
block diagrams, communication cable list, schematic wiring diagrams, Project Collector Substation
SCADA System data point list, Transmission Provider and ,all configuration files in electronic
format, graphic screen development, system programming, Project Collector Substation SCADA
System hardware and software licenses, Project Collector Substation SCADA System desktop
computer and printer, onsite commissioning and acceptance testing for the Owner, preparation and
completion of any documents required by the Owner to establish that the Project Collector
Substation has been properly commissioned before interconnection is allowed.
6.1 NETWORK AND COMMUNICATIONS INFRASTRUCTURE REQUIREMENTS
6.1.1 General Requirements & Scopes of Work
All work regarding Project Collector Substation SCADA System, network, and communications shall
be in the Contractor’s scope except where explicitly stated otherwise in this document.
6.1.1.1 General
Contractor shall provide all trenching of the fiber infrastructure . This will include the fiber
cabling within the Project. It may also include fiber installation outside the Project
boundary. The layout of the fiber cables in the collection system shall follow the collection
power cable layout as closely as possible.
Contractor shall assign rack positions for all equipment, and provide drawings to convey
the design. Contractor shall also furnish and install all equipment racks.
Contractor shall provide all Ethernet cabling and connections including but not limited to
the Project SCADA system, WAN, Owner IT network, etc. The Ethernet cabling will be Cat-6
or better and should support power over Ethernet.
6.1.1.2 Construction
During construction, the Contractor will supply Internet and phones at construction
laydown yard work site for Owner, Contractor, and any Subcontractors. Aggregate Internet
connection for Owner shall be at least 20 Mbit/s download and 15 Mbit/sec upload and
satellite communication shall not be used.
2-way radio. During construction, the Contractor will set up a radio system for use during
construction.
o The Contractor will design/supply equipment for a portable, multi-channel two-way
radio system for use by Contractor and Owner during the construction phase.
o The radio system shall be configured to allow other Subcontractors of the Contractor
and subcontractors of the Owner (for example, the Turbine Supplier) to share two-way
communications and channels for tight coordination of work.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 930 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-2
6.1.1.3 Project Collector Substation
Contractor shall furnish and install Ethernet and serial cabling from relays, RTU’s (Remote
Terminal Units), etc. to Owner’s IT devices.
Contractor shall furnish and install collector fiber optics, test, and terminate to cross
connection panel and then to Project SCADA System cabinet Ethernet switches.
Project Collector Substation may utilize microwave data connection. This option is not
primary WAN interconnection but may be required.
In order to avoid high voltage isolation equipment, the Project Collector Substation shall not
utilize copper data lines of any sort (examples: POTs (Plain Old Telephone Service), T1 over
copper).
Contractor shall furnish, configure, and install RTU.
Contractor shall design Project Collector Substation SCADA System interface with Owner PI
historian. This involves programming RTUs to communicate with an Owner PI historian,
via OPC (Object Linking and Embedding for process control) and/or DNP3 (Distributed
Network Protocol).
Contractor shall provide quantity of two (2) 2-post communication racks and two (2)
Project Collector Substation SCADA System cabinets in building design. The power to these
cabinets should be backed up by the Project Collector Substation battery system, providing
at least ½ hour of backup power. The racks will grounded per applicable standards.
o The 2-post communication rack should be equivalent to Chatsworth Products p/n
55053-703, which is a standard 2-post to accommodate 19” EIA width equipment, 3”
deep rack with at least 7’ height. The standard 2 post rack will have vertical cable
management on both sides of each 2-post rack. The standard 2 post rack will have
vertical cable management on both sides of each 2-post rack, Chatsworth Products p/n
30162-703 or equivalent.
Each 2-post communications rack will have -48 VDC power in each rack.
There will be two -48 VDC power circuits that terminate to a Telect fuse
panel with at least 10 fuse positions (A and B feeds). If the station battery
power needs to have DC to DC conversion (from higher stack voltage down
to -48VDC), each rack will contain a DC to DC converter.
Each 2-post communications rack will have (2) 30A AC circuits terminated
to Power Distribution Units (PDUs) (with 5 outlets minimum)
o The two Project SCADA System cabinets (supplied by Turbine Supplier) will need one
square meter floor space each and are 1,850 mm tall x 625 mm wide x 1,200 mm deep
and weighs about 500 kg. Cable entry can be through either the top or bottom of the
rack. 48 inches / 1.2 meters must be allowed in the front and the back of the rack for the
doors to open. Power requirements are two circuits of 120 VAC / 60 Hz / 30 A / NEMA
L5-30R Outlet. To be supported by Project Collector Substation batteries, an inverter
shall be provided by the Contractor.
The Owner will be in charge of cyber security at the wind farm. The Owner will install a
firewall to isolate the Project’s control network.
Contractor shall provide DC power in each rack position. Contractor shall design the
battery system required to provide -48 VDC power, with one Telect DC fuse panel in each 2-
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 931 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-3
post rack. Contractor shall provide one AC inverter in each 2-post rack, providing at least
50Amps total output at 120 VAC, 60 Hz, and at least 4 power outlets. The power to these
racks should be backed up by the Project Collector Substation battery system, providing at
least ½ hour of backup power. The Transmission Owner shall be given at least 2 rack
positions, with enough space for working, DC power, backup power requirements, etc.
6.1.1.4 Facility Security
Contractor shall furnish and install the following security-related devices and equipment for the
entire site, including the Project Collector Substation. Please refer to Section 2.4 for applicable
standards.
Data and power wiring for security cameras, badge readers, control panels, etc. These will
be on the Project Collector Substation building. Contractor will install conduit for cameras
or badge readers per A-3.1 near the gates and corners of the Project Collector Substation
yard. Design space for access control panels.
Contractor to coordinate purchase of doors to meet Owner standards.
6.1.2 Required Equipment
6.1.2.1 Project Collector Substation
Firewall
Other WAN equipment
Ethernet switch (used to communicate with RTUs, WAN interconnection router, and MUX
Phone
Cameras
Badge Readers for door
Fiber patch panels, for inside Project Collector Substation building and outside
DC batteries, Telect fuse panel (containing at least 10 fuse circuits), for at least 40ADC at -48
VDC.
DC-DC converters, inverters, as needed
Project RTUs. Quantity of RTUs will be determined by the design, but anticipate 2 or 3 RTUs
will be required
HMI Computer, the interface to Project RTUs
Serial to Ethernet converters
2-post racks and 4-post cabinets per Contractor design, interconnecting cabling, power
cabling, etc. for Project Collector Substation SCADA System, to Owner IT equipment and to
Contractor-provided RTUs, relays, power meters, Intelligent Electronic Devices (IEDs), etc.
Satellite-synchronized network clock, providing IRIG-B (inter-range instrumentation group)
protocol clock signal, SEL-2488
WindSCADA cabinet
WindCONTROL cabinet
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 932 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-4
All equipment within Project SCADA System cabinets
6.1.3 Required Drawings in Final Design Package
Contractor shall provide the following for Project Collector Substation unless stated otherwise:
Network block diagram – Owner will provide WAN connection details for this drawing.
Contractor will design relay protection network
Wiring diagrams for all equipment
Panel layout diagram
Fiber one-line diagram
Equipment elevation drawings
6.1.4 Standards
Contractor shall provide a network and communication system that complies with all NERC (North
American Electric Reliability Corporation) CIP (Critical Infrastructure Protection) and COM
(Communications) requirements, as well as any applicable internal Owner standards.
6.1.5 Communication Protocols
Contractor shall configure RTU and other devices to interface with Project SCADA System.
Only the following communications protocols shall be allowed:
MODBUS, for connection of RTU to Project SCADA System
DNP3, Owner’s preferred protocol for all Project Collector Substation SCADA System
interfaces. Used in the control center communications to Project Collector Substation
SCADA System RTUs for monitoring and control. Used in PI Historian interfaces to RTU.
OPC, PI Historian to Project SCADA System for data collection
SEL communications protocol, SEL-ASCII, used in RTU to IED communications, remote
engineering access, MV90 access (metering)
For IT security reasons, only serial communications to/from the RTU will be allowed unless
approved by Owner.
6.2 PROJECT COLLECTOR SUBSTATION SCADA SYSTEM REQUIREMENTS
6.2.1 Project Collector Substation SCADA System Communication Design
The Project Collector Substation SCADA System will interface and exchange information with the
Project SCADA System provided by the Turbine Supplier, Owner SCADA System and the
Interconnection SCADA System. The Project Collector Substation SCADA System will, at a minimum,
accept trip commands from the Owner’s remote control center to isolate the Project from the local
electrical grid. The Project Collector Substation SCADA System will be comprised of RTUs, and
ancillary equipment to connect with IEDs and other systems.
The Contractor will coordinate with the Owner’s telecommunication engineering, system
protection, Generation Dispatch control center (GDC), and Distribution Dispatch Center (DDC)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 933 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-5
subcontractor teams to design and specify the Project Collector Substation SCADA System and
equipment.
The Project Collector Substation SCADA System will provide the following for all the equipment
contained in the Project:
Modulating (continuous) control
Discrete (sequential) control
Alarm monitoring and report generation
Information display
System data reporting and trending
Short and long-term data storage
An IRIG-B signal shall be distributed to protective relaying devices by the RTUs for
transformer protection.
Contractor shall prepare communication block diagrams of the Project Collector Substation
illustrating the interconnection of the Project Collector Substation SCADA System devices located at
the Project Collector Substation, the Project SCADA System, and the Interconnection SCADA System.
The block diagram shall identify devices, port number, communication cable type, protocols and
device addresses at a minimum. The block diagram shall also indicate communication devices
outside of the project (e.g. Owner IT network), as well as network connections from the telecom
provider.
Contractor shall design, procure and install the equipment and programming necessary to interface
with the Project Collector Substation SCADA System via a permanent desktop computer located in
the Project Collector Substation.
All equipment operations or changes performed by an operator through the Project Collector
Substation SCADA System shall require the operator to be logged in. The operator’s actions shall be
recorded as part of the Project Collector Substation SCADA System’s data logger.
An historian shall also be integrated into the Project Collector Substation SCADA System such that it
retains all data points captured by the Project Collector Substation SCADA System for a rolling two
year period. All currently stored data shall be downloadable from the historian when accessed by
the Owner. The Owner shall be allowed access to historian upon request.
6.2.2 Control Display Screens
The Project Collector Substation SCADA System shall include an HMI computer designed to provide
means for the operator to monitor and control the Project and Project Collector Substation
equipment. Each control display shall contain textual, geometric graphic, dynamic analog trending,
dynamic bar chart, and alarm information representing plant systems, equipment, and other
process information. Owner will own all software licenses after turnover to Owner.
The control displays shall be implemented on a high-resolution display system that, at a minimum,
includes the following capabilities:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 934 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-6
One computer suitable for installation in the Project Collector Substation, with monitor,
keyboard, and mouse. The computer will have either MS Windows or Linux operating
system. The entire system should be housed for operation in one of the 2-post racks.
One computer suitable for installation in the O&M Facility office, with monitor, keyboard,
and mouse. The computer will have either MS Windows or Linux operating system.
Dynamic numeric data linked to analog variables shall display the current numeric value of
the variable, scaled as specified in the database, with engineering units.
The latest in pictorial abilities such as automation of symbols with three-dimensional
effects applied to lines and symbols shall be available.
Standard geometric shapes shall include, as a minimum, lines, polygons, rectangles, arcs,
and ellipses.
Standard geometric symbols (circuit breakers, transformers, protective relays, etc.) and the
ability to create new symbols using standard symbols and standard geometric shapes shall
be included.
The Project Collector Substation one-line power schematic should be one of the available
display screens, displaying the status of all circuit breakers. Green status is used to show a
breaker is open and red is used to show a breaker is closed. This screen should also display
the present 345kV voltage and current readings.
The capability to fill any closed geometric shape with any available color shall be included.
This capability shall allow fill in proportion to the value of an analog variable, and to select
the fill color in response to the analog variable or according to the status of a discrete
variable.
The display system shall also include the following user selectable capabilities:
o Creation, modification, and selection of colors in the color library.
o Definition of attributes of all textual and geometric graphic elements, such as color, line
weight, line type, blinking, and dynamic conditional linkage to system variables and
attributes.
The system shall provide, at a minimum, the capability for any control display to show 200 dynamic
variables (analog and digital) and/or geometric symbols, control 10 data entry points, and control
100 target points. Based on an operator clicking on or selecting a dynamic variable, the system shall
provide the functionality to jump directly to its point detail display. Through operator entry of a
value into a data entry point, the system shall provide the functionality to store and use that value
for system and equipment control. By an operator clicking on or selecting a target point, the system
shall activate a "pop-up" control to allow system and equipment control.
6.2.3 Trend Displays
Trend displays shall simulate a multiple pen strip chart recorder and shall consist of a time plot of a
minimum of five points concurrently. Each trace shall be in a unique color. Alphanumeric
information shall be overlaid on the same screen to identify points, scales, current value, and
related information. Chart roll-down shall be included. Chart roll shall be in the horizontal direction
with the latest value appearing at the right-hand side of the screen. Time shall be plotted on the
horizontal axis. The operator shall be able to set the zero and full-scale values for each trended
variable in any screen location. The system shall permit the operator to set the grid roll speed and
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 935 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-7
the interval between time lines. The system shall provide standard trend displays with variable full-
scale time ordinates. All trends shall be backward and forward scrollable from the trend start time.
Selection of points to be trended shall be menu driven.
The system shall allow any system variable to be trended, and shall allow points from short-term
and long-term storage to be trended. The trend display period between points on trends using data
from short-term and long-term data storage shall be the same as the storage frequency selected for
those points. Trending resolution shall not be coarser than ±0.5% full scale using pixel displays.
The system shall also provide the capability to incorporate trend displays into any user-created
control or information display.
6.2.4 System Acceptability
The equipment used in the design must be in commercial operation in a minimum of five power
generating plants of scope and magnitude similar to that for which the equipment is proposed or
provided as a part of this Contract. The system shall be compatible with the electromagnetic
environment in which it will operate, and shall not misoperate or sustain damage from the
influence of radiated or cable conducted fields typically found in power generating plants. The
system shall be designed and equipped to withstand, to the maximum extent possible, lightning
surge by atmospheric electrical disturbance without damage or disruption. The system architecture
shall accept new technology as it becomes available, and future system enhancements shall be
compatible with the equipment supplied under this Contract so that extensive hardware and
software retrofitting is not necessary. The Contractor shall not propose nor provide equipment
from any manufacturer that is expected to be superseded or outdated by a later generation of
equipment prior to the commercial operation date. All equipment shall be new, unused, and of the
highest quality available from the manufacturer.
6.2.4.1 Failure Modes
The Project Collector Substation SCADA System’s design shall carefully consider the effects of
potential hardware and software failures on the functions being performed by the system.
Contractor shall design the system to do the following:
Detect failures by the use of continuously running diagnostic routines and bring them to the
operator's attention.
Provide hardware and software designs that react to failures in a predictable and
repeatable manner.
Mitigate the effects of failures by the use of equipment redundancy, software error
correction, or other available means.
The system shall meet NERC failure reporting requirements
6.2.4.2 Fault Reporting
Contractor shall ensure that the Project Collector Substation SCADA System meets NERC fault
(power system short circuit events) reporting requirements.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 936 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-8
6.2.5 System Interface Requirements
The update rate, processing rate, and response time of all control processors, the data highway
communications network, and of the overall system shall be sufficient to maintain control over the
equipment under all system operating conditions, including extreme upset conditions with all
points in alarm.
The following Project Collector Substation SCADA System interfaces will be implemented
(associated group named). The Contractor will coordinate with the Owner the development and
programing of Project Collector Substation SCADA System database for each interface with the
named group (quantity is preliminary and relationships to be finalized by Contractor during
detailed design):
GDC master-to-RTU slave
GE SCADA (WIND SCADA) master-to-RTU slave
RTU master to GE SCADA WindControl slave
PI Historian master-to-RTU slave (Owner’s PI historian)
RTU master-to-revenue meter(s) slave (system protection)
At a minimum, the system shall scan all inputs and outputs, process all control logic, and perform all
other functions required to record the changes and the time of the changes as follows:
The scan rate for all I/O (Input/Output) shall be user selectable (must allow I/O scan every 0.5
second as a minimum).
RTU: Analog inputs and analog outputs shall be scanned at least every 0.5 seconds with at
least 10 percent of the inputs and outputs able to be scanned at a 0.1 second interval.
RTU: Digital inputs and digital outputs shall be scanned at least every 0.5 second.
Relays: Digital sequence of events (SOE) inputs shall be scanned at least every 0.001
second. The time resolution of SOE points in different control processors shall be the same
as SOE points residing in the same control processor.
All non-SOE alarms shall be time tagged to a resolution of 0.5 second (or as specified in the
I/O database).
Relays: The processing rate for all control logic routines and calculations shall be
individually selectable.
Modulating control logic and calculations shall be processed at least every 0.5 second with
the capability to process at least 10 percent of the logic at a 0.1 second interval.
Discrete control logic shall be processed at least every 0.5 second.
At a minimum, the system shall respond to operator commands and control system changes as
follows:
Time to completely generate a display shall not exceed 2 seconds.
The indication of any variable, on all displays including alarm displays, shall be updated
within 1 second of its value or status change.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 937 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-9
The time to respond to any operator command shall not exceed 1 second.
The time to respond for FDI (foreign device interface) functions shall not exceed 1 second
(response time will not include the time required for the foreign device to respond to the
Project Collector Substation SCADA System; only the actual bi-directional communication
time shall be considered).
The response time is the total elapsed time for transmission of data through the system
communications path. This time shall include all communication time from control processor to
control processor, I/O scans, nodes, FDIs, monitors, keyboards, and associated equipment internal
to the system.
6.2.6 Remote Web Server Interface
Contractor shall provide the hardware and software necessary to allow remote access of real-time
process information by any Intranet web browser on any connected personal computer (PC).
Contractor shall also provide remote access client licenses, if required.
The interface shall allow client PCs with web browsers to dynamically display process values and
data, displays, trends, and reports. The remote web server interface shall also, at a minimum,
provide the following functionality:
Connectivity through company Intranet connections, dial-up connections, and standard
Internet connections.
Read-only access to all process information of the Project Collector Substation SCADA
System, including access to the point database information and live and historical trend
data.
Ability to convert Project Collector Substation SCADA System graphics to web based objects
to allow graphics access from standard web browsers.
6.2.7 Minimum Required Points List
Contractor shall program Project Collector Substation SCADA System RTUs to provide, read and
report data tags/points for communication to and from the Owner’s Pi Historian, Owner SCADA
System and control centers and Project Collector Substation IEDs. Contractor will be responsible
for generating the actual points list through discussion and coordination with Owner.
6.2.8 Project Collector Substation SCADA System Functional Control Requirements
The RTU will receive MW (megawatt) set point from Owner’s GDC, and forward this to the Project
SCADA System. The RTU will send response messages back to GDC, based on messages from the
Project SCADA System.
The RTU will send regular status messages to Owner GDC and DDC (Distribution Dispatch Center)
control centers of breaker status, voltage, current, and power (VAR (Volt-Ampere Reactive and
MW) measurements. The status message rate will be communicated to the Contractor. Any fault or
alarm messages will be sent to Owner GDC and DDC as they are generated.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 938 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| SCADA and Communication Systems 6-10
6.2.9 Project Collector Substation SCADA System Commissioning Requirements
Contractor shall develop test plans (which the Owner will approve) then perform the test and
verifications of the Project Collector Substation SCADA System including but not limited to the
following:
Verify RTU communication with Project SCADA System
Verify RTU communication with Owner IT network and Owner control centers (Owner
SCADA System)
Verify RTU and power meter communication with Transmission Owner/operator as needed
(Interconnection SCADA System)
Verify remote RTU Project Collector Substation SCADA System control/login ability,
connections and data transfer of all points and data tags to the Owner Pi Historian and
Owner SCADA System.
Verify functionality of the individual RTUs, relays, and other IEDs.
Verify functionality of MW output set-point (curtailment)
Verify functionality of any line drop compensation algorithms (if applicable)
Verify functionality of voltage control at the POI (point of interconnect)
Verify functionality of the reactive power control (ability to maintain required power factor
at the POI)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 939 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-1
7.0 MET Tower
7.1 PERMANENT MET TOWER
This specification is for the complete engineering, procurement, installation, testing, and
commissioning of meteorological (MET) towers for power curve testing and site monitoring
purposes. Contractor shall furnish and install two permanent MET towers in accordance with this
exhibit and the applicable sections of the most current accepted standards for power curve testing,
as specified by the IEC 61400-12-1, MEASNET, and applicable technical documentation from the
Turbine Supplier.
The Contractor shall procure and install two permanent met towers, the power required to operate
the equipment and the instrumentation of the permanent met towers in accordance with these
specifications. The Contractor shall furnish and install low voltage cable, fiber optic cable and
grounding conductor from anemometer masts to the nearest wind turbine. Grounding rings and
associated rods shall be provided and installed at each permanent mast to meet applicable codes.
Locations listed above are considered indicative at this time. Permanent met towers shall be placed
into service prior to the scheduled date of power performance testing. It shall be designed with
intent for all components, with the exception of wind monitoring and logging equipment, to remain
in service for the life of the wind farm.
The tower shall be a self-supported galvanized steel lattice structure designed for maximum wind
and ice loading and shall be certified for the particular site conditions. The tower shall be designed
and fabricated to the latest EIA/TIA-222-H structural Standards for Steel Antenna Towers and
Antenna Supporting Structures. The Contractor shall furnish and install FAA obstruction lighting
onto the tower as required by the FAA lighting design. The MET tower design shall incorporate a
safety climb cable. The MET tower foundation shall be designed according to the specifications of
Section 3. The Contractor shall also install sufficient grounding as specified in the latest IEC 61400-
12-1 and EIA/TIA-222H standards. The area around the tower shall have a chain link fence in,
enclosing a perimeter of approximately of 150 feet, to protect the facility from the public. The fence
shall contain a walk-in gate door with a 2 foot clearance to the ground. The gate shall accept a
padlock to keep closed and locked to protect the facility. All enclosure electrical boxes at the
ground level shall be lockable with a padlock.
7.2 TEMPORARY MET TOWER
All equipment and instrumentation on the permanent MET towers shall be connected to the Project
SCADA System and supply data to the Turbine Supplier’s SCADA client. Permanent MET tower data
shall be available to the Owner through open platform communications (OPC) (or similar interface)
for consumption in a PI database (or similar system).
Contractor Scope of Work is as follows:
Tower design (with additional antenna loads), grounding design of compound, fence
perimeter length determination.
Civil work, rock base, ground grid procurement and installation.
Procure and erect tower, fence, gates, Met equipment, ice bridge structure.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 940 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-2
Procure a DC-DC converter to supply DC power to MET equipment.
Pour concrete pad for 12’x16’ building, a concrete pad for a generator, and concrete for ice
bridge footings.
Procure and install underground conduits for power cable from generator pad to building
pad and a conduit from an H-frame outside fence to the building pad. Each conduit rises up
to a disconnect switch, mounted on the outside of the building.
Provide and install cable of 240VAC power from nearest turbine, 100 amp rating.
Provide and install 400/240 VAC transformer at nearest turbine, KVA rating to match
power requirements.
Setup, configuration, troubleshooting of MET equipment.
Provide and install fiber optic connection according to contract. 12 fiber bundle is delivered
to the tower as follows:
o One pair will connect to MET equipment: this is part of the wind turbine network.
o One pair will connect to radio equipment and will be fused back to the substation as a
continuous fiber.
Deliver drawings in DWG format.
Offload building from truck to concrete pad at MET location. If pad not available to store
building or in laydown yard, move to pad when available.
Connect 240 power from turbine to the building’s disconnect switch.
The Contractor shall procure and install four temporary MET towers as well as the power
required to operate the equipment and the instrumentation of the temporary MET towers.
Temporary towers shall be guyed, triangular lattice MET towers. The Contractor will
remove temporary towers from service after completion of power curve testing. No fence
will be required for the temporary towers. Upon removal of the temporary towers, land
shall be restored to the pre-existing condition. The Contractor will not be required to
furnish and install low voltage cable, fiber optic cable and grounding conductor from
anemometer masts to the nearest WTG. Contractor shall provide standalone power supply,
communications, and lighting for the tower sufficient to meet all tower needs.
Solar/battery power and cellular or satellite communications are acceptable.
In order to minimize cost, the tower structures and associated components may be ‘rented’
from a tower supplier.
All power curve standards and safety guidelines must be met. Instrumentation placement
and configuration shall be completed in order to satisfy requirements for power
performance testing and be subject to approval by the Owner prior to implementation. 90
meter temporary tower sensor and logging equipment shall conform to those listed in
Exhibit A-4.2. The 80 meter temporary tower sensor and logging equipment shall conform
to those listed in Section 7.3.
7.3 TOWER AND INSTRUMENT SPEC – 80 METER
This specification is for the configuration of the towers and instruments for 80 meter MET towers
for power curve testing. It provides the potential tower installation team the information they need
regarding sensor types and measurement heights, boom lengths and orientations, and other
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 941 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-3
configuration details. The specifications adhere to the various requirements of IEC 61400-12-1 (2 nd
Edition) and MEASNET.
The Richland Wind Park will require two temporary towers of height 80 meters. Temporary towers
are to be guyed triangular lattice and IEC 61400-12-1 solidity of 0.3 or less. The tower shall be
engineered to withstand 59.5 m/s winds. Additional requirements and details with respect to
Project temporary towers are provided in Exhibit A-4.3.
Government approved warning lights are to be applied in accordance with FAA requirements and
guidelines.
Hub height and rotor diameter are based on the GE 2.3-116 turbine at 80.0 meter hub-height. Any
sensor heights listed will need to be adjusted based on the exact turbine model and hub height that
is eventually used on the project.
The primary boom orientation is 60° true azimuth, with secondary orientation of 240°, as
illustrated below. These orientations may change during further review of the project.
The top view of the tower is provided on the following figure:
When side-mounted, boom lengths will be at least 113 inches in
total length, or 95 inches from the tower edge. The top
anemometer is on a vertical post.
One of the vertices of the triangular met tower should face into
the wind, and a flat face of the tower should face the potential test
turbine.

During construction of the towers it is critical that the installer strictly follow the sensor heights
provided in this document. The boom height will need to be adjusted downward to account for the
sensor height and the riser length from the boom to deploy the sensors at the specific height.
Table 1: Configuration should be self-explanatory. The sensor listing comes from the project
requirements and as specified by the IEC 61400-12-1 (2nd Edition), MEASNET and GE. Please refer
to the notes regarding the individual requirements of the various documents to the right of the
main table. Contractor will furnish all equipment listed in Table 1.
Alternative configurations and sensors are possible. If changes are desirable, please contact Owner
for additional guidance.
Figure G.1: Top-mounted anemometer shows the most relevant IEC 61400-12-1 meteorological
tower configuration for towers with top-mounted anemometers. Additional equipment is mounted
at 4 meters below the primary anemometer.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 942 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-4
80 Meter MET Instrumentation – Richland
TABLE 1: Instrument Configuration for Power
Performance Testing
Idaho Power Company
Revised 8/1/2018
Some IEC Class
1 rated
anemometers

Vector A100K:
Class
1.8A/4.5B
80 Meter Power Performance Test Reference
Meteorological Tower Configuration
WindSensor
P2546A: Class
1.32A/3.71B
Reference tower located 2-4 RD from test turbine/site
calibration locations, per IEC 61400-12-1 (2nd Ed.) and GE
siting requirements
NRG Class 1:
Class
1.01A/8.44B Thies First Class
Advanced (4.3351):
Class 0.9A/3.0B
Tower
face
width:
18" Tower type: lattice, triangular, guyed, with lightning protection, mounted at 240° and offset approximately 1 m
from the tower center, with a 60° protection umbrella to the top anemometer
Tower detail: round members, CT less than or equal to 0.3 (solidity, the ratio of the projected
area of all structural members on the side of the tower to the total exposed area, of 0.3 or less)
Guy wires must not cross upwind, perpendicular and
within a 1 m upwind radius from the anemometers or
vanes

Supply
Only
Install/Co
mmission
Sensor*
Manu
factur
er Model
Minimum
Required
Accuracy
Sensor*
*
Height
(m)
Boo
m
Orie
ntat
ion
(°)
Bo
om
Ty
pe
Boo
m**
*
Leng
th
(cm)
Bo
o
m
Di
am
et
er
(c
m)
Ris
er ^
Hei
ght
(cm
)
Ris
er
^^
Di
am
et
er
(c
m)Notes
O
wn
er
Con
trac
tor
O
w
n
er
Co
ntr
act
or
Primary
Anemomet
er Thies
1st
Class
Advanc
ed
IEC 61400-12-
1 (2nd Ed.) 80.0
Vert
ical
Ve
rti
cal 250 2.5 -----
----
-
IEC Class 1, as
close to hub
height as possible
with min. 1.5 m
from tower top x x
Secondary
Anemomet
er Thies
1st
Class
Advanc
ed
IEC 61400-12-
1 (2nd Ed.) 76.0 60
Sid
e
M
ou
nt 250 2.5 -----
----
-
IEC Class 1, at
least 4 m below
primary x x
Primary
Wind Vane Thies
±3°, 1°
resolution, <6°
dead band 76.0 240
Sid
e
M
ou
nt 150 2.5 20 2.5
Within 4 m to 10
m of primary
anemometer x x
Thermo-
Hygromete
r
Met
One
#083E-
1-35
±1°C, -15-50°C
/ ±2-4%, 5-
95% 74.0 180
Sid
e
M
ou
nt 10 2.5 -----
----
-
Radiation shield,
calibration
tested, within 10
m of hub height,
T/RH x x
Secondary
Wind Vane NRG 200P
±3°, 1°
resolution, <6°
dead band 73.0 60
Sid
e
M
ou
nt 250 2.5 -----
----
-
Within 4 m to 10
m of primary
anemometer x x
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 943 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-5
Supply
Only
Install/Co
mmission
Sensor*
Manu
factur
er Model
Minimum
Required
Accuracy
Sensor*
*
Height
(m)
Boo
m
Orie
ntat
ion
(°)
Bo
om
Ty
pe
Boo
m**
*
Leng
th
(cm)
Bo
o
m
Di
am
et
er
(c
m)
Ris
er ^
Hei
ght
(cm
)
Ris
er
^^
Di
am
et
er
(c
m)Notes
O
wn
er
Con
trac
tor
O
w
n
er
Co
ntr
act
or
Barometric
Pressure
Met
One #092
±5 hPa, 800-
1060 hPa 74.0 180
On
To
we
r 0
----
- -----
----
-
Calibration
tested, within 10
m of hub height x x
Vertical
Flow
Anemomet
er
RM
Young
27106-
T ----- 73.0 240
Sid
e
M
ou
nt 250 2.5 -----
----
-
To measure
upflow for data
screening x x
Lower
Anemomet
er Thies
1st
Class
Advanc
ed
IEC 61400-12-
1 (2nd Ed.) 22.0 60
Sid
e
M
ou
nt 250 2.5 -----
----
-
Lower blade tip
anemometer x x
Lower
Wind Vane Thies
±3°, 1°
resolution, <6°
dead band 22.0 240
Sid
e
M
ou
nt 150 2.5 20 2.5
Near lower blade
tip anemometer x x
Lower
Thermome
ter
Met
One
#083E-
1-35 ±1°C, -15-50°C 10.0 180
Sid
e
M
ou
nt 10 2.5 -----
----
-
Calibration
tested, 10 cm off
tower for
ventilation x x
Ground-
Level Baro.
Pressure
Met
One #092
±5 hPa, 800-
1060 hPa 2 - 10 180
H-
Fra
me 0
----
- -----
----
-
Calibration
tested, 2-10 m
above ground x x
Rain Gauge
Camp
bell
Scient
ific 237-L binary 2.0
Vert
ical
H-
Fra
me 100 2.5 -----
----
-
Mount on post, in
ground, away
from tower x x
GPS
Garmi
n
GPS16X
-HVS ----- 1.5 -----
On
Lo
gg
er -----
----
- -----
----
-
Mount on logger
box, for
synchronization x x
Data
Logger
Camp
bell
Scient
ific CR3000
1 Hz, 10 min
statistics 1.5 360
Ins
ide
Ca
bin
et -----
----
- -----
----
-
Requires power
source, near
ground, for
access, can be
uptower x x
Note: Sensor heights are
subject to change to be IEC
Ed. 2 compliant * Other sensors, or riser diameters may be used, see Class 1 anemometer list
starting in Cell G3, for example; contact Owner if you would like to make
changes ** Boom mounting height must be adjusted downward for the length of the
riser and the sensor body itself to ensure the sensor is at the designated
sensor height *** Assumes 18” tower width; Boom lengths for lower tower sections of larger widths to
be sized according to requirements specified by IEC 61400-12-1. Boom length measured
from tower leg nearest sensor to end of boom; total boom length to include one additional
tower face width (18") for mounting across full face width. ^ Riser height must be adjusted downward for the length of the riser and the sensor body itself, and must be at least
20 times boom diameter in total height to ensure the anemometer is at the designated height
^^ Riser diameter must be less than the anemometer
body, and the same as that used during anemometer
calibration

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 944 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-6
NOTES: Order-mounting hardware: as needed, sensor cables: to fit
distance between data logger and each sensor mounted on
tower. Annual tower
checks are
required.
Anemometers are to be of the same type and MEASNET calibrated before deployment and at least every 24
months by an accredited MEASNET laboratory in accordance with ISO/IEC 17025. Recalibrations must comply with
IEC 61400-12-1, Annex F.
The station needs spare sensors in order to continue operations while the
sensors (and logger as noted below) have calibrations checked and in case of
sensor failure.
Data logger must be calibrated before deployment and after each year of
field service. Calibration must follow IEC 61400-12-1 (2nd Edition)
requirements. Data logger must have a GPS system to ensure synchronicity of measurements
to time reference of UTC-6 hours, assuming a project location in the Central
Time Zone
Figure G.1: Drawing from IEC 61400-12-1:2016 (2nd Ed.), Mounting of
Instruments on the Meteorological Mast

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 945 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| MET Tower 7-7 Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 946 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-1
8.0 WTG Technical Specifications
8.1 STANDARDS AND CODES
Work performed under these specifications shall be done in accordance with the following codes
and standards. All work shall be governed by applicable international and national codes.
Supplier shall provide list of standards and codes used when codes differ from those detailed in this
specification.
Work
NOTE: The active, most current released version of these
standards at the time of contract signature shall apply.
Design and fabrication of the Wind
Turbine
IEC 61400-1 ed. 3: 2005, wind design class S, for wind
conditions as stated in the WTG general specification.
Type Certification of Wind Turbine
Design1
DNV-GL, TÜV Nord, or equivalent world-recognized certifying
agency
Design and fabrication of wind turbine
towers
Applicable portions of IEC 61400, EN 1090, ANSI B16.25, ANSI
B16.5
Design and construction of electrical
components
Applicable IEC standards, as well as relevant portions of UL
Standards.
Switchgear IEC
Step-up transformers IEC 60076
Lightning protection system IEC61400-24, and/or IEC 62305
SCADA system IEC 61400-25 and/or DNP3 and OPC protocol support for
remote access and operation
All other work All applicable national codes
Noise Relevant portions of IEC 61400, State of Idaho requirements,
Any additional local requirements
1Type certificate is required before COD.
These references shall govern the Work except where they conflict with Supplier’s and Purchaser's
specifications and requirements. In case of conflict, the more stringent requirement shall govern to
the extent of such difference.
The Wind Turbine Generators shall be type certified by a recognized international standards body
before the Commercial Operation Date. Type certification shall attest compliance with IEC 61400-1
design requirements for 60 Hz operation in the appropriate wind design class for the Project Site. A
copy of the type certificate shall be provided.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 947 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-2
Wind Turbine Generators shall be manufactured at facilities with current ISO 9001 Quality
Management System certification. Copies of applicable ISO 9001 certificates shall be provided.
8.2 PRODUCTS
8.2.1 Design Conditions
Wind Turbine Generators shall be horizontal axis three-bladed upwind machines with active pitch
and yaw control. Wind Turbine Generators including all filters, seals, heaters, and coolers, shall be
designed and constructed such that they are appropriate for installation at the Project Site. The
Wind Turbine Generator shall operate under the full range of temperatures encountered at the
Project site. Turbine design shall incorporate lock-out-tag-out (LOTO) provisions for all systems
and components which store energy or otherwise cause potential for personal injury.
8.2.2 Mechanical Equipment
The mechanical components of the Wind Turbine Generators shall be designed and tested to the
relevant parts of IEC 61400.
Wind Turbine Generator shall provide the means for safe evacuation of personnel from any and all
areas within or on Wind Turbine Generator in case of emergency or injury.
Wind Turbine Generator tower, nacelle, and blades, and hub shall be factory painted or otherwise
coated using Supplier’s standard color, provided standard color meets the requirements of FAA
advisory circular AC 70/7460-1L Marking and Lighting Wind Turbines for daytime marking of
Wind Turbine Generators.
Flange joints shall meet AISC or equivalent specifications. The flange joint shall be checked during
construction to ensure flanges are mated properly. Surfaces shall be flat and parallel as defined in
manufacturing drawings.
8.2.2.1 Tower
Wind Turbine Generator towers shall be self-supporting and fully enclosed. The towers shall be
designed to withstand the extreme load and maximum wind speeds of the relevant operating
conditions per the IEC 61400 standard.
Towers shall be accessible through a lockable access door at the base of the tower. If the access
door is above grade level, permanent metal stairs shall be provided. Metal stairs shall be non-slip
and include a metal hand rail, and be adequately coated for the Site conditions. Wind Turbine
Generator doors shall provide an adequate seal to minimize the entrance of dust, dirt and water
into the Wind Turbine Generator tower. Wind Turbine Generator tower door shall have a positive
means to remain latched open in strong winds.
Door vents shall have filters installed by Supplier. Filters shall be either cleanable for reuse or shall
use a standard available HVAC filter.
Towers shall include a permanently installed metal ladder allowing access to nacelle and all Wind
Turbine Generator equipment. Ladder shall be permanently affixed to tower using bolts, welds
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 948 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-3
and/or magnets. Access ladder shall have an integral climbing safety system. Ladder shall include
rest areas at reasonable intervals between tower sections.
Wind Turbine Generator towers shall include platforms between tower sections. Platforms and
floor surfaces shall have a fall prevention system such as a metal trap door or railing and include
anchors at each platform. Platforms and floor surfaces shall have non-slip surfaces.
Tower shall include electrical connections for service tools and auxiliary lighting at tower base and
at platforms between tower sections.
Supplier shall provide structural drawings and calculations verifying that the Tower designs
comply with the load requirements of the International Building Code (edition adopted by local
building department or other jurisdiction having permit authority), issued by a professional
engineer licensed in the State.
Tower design and components meet all OSHA, State, and local safety requirements and regulations.
8.2.2.2 Personnel Lifts
Not Used
8.2.2.3 Nacelle
Wind Turbine Generator nacelles shall house and protect the internal components of the Wind
Turbine Generator against various environmental factors, including rain, snow, dust, and sunlight.
Nacelle shall be weather tight. The nacelle shall be designed such that it will perform its function in
the climate conditions encountered at the Project site.
Nacelle shall provide adequate access and working space for all service and maintenance work that
may be required. Safety rails, tie offs, ladders, guards, steps, doors, and anti-slip surfaces shall be
installed as needed to ensure safe access to all maintenance locations. Nacelle shall provide for
adequate means to safely lower personnel from the nacelle in case of an emergency using the
provided tower top rescue device.
Access to the Wind Turbine Generator rotor hub, the exterior of the nacelle, and all Wind Turbine
Generator instrumentation shall be safely achievable from the interior and/or exterior of the
nacelle.
Nacelle shall provide the means for safe evacuation of personnel in case of emergency or injury.
Nacelle shall contain sufficient equipment to allow personnel to move safely between the inside and
outside (roof) of the nacelle. Nacelles shall contain adequate safety equipment to allow personnel to
safely perform any and all work that the Supplier intended to be performed on the outside (roof) of
the nacelle, including but not limited to tie-off points.
8.2.2.4 Hoists and Cranes
Turbines shall be equipped with a hoist or crane in the nacelle for transporting tools and minor
components from the tower base to the Wind Turbine Generator nacelle. Standard hoist or crane
shall have a minimum rated capacity to lift all equipment or parts required for maintenance and or
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 949 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-4
replacement in the nacelle not including major components such as, but not limited to the gearbox
(if applicable), generator and transformer (if located in nacelle).
Hoist or crane must be securely fixed to beam or girder designed to support the hoist and rated
capacity. If high capacity service crane is an option, beam or girder must be designed to support
rated capacity of the high capacity crane.
8.2.2.5 Rotor and Blades
The rotor shall consist of a set of blades and a hub, and shall be designed to operate reliably in the
conditions at the Project Site.
Rotor blades shall be manufactured with UV protection sufficient to ensure blade integrity as an
integral part of construction.
Subject to the performance of ordinary maintenance, including cleaning the blades of accumulated
dirt and insects, rotor blade design and pitch system operation shall be such that the Wind Turbine
Generator is resistant to power curve (performance) degradation due to fouling of the blade
surface.
Rotor shall be manually lockable to prevent movement of rotor and drive train during service. If a
low-speed lock is not part of the design a low-speed rotor lock shall be supplied.
Rotor blades shall maintain adequate separation from the Wind Turbine Generator tower under all
operating conditions.
Lightning protection system shall be IEC compliant.
Rotor blades shall be supplied as a balanced set for each Wind Turbine Generator. Balance may be
by matching blades before delivery or through manufacturing controls. Any replacement blades
that may be provided for a Wind Turbine Generator shall not cause rotor imbalance. All blades shall
be labeled from the Supplier with appropriate reference measures such as blade weight and
moment of inertia.
All bolted connections between hub and blade shall provide suitable access to retighten said bolts.
Fasteners shall have a protective coating pursuant to Section Q301. Such coating shall allow service
without removal or reapplication of coating.
Blade bearings shall be designed to prevent grease contamination on blades and nacelle.
An automatic lubrication system shall be included for the blade bearings.
8.2.2.6 Brakes
The rotor shall be the primary braking system for the Wind Turbine Generator. Aerodynamic rotor
braking system shall be designed to pitch the blades in order to stop the rotor at the cut-out speed
of the wind turbine without damage to the Wind Turbine Generator. The rotor braking system shall
be capable of preventing rotor overspeed at wind speeds to the rated survival wind speed of the
Wind Turbine Generator.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 950 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-5
Wind Turbine Generator shall have a mechanical disk brake which shall be used as a parking brake
during maintenance. Mechanical brake shall provide braking assistance during emergency stops.
Mechanical brakes shall not be used to stop the Wind Turbine Generator during normal shutdown
or similar situations.
Rotor brake shall operate in a failsafe mode in the event of power loss.
8.2.2.7 Pitch System
Wind Turbine Generators shall be equipped with an active blade pitch system to optimize
performance and power production.
Pitch system shall have a redundant safety system such as backup batteries or hydraulic
accumulators. Pitch system shall operate in a failsafe manner such that loss of electric power or
hydraulic pressure shall result in safe shutdown of the Wind Turbine Generator. Redundant system
shall be capable of being monitored or regularly inspected such that pitch system failsafe operates
in accordance with Wind Turbine Generator design requirements.
Pitch system shall be manually lockable for Wind Turbine Generator service.
8.2.2.8 Yaw System
Wind Turbine Generators shall be equipped with an active yaw system to keep the Wind Turbine
Generator facing upwind during operation. Yaw system shall be designed and operated such that
Wind Turbine Generator maintains upwind direction and maximizes Wind Turbine Generator
performance while limiting yaw motor duty cycles to maximize operating life.
Yaw system shall include sensors to report yaw direction in degrees from true north, and
provisions (via Wind Turbine Generator controller) for measuring power cable twist and
untwisting power cables if necessary.
Yaw system shall be manually operable via Wind Turbine Generator controller or project SCADA
system such that Wind Turbine Generator direction can be set while the machine is offline, which
means that the turbine is not producing electricity but still has power and communications with the
SCADA System.
Yaw system shall provide a means to prevent grease from contaminating inside and outside of
tower.
Yaw system shall include an automatic lubrication system for the yaw bearing.
8.2.2.9 Cooling and Heating
Major components of the Wind Turbine Generator shall have cooling and/or heating systems as
necessary. Cooling and/or heating systems shall be designed and implemented with the intent to
aid in maintaining bearing, oil and oil reservoir, and related temperatures within manufacturer’s
recommended ranges.
Other heat generating systems shall be equipped with fans or other adequate coolers to aid in
temperature maintenance as necessary.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 951 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-6
Nacelle temperatures shall be maintained by heating and cooling such that a safe working
environment is maintained for operating personnel.
Cooling and heating systems are not required to operate in the event that reliable power from the
electric grid is unavailable.
8.2.2.10 Condition Monitoring System
Not Used
8.2.2.11 Gearbox
Enclosed gearbox units furnished with equipment shall be designed for continuous service and in
accordance with the most current IEC 61400 standards for the type of gearbox being furnished.
Gearbox shall be a wind turbine specific design. Gearbox shall have inspection ports to allow
viewing of gear teeth and faces during maintenance activities.
8.2.3 Electrical Equipment
All electrical equipment shall comply with relevant IEC and UL standards.
8.2.3.1 Raceways and Conduit
To the extent possible, all raceways and conduit required between devices mounted within or on
the Wind Turbine Generator shall be factory installed.
Signal and communication wiring shall be shielded from interference from power cables.
8.2.3.2 Wires and Cables
Provide tower wiring and connection; and internal cabinet wiring and connections with the
requirements of the following articles:
General/Tower/Cabinet Wiring: Shall meet or exceed IEC 61400 and UL standard
specifications.
Wiring Diagrams: Furnish one-line diagrams. Furnish complete wiring diagrams.
Preferably, drawings shall include dimensions of cabinets and enclosures.
8.2.3.3 Cabinets and Enclosures
Furnish all required cabinets and enclosures inside the Wind Turbine Generators. Enclosures shall
meet applicable IEC requirements. Enclosures shall include arc flash labeling in compliance with all
relevant standards.
Enclosures shall be wired for bottom-entry of cables as needed.
8.2.3.4 Generator
The electrical generator within the nacelle of the Wind Turbine Generator shall be a Wind Turbine
Generator specific design. The generator shall be designed according to relevant IEC standards for
generators.
Insulation system shall provide sufficient dv/dt withstand.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 952 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-7
Generator voltage shall be to Wind Turbine Generator manufacturer’s standard.
The generator shall produce three-phase alternating current power. Generator output shall be
controlled as necessary to provide 60 Hz three-phase power at constant voltage to the step-up
transformer.
The generator shall have a cooling system adequate to maintain operating temperatures within
Supplier specified limits at all times. Generator may be air or liquid cooled.
Randomly wound type generators are not acceptable.
Generator shall include at least one set (one per phase) of extra RTDs for temperature monitoring.
8.2.3.5 Transformer (if applicable)
Wind Turbine Generator transformers shall comply with the applicable requirements of IEC 60076.
Transformer shall be a three-phase transformer. Transformer shall include a lock-out-tag-out
provision including a visual open indicator.
The high side voltage of the transformer shall be the same as the medium voltage collection system:
34.5 kV.
Transformer shall be suitable for continuous operation at 100 percent of the Wind Turbine
Generator nameplate VA rating at rated power factor or higher.
8.2.3.6 Power Factor Control
Wind Turbine Generator shall be capable of producing output at least 0.95 leading and lagging
power factor across the range of generator output.
Power factor correction and control shall be achieved through the use of power electronics, by the
use of capacitors switched by power electronics or zero crossing switching, or by any other means
sufficient to meet the criteria in this specification. Control signals will be transferred via site RTU
using DNP3 or
MODBUS protocol via TCP/IP communications.
All capacitors shall be standard units with indicating fuse protection for each unit. Capacitors shall
meet NEMA and ANSI or IEC standards. Capacitors shall be adequately cooled to keep capacitor or
IGBT temperature from exceeding manufacturer specification.
Switching devices shall meet NEMA or IEC standards. Switching devices shall be specifically rated
for capacitor switching and inverter output. Switching strategy shall be optimized as to not reduce
the life of switching components beyond manufacturers’ suggested life expectancy. Expected
replacement schedule for switching devices shall be provided.
Capacitors and switches shall be located in one dedicated cabinet or cubicle of the main control
cabinet. Switches and capacitors shall be readily accessible for inspection and maintenance.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 953 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-8
8.2.3.7 Disconnect Switches
Wind Turbine Generator design shall include lockable switches for disconnection from power
sources for inspection and maintenance. Switches shall be clearly marked and located in Wind
Turbine Generator nacelle and at tower base.
All machines, equipment, and electrical circuits shall be capable of being stopped and isolated from
all sources of energy to allow activities such as, but not limited to service, maintenance, or
inspection to be safely performed. All machines, equipment and electrical circuits shall include
provisions for control of unexpected energization or startup of or the release of stored energy such
that work may be safely performed on said machines, equipment and electrical circuits in
compliance with OSHA standard 29 CFR 1910.147 – Control of hazardous energy (Lockout/Tagout).
Energy in this context includes, but is not limited to, electrical, thermal, hydraulic, pneumatic,
chemical, and potential energy, such as that from elevated weights and compressed springs.
8.2.3.8 Motors
Electric motors shall be designed, manufactured, and tested in accordance with the relevant parts
of IEC 60034 and IEC 61400.
To the extent possible, motors shall be of standard size and rating, and motors of equivalent size
and rating shall be interchangeable between components and applications.
8.2.3.9 Switchgear (if applicable)
Switchgear shall meet Supplier’s specification requirements for the Wind Turbine Generator.
Medium voltage switchgear, if any, shall be designed for 34.5 kV 60 Hz operation. Low voltage
switchgear, if any, shall be designed for 1,000 V 60 Hz operation. Switchgear shall be rated for the
full temperature range of the Wind Turbine Generator.
Switchgear shall be: (i) installed in the base of the Wind Turbine Generator tower, (ii) sized such
that it can fit through the Wind Turbine Generator tower door, and (iii) equipped with a mooring
system such that it can be secured to the Wind Turbine Generator tower. Switching instructions
and procedures to be provided to purchaser.
8.2.3.10 Receptacles
Electrical receptacles shall be provided in the turbines at the base of the tower, in the tower
sections and in the nacelle. Electrical receptacles shall allow for personnel inside the turbines to
access electrical energy for the connections of service tools and auxiliary lighting. A minimum of 1,
120 VAC, 20 A, ground fault protected electrical receptacle shall be placed in the nacelle, as well as
any other receptacles and voltages that may be required for operations not limited to
manufacturers standard tools.
8.2.3.11 Interior Lighting
LED Interior lighting shall be provided. Lighting shall provide adequate visibility for day or night
work inside the tower and nacelle, and shall be operational from the bottom of the tower. The light
switch for the bottom tower section shall be installed in a convenient location within arm’s reach of
the latch side of the door.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 954 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-9
Emergency lighting shall be provided for safe egress from Wind Turbine Generators. Minimum
lighting times shall be in accordance with UPS requirements. Uninterruptible Power Supply.
Emergency lighting shall cover the nacelle, ladder, and ground level interior locations.
8.2.4 Special Systems
8.2.4.1 Uninterruptible Power Supply
Wind Turbine Generators shall be equipped with an uninterruptible power supply (UPS) for
storage of data in the turbine controller’s non-volatile memory and lighting for safe egress in the
event power from the grid is lost.
The UPS shall provide power for sufficient time such that safe shutdown of the Wind Turbine
Generator is possible without data loss. The UPS shall provide a minimum of 35 minutes of
uninterrupted power for safety related functions including lighting for safe egress from the Wind
Turbine Generator, aviation lighting and safe shut down of the Wind Turbine Generator and control
systems.
Batteries shall be selected and sized in accordance with IEC 61400 and codes and standards
referenced therein.
UPS system shall be capable of communicating its status information (i.e., whether UPS is working
or not) through the Project SCADA system.
In the event of a long-term power loss, the Wind Turbine Generator controller must not lose any
previously collected data.
8.2.4.2 Lightning Protection
The Wind Turbine Generators shall be furnished with an integral lightning protection system
covering all aspects of the Wind Turbine Generator, including but not limited to blades, generator,
gearbox, and control system.
The lightning protection system shall comply with applicable portions of the current edition of the
following codes and standards:
IEC 61400-24
IEC 62305
Lightning protection system shall be grounded through Wind Turbine Generator foundation
ground system provided by others. Minimum requirements for grounding system shall be provided
by Supplier.
The lightning path shall not pass through bearing rolling elements.
8.2.4.3 Overspeed Protection
Wind Turbine Generators shall be equipped with a redundant overspeed protection system.
Protection system shall operate continuously and automatically, and be capable of activating Wind
Turbine Generator braking system to prevent Wind Turbine Generator overspeed independently of
the primary Wind Turbine Generator controller.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 955 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-10
8.2.4.4 Emergency Shutdown
Wind Turbine Generators shall include manually activated emergency stop switches in the nacelle,
Wind Turbine Generator hub, and tower base. Emergency stop switches shall be large, clearly
marked, and of a push button type.
8.2.4.5 Automatic Fire Detection System
Not Used
8.2.4.6 Aviation Lighting System
Aviation obstruction lighting shall be based on the requirements of FAA Advisory Circular AC
70/7460-1L Marking and Lighting Wind Turbines, Chapter 13. The actual project lighting plan is to
be developed at a later date per Project based on the final project layout.
Lighting brackets shall be mountable to the Wind Turbine Generator nacelle without requiring in-
field modification to brackets or nacelles.
Flashing of aviation lights shall be synchronized at the Project by means of Global Positioning
System (GPS) based devices or similar. Synchronization shall be automatic, and shall self-correct in
the event that synchronization is lost, such as after an extended power outage.
Aviation obstruction lighting status (operational/non-operational) shall be reported via the project
SCADA system.
Aviation obstruction lighting shall be LED and shall include independent power backup to maintain
functionality as required by the FAA in the event of an extended power outage.
8.2.5 8.2.5 Controls
8.2.5.1 Wind Turbine Generator Controller
Each Wind Turbine Generator shall be supplied with an on-board control system capable of
controlling, monitoring, transmitting, and recording the performance of the Wind Turbine
Generator and the status of critical sensors.
Requirements. The control system shall be capable of automatically controlling and
monitoring all operations of the Wind Turbine Generator. The control system shall
optimize output of the generator, process all alarms, log events and performance data, and
interface with the project SCADA system.
The control system shall transmit real-time performance data and alarms to the project
SCADA system. The control system shall be capable of receiving commands from the project
SCADA system and adjusting Wind Turbine Generator operation and performance
accordingly. A complete list of parameters which may be sent to or read from the Wind
Turbine Generator control system shall be provided.
The control system shall operate automatically under all operating conditions and
conditions of power availability. The control system shall also automatically shut down the
Wind Turbine Generator prior to damage occurring whenever any measured operational
parameters exceed the set criteria.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 956 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-11
After loss of utility power interconnection or failure of utility power, restart of the
instrumentation and control system to a full functioning condition shall require no local
manual operations.
Wind Turbine Generator control system shall be switchable to local manual operation.
Controller shall clearly indicate when Wind Turbine Generator is in this mode. Status and
monitoring information shall be available to local operators at the Wind Turbine Generator
controller. If controller requires the use of a handheld terminal, an appropriate number of
terminals, per Supplier’s recommendations, shall be provided for the Project Site.
Performance Data Monitoring. Controller shall be capable of monitoring, recording, and
transmitting all operational, performance, and alarm data to the Project SCADA system.
Monitoring capability shall include, but not be limited to:
o Wind speed and direction from Wind Turbine Generator atmospheric sensors
o Yaw direction
o Power output
o Reactive power
o Power factor
o Rotor speed
o Generator speed
o Flow or pressure sensor in the forced lubrication system
o Oil filter status(es)
o Temperatures
Generator including but not limited to windings
Gearbox, including but not limited to the oil sump and gearbox cooler
Transformer, for Wind Turbine Generators with transformers in the nacelle
Bearings, inclusive of but not limited to the gearbox high-speed bearing(s)
and generator bearings
Nacelle interior
Ambient air
Fluids, including coolant, oil, lubrication and hydraulic systems
Thyristors
Converter
Main Bearing(s)
Any component capable of triggering an alarm or fault
o Pressures
Gearbox oil
Hydraulic systems
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 957 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-12
o Grid connection status by phase
o Voltage by phase for both the rotor and the stator
o Amperage by phase for both the rotor and the stator
o Generator frequency
o Blade pitch for all blades
o Parking brake status
o Obstruction lighting status
o Cumulative real and reactive energy production
o Cumulative Wind Turbine Generator operating time
o Turbine operating state
o Turbine direction from North
System shall record Wind Turbine Generator status, and generate alarm codes whenever
Wind Turbine Generator shuts down, such as when operational limits are exceeded, the grid
connection is lost, a fault is recorded, or the Wind Turbine Generator is manually
deactivated for maintenance. Codes shall include routine shutdown events such as power
cable untwisting.
8.2.5.2 Project SCADA System
Wind Turbine Generator package shall include a Supervisory Control and Data Acquisition
(SCADA) system capable of monitoring and recording diagnostic and performance data for all Wind
Turbine Generators in a wind project. System shall include all hardware, software, and perpetual
software licenses to perform the required functions. Hardware shall include SCADA server for
installation in project substation. Further details on SCADA system are provided in the Agreement.
System shall be capable of direct interaction with individual Wind Turbine Generators for
operation and troubleshooting. System shall be capable of clearing or resetting alarms remotely
from Purchaser and/or Supplier’s monitoring facility, except where alarms require local (at the
Wind Turbine Generator) service and inspection to rectify.
System shall be capable of interfacing with and monitoring and recording atmospheric
measurements from multiple met towers.
System shall be capable of controlling turbines in a group or in a number of groups. Control will
include starting or stopping groups of turbines together or with a user-defined time delay. Control
will have ability to start and stop groups of turbines based on environmental inputs (temperature,
wind speed, time, etc.),and to curtail or stop turbines for avian and bat mitigation. Inputs should be
user-defined via SCADA client.
System shall be capable of interfacing with, monitoring, and recording data from project
interconnection substation equipment using DNP3 or MODBUS protocol.
System shall provide a comprehensive view of an entire wind project, including Project level
interfaces.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 958 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-13
System shall be capable of managing active power curtailment requirements on a Project level via
setpoints and ramp rates entered into the client application or by reading a setpoint from
substation equipment via DNP3 or TCP/IP protocols. The system shall have hierarchy logic to
determine which setpoint will take precedence.
System shall be capable of calculating and reporting overall plant performance, including real and
reactive power, energy production, and availability, from recorded operational data. System shall
be capable of displaying and analyzing trends for recorded data.
System shall be able to produce wind GADs reports as required by NERC as defined at the time of
Agreement. The reports should be generated in complete GADs format and should not require
additional medication by personnel to complete. Prior to running the report, some SCADA data may
require manual input by personnel.
System shall provide SMTP notification service to alert on-call staff of alarms. To the extent
possible, notification service shall be able to integrate with existing Purchaser and/or Supplier
notification systems.
System shall include a database to store Project Site and Wind Turbine Generator operational data.
Long-term data retention must be possible by export to Purchaser long-term data storage systems
via DA2.0 OPC, or other archival storage system. Data system shall include backup facilities.
SCADA system interfaces shall be provided such that the Project SCADA system can interface with
external Purchaser SCADA system for control and monitoring and with Purchaser system for data
storage and retention via DNP 3.0 or OPC protocols as required.
Hardware provided by Supplier for SCADA connection shall be industry standard physical interface:
Ethernet, RS-232, USB, etc.
System shall be capable of secure interconnection with remote monitoring and control system over
network. Remote system connection shall support diagnostics and alarm management and shall be
fully accessible and available to Purchaser’s Generation Systems Operations. The purchaser will
have administrative control of the SCADA system and all data equipment and all turbine controller
and turbine computers, including administrative passwords. The SCADA system shall comply with
NERC CIP requirements active at the time of Agreement.
Project SCADA system shall include an uninterruptible power supply (UPS) with a backup time of
up to 30 minutes.
Project SCADA system shall provide time synchronization such that time stamps for recorded data
for all Wind Turbine Generators are synchronized.
The time step used for monitoring and recording data when computing averages shall be 10
minutes.
Status indications relayed by the plant SCADA system shall be set from controlled device rather
than controlling system.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 959 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-14
SCADA system shall be capable of maintaining an accurate and up-to-date operating log accessible
in real-time by Purchaser’s GSO, with records of production for each clock hour; changes in
operating status; Scheduled Outages/Deratings and Forced Outages, including such records as may
be required by state or federal regulatory authorities and Utility in the prescribed format.
Supplier access to real-time or historical SCADA data is described in the Agreement.
Project SCADA system shall provide owner with administrative level access, including access to
real-time and historical data for all aspects of the wind turbines.
Supplier shall install on each PC, virus protection software. Upon initial energizing of each Wind
Turbine Generator and PC, and prior to connection to the on-Site intranet, Supplier shall warrant
that, at the moment of commissioning completion for any single Wind Turbine Generator or PC,
said system will have been determined, to the extent that the anti-virus software and operating
system upgrades can detect, to be free of viruses. Any laptop or PC connected to the Project
network by Supplier personnel or subcontractors shall also contain the latest Virus Protection
software and updates, and shall be free of any viruses, spyware, malware, etc.
All software licenses will be delivered to purchaser including but not limited to: virus protection
software, operating system software, WTG software, device drivers installed, protocol licenses and
any 3rd party installed software.
8.3 ELECTRICAL STARTUP AND COMMISSIONING
8.3.1 General
8.3.1.1 Scope of Work
This section describes and defines general criteria which pertain to the startup, testing, and
commissioning work covered by these specifications. This specification is applicable only to the
Work or equipment provided by the Supplier. This work is in addition to testing activities required
in other sections of this specification. Portions of the work may be performed prior to in field
activities. The Supplier shall be responsible, as part of the base scope, for all labor and materials
required to demonstrate that the electrical equipment has been installed correctly and functions
properly. Functional testing shall include a demonstration that all major equipment installed can
be operated in accordance with the design from local and remote stations, control loops and
protective devices perform as designed, and other equipment operates in accordance with their
specification. Purchaser may participate, oversee or witness commissioning and completion
activities performed by either the Supplier or the Supplier’s sub-contractors.
The Supplier test procedures and plans must meet IEC 61400 standards for testing on Switchgear,
Load Centers, Dry Transformers, Relay Protection, and Circuit Breaker Testing, as well as Circuit
Loop Checks and Control Loop Checks. The Supplier shall document all testing and inspections.
The Supplier shall make available to the Purchaser their proposed Electrical and Instrumentation
Testing procedures for review.
The following activities shall be performed as part of the equipment installation. The Supplier shall
perform all mechanical and electrical work required to calibrate, check out, and make the
equipment ready for service as required by these specifications.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 960 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-15
The following activities shall be completed under these specifications:
Visual and mechanical inspection of equipment.
Mechanical adjustment and testing of all electrical equipment, as required, to assure proper
mechanical functioning and operation.
All testing and reconnection necessary to obtain correct operation of the electrical
equipment.
For field installed items, loop verification of all control and instrumentation circuits, in
accordance with the Circuit List, to confirm continuity of conductors and that conductors
originate and terminate at the locations designated in the circuit list or on the drawings.
All mechanical adjustment necessary or recommended by the manufacturer of all Supplier -
supplied electrical equipment being connected or installed.
Complete testing of the lighting and receptacle system, (including any welding receptacles
added to the system) as applicable.
All instruments wired and calibrated as applicable.
Assistance shall be provided as required during trial operation and functional testing to correct
installation deficiencies.
8.3.1.2 Items Furnished by Others and Interfaces
Items furnished by others and not in this Scope of Work are as described in other sections of this
specification and Agreement.
8.3.1.3 Electrical Startup, Testing, and Checkout Requirements
Electrical startup, testing, and checkout shall be in accordance with the equipment manufacturer's
instructions and recommendations, the applicable requirements of the Supplemental Specifications
in Section 01400, and the requirements of this section.
8.3.1.4 Codes and Standards
Work performed under these specifications shall be done in accordance with the most current
applicable codes and standards. Unless otherwise specified, the applicable governing edition and
addenda to be used for all references to codes or standards shall be interpreted to be the
jurisdictionally approved edition and addenda. If a code or standard is not jurisdictionally
mandated, then the current edition and addenda in effect at the date of this document shall apply.
These references shall govern the work except where they conflict with the Purchaser's
specifications. In case of conflict, the latter shall govern to the extent of such difference.
8.3.1.5 Not Used
8.3.1.6 Not Used
8.3.1.7 Test Requirements
The following testing shall be conducted in accordance with the specified source. This testing is to
be considered part of the defined Scope of Work, and all associated costs are the responsibility of
the Supplier unless specifically identified as a Bid Option or Purchaser-conducted. Tests identified
as an option are to be priced separately. If identified as Purchaser-conducted, costs for the initial
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 961 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-16
test will be the responsibility of the Purchaser. Testing costs for tests performed by Others, but
confirmed by Supplier shall not be the responsibility of the Supplier; however, any cost to confirm
or oversee said test shall be paid by Supplier.
Tests
Acceptance Testing IEC Supplier
Transformer phase rotation is correct Supplier
MV and HV cable connections are properly torque and
marked
Supplier
MV and HV cables are properly routed, secured and not
severely kinked
Supplier
All other tests required by equipment manufacturers for
Work provided by Supplier
Supplier
8.3.1.8 Not Used
8.3.1.9 Supplemental Specifications
Technical supplemental specifications that are applicable to the work covered under this technical
specification section are identified and included in Section 01400.
8.3.2 Not Used
8.3.3 Execution
8.3.3.1 Calibration, Testing, and Checkout Procedures
The following procedures shall be performed and followed by the Supplier. Documentation of the
Inspections and Testing shall be made. These forms will be supplied by the Supplier.
Inspection
The Supplier shall inspect the installed instrument systems and the installed equipment specified
and shall document such inspection in writing.
Discrepancy Procedure
The Supplier shall endeavor to promptly discover major discrepancies in equipment, materials, and
installation so that corrective procedures can be initiated without delay. When the Supplier
discovers equipment with an incorrect rating, damage, not being as specified, or is otherwise
unsatisfactory, arrangements will be made for replacement of the equipment. The Supplier shall
promptly report to the Purchaser any improper field installations or material usage which the
Supplier believes should be corrected.
Supplier - Caused Defects.
Refer to the Agreement
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 962 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-17
Manufacturers' Procedures
The Supplier shall follow the manufacturers' instructions in the performance of this work and
perform all required and recommended tests, calibrations, and settings identified in these
instructions.
8.3.4 Personnel
The Supplier shall provide all personnel required to complete the work in accordance with the
project schedule. The Supplier shall provide sufficient staff so that the project schedule is met.
The cost of all labor, supervision, materials, equipment, vehicles, supplies, and services necessary to
provide field tests and adjustments required to demonstrate that electrical systems are correctly
installed, tested, and calibrated shall be included in the base lump sum price.
8.3.5 Tools and Test Equipment
The Supplier shall provide all required tools and test equipment to perform the work in accordance
with these specifications and the project schedule. The test equipment shall be periodically
certified. Any test equipment found out of tolerance during certification shall be replaced or
repaired.
8.3.6 Test Instrument Certification
Certification methods shall follow recommendations of the test instrument manufacturers.
The Supplier’s personnel performing certification shall be specially trained in the methods and
procedures for carrying out these calibration certifications.
8.3.7 Calibration or Testing Certification Sticker
As required, the Supplier shall furnish and affix a self-adhesive label to each device calibrated or
adjusted. The label shall indicate the date and the name of the person performing the calibration or
adjustment.
8.3.8 Checkout and Test Report Forms
The Supplier shall document all instruments, mechanical devices, and electrical devices that are
tested or calibrated.
8.3.9 Startup
Startup will be under the jurisdiction of the Supplier throughout the startup period.
Except as stated elsewhere, the Supplier shall render all services and do all work required by the
Agreement to place each item of equipment installed by it, including all auxiliaries, in operating
condition to the satisfaction of the Agreement documents. All equipment shall be prepared for
operation as recommended by the equipment manufacturer.
The Supplier shall provide all temporary instrumentation and gauging devices required during
checkout and trial operation of the equipment and systems.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 963 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-18
8.3.9.1 Equipment Checks and Calibration
Preoperational checks and inspections shall be performed on all equipment as specified herein, and
in accordance with the equipment manufacturer's recommendations.
The Supplier shall verify in writing that all work and preoperational checkouts have been
completed.
8.3.10 Electrical and Instrumentation Checkout
This article defines the scope of electrical and all instrumentation devices and equipment which
shall be calibrated in-place, adjusted, or checked out by the Supplier as part of the work covered by
these specifications.
The Supplier shall provide all temporary instrumentation and gauging devices required during
checkout and trial operation of the equipment and systems.
8.3.10.1 Equipment Checks
Preoperational checks and inspections shall be performed on all equipment as specified herein and
in accordance with the equipment manufacturer's recommendations. Field tests shall be witnessed
by the Purchaser at the Purchaser's discretion with the exception of commissioning activities.
Preoperational checks shall include, but not necessarily be limited to, the following:
Safety Equipment. All coupling guards, belt guards, and other personnel safety items shall
be installed. All bolting shall be securely tightened to the correct torque as recommended
by the equipment manufacturer.
All temporary shipping braces, blocks, or tie rods shall be removed.
Instrumentation and Controls.
o If applicable, interlock jumpers shall be removed.
o Panel instrumentation shall be turned on.
Lighting and Receptacle Checkout. The Supplier shall test, check out, and energize the lights
and receptacles furnished and installed under this Agreement. Immediately before ener-
gizing a lighting or receptacle circuit, the Supplier shall make the following checks:
o The transformer neutral supplying the source panelboard is solidly connected to
ground.
o The phase and neutral conductors to be energized are free from grounds.
o All covers are on lighting fixtures, pull boxes, and junction boxes so exposed conductors
will not be energized.
o The ground conductor (if required) is solidly grounded.
After completing the pre-energization checks, the Supplier may request energization of the
circuit.
All metering, including panel meters and transducers, shall be calibrated to within the manu-
facturer's accuracy.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 964 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-19
Panel instrumentation indicating lights, switches, and relays shall be adjusted and checked out as
part of the checkout of the Supplier installed electrical equipment.
Electrical panel instrumentation shall be calibrated.
Unless specified otherwise, all meters shall be tested and calibrated with equipment of no more
than 50 percent of the manufacturer's stated accuracy instrument being tested.
All meters shall be visually inspected for damage, and wiring connections shall be verified in
accordance with the one-line diagrams.
Every instrument utilizing a plastic lens or window shall be given a static effect check. The static
check shall consist of wiping the lens or window vigorously with a dry cloth of a type recommended
by the manufacturer which will not harm the surface. If the needle or pointer holds up-scale or
below zero set for more than 15 seconds, the surface of the lens or window shall be treated with a
clear antistatic compound recommended by the manufacturer.
Measurement of resistance to ground shall be made of all motors, switchgear, isolated phase bus,
cable bus, panelboard bus, nonsegregated phase bus, and motor control center bus prior to placing
in service. Measurement of resistance will be with a line operated tester. Voltage of testing device
shall be in accordance with the following table or the equipment manufacturer's recommendation:
480 volts 1000 volts 3
4.16 kV 2 kV 1
Above 4.16 kV 5 kV 1
For each transformer rated 500 kVA or larger, measurement of resistance to ground and
polarization index of each winding with all other windings grounded shall be made and recorded.
Measurements shall be with a winding tester. Measurements for each transformer shall be made
immediately prior to placing in service. If a transformer winding has a resistance to ground or
polarization index less than recommended by the manufacturer, the transformer will not be placed
in service. The voltage of the testing device shall be in accordance with the preceding table.
Complete check of all field wiring shall be made after installation and connection to verify that field
wiring is as indicated on the drawings and schematic wiring diagrams. Equipment jumpers as
indicated on the schematics shall be checked.
All instrument transformers, including bushing current transformers, shall be tested.
Ratio and polarity tests shall be performed on all instrument transformers. Current transformer
ratio and polarity tests shall be voltage ratio tests using a digital voltmeter or current ratio tests
using high current injection test equipment.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 965 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-20
The external circuit for each current transformer shall be completely tested before the shorting
devices are removed from the current transformer secondary terminals. The tests shall include the
following:
Continuity check of the circuit external to the current transformer by application of current.
Phase check to verify correct phase relationship at each device connected in the current
transformer circuit.
The Supplier shall verify in writing that all work and checkouts have been completed.
8.4 MECHANICAL STARTUP AND COMMISSIONING
8.4.1 General
Mechanical erection and installation shall be completed by Purchaser or its contractors.
8.4.1.1 Scope of Work
Scope of Work shall include performing all work required to place all component systems and
equipment provided by the Supplier into operation. Portions of the work may be completed prior
to in field work.
In addition, Scope of Work for mechanical startup includes the following preoperational checks:
Before starting equipment, all bearings, shafts, and other moving parts shall be checked for
proper alignment, as necessary.
All coupling guards, belt guards, and other personnel safety items shall be installed.
All fire protection systems and equipment shall be installed and operative.
All temporary shipping braces and blocks shall be removed from expansion joints.
Each lubricating oil system shall be sampled, and if necessary filters inspected and system
flushed. All oil tanks, reservoirs, gear cases, and constant level type oilers shall be checked
for proper oil levels. All points requiring manual lubrication shall be greased or oiled as
required.
If applicable, all belts, pulleys, and sheaves shall be checked for correct alignment and belt
tension.
Purchaser shall approve the Mechanical Completion Checklist before startup and
commissioning work begins
8.4.1.2 Items Furnished by Others and Interfaces
Items furnished by others and not in this Scope of Work are as described in other sections of this
specification and Agreement.
8.4.1.3 Startup Requirements
Mechanical startup shall be in accordance with the equipment manufacturer's instructions and
recommendations, and the requirements of this section.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 966 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-21
8.4.1.4 Codes and Standards
Work performed under these specifications shall be done in accordance with the most current
applicable codes and standards. Unless otherwise specified, the applicable governing edition and
addenda to be used for all references to codes or standards shall be interpreted to be the
jurisdictionally approved edition and addenda. If a code or standard is not jurisdictionally
mandated, then the current edition and addenda in effect at the date of this document shall apply.
These references shall govern the work except where they conflict with the Purchaser's
specifications. In case of conflict, the latter shall govern to the extent of such difference.
8.4.1.5 Test Requirements
The following testing shall be conducted in accordance with the specified source. This testing is to
be considered part of the defined Scope of Work, and all associated costs are the responsibility of
the Supplier unless specifically identified as a Bid Option or Purchaser-conducted. Tests identified
as an option are to be priced separately. If identified as Purchaser-conducted, costs for the initial
test will be the responsibility of the Purchaser. Testing costs for tests performed by Others, but
confirmed by Supplier shall not be the responsibility of the Supplier ; however, any cost to confirm
or oversee said test shall be paid by Supplier :
Tests
Perform or confirm that foundation stud nuts are properly
tensioned, marked. Supplier shall confirm that protection
devices are installed at the 90 day check.
Purchaser
Test, or confirm that Ping Test on every tower bolt has been
performed
Purchaser
Perform or confirm that torque check has been performed
on tower bolts, as specified
Purchaser
Tower bolts are installed, torque and properly marked Purchaser
Hub bolts are installed, torque and properly marked Purchaser
Perform or confirm that Ping Test has been performed on
rotor bolt
Purchaser
All hydraulic connections are tight and no leaks are present Purchaser
All warning and safety stickers are present and legible Purchaser
All other tests required by equipment manufacturers for
Balance of Plant Work provided by Supplier
Purchaser
8.4.2 Execution
The Supplier shall render all services and do all work required by the Agreement to place each item
of equipment installed by him, including all auxiliaries, in operating condition. All equipment shall
be prepared for operation as recommended by the equipment manufacturer, and shall be operated
in accordance with the recommendations of the equipment manufacturer.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 967 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-22
Individual systems and items of equipment shall be completed in a sequence that will permit
systematic checkout and trial operation of each such component before it is incorporated into the
initial operation.
The Supplier shall furnish operating personnel during the startup, as specified in the Agreement.
The Supplier shall apply, all oils, greases, and other lubricants required to place permanent plant
equipment in a condition ready for operation. The Supplier shall provide all temporary
instrumentation and gauging devices required during checkout and trial operation of the
equipment and systems.
8.4.2.1 Equipment Checks
Preoperational checks and inspections shall be performed on all equipment as specified herein and
in accordance with the equipment manufacturer's recommendations. A representative of the
Purchaser may be present during the equipment checks with the exception of during
commissioning activities.
The Supplier shall verify in writing that all work and checkouts have been completed; and, when
the services of equipment manufacturer's field service representatives are specified, the Supplier
shall include verification by such representatives that the equipment is ready for trial operation.
8.4.2.2 Trial Operation of Equipment
If specified by Supplier, after all preoperational checks and inspections have been completed, each
piece of equipment will be given a trial operation. Trial operation of equipment will be conducted
by the Supplier.
Trial operation of all equipment shall extend for a 72 hour period as required to reveal any
equipment weaknesses in bearings, cooling systems, heat exchangers, and other such components,
or any performance deficiencies that may later handicap the operation of main systems and the
complete plant.
All rotating equipment will be checked by the Supplier for overheating, noise, vibration, and any
other conditions that would tend to shorten the life of the machinery.
Cooling water systems shall be adjusted by the Supplier to provide the proper flow of coolant to
each item of equipment.
Each trial operation shall be summarized by the Supplier in a written report describing the
observations and results of the operation and the specific deficiencies discovered that require
additional work.
8.4.2.3 Not Used
8.4.2.4 On-Line Operational Checks
If specified by the Supplier, during on-line operation of the integrated systems, all equipment will
be checked by the Supplier for overheating, noise, vibration, and any other checks recommended or
required by the manufacturer of the specific piece of equipment.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 968 of 1056
RFP| WIND SPECIFICATIONS DATE{}
IDAHO POWER CO.| WTG Technical Specifications 8-23
8.4.2.5 Operational Control
The Supplier shall establish a system of control to protect personnel and equipment as the
permanent plant equipment and systems are completed and capable of energization.
The system will consist of placing appropriate tags on all equipment and system components to
indicate their status and requiring mandatory clearances from designated personnel to operate,
energize, or remove from service the equipment or systems. The controls established will
encompass the following phases:
Equipment or systems completed to the point where they may be energized, pressurized, or
operated, but that have not yet been checked out, will be tagged; and the sources of power
or pressure will be turned off and tagged. The affected components shall not be operated
without clearance.
Following initial operation of the equipment or system, tagging will be performed as stated
above and the affected components shall be operated only by the personnel designated by
the Purchaser.
Equipment and systems released for service will be so tagged. When a request to remove a
system from service is made, all controls and sources of power or pressure will be tagged
out and shall not be operated under any circumstances. Only the personnel originally
tagging the system shall clear the system for service.
To protect the equipment or systems from damage, and to ensure the safety of all personnel, the
procedures established shall be followed strictly.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 969 of 1056
Idaho Power 2026 All Source RFP
Exhibit K – Wind Technical Specifications

IDAHO POWER CO. | General 1

APPENDIX A

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 970 of 1056
1. General
Suppliers/Vendors approved for use by Contractor are identified in this Appendix A.
Contractor may propose additional suppliers/vendors for Owner review and approval. Owner
has the right to approve or deny any proposed vendors or suppliers.
2. Battery Equipment
2.1 BATTERIES
Alcad
C&D Technologies –preferred
Enersys
Exide
Saft
2.2 BATTERY CHARGERS
Alcad/Hindle
C&D Technologies –preferred
Enersys
LaMarche
2.3 UNINTERRUPTED POWER SUPPLY (UPS)
Ametek/Solid State Controls
Emerson: Liebert
EP2
Power Control Systems
Wilmore Electronics
3. Cable
3.1 CONTROL CABLE
Anixter
AWG
Belden
Continental Wire and Cable
Dekoron
Draka Cableteq USA
General Cable
Lake Cable
Okonite
Prysmian
Southwire
Synergy
3.2 LOW VOLTAGE POWER CABLE
Anixter
AWG
Cablec
Draka Cableteq USA
General Cable
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 971 of 1056
Idaho Power 2026 All Source RFP
Exhibit K – Wind Technical Specifications

IDAHO POWER CO. | Cable Equipment 3
Houston Wire & Cable
Lake Cable
Okonite
Prysmian
Southwire
Synergy
WTEC
3.3 MEDIUM VOLTAGE POWER CABLE
Anixter Wire and Cable
AWG
Cablec
General Cable
Kerite
Okonite
Prysmian
Southwire
3.4 FIBER-OPTIC CABLE
AFL
AWG
Brugg
Corning
Fujikura
Prysmian
4. Cable Equipment
4.1 MV POWER CABLE SPLICES
3M
Prysmian
TE Connectivity (Raychem/Tyco)
Thomas and Betts (T&B)
4.2 MV POWER CABLE TERMINATIONS
3M
Cooper-Eaton
TE Connectivity
Thomas and Betts (T&B)
4.3 FIBER OPTIC ACCESSORIES
Refer to Exhibit A-3.2, Section 8.0.
4.4 SECTIONALIZING CABINETS (JUNCTION BOXES)
Cooper-Eaton
Hubbell (Trinetics)
Nordic Fiberglass
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 972 of 1056
4.5 CABLE TRENCH (SUBSTATION)
Concast
Old Castle
Trenwa - preferred
5. Capacitor Banks
ABB
Cooper-Eaton
General Electric
Siemens/Trench
6. Circuit Interruption
6.1 CIRCUIT BREAKERS
6.1.1 Medium Voltage
Mitsubishi
6.1.2 High Voltage
Mitsubishi
6.2 DISCONNECT SWITCHES
6.2.1 Medium Voltage
ABB
Cleveland/Price
General Electric
Hubbell (Ohio Brass, Trinetics)
Morpac
Pascor Atlantic
Royal
Siemens
Southern States
USCO
6.2.2 High Voltage
ABB
Cleveland/Price
GE
Morpac
Pascor Atlantic
Royal
Siemens
Southern States - preferred
USCO
7. Insulators
Lapp Insulators
Newell–PSN, LLC.
Hubbell (Ohio Brass)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 973 of 1056
Idaho Power 2026 All Source RFP
Exhibit K – Wind Technical Specifications

IDAHO POWER CO. | Mechanical 5
PPC
Victor Insulators
8. Mechanical
8.1 HEATING/AC
Bard - preferred
Carrier
Daikin Applied
Lennox
Trane
York International
8.2 HEATERS
Hastings
Modine
Reznor
Sterling
Trane
9. Monitoring/Communication
9.1 RELAYS
9.1.1 Auxiliary Control
Allen Bradley
GE
Potter Brumfield
9.1.2 Fault Indicators (Collection)
Cooper-Eaton
Power Delivery Products
Schweitzer Engineering (SEL)
9.1.3 Primary Protection (Substation)
Schweitzer Engineering (SEL)
9.1.4 Panels (Substation)
EP2
SEL
Systems Control
9.2 SCADA - RTU
Novatek
9.3 METEROLOGICAL
9.3.1 Anemometers
NRG Systems
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 974 of 1056
RM Young
Thies (First Class Advanced)
Vaisala
WindSensor (RISØ)
9.3.2 Data Loggers
Campbell Scientific
NRG Systems
9.3.3 Tower Manufacturers
Double K
Nello Corporation
Renewable NRG Systems
Tower Systems
9.3.4 Tower Installers
Anemometry Specialists
Capital City Renewables
Sioux Falls Tower
Tower Systems
9.3.5 Wind Direction Sensors
NRG Systems
Thies (First Class Advanced)
Vaisala
10. Steel Fabrication
Cives Steel Company
Distran
Hirschfield Steel
Klute
LAX
Merrill Iron & Steel
Mid-City Steel
Minnesota
Owen Industries
PSP
Qualico Steel Company
Schuff
Severfield Structural Fabricators of Monroe, Inc.
Structural Steel Services, Inc.
United Steel Structures
Valmont
11. Structures
11.1 BUILDINGS/ENCLOSURES
American
Butler
Mekco
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 975 of 1056
Idaho Power 2026 All Source RFP
Exhibit K – Wind Technical Specifications

IDAHO POWER CO. | Surge Arresters 7
Morton
Parkline
Trachte
11.2 CONTROL BUILDING (PROJECT COLLECTOR SUBSTATION)
EP2
Systems Control
Trachte
12. Surge Arresters
ABB
Cooper-Eaton
General Electric/Alstom
Hubbell (Ohio Brass)
Siemens
13. Transformers
13.1 MAIN POWER
ABB
GE-Prolec
Cooper-Eaton
EFACEC
Hyundai
MEPPI
Siemens
Waukesha
WEG
13.2 PAD-MOUNT
GE-Prolec
CG Power
Virginia Transformer
WEG
13.3 STATION SERVICE TRANSFORMERS
ABB
Cooper-Eaton
ITEC
Siemens
13.4 GROUNDING TRANSFORMERS
ABB
General Electric
Hammond Power Solution
Niagara Transformers
Pacific Crest
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 976 of 1056
13.5 PADMOUNT TRANSFORMER BOX PADS
Concast
13.6 INSTRUMENT TRANSFORMERS
13.6.1 Current (for relaying/system protection)
ABB
Alstom/General Electric
ITEC
Koncar
Meramec
Ritz
Siemens
13.6.2 Voltage (for relaying/system protection)
ABB
Alstom/General Electric
ITEC
Koncar
Ritz
Siemens
13.6.3 Local Balancing Authority Metering Package
ABB
General Electric
Trench
14. Package Substation Testing and Commissioning
Energis
CE Power
Shermco
Steinmetz Corporation

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 977 of 1056
Idaho Power 2026 All Source RFP
Exhibit L – Gas-Fired Convertible to Hydrogen Specifications
Single Shaft Combined Cycle Unit Convertible to Hydrogen Fuel
EPC General Requirements

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 978 of 1056
i
Table of Contents

01100 - General Requirements and Scope of the Work .......................................................................... 2
01100.1 General Description ................................................................................................................... 2
01100.1.1 Project Description .............................................................................................................2
01100.1.2 Scope of Work....................................................................................................................6
01100.2 Scope of Work Additional Requirements ................................................................................. 13
01100.2.1 General ............................................................................................................................. 13
01100.2.2 Performance.....................................................................................................................15
01100.2.3 Mechanical ....................................................................................................................... 16
01100.2.4 Chemical...........................................................................................................................17
01100.2.5 Electrical/Control..............................................................................................................17
01100.2.6 Civil Structural .................................................................................................................. 18
01100.3 Engineering .............................................................................................................................. 20
01100.3.1 Engineering and Design...................................................................................................21
01100.4 Procurement ............................................................................................................................ 22
01100.5 Construction ............................................................................................................................. 22
01100.6 Plant Startup and Commissioning...........................................................................................24
01100.6.1 Pre-Commissioning Walk Down ....................................................................................... 26
01100.6.2 Post-Commissioning Walk Down ..................................................................................... 26
01100.7 Equipment Expediting and Inspection Services ...................................................................... 26
01100.8 Scheduling and Progress Reporting ........................................................................................ 27
01100.9 Operator Training .................................................................................................................... 28
01100.10 Codes and Standards ............................................................................................................ 29
01100.11 Division of Responsibility ....................................................................................................... 30

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 979 of 1056
2
01100 - General Requirements and Scope of the Work
01100.1 General Description
This section covers the Project description, scope of the Work, and supplementary requirements for the
engineering, procurement, construction, and commissioning of the Project.

01100.1.1 Project Description
The Project will be located at [ ] site near [ ] in [ ] County. The Project will be constructed at the
Facility as shown on the Site Arrangement Drawing included in Attachment [ ].

The Plant will consist of two (2) combined-cycle power trains in single shaft configuration each with a gas-
combustion turbine, heat recovery steam generator (HRSG), and steam turbine and associated balance-
of-plant equipment and materials. The fuel will be natural gas with the capability to burn up to 30%
hydrogen, by volume, blended gas. The net electrical output of each unit shall be a nominal [ ] MW.

The Plant shall be designed for unlimited operation on natural gas with up to 30% hydrogen, by volume,
with the operational requirements stated in Article [ ] and permitted for operation on natural gas,
hydrogen, or a combination of both fuels. Each unit shall be designed for cycling load operation.
The Plant shall be designed such that a single failure does not remove a unit from service. This requires
that the two generating units be completely isolated from each other during normal operation. The use of
maintenance ties is acceptable when one unit is off-line. The balance of plant equipment should be
designed with enough redundancy so faults in any of those systems do not result in a unit trip.
Redundancy not only includes enough capacity to operate the generating station at full rated capacity, but
also includes the ability to transition to a lower load point when equipment trips; e.g. if you have two 50%
rated components and one trips, the remaining equipment should be able to safely transition down to a
stable operating point.

Each single shaft combined cycle unit (SSCC) will be located indoors including the HRSG, with exception
of the HRSG stack. The SSCC’s and ancillary equipment shall be arranged generally as shown on the
arrangement drawings included with Attachment [ ].

Unodorized natural gas will be delivered to the Facility by a new pipeline and will be regulated and
metered onsite. The pipeline and the fuel gas metering and will be furnished by the Contractor. A
flanged connection will be provided at the downstream side of the fuel gas metering station for connection
of the Contractor’s gas conditioning, metering and pressure regulating fuel gas yard. Natural gas
pressure and temperature at the outlet of the Contractor fuel gas metering station are defined in Article [
].

Hydrogen gas will be delivered to an interface point at the Facility by others.

Each SSCC unit shall be located indoors with two overhead bridge cranes required for maintenance. The
exhaust of the steam turbine shall be directed to a water-cooled surface condenser.

The boiler feed pumps and Turbine Cooling Air (TCA) cooler feed pumps (if required) shall be located
indoors in a pump enclosure located adjacent to the utility rack. A selective catalytic reduction (SCR)
system shall be included with the HRSG to reduce NOx emissions. Space shall be provided in the HRSG
for installation of a future oxidation catalyst for reduction of CO and VOC emissions.

The heat rejection system of each unit shall utilize an induced mechanical draft counterflow type cooling
tower. Makeup water for the cooling towers will be provided from a new raw water supply system which is
supplied from on-site wells and the [ ].

Raw water for the Facility will be provided from two sources. The service/fire water system, potable water
system, and demineralized make-up water will be sourced from the on-site well system. The circulating
water make-up system will be sourced from the on-site storage reservoir, on-site wells, or a combination
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 980 of 1056
3
of the two sources, with the ability to be fed directly from the on-site wells for extended periods of time
during maintenance of the reservoir. Details of the water treatment systems are provided in the [ ]
Section.

Sanitary drains from the Facility shall be discharged to the [ ].

Wastewater, including evaporative cooler blowdown, boiler blowdown, and RO wastewater, shall be
recovered to the cooling towers. Cooling tower blowdown, demineralizer and condensate polisher
regeneration wastes, shall be discharged to new on-site evaporation ponds.

Groundwater monitoring well water shall be discharged to the new evaporation ponds.

Stormwater from the Facility shall be collected in stormwater basins or the new evaporation ponds.

Oily wastes shall be directed to an oil/water separator. Effluent from the oil/water separator shall be
directed to the new evaporation ponds.

The plant shall be designed as a zero-liquid discharge (ZLD) facility including tie in points for portable
equipment in the event the site equipment malfunctions, as well as design for redundancy of ponds to
allow maintenance of liners in the event of a leak.

Locations of tie-ins to existing systems are listed in Attachment [ ] and detailed in the system definitions
included in Section [ ]. A Control/Administration Building will be provided including areas for the Plant
control room and Lock Out Tag Out/Work Authorization Room. A Warehouse will be provided for material
and equipment storage. The Contractor shall be responsible for providing any other required warehouse
facilities for temporary indoor storage of equipment prior to installation within the permanent plant Facility.
The Contractor shall remove all temporary warehouse facilities, including foundations, at the completion
of construction

One gas fired auxiliary boiler shall be provided by the Contractor to provide steam for pre-heating piping
and equipment as required for plant startup and for supplying initial steam to the turbine gland seal steam
system. The auxiliary boiler shall be designed for indoor installation. Each SSCC unit auxiliary steam
supply system shall be cross-tied to each unit to provide backup auxiliary steam.

One two-winding, three phase generator step-up transformer (GSU) shall be provided for each unit.
Facility synchronization to the [ ] kV switchyard shall be accomplished through a low-side generator
breaker for each unit generator. A three-winding unit auxiliary transformer (UAT) shall be provided by the
Contractor and connected to the isolated phase bus system for each SSCC. The unit auxiliary
transformer shall supply power to the medium voltage 6.9 kV switchgear, which distributes power to the
secondary unit substation (SUS) transformers, medium voltage motors and combustion turbine static
frequency converter (SFC) system. Switchgear and motor control centers shall be provided to distribute
power to the 480 volt loads. A two-winding, three phase reserve auxiliary transformer (RAT) shall be
provided as a backup source for both SSCC. The RAT will be connected to the 46kV switchyard and
shall provide backup power to each unit.

One identical spare transformer shall be provided with containment pad, power and control provisions for
transformer space heaters and accessories, for the spare GSU, RAT and UAT.

A Plant-wide distributed control system (DCS) shall be provided to monitor and control the balance-of-
plant equipment and materials. The DCS shall communicate with the SSCC control systems via
redundant data highway links. An Contractor-provided virtual model and simulator shall be integrated into
contractors overall control scheme. The overall network architecture of the DCS shall have the units
isolated from each other physically, electrically, and logically. Controls for common area equipment shall
be accessible and controlled from either DCS utilizing hardwired interfaces and logics controlling which
unit has control of a given common are control system.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 981 of 1056
4
CTG NOx emissions shall be controlled by dry low-NOx (DLN) combustors. The HRSG shall be furnished
with an SCR system to reduce NOx emissions.

Base load for each SSCC shall be as defined in Section [ ] of these specifications. Maximum Load shall
be as defined in the Contract Definitions.

The Plant operating modes and basic control philosophy are described below:

Each SSCC shall be designed to operate in daily cycling mode with normal operation consisting
of Maximum Load and automatic generation control operation for 12 hours per day during
weekdays, but also to operate 24 hours per day as necessary.

Each SSCC shall be capable of operating continuously at any load over the entire range of
design ambient conditions. Load control between the units shall be coordinated to ensure the
total combined net load does not go below the minimum requirement for support of operations
and transmission at the point of interconnection.

Each SSCC shall be capable of operating in a stable, continuous, and controllable manner over
the entire design operating range of the SSCC from a Plant load with the SSCC operating at its
lowest load level, up to Maximum Load with the SSCC operating at its maximum capability
throughout the design ambient conditions, while maintaining emissions compliance.

Each SSCC shall also be capable of running continuously at base load in pseudo simple-cycle
mode while bypassing HRSG steam to the condenser in a cascading manner with the steam
turbine offline. The STG bypass system shall be designed for continuous operation in bypass
mode.

Reference Section [ ] for Plant operating performance guarantees.

The Plant does not need to be designed to generate electricity while isolated from the utility grid.

The control system design shall be based on a DCS type system. Control of the Plant shall be
through the DCS as defined herein. In general, separate PLC systems shall not be utilized,
except as specified herein or approved otherwise by the Owner.

The SSCC, and BOP equipment and materials shall be operated primarily from workstations
located in the central control room.

01100.1.1.1 Hydrogen Capabilities. Owner expects to transition from natural gas to hydrogen fuel in
incremental steps between 2025 and 2045 (“Transition Period”) as the hydrogen supply system and
combustion turbine technology develops to support more hydrogen usage. The plant shall be designed to
operate starting COD with a blend of 30% hydrogen by volume, and 70% natural gas by volume.
Modifications to the systems and components (such as increasing fuel piping diameters, changing seal
materials, increases in NOx Catalysts, and other related balance of plant systems) to support greater than
30 percent hydrogen content is expected for future upgrades.

The combustion turbine shall be capable of operating with a natural gas fuel blend containing up to 30
percent hydrogen content on a volumetric basis. Contractor’s Work shall include a fuel mixing system (per
Attachment [ ]) to deliver a 30%/70% Hydrogen/Natural Gas mixture that meets Supplier’s requirements.

Contractor shall include a detailed design case to allow the Units to operate with a fuel mix of 30%
hydrogen and 70% natural gas by volume at COD and shall also include detailed design for balance of
plant equipment to support 100% hydrogen fueled operation. The detailed design for the 100% case shall
include allowances for physical space, and sufficient room around equipment layouts for future auxiliary
system expansion to allow for greater than 30% Hydrogen by Volume up to 100% hydrogen by volume
injection. Contractor shall evaluate and present recommendation to the Owner for equipment that should
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 982 of 1056
5
be installed now to support 100% hydrogen fuel combustion that would lower life cycle costs for the
Owner. The systems that should at a minimum be considered in detailed design of the overall plant are as
follows:

Assigned Equipment that should be considered
Turbine Cooling Air (TCA)
Additional NOx Catalysts
Fuel Gas Heater
Balance of Plant Equipment that should be considered are
Cooling Water Systems
Emission Control Systems
Changes in supporting infrastructure.

OEM Supplier
OEM Supplier has implemented modifications to their scope of supply to allow for 30% of hydrogen fuel
by volume upon COD, as well as to facilitate transition to 100% of hydrogen fuel by volume during the
transition period with overall lower life cycle capital cost. The modifications were identified by Supplier
and are listed in this section. In addition, Supplier has identified the roadmap of major components that
will require capital improvements during the life of the units. See OEM Contract (Attachment [ ]) for further
details. The modifications to major equipment are listed here, as well as future equipment modifications
that are planned during the life of the units.

Year Description
2025 GT Enclosure
Control Valves
Instrumentation
Foundation hardware & Design
Redundant Calorimeter
Control System Hardware
2032 Multi Cluster Combustors
Turbine Section Casing
Fuel Gas Heater
GT Control System Mods
SCR Catalyst
Calorimeter
Foundation Hardware
2040 Multi Cluster Combustors
Hydrogen Supply
Refer to the Terminal Point/Interface List in Attachment [ ].

Fuel Mixing Skid
Refer to the fuel mixing skid specification (Attachment [ ]).

01100.1.1.2 Virtual Model. The DCS shall interface through data diodes with the Assigned Equipment
supplied interactive Virtual Model. The Virtual Model includes a digital representation of all OEM supplied
equipment and any equipment critical to the generation process. These interfaces provide a means for
any required data in DCS controlled systems to get into the Virtual Model. Contractor shall coordinate the
signal requirements with the Assigned Equipment. Contractor shall supply any Virtual Model specific
instrumentation as part of their Balance of Plant scope of systems. Refer to Attachment [ ].

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 983 of 1056
6
01100.1.2 Scope of Work
The Work described in these specifications shall be incorporated into a combined cycle Plant. The Work
shall include design, engineering, procurement, construction, construction management, startup,
commissioning, operator training, and demonstration and performance testing of the Plant and warranty
administration. The Contractor shall provide or cause to be provided equipment and materials,
machinery, tools, labor, transportation, construction fuels, chemicals, lubricants, oils, fencing, relocation of
any existing utilities and security facilities, temporary power, construction utilities, administration, and
other services and items required to complete the Plant. The equipment and materials, and systems to
be designed, furnished, and installed by the Contractor shall include, but not be limited to, the items
described in the following paragraphs.

01100.1.2.1 Owner-Furnished Work and Contractor Interface. Two one-on-one, single shaft units
including CTG, ST, and HRSG, each with ancillary equipment, and other Assigned Equipment, have been
purchased by the Owner and will be assigned to the Contractor. See OEM Contract (Attachment [ ]) for
further details. The Contractor shall administer the OEM Contract including managing vendor drawings,
quality control/inspections, delivery of equipment (including receiving, unloading, installing and
maintenance during storage), erection through final acceptance by the Owner, equipment performance
guarantees, field technical advisory services, etc. The Owner and Owner’s engineer shall receive
submittal documents from the OEM Suppliers as discussed in Section [ ].

Foundations and utilities for long term storage of the spare transformers identified above will be required.
Scope of supply information for the Assigned Equipment is contained in Attachment [ ].

The CTs will be [ ] units and the STs will be [ ] two-cylinder tandem-compound, double-exhaust,
condensing reheat steam turbines (TC2F) with [ ] inch last stage blades. The HRSGs will be horizontal
gas-flow, triple pressure with superheat, reheat, and economizer sections supplied by [ ].

Contractor shall provide all equipment and system first fills of oils, greases and lubricants, required for
startup tests and turn over to the Owner.

The Contractor shall manage the technical advisor time associated with the Assigned Equipment,
included in the Owners Agreement. The technical advisor time provided is considered adequate for all
Owner purchased equipment including erection, start up, testing and turnover to the Owner. The
Contractor assumes the risk for the use of this time and other costs. Any technical advisor time required
in excess of the Owners contract shall be to the Contractor’s account. The technical advisor scope of
work is detailed in Attachment [ ].

The Contractor will be providing a new [ ] kV switchyard. The Contractor shall install foundations and
take-off structures on the high side of the GSU transformers and intermediate transmission towers for
connection to the switchyard at an interface point as shown on the drawings in Section [ ]. Additional
details on the interface with the [ ] kV switchyard are included in Section [ ].

The fuel gas metering station will be furnished and installed by others in a separately fenced portion of
the Facility. The Contractor shall connect to above grade pipe flanges at the boundary of the fuel gas
metering station and shall be responsible for the supply and installation of all fuel gas system scope
downstream of that point. Attachment [ ] and Article [ ] of these specifications provide additional details
on the Contractor’s terminal points.

The Contractor shall provide a geotechnical and soil investigation laboratory testing, and a report for the
basis of their own foundation and grounding design. Contractor shall not remove any soils including top
soil from the Facility without the approval of the Owner. A location for excess material to be stored onsite
will be furnished by the Contractor.

Staging, craft parking, temporary roads and laydown areas shall be as shown on the Site Construction
Facilities drawing included in Attachment [ ]. Contractor shall remove and remediate the parking lots and
lay down areas that are created by the Contractor. Space for construction facilities including trailers,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 984 of 1056
7
parking, security entrances, etc., shall be as indicated on the Site Construction Facilities drawing. All
changes to the plan must be approved in advance by The Owner. Parking for Contractor personnel is
shown Construction Facilities Drawing [ ]. Badging of Contractor personnel is the responsibility of the
Contractor. Operation and supplies of the Contractor’s badging program shall be by the Contractor. The
Contractor must comply with the Site Security Plan program requirements when issuing badges to all
personnel. Contractor badging control shall include a means of mustering and accounting for all persons
onsite in the event of a generation construction area or site wide emergency. Parking and badging
facilities shall be independent of other contractors, Owner and outage contractor and their personnel. All
contractors shall jointly share in keeping these areas clean and maintaining a safe orderly operation
during all periods of use. Badging for access to any existing Owner facilities will be managed by the
Owner. Any Contractor personnel requiring access to any existing Owner facilities will need to obtain
clearance from the Owner.

01100.1.2.1.1 Existing Facilities [if applicable]. Contractor interfaces with and the location of existing
facilities are listed and detailed, in Attachment [ ] and the system definitions referenced in Section [ ].

While working in the existing facilities, Contractor shall strictly adhere to the Owner’s site procedures
Jobsite Policies included in Exhibit [ ], as well as any updates to the Owner’s site procedures Jobsite
Policies. Contractor’s work in the existing facilities shall be performed with as little impact to the existing
facility operations as possible. All work in the existing facilities shall be communicated and coordinated
with the Owner and shall have Owner’s pre-approval of the work plan. The Contractor shall coordinate
this work such that tripping of the existing facilities is avoided.

The Contractor shall be responsible for confirming the adequacy of and making repairs to any rail spurs it
uses for material delivery. Any repairs made to rail spurs shall be reviewed and approved by the Owner.
The Contractor shall also be responsible for the installation and costs of required onsite rail unloading
facilities. It is the Contractor’s responsibility to locate, acquire access, and improve all such facilities.

01100.1.2.2 Scope for Contractor Furnished Work. The Contractor shall be responsible for all
equipment and materials and services not provided by the Owner as described herein that are required
for a complete, operating combined cycle plant within the terminal points of the Contractor's Work.

The following lists the major components of the Work. This is not intended to be a complete, exhaustive
or comprehensive listing, but is provided for convenience of the Contractor in quickly developing an
understanding of the overall scope of Work of the Project. More detailed information and requirements
are provided in the later sections of this scope of Work and specification.

The Contractor’s scope of Work for the Assigned Equipment under this Contract includes contract
administration (including review and processing of vendor drawings and data), receiving, unloading,
transportation (including heavy haul) from the Owners delivery points, storing including in-storage
maintenance, installing, checkout, testing, insulating, commissioning, startup, finish painting of all
equipment and materials and systems including surface preparation and priming as necessary, touch-up,
tie-coats, finish coats in accordance with Section [ ] ,and testing of all equipment and materials furnished
by the Owner, which includes, but is not limited to, the following equipment:

The OEM manufacturer’s scope of supply is included in Attachment [ ].

Major Plant equipment to be furnished and installed by the Contractor includes:

Deaerating steam surface condensers.

Induced mechanical draft counterflow type cooling towers.

Auxiliary boiler.

Water Treatment system
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 985 of 1056
8

Service Water and Demineralized water storage tanks.

Generator Step-up Transformers.

Unit Auxiliary Transformers.

Reserve Auxiliary Transformer

Combustion/Steam turbine generator breakers.

Fuel Gas Startup/Dewpoint Heater

Fuel Gas Compressors.

All necessary mechanical equipment, electrical equipment, and control systems as defined in
Article [ ] of these specifications for a complete, redundant, reliable, operable, maintainable, and
functional SSCC plant to meet Owner's intended operations shall be designed, furnished and
erected

Civil/Structural:

All necessary civil/structural systems as defined in these specifications for a complete and functional
combined cycle power generating plant to meet the Owners intended operations shall be designed,
furnished and erected. The civil/structural activities shall be complete including, but not limited to, the
following:

Surveying and control, including LIDAR.

Verification of any existing on-site utilities.

Site geotechnical investigation – The Contractor shall be solely responsible for all investigations
of the Jobsite that may be necessary to collect design basis information for the plant and assure
Contractor of completeness of information required to perform the Work. Any Owner furnished
geotechnical reports are provided for reference information only and are not intended to be used
for design basis.

Final site drainage system including but not limited to, inlets, culverts, ditches, piping, and
manholes.

Modifications and repairs to any existing perimeter security fencing, gates, and security system
compatible with any Owners existing security systems and requirements.

Supply and installation of perimeter security fencing, gates and security systems for expanded
project areas.

Oily water separator system including new oil/water separator.

Underground utilities and piping.

Final storm water control system complete including berms, drainage structures, piping, drainage
ditches and stormwater collection basins/new evaporation ponds.

Excavation of native soil with salvage and stockpile of top soil, filling, backfilling, and compaction
of structural fill with reinstallation of all onsite top soil.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 986 of 1056
9
Finish grading including disposal of all spoil (waste) excess material.

Soil erosion, sediment control, and final stabilization. Contractor shall be responsible for
maintaining all sediment controls until Final Completion.

Installation and repair of roads, parking, sidewalks, and new paving including striping and
subsurface preparation.

Seeding, sodding, landscaping and final combined cycle site restoration. No existing soils shall
be removed from the Jobsite without the consent of the Owner.

Development, maintenance, and security of material laydown areas as needed to complete the
scope of Work.

All areas of the Plant and any existing Owner facilities disturbed by the Contractor, including
laydown areas, shall be restored to acceptable condition before demobilizing from the Jobsite.

Fuel and chemical storage secondary containments.

All foundations and necessary concrete blast walls (including foundations with oil spill
containment basins for on-site storage of the spare GSU, UAT and RAT transformers). The
spare transformer shall be installed on concrete pad with easy access to either of the operational
transformers. The path way from the spare transformer to either of the operational transformers
shall be rated to support 110% of the weight of the fully dressed transformer and the heavy haul
transportation equipment without any structural modifications (should not require removal of
bushings, or high side leads of adjacent units).

Elevated foundations for steam and combustion turbine generators as required to comply with the
foundation criteria and arrangement of the equipment as specified by the Assigned Equipment
supplier.

Stairs and platforms for elevated equipment and materials.

All interconnecting walkways, stairs, ladders, handrails/guardrails not provided with the Assigned
Equipment but required to provide appropriate access to all equipment. Platform sizes shall be
provided for Owner review and approval.

All buildings identified in the system definitions, arrangement drawings and as determined by the
Contractor to be required for a complete operating plant. The buildings and sun/rain protection
systems shall include but not be limited to foundations, grouting, structural steel superstructure,
elevated floors of grating and/or reinforced concrete, miscellaneous access platforms and support
structures including structural steel, stairs, ladders, stair treads, grating and handrail/guardrail,
metal wall and roof panels, insulation, doors, windows, louvers, prime and finish painting, and all
other miscellaneous architectural items such as block walls, gypsum board/metal stud walls,
insulation, hardware, trip work fireproofing, caulking, sealing, firestopping, flooring, plumbing and
plumbing fixtures and breakroom and toilet room accessories as required to provide compete
building systems.

Combustion turbine air inlet support steel structure. The location of the air inlet support structure
steel is critical to the combustion turbine layout. The Contractor shall coordinate the design of the
support steel to meet the specific location criteria identified by the Assigned Equipment supplier.

Access provisions to the HRSG inlet test emission ports on the HRSG inlet duct. Access
provisions shall include support steel, platforming, walkways and stairs as required to provide
necessary access to the test emission ports.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 987 of 1056
10
Overhead cranes, monorails, hoists/trolleys, and enclosures as specified.

Demolition and disposal of all construction debris.

Painting, including finish painting of all equipment and materials and systems including building
interior and exterior surfaces, piping systems, structural steel, surface preparation and priming as
necessary, touch-up, tie-coats, and finish coats in accordance with Section [ ]. All interior and
exterior ladders, cages, handrail and guardrails including those furnished with the Assigned
Equipment shall be galvanized.

Sanitary waste collection and disposal to a sanitary treatment facility.

Upgrades and repairs to roads, bridges, etc., located outside the Facility required for
transportation of Equipment and Materials, including Owner Furnished Equipment, to the Jobsite
Mechanical:
All necessary mechanical systems as defined in these specifications and as required for a complete and
functional combined cycle power generating plant to meet the Owner's intended operations shall be
designed, furnished and erected. The mechanical systems shall be complete including, but not limited to,
the following:
For each SSCC:

High pressure, intermediate pressure, low pressure and auxiliary steam systems.

Condensate system.

Condenser air extraction system.

Boiler feed system.

Heat rejection system including circulating water system and cooling towers.

Closed cycle cooling water systems.

Boiler vents and drains system.

Steam turbine vents and drains system.

Steam turbine seals and drains system.

Generator Rotor Removal System

CT, Gen and ST lubricating oil systems (interconnecting piping not furnished by the OEM
Supplier).

Combustion turbine off-base auxiliaries’ system (interconnecting piping not furnished with
the CT).

Selective catalytic reduction (SCR) system (furnished by OEM Supplier).

Fuel gas system including regulating, odorizing, fuel gas compressors, separators, and
heaters.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 988 of 1056
11
Hydrogen blending system, Attachment [ ]. Hydrogen fuel gas system including
regulating, odorizing, fuel gas compressors, separators, and heaters and blending
system.

Two Gas Calorimeters.

Common for the Plant:

Ammonia storage and supply system.

Cycle makeup storage and distribution system.

Auxiliary Boiler system with stack, platforms, walkways, ladders, stairs and railings.

Compressed air system (including service air and instrument air).

Compressed gas storage and supply systems for N2 and CO2.

H2 generation, storage, venting and supply system for generator cooling.

Service water system.

Potable water system.

Fire protection systems (including interconnection to any existing Owner equipment fire
protection and site fire protection).

Continuous fuel gas sampling capability to meet permit requirements.

Fuel gas chromatograph with all necessary instrumentation housed in a free-standing
weather proof enclosure with heating, ventilation and air conditioning as required by the
equipment Supplier’s design.

Raw water supply system.

Wastewater collection system.

Sanitary drainage system.

Insulation as required of piping, equipment, and vessels.

Electrical and Control:

All necessary electrical and control systems as defined in these specifications for a complete, redundant,
reliable, operable, maintainable, and functional SSCC plant to meet Owner's intended operations shall be
designed, furnished and erected. The electrical and control systems shall be complete including, but not
limited to, the following:

For each SSCC:

Bus ducts and supports between the generator and the generator breaker, including bus
ducts and supports to the PT and surge arrestor cubicle and generator excitation
transformer.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 989 of 1056
12
Bus ducts and supports between the generator breaker and the generator step-up
transformer, including bus ducts to the unit auxiliary transformer and support system as
required.

Redundant auxiliary power system.

Batteries and UPS system.

Distributed control system (DCS), including system interface work stations, large screen
display, printers, I/O modules, control and communication processors, video drivers,
electronics and termination cabinets, data highway, and DCS intrusion detection system.

Control consoles, emergency trip panel, and dedicated process indicators.

DCS interface with the OEM turbine control system, and miscellaneous packaged
equipment controls.

OEM turbine control system interconnection to the OEM operator interface stations
located in the unit control room, including fiber optic cables and patch panels.

All cable and non-segregated bus between OEM supplied equipment and devices

Control and electrical interface between the plant and [ ] kV switchyard and any existing
electrical grid facilities and any new gas yard.

Instrumentation, mounting structures, accessories and impulse piping.

Balance of Plant SUSs and MCCs.

Reserve Auxiliary Transformer and interconnecting electrical systems.

Cable and raceway systems.

Common for the Plant:

Standby Diesel Generator system.

BOP DCS simulator components for OEM supplied Simulator

BOP components for OEM Virtual Model

Underground duct bank systems.

Site and Plant lighting within the Facility boundaries including the new cooling tower area.

Lightning protection system.

Facility grounding system.

Cathodic protection system.

Heat tracing and freeze protection system.

Communication systems.

Construction power system.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 990 of 1056
13

Telephone, security and page/party system.

Building Management System for HVAC.

Plant Physical Access Control System.

Chemical:

All necessary chemical systems as defined in these specifications for a complete and functional
combined cycle power generating plant to meet the Owner's intended operations shall be designed,
furnished and erected. The chemical systems shall be complete including, but not limited to, the
following:

Common for the Plant:

Raw water pretreatment system.

Cycle makeup treatment system.

Potable water treatment system.

Service water treatment system.

For each SSCC:

Condensate polisher system.

Cycle chemical feed system.

Sampling and analysis system.

Circulating water chemical feed system.

01100.2 Scope of Work Additional Requirements
01100.2.1 General
Equipment and materials shall be designed in accordance with Prudent Utility Practices, relevant codes
and standards, and local regulations. All Contractor supplied equipment and materials shall be new and
unused. Equipment and materials manufactured previously for another application shall not be utilized.
Equipment and materials ratings and spare capacity shall be provided in accordance with this Scope of
Work. Systems shall be designed in strict accordance with original equipment manufacturer’s
requirements. All equipment and materials shall be of proven design; experimental or prototype designs
will not be accepted.
The Contractor's design engineer(s) shall attend a kickoff design conference at a time and place to be
selected by the Owner to discuss matters relative to the execution of this Scope of Work. The
Contractor's design engineer(s) shall attend additional design conferences as required by the Owner to
review and expedite the Work.
The Plant shall be designed and constructed to meet all requirements set forth in the permits included in
this Scope of Work.
Conditional Use Permit (CUP) – The Contractor has applied for the CUP with [ ] County.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 991 of 1056
14
Construction Air Permit - The Contractor has applied for a Construction Air Permit and has
received the Draft Air Permit included in Attachment [ ].

Stormwater Construction General Permit – The Contractor will be responsible for developing a
draft Storm Water Pollution Prevention Plan (SWPPP) for the work associated with the Jobsite
including parking, laydown and storage areas. Contractor will update the SWPPP for their portion
of the site work and obtain the required Stormwater Construction General Permit. The Contractor
will be responsible to implement, maintain, and monitor the SWPPP and affected areas impacted
by the generation project.

FAA Notice of Construction or Alteration (FAA NCA) – The Contractor will obtain the necessary
FAA NCA for the HRSG exhaust stacks and [ ]. The Contractor shall obtain the necessary FAA
NCA for any erection equipment such as cranes.

Wastewater Facility Construction Permits – The Contractor will obtain the necessary permits for
the construction of any evaporation ponds.

The Contractor shall be responsible for obtaining any other permits or developing any necessary
plans to support construction of the Facility such as Spill Prevention Control and
Countermeasures Plan, Mobile Concrete Batch Plant permit, Temporary Above Ground Storage
tank registration, and others as required by the state and local jurisdictions.

The Contractor shall be responsible for delivery, receipt, inspection, unloading, hauling, handling, storage,
security, assembly, and preventive maintenance of all equipment and materials until Final Completion
including the Assigned Equipment delivered to the Jobsite. The Assigned Equipment will be delivered by
rail, truck, or heavy haul to the Jobsite.

Contractor shall be responsible for any necessary improvements to the area adjacent to the rail sidings
for crane set-up and operation, unloading, loading, and transportation from the rail sidings. Contractor
shall be responsible for all heavy haul requirements between on-site railroad sidings and the equipment
final set location or storage location.

Contractor shall be responsible for disposal of all waste generated during construction and start up
including but not limited to cleaning effluent of piping systems and HRSG chemical cleaning.

Contractor shall be responsible for removal and disposal of construction waste generated or presently in
the area of construction.

Construction water and construction power will be provided by the Contractor at defined terminal points.
Other construction utilities such as construction fuels, telephone, and data connections shall be secured
and provided by the Contractor at Contractor’s expense. The Contractor shall be responsible for
designing and installing modifications to any existing Owner facilities as described in Article [ ] and Article
[ ] to provide construction power for its use during construction. Contractor shall provide first fill of fuel for
the emergency diesel generators and all fuel consumed during startup and commissioning. Contractor
shall also furnish the first fill of all lubricants, materials or fluids used for flushing and startup of all
equipment and materials including steam turbine, combustion turbine, boiler feed pumps, TCA cooler
feed pumps and all other lubricating and hydraulic systems. The Contractor shall also provide all
chemicals used during storage, startup, and commissioning and shall dispose of these materials as
necessary using methods acceptable by federal, state, and local requirements. Contractor shall maintain
an adequate supply of these lubricants, materials, fluids, and chemicals to provide replenishment up to
the time of Substantial Completion.

It is the Contractor’s responsibility to provide clean equipment and materials, piping, and systems ready
for operation and use by the Owner. All costs associated with providing a clean and ready to operate
condition shall be the responsibility of the Contractor; including but not limited to demineralized water
obtained from off-site sources, rental equipment and inert gas for fuel gas line blows.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 992 of 1056
15

Disposal of shipping fluids, materials, or flushing liquids/materials such as water, demineralized water,
wastewater, lube oil, diesel fuel and fuel gas, from the Jobsite shall be performed by the Contractor to
acceptable disposal sites, so that disposal is performed according to local, State, and Federal
requirements.

The Contractor will be responsible for completion of system tie-ins to allow plant startup utilities such as
backfeed power, water services, and fuel to be operational for combustion turbine operation.
Land and rights-of-way will be provided by the Contractor.

The Contractor shall coordinate with the Owner for any access to any existing facilities of the Owner.

Each SSCC shall be designed such that it can be safely and reliably operated under all conditions,
including startup, shutdown, load ramping, and continuous operation at any load in the load range. The
load range shall include any operating condition from shutdown through Maximum Load.

All piping, conduit, and cable tray shall be routed so as not to interfere with routine equipment
maintenance activities. All major equipment shall have an open access path for disassembly and
removal or replacement purposes. Access and egress paths shall comply with OSHA requirements but
shall also meet Owner’s specifications herein requiring additional space, access, and other
accommodations. Owner’s specifications will often exceed OSHA requirements.

Pipe racks, bus bar and cable trays shall be designed to allow for passage of truck deliveries, equipment
removal/replacement, crane access, maintenance access and operations.

01100.2.2 Performance
The Performance Guarantees for the Units included in Section [ ], Plant Performance Guarantees and
Tests shall be based on Project-specific data from the OEM supplier and all associated equipment and
systems as described in Attachment [ ].

Fuel for performance testing shall be natural gas. The fuel analyses are included in Section [ ].

Others will provide natural gas to a natural gas metering and pressure control station to be furnished and
installed by the Contractor. The Contractor shall be responsible for all scope downstream of the fuel gas
metering and pressure control station.

For purposes of Unit auxiliary power loads, all Unit equipment and materials required for normal
Maximum Load operation of the Unit shall be in service during testing as defined in Article [ ]. A list of the
auxiliary electric equipment which will be operating during testing shall be provided in the Contractor's
detailed Performance Test procedures.

Thermal Performance Test procedure guidelines are included in Section [ ], Performance Test Guidelines.
The Performance Test procedures shall be developed by the Contractor with input and agreement from
the OEM Supplier and the Owner.

The Contractor shall provide test thermowells, pressure test ports, and sampling ports as necessary to
perform the thermal Performance Test procedures. These locations shall be provided with the detailed
test procedures developed by the Contractor. Temporary strap on instrumentation for temperature or flow
measurement will not be allowed.

01100.2.2.1 Noise. The guaranteed noise emissions for the Facility are included in Section [ ]
Performance Guarantees and Tests.

01100.2.2.2 Emissions. The guaranteed air emissions for the Plant as presented in Section [ ] and shall
be in compliance with the air permit located in Attachment [ ], Plant Performance Guarantees and Tests,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 993 of 1056
16
are based on the combustion turbine emissions guarantees included in the OEM contract; and
emergency diesel generators emissions, auxiliary boiler emissions and fuel gas dew point heater
emissions listed in the draft air permit included in Attachment [ ] .

A continuous emissions monitoring system (CEMs) shall be complete and operational and ready to be
certified a minimum of 24 hours before at the time of first fire.

01100.2.3 Mechanical
Startup steam used during commissioning of the combustion turbine, steam turbine and auxiliary boiler
shall be vented to atmosphere. Silencers shall be provided by the Contractor. The Contractor shall be
responsible for obtaining any governmental approval, if required, to exhaust steam to the atmosphere
during construction, startup, and commissioning of the Plant. The Owner reserves the right to review and
request changes to the steam venting plans.

A basis of design description of the proposed fire protection systems suitable for submission to the
Owners insurance provider shall be submitted to the Owner for review and approval.

Piping shall be painted as specified in Article [ ].

The Contractor shall be responsible for touch up painting of piping and equipment and materials including
Assigned Equipment, meaning cleaning, surface preparation, priming, and finish coating with a matching
color prior to Final Completion. The Contractor shall submit its piping color code system to the Owner for
approval. All equipment and materials and piping shall be painted and/or coated per the Owner approved
Contractor’s piping color code system. Equipment supplier’s standard painting, if different than
Attachment [ ], is not acceptable unless approved in writing by the Owner. Contractor shall touch up
prime coat before applying finish coat. Piping color shall be in accordance with the approved Contractor’s
color code system to identify the process contents of the piping.

All piping shall be labeled. Labeling shall conform to ASME A13.1-1996 "Scheme for the Identification of
Piping Systems" unless otherwise specified in this Scope of Work. Labels should match the piping color
code system. This ASME standard defines pipe marker sizes and letter heights based on the outside
diameter of the pipe to ensure good legibility of the markers.

Contractor shall follow the equipment identification and labeling system included in Attachment [ ]. All
Equipment and Materials shall have a unique identification number. Equipment and Materials shall be
labeled prior to shipment. Equipment and Materials identified as not having a label shall not be operated
by Owner personnel until the label is in place.

Color coding of pipe systems shall be based on the pipe contents unless otherwise indicated by the
Owner (inherently Hazardous Materials are identified with yellow markers and black print; nonhazardous
liquids with green markers and white print; nonhazardous gases with blue markers and white print; and
fire protection systems with red markers and white print). This color scheme allows for quick
differentiation based on pipe content's relative level of hazard.

Piping shall have heavy duty, UV/chemical resistant labels with the system name, fluid, and flow arrow.
Pipe labels shall have a spacing of not more than 20 feet, at changes in elevation, valve stations and
equipment, changes in direction, intersections, and above and below floor and wall penetrations. Pipe
labels shall be compatible with the surface to which it is applied. Labels shall be at least as high as the
pipe diameter for pipes under 10 inches. Pipes over 10 inches shall have labels at least 10 inches high.
For piping 2 inches and smaller, labels shall be able to be clearly read, but shall not be less than 1 inch.
Labels shall withstand the minimum to maximum temperature range of the process piping, indoor and
outdoor ambient air temperatures and be suitable for the environment.

Equipment and Materials shall not be located in trenches, pits or sumps except for sump pumps,
circulating water pumps, and the condensate pump cans as required.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 994 of 1056
17
01100.2.4 Chemical
All water analysis and monitoring facilities (hardness, silica, iron, etc.) required for the Plant startup and
commissioning will be provided by the Contractor. All other analyses shall be procured from a third party
by the Contractor. Chemicals as defined in the Division of Responsibilities Matrix included at the end of
this section shall be provided by the Contractor.

Commodity chemicals (e.g., amine), shall be used for the cycle chemical feed systems.
01100.2.5 Electrical/Control
The plant auxiliary electric system shall in concept be based on the one-line diagrams included in
Attachment [ ]. The [ ] kV switchyard expansion will be designed so that the switchyard will have
sufficient capacity to allow starting of the plant's largest motor or combustion turbine starting system while
also supplying auxiliary load equal to the sum of the unit auxiliary transformer's highest MVA nameplate
rating. When the actual [ ] kV system impedances are provided, a system analysis shall be completed by
the Contractor to determine if changes to the auxiliary electric system are required (reduced voltage
motor starters, etc.).

The power factor shall be guaranteed at the terminals of the generator, and not at the high side of the
generator step-up transformers. When the existing [ ] kV system impedances are provided, the
Contractor shall work to attain the system power factor desired.

Electrical system studies included in the Contractor's scope shall include those required to design and
specify the Plant auxiliary electric system within the Facility boundaries. Studies include, but are not
limited to, load calculations, load flow, short circuit, GSU voltage/VAR flow, and motor starting.

Plant synchronization to the [ ] kV grid shall be accomplished through the low-side generator breaker for
each unit.

The Contractor shall provide the necessary information related to Contractor supplied Equipment and
Materials to allow the Owner to perform system stability studies.

A minimum of three diesel generators shall be provided and shall have sufficient capacity to safely
shutdown the plant following a unit trip and coincident loss of external auxiliary power.

The integrated control system for Plant operation and monitoring shall provide for complete remote
operation of all systems. Manufacturers' control systems shall be supplied with remote indications and
alarms. The auxiliary electric system shall not be provided with a control room main electrical panel;
however, similar functionality shall be provided within the DCS using a work station flat panel screen as
the operator interface in lieu of a hard device control panel.

Factory acceptance testing (FAT) of the DCS shall be conducted. The Owner and the Owner’s
representatives shall be permitted to participate in the FAT. All actual components, HMI displays,
input/output signals and system interfaces shall be thoroughly tested and simulated. All modifications
requested by the Owner during FAT shall be maintained in a formal log, incorporated and signed off prior
to shipment of the DCS to the Jobsite. The proper operation of the DCS and its actual interfaces shall be
verified, and control loop tuning shall be finalized, prior to each Units acceptance testing. All logic
simulations and emulators shall be provided for testing and then removed after testing prior to shipping.

The Contractor shall ensure that the DCS computing and networking infrastructure is designed and
provided, fully compliant with the NERC CIP Standards as outlined in Article [ ]. The Contractor shall be
responsible for implementing, if necessary, other Supplier’s control systems (i.e. turbine controls, PLC
controls) with the applicable NERC CIP Standards based on those systems being directly interfaced with
the Plant networking infrastructure.

Contractor shall provide plant communications systems. The Contractor shall furnish and install the PBX
telephone equipment and other plant communications equipment including voicemail system routers,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 995 of 1056
18
switches, UPS, fiber management, fiber electronics, main distribution frame, channel bank, commercial
telephone system, and servers.

A page/party system (Gaitronics) shall be furnished and installed by the Contractor.

The Contractor shall use a radio communication system during construction of the Plant and shall provide
the Owners designated onsite personnel with radios for communication with the Contractor. All
Contractor furnished radios shall be equipped identically and with the same set of multiple frequencies
that are installed in all radios for cross communication between Contractor, Owner, and security service
on the Jobsite.

The Contractor shall provide a local area network for wireless access for the Facility. Wireless access
shall be available in all operating areas of the plant.

The Contractor shall provide a building management system for HVAC controls.

The Contractor shall provide and coordinate installation of the Plant Physical Access Control System for
the Facility.

The fuel gas input custody transfer meter will be supplied and calibrated by the Contractor as part of the
fuel gas metering and pressure control station. The Contractor shall provide a revenue quality fuel gas
meter near the custody transfer point. The CTG fuel gas meter will be utilized for each Units Performance
Tests. A separate fuel gas meter for the auxiliary boiler shall also be provided. All fuel gas flow signals
shall be taken from the onsite meters to the DCS for display and totalized in the DCS. All Contractor
provided gas meters shall be designed and calibrated in accordance with AGA Report #3.

The Contractor shall install cables between the switchyard and each Unit DCS for protective relaying.

Interface provisions for load dispatching commands and Facility status signals shall be included to
support automatic generation control (AGC), automatic voltage control (AVC) and frequency response
commands from the Owner’s Energy Control Center (ECC). The interface provisions for load dispatching
commands, status points, and communication interfaces shall be through an RTU for each Unit. Actual
Facility operation and, configuration, and output (generation decisions) remain in the control of the local
Plant operators. RTUs for each Unit will be provided by the Owner.

Provide cabinet, relays and other devices for a complete system for controls and signals to support the
Remedial Action Scheme (RAS)

Contractor shall install all required systems to any existing stations. Refer to [ ] and [ ] in Attachment [ ].

Instrumentation shall be provided for control, protection, operation and automation of equipment and
systems in accordance with this specification.

Transmitters and valves that will provide signals to the Distributed Control System shall be furnished with
Foundation Fieldbus signal communications

All instruments shall be calibrated and configured before installation and verified prior to startup and
commissioning. Instruments shall be recalibrated prior to Performance Testing.

01100.2.6 Civil Structural
It is the Contractor’s responsibility to perform an independent geotechnical study, including testing and
analysis as necessary to confirm the Contractor’s design. Soil testing, soil remediation, soil
improvements, soil stabilization, piling, removal of underground obstructions, and or remediation related
to removal of underground obstructions is part of the Contractor’s scope.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 996 of 1056
19
Handling and disposal of any and all existing contaminated soils or other materials will be performed by
the Contractor.

The Facility site boundary and topographic survey is included in Attachment [ ]. Normal construction
surveys for laying out and controlling the Work shall be included in the Contractor's Scope of Work. The
Contractor shall perform a supplementary Jobsite survey to identify existing contours and features as they
exist prior to startup of the Contractor's work, and to establish baselines for locating and controlling the
Work. Contractor shall also establish Jobsite control geometry, subject to approval of the Owner.

Dewatering, disposal of the water and shoring of excavation works shall be the responsibility of the
Contractor.

Drives to vehicle entrances to buildings shall be asphalt paved. Buildings shall be interconnected with
concrete sidewalks or asphalt pavement. All other areas inside the power block loop road shall be
surfaced with compacted crushed rock. The remaining open areas not paved or aggregate surfaced shall
be surfaced with retained topsoil suitable for seeding with native grasses (seeding by others). The
Contractor shall be responsible for repairing aggregate-surfaced onsite roads installed both by the
Contractor and by others and providing final asphaltic concrete paving and striping as indicated on
Drawing [ ] in Section [ ]. In addition, existing paved roads so designated on [ ] shall be crack and chip
sealed with all markings repainted prior to the Contractor leaving the Jobsite.

A monorail shall be provided over each piece of equipment or removable component weighing 1000
pounds or more not accessible by mobile cranes, forklifts, or generation building cranes as required for
maintenance. A permanent hoist and trolley, suitably sized, shall be installed on the monorail above the
equipment listed below. Additional requirements are specified in Section [ ].

Permanent Hoist Required Equipment:

Generation building cranes.

Condenser water boxes.

Boiler feed pumps and motors.

TCA cooler feed pumps minimum recirculation valves and motors.

Condensate pumps and motors.

Closed cycle cooling water pumps and motors.

CTG/ST lube oil skid.

CTG motors on top of roofs.

CTG inlet air filter panels, from grade to inlet filter elevation.

CTG lube oil reservoir

CTG generator bearing covers, minimum two locations.

HRSG LP recirculation pumps (if applicable).

HP, IP, and LP ST main stop and control valves.

Feedwater HP and IP discharge valves.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 997 of 1056
20
Feedwater pump minimum recirculation valves.
LP admission valve.

Bypass valves.

SCR Catalyst removal

Stack platform at locations where CEMS connections are located, with
weather proof cover.

In the alleyways of power control cubicles.
In all battery rooms.
Fire water pump and motor.

Circulating water and auxiliary cooling water pumps and motors.

Fuel gas compressors and motors.

Diesel generators.

Auxiliary boiler equipment.

Interior furnishings for the buildings such as desks/furniture, bulletin boards, etc., shall be included in
Contractor's Scope of Work. All control room consoles and work stations are described within the
specification and shall be included in the Contractor’s Scope of Work. Breakroom, bath room, etc., shall
be complete with all permanent and non-permanent fixtures as specified herein.

Interior structural steel located inside buildings and exposed in the finished construction shall be shop
prime painted, cleaned and surface prepared for field touch up of primer paint, and finish painted in the
field. All exterior structural steel structures shall be galvanized or painted with a durable industrial shop or
field applied coating system. All structural steel coatings shall be applied in accordance with Section [ ]
and shall be painted and/or coated per the Contractor’s approved color code system.

Column identification by row letter and number shall be stenciled on four faces or all exposed faces of all
steel columns. Identification shall be placed at a height of 66 inches above finished grade on each
building operating level. If required to avoid obstructions, the height may be adjusted between 57 inches
and 72 inches to ensure it is visible. Letters and numbers shall be a minimum of 4 inches tall in
accordance with Attachment [ ].

01100.3 Engineering
An up-to-date printable index listing all issued Contractor drawings, by number and title, and which shows
the revision status of each drawing, shall be maintained and shall be made available to the Owner at all
times. An updated copy of the index shall be issued to The Owner in the monthly report. Electronic
copies shall be provided in a searchable format. A copy of drawings issued for construction with revisions
shall be maintained in the Owner field office by the Contractor for Owner use. This will ensure that the
Owner will be working from the same up to date information as the Contractor.

Contractor shall provide a complete list of standards anticipated to be used during design. Contractor
shall update the list of standards prior to Final Completion.

A complete set of “as-built” drawings (drawings that have been conformed to construction records) shall
be provided to the Owner prior to Final Completion. As-built drawings shall be provided as searchable
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 998 of 1056
21
.PDF files and in the drawings native CADD file format (2D AutoCAD 2012 or more current or similar as
approved by Owner).

Contractor will provide to Owner the right to use and share drawings with third parties for maintenance
support and plant design efforts in future. Contractor will add IPC numbers to drawings in addition to
Contractor numbers.

01100.3.1 Engineering and Design
Contractor shall perform all engineering and design work, within the scope of Work, required for the Plant.

Within two (2) months following award of the Contract, Contractor shall develop and submit to Owner a
facility design manual defining the design criteria for the Plant. Design manual shall be subject to review
and approval by Owner with respect to level of detail and conformance with the requirements of the
Contract. However, Owner’s review of the design criteria does not relieve the Contractor of fully
complying with these specifications. Contents of the facility design manual shall include the following
items as a minimum:

Design criteria for each engineering discipline
Results of Contractor’s site subsurface investigation per Schedule of Submittals
Contractor's equipment and system designation methods
List of systems and system designations
Water/Mass Balances
Cycle heat balances at the following load points: Steam Turbine Valves Wide Open, Net
Power Output Guarantee point, 50% and 75% of the Net Power Output Guarantee point,
and Steam Turbine Generator minimum stable load
Full load steam generator loss tabulation and temperature profile drawing
Auxiliary load lists
3D model showing preliminary maintenance access and hoist location.
Preliminary Maintenance access study to accompany the 3D model for Owner review.
The final maintenance access study shall be provided which incorporates the Owner’s
comments.

An up-to-date printable index listing all Contractor drawings by number, title, and revision shall be
maintained and available to Owner at all times. An updated copy of the index shall be issued to the
Owner at a minimum in the monthly report. Electronic copies shall be provided in a searchable format.

All vendor drawings, including drawings for Owner-supplied Materials and Equipment, shall be assigned a
Contractor drawing number. An up-to-date printable index listing all vendors’ drawings, including
drawings for Owner-supplied Materials and Equipment, received shall be maintained and be available to
Owner at all times. The listing shall show the Contractor-assigned number, vendor’s drawing number,
title, and revision number. An updated copy of the index shall be issued to the Owner at a minimum in the
monthly report. Electronic copies shall be provided in a searchable format.

All engineering and design calculations prepared by Contractor during the design of the Facility shall be
made available for Owner to review. Such calculations shall include architectural, civil, electrical,
mechanical and instrumentation/control details.

The plant shall be designed and fabricated in accordance with all codes and standards and federal, state,
and local regulations pertaining to the electric power industry or the equipment and services furnished
pursuant to the Contract.

Contractor shall designate an Engineering Manager who will be responsible for the overall management
and administration of engineering and design work.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 999 of 1056
22
01100.4 Procurement
Except for the Owner Furnished Equipment, the Contractor shall be responsible for the procurement,
handling, and delivery to the Jobsite of all equipment and services, including, without limitation, locating,
negotiating, inspecting, expediting, shipping, unloading, receiving, verifying, customs clearance and
claims. Contractor shall also be responsible for inspecting, expediting, unloading receiving, verifying and
onsite storage of Owner-supplied Materials and Equipment. Storage of Owner-supplied Materials and
Equipment shall be in accordance with the manufacturer’s requirements.

Contractor shall store all equipment at the project site in accordance with Prudent Utility Practice and
equipment manufacturer’s recommendations. Contractor shall take all actions necessary to preserve
equipment manufacturer warranties. Contractor shall use reasonable measures to keep the equipment
free from dirt, moisture and debris. Contractor shall perform all maintenance activities, including without
limitation, lubrication checks, rotations, temporary heater operation, and megger checks, to ensure
compliance with equipment manufacturer recommendations. Contractor shall maintain an up to date log
of such maintenance activities, such log to include the dates of such activities and the signatures of the
personnel performing such activities. Such log shall be available to Owner for review in Contractor’s field
office at all times.

Contractor shall be responsible for the procurement of all bulk materials, permanent or temporary,
needed for the proper erection of systems and components of the Work. This includes, but is not limited
to, all grading and fill material, foundation materials (including piling, concrete, rebar, and forms), steel,
pipe, hangers, conduit, cable, cable tray, and insulation and lagging.

All technical portions of purchase orders and subcontracts for permanent engineered equipment shall be
prepared in accordance with Contractor’s standard practices and numbering system.

Contractor shall provide to Owner, for review and comment, all technical sections of the bid specifications
for permanent equipment incorporated into the plant. Contractor shall provide record copies of
conformed technical specifications for such equipment.

All vendor drawings, including drawings for Owner Furnished Equipment, shall be assigned a Contractor
drawing number. An up-to-date printable index listing all vendors' prints, including drawings for Owner
Furnished Equipment, that have been received shall be maintained and be available to the Owner. The
listing shall show the Contractor-assigned number, vendor's drawing number, and title. An updated copy
of the index shall be issued to the Owner on a monthly basis. Electronic copies shall be provided in a
searchable format.

Promptly after receipt by Contractor, Owner shall be provided shop inspection reports, shop and field
performance test reports, equipment data sheets, and performance curves and data for all permanent
equipment as described in Article 21000.

01100.5 Construction
Contractor shall be responsible for all erection and installation work. Contractor shall manage the
performance of all subcontractors and shall be responsible for the quality and time of performance for all
subcontract work.

Contractor shall be responsible for all indirect construction costs including, without limitation, costs for
personnel and supervision, employee travel and per diem, construction equipment (including mobilization
and demobilization), material, consumables, utilities, facilities, tools, apparatus, temporary buildings,
temporary utilities, scaffolding, project job office expenses, quality control testing (such as for concrete
and welding), and demobilization costs.

Contractor shall be responsible for grading, excavation, dewatering, backfill, foundations, and piling. All
excess excavated materials shall be stockpiled on the site as shown on the Construction Facilities Dwg [
].

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1000 of 1056
23
Contractor shall be responsible for flushing, boil-out/degreasing, and chemical cleaning of the feedwater
system, condensate system, and all wetted HRSG sections. Chemical cleaning shall incorporate all
requirements of the OEM Contractor and shall include acid or chelant cleaning and shall be followed by
passivation and at least two (2) rinses with demineralized water (and additional rinses as required if the
conductivity of the circulated rinse water is not acceptable, per the agreed upon chemical cleaning
procedure. Contractor shall be responsible for furnishing all temporary equipment and for the proper
disposal of flushing water and boil-out/degreasing and chemical cleaning wastes. Non-contaminated
flushing water and any chemical cleaning rinses after the second rinse may be directed to the Facility
evaporation ponds for disposal. Contractor shall furnish to Owner, for review and approval, the cleaning
procedures and acceptance criteria proposed by Contractor no less than thirty (30) Days prior to
Contractor commencing such cleaning.

Contractor shall be responsible for all steam blows on steam piping and air blows on air and gas piping,
including all temporary equipment, piping, silencers, targets, and water treatment chemicals. Steam
blows on each section of HRSGs and steam piping shall be done at a minimum cleaning force ratio or
momentum ratio of 1.2 at the critical point of such sections. Contractor shall furnish to Owner, for review
and approval, the steam and air blowing procedures and acceptance criteria proposed by Contractor no
less than sixty (60) Days prior to Contractor commencing such steam and air blows.

Contractor shall be responsible for managing all subcontractors on the Jobsite, controlling the flow of
traffic and personnel entering and leaving the Jobsite, and coordinating the use of heavy equipment and
rigging equipment.

Any Work found to be in non-compliance with any drawing, specification, standard, or code, which
requires any type of engineering evaluation to determine acceptability for use or corrective action to bring
into compliance, shall be documented and dispositioned by appropriately trained and authorized
personnel. Written documentation of the non-compliance shall be provided to Owner at the time of
discovery. Written documentation of the evaluation and disposition by Contractor shall be promptly
provided to Owner. Such documentation shall be in accordance with Contractor’s standard format for
such documentation as outlined in these specifications and Article [ ].

During construction and updated on weekly basis, the Contractor shall keep on file one set of current
"conformed-to-construction records" (“as-built”) drawings, including vendor drawings as defined in Exhibit
[ ]. Such drawings shall be available to Owner for review in Contractor’s field office at all times. The
information contained in these drawings shall be incorporated into subsequent formally issued revisions
of these drawings. The information contained in these drawings shall be incorporated into the final
"conformed-to-construction records" drawings issued to Owner as a requirement for Final Completion.

Contractor shall designate a resident Construction Manager who will be responsible for the overall
management and administration of the plant construction effort. This shall include supervision and
execution of subcontracts, maintenance of safe working conditions, and ensuring that contract terms and
conditions are fulfilled, and that the installation is in accordance with plans and specifications.

Contractor will provide graded areas for Contractor’s use for Contractor personnel parking, construction
offices, and laydown as indicated on the Construction Facilities Dwg [ ]. Security fencing will also be
provided separating the Contractor’s designated area from any existing facilities and from the laydown
areas assigned to other contractors. Improvements to the assigned areas, such as trailer slabs,
aggregate surfacing, guard stations/badging facilities, and additional fencing within the assigned areas
shall be the responsibility of Contractor.

All temporary construction office facilities, furnishings, janitorial services and supplies for the Contractor’s
and subcontractor’s personnel shall be furnished by the Contractor. Power for the Contractor’s temporary
construction offices shall be extended from the construction power terminal point by the Contractor.
Construction (non-potable) water supply for the Contractor’s use will be provided by the Contractor and
extended as needed by the Contractor. Locations of the construction power and construction water
terminal points are depicted on the Construction Facilities Dwg [ ]. Potable water supply and sanitary
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1001 of 1056
24
facilities for the Contractor’s construction offices and work areas shall be furnished and maintained by
Contractor. Tie-in to any existing onsite potable water and sanitary system will not be allowed.
Contractor shall provide temporary office facilities for the Owner’s use.
A temporary heated and air-conditioned furnished office trailer shall be provided by the Contractor for use
by the technical field assistance personnel for Owner-supplied Materials and Equipment. In addition, a
temporary heated and air-conditioned furnished trailer shall be provided by the Contractor for use as a
dedicated training room. Contractor shall also provide furnishings and services for these trailers including
appropriate office furniture, copier/fax/scanning/printing machines, Internet connections, phones lines (2
voice and data lines per office), power, janitorial services, potable water and sanitary service, and
drinking water. Trailer and furnishings shall be new and unused unless otherwise approved by Owner.
All facilities must be installed, functionally tested, and permitted prior to occupying.

It is required that a schedule of specific services and their frequency for all Contractor-furnished office
trailers be included, covering, at minimum, the following.

Janitorial: Sweep floors each day of work using floor sweeping compound to control dust. All
bathrooms and plumbing fixtures to be cleaned and disinfected daily. All trash receptacles
emptied daily.

Security: Inspection, walk through, and daily door lock check at hours identified by Owner.

01100.6 Plant Startup and Commissioning
Plant commissioning is defined as all those activities, procedures, and tests required to start-up and bring
installed systems and equipment to a state of readiness for contract testing and subsequent Owner
acceptance and commercial operation. Plant commissioning shall include all prerequisite component and
system testing, cleaning, flushing, initial operation, mechanical testing, and electrical testing, including,
but not limited to:

Hydrostatic testing of piping and pressure vessels and leak testing of tanks
Equipment alignment checks
Balancing of rotating equipment, as required by equipment supplier technical service
representatives
Chemical cleaning, flushes, steam blows and air blows for components and systems, as
required
Lubrication checks
Inspection, stroking and adjustment of all manual valves, motor operated valves and
control valves, and setting of torque, limit, and position indicating switches
Setting of all relief and safety valves that are not factory certified
Testing of electrical equipment (e.g., transformers, circuit breakers, switchgear, motor
control centers, motors, batteries, chargers, inverters, etc.)
Testing and calibration of all instrumentation (e.g., meters, relays, gauges, transmitters,
switches, etc.) that are not factory calibrated
Testing and tuning of all analog and digital controls and control loops; verification of
indications, alarms, and annunciators in DCS or PLCs, as applicable; and establishment
of proper values for setpoints and alarm points
The simulator shall be used to train and verify DCS configurations prior to plant startup.
Verification of analog and digital interlocks and protective devices and schemes
Electrical wire and cable termination checks
Megger, continuity, and high potential tests (as applicable)

Plant commissioning shall be completed on a system-by-system basis in accordance with these
specifications and Exhibit [ ]. Appropriate documentation, referred to as System Turnover Packages,
verifying successful commissioning of systems and equipment shall be submitted to the Owner on a
system-by-system basis for review and approval prior to Performance Tests and Facility Capability
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1002 of 1056
25
Demonstration Tests. Turnover packages shall be available 60 days before the first scheduled turnover
for Owner review and comment. Turnover packages shall also be prepared for the buildings and
improvements such as fencing, landscaping, paving, etc.

The System Turnover Package shall contain all information and data relevant to the design, construction,
and commissioning of a system. The information shall be as a PDF and 3 hard copies contained in a
heavy duty three ring binder and organized in a consistent fashion for each system. System boundaries
shall be defined using project P&IDs and one-line drawings.

Each System Turnover Package shall contain a turnover control sheet. The turnover control sheet shall
have signature blocks which, when signed and dated, shall signify the formal transfer of lockout/tagout
control for a system from the construction manager to the commissioning manager and from the
commissioning manager to Owner.

Each System Turnover Package shall contain, as a minimum, the following items, if applicable for the
given system:

Table of Contents
List of all system components
Hydrostatic, pneumatic, and leak tests (procedures, acceptance criteria, and attested
results)
Piping system velocity flushes (procedures, flow paths, acceptance criteria, and attested
results)
Initial equipment alignment, lubrication, and adjustment
High potential and megger tests
Wiring integrity and continuity tests
Wire termination checks
Equipment and system commissioning data (pressures, temperatures, flow rates,
currents, voltages, vibration levels, etc.) including pump curves or other performance
graphs that indicate performance relative to the referenced design target or standard.
System P&IDs with system boundaries marked
System control wiring diagrams
Circuit verification records (loop checks), including verification from field device to control
system operator interface
System logic diagrams or applicable DCS system configuration printouts + logic
narratives
System defect/deficiency list/punch lists

Functional testing shall be in accordance with requirements indicated in Section [ ].

Plant commissioning and functional testing shall be conducted in accordance with a written plan to be
submitted to Owner for review not less than sixty (60) days prior to initial commissioning activities.

Contractor shall provide to Owner week-ahead and day-ahead schedules for any commissioning activities
that involve the delivery of electric power to the grid to allow Owner to coordinate such delivery with third
parties. Such schedules shall include reasonably accurate estimates of the quantity of electric energy to
be delivered on an hour-by-hour basis. Contractor shall promptly provide any revisions to such
schedules. Contractor shall cooperate with Owner in meeting any scheduling requirements of third
parties.

Contractor shall designate a resident commissioning manager who shall be responsible for implementing
the plant commissioning and functional testing program.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1003 of 1056
26
01100.6.1 Pre-Commissioning Walk Down
Contractor shall walk down turnover packages prior to commissioning. Contractor shall keep and
maintain a master Punch List, listing and prioritizing deficient items found during and after system walk
downs. The Owner shall be invited to participate in system walk downs and shall have the opportunity to
add Punch List items that must be completed prior to turnover to commissioning. Contractor shall
manage the completion of all Punch List items. Additional Punch List items identified during
commissioning and startup shall be added to the Punch List. The Owner may choose to add additional
items to the Contractor’s master Punch List by issuing such lists to the Contractor

01100.6.2 Post-Commissioning Walk Down
Contractor shall perform a final walk down after commissioning activities are completed. This walk down
shall include the Owner. Any additional Punch List items identified at this time will be added to the Punch
List.

01100.7 Equipment Expediting and Inspection Services
Contractor shall comply with expediting, inspection, testing, and quality control/assurance requirements
including submittals to the Owner as defined in this specification and within the Contractors quality
manual.
Contractor shall submit to the Owner a quality manual within 45 days after the Effective Date. The quality
manual shall outline the Contractor's quality assurance and quality control program. The quality manual
shall include a supplier quality surveillance matrix which shall include: description of Equipment and
Materials, frequency/number of visit(s), and description of activities scheduled for each visit. Contractor
shall follow procedures as outlined in the quality manual unless otherwise approved by the Owner in
writing.

The Owner shall have the right to perform shop inspections and witness testing as noted in the Contract.
The quality surveillance plan shall include advance notification to the Owner prior to trips to allow the
Owner to schedule an inspector if desired. The Owner reserves the right to inspect and witness the
following as a minimum:

Single-shaft turbine generators with accessories included in Attachment [ ] to this Scope of Work.

Steam turbine rotor and shells fabrication and testing.

HRSG pressure parts fabrication included in Attachment [ ] to this Scope of Work.

Condenser tubes and parts fabrication.

Boiler feed pumps, TCA cooler feed pumps, and condensate pumps performance tests.

Circulating water, closed cycle cooling water and auxiliary cooling water pumps performance
tests.

Lube oil pump performance tests.

Motor driven fire pump performance tests.

Fuel gas compressors performance tests.

Raw water pretreatment system skid assembly completion prior to shipment.

Cycle makeup treatment system skid assembly completion prior to shipment.

Sampling system and chemical feed systems skid assembly completion prior to shipment.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1004 of 1056
27
Condensate polisher system skid assembly completion prior to shipment.

DCS, Simulator, and Virtual Model factory acceptance test (FAT).

CEMS factory acceptance test included in Attachment [ ] and Attachment [ ] to this Scope of
Work.

Transformer factory tests

Prefabricated piping systems

Skid mounted systems

Electrical component tests

01100.8 Scheduling and Progress Reporting
Contractor shall plan, schedule, and report the progress of the Work using the critical path network
scheduling method. Contractor shall prepare and maintain a detailed project schedule using Primavera
Project Planner software, or equivalent software approved by Owner. The project schedule shall be
developed in consideration of the durations and interdependence of all activities of the Work, including
engineering, procurement, manufacturing, delivery, construction, startup, commissioning, and testing
activities. The project schedule shall be resource loaded with engineering and field man-hours and
construction commodity quantities. The project schedule shall identify the critical path (least float) chain
of activities.

Within 90 (ninety) days following award of the Contract, Contractor shall submit for Owner's review and
comments the project Level 3 schedule. The Contractor shall incorporate all reasonable comments
provided by the Owner. Thereafter, the project schedule shall be updated and submitted to Owner on a
monthly basis (or more frequently if necessary) reflecting actual progress for prior activities and its effects
on future activities. Each submittal of the project schedule shall be made in hard copy form and
electronic form (in the native format of the scheduling software), provided however, it may exclude
resource loading information.

The Level 3 schedule shall include the following minimum of detail. The detailed engineering and
procurement schedule shall support the construction and startup plan. It shall contain sufficient detail to
identify critical path engineering deliverables, equipment and material deliveries, material installation
items, and key construction sequences to support startup. This project schedule shall be based on the
standard logic showing the start and finish dates of all deliverables to be produced during the life of the
Project, including activities for constructability studies or reviews. Schedule activity details shall not
exceed 1 month in duration, except in those instances where the smallest logical division of the Work is
greater than 1 month (e.g., fabrication of long-lead equipment). The engineering and procurement
activities shall be connected to the construction and startup activities with suitable logic driven
relationships. Plan dates (also called target dates) shall be established for every activity in the form of a
base line schedule (plan/target date schedule). It shall contain construction and startup activities showing
the installation and commissioning of all discrete components of the Project.

Contractor shall prepare a weekly progress report to accurately describe the construction activities which
occurred during the most recently completed week. The report shall include, as a minimum, sections on
the following subjects:

Summary of major construction activities completed or commenced since the last weekly
progress report.
Summary of significant activities planned for the upcoming period
Total labor hours worked.
Total average daily number of personnel on site for the regular work week.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1005 of 1056
28
Installed quantities of materials such as concrete, pipe, wire, conduit, etc.
Equipment deliveries received since the last weekly progress report.
Equipment deliveries expected during the upcoming period.
Equipment in on site storage.

The weekly progress report shall be submitted to Owner by Tuesday of the week following the reporting
week.

Contractor shall prepare a monthly progress report to accurately describe the current status of the Project
in the main categories of engineering, procurement, construction, and commissioning. The report shall
begin with an executive summary and shall include, as a minimum, sections on the following subjects:

Summary of major engineering, procurement and construction/commissioning activities
completed since the last progress report
Summary of significant engineering, procurement and construction/commissioning
activities planned for the upcoming period
Procurement status including an aggregate list of purchase orders and contracts
executed, including date of execution
Expediting status including an aggregate list of equipment delivered to the site, including
date of delivery and acceptance by Contractor
Schedule analysis and overview, including the most current project schedule, milestones
met, milestones not met and reasons why, targeted milestones for the next month and
next ninety (90) Days, slipped dates, plan to recover slippages, etc.
Identification of any construction quality problems
Identification of any safety accidents and events
List of any problem areas and a plan for correction
Updated list of significant action items for Contractor and Owner
List of approved and pending Change Orders
Drawing list with current revisions and approval dates, as appropriate
Construction photos with captions
On site labor statistics including Contractor and Subcontractor craft man-hours, broken
down by craft
Status of Contractor permits.
Progress on Owner’s punch list items.
Equipment in on site storage.

The monthly progress report shall be submitted to the Owner by the fifth day of each month following the
reporting month.

Weekly and Monthly reports shall be submitted in a searchable electronic format acceptable to Owner.
The Construction schedule for these reports shall include searchable Gantt chart. The weekly report shall
be a level 4 report.

01100.9 Operator Training
The Contractor shall provide training for Owner’s engineering, maintenance, and operator personnel.
Such training will be conducted to familiarize operating and maintenance personnel with each of the
various operating systems, the major mechanical and electrical equipment, and the control systems.
Detailed requirements for training are found in Exhibit [ ] Applicable vendors shall provide training on
major systems and equipment. The OEM Contract includes training that shall be incorporated into the
Contractors training program.
.
As part of the training program, each member of the operating and maintenance staff will be provided with
copies of the P&ID’s, the electrical single-line diagram, the major equipment list, and the system
definitions, as outlined in Exhibit [ ]. The trainees will be expected to “walk down” each of the systems
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1006 of 1056
29
using these reference documents to establish the location and function of all equipment and major control
components in the Plant.

The classroom training will be conducted by knowledgeable instructors, subject to the Owner’s approval
and replacement at the Owner’s request, in in a formal classroom setting. The classroom training
sessions are intended to provide concentrated instruction in the design, capability, operation, inspection,
and control of the equipment and systems within the Plant
.
As a supplement to the classroom training, additional training will be accomplished in the form of “hands-
on” indoctrination during the commissioning of the Plant. As part of this phase of the training, the
operating and maintenance personnel will be expected to work with and provide assistance to the
Contractor during commissioning of the Plant. In this way, commissioning will become an extension of
their actual work.

The Contractor’s training program will assume that the trainees have some knowledge and experience
with the types of systems and equipment to be found in power plants. The program is not intended to
qualify operators having no prior knowledge and experience or training.

01100.10 Codes and Standards
The design and specification of Work shall be in accordance with applicable state and federal laws and
regulations, and local codes and ordinances. The codes and industry standards used for design,
fabrication, and construction are listed below and will be the editions in effect, including all addenda, at
the date of Contract, and as stated in equipment and construction purchase or contract documents.
Other recognized standards may also be used as design, fabrication, and construction guidelines when
not in conflict with the listed standards.

American Concrete Institute (ACI)
American Institute of Steel Construction (AISC)
American Iron and Steel Institute (AISI)
American National Standards Institute (ANSI)
American Petroleum Institute (API)
American Society of Civil Engineers (ASCE)
American Society of Heating, Refrigerating and Air-Conditioning Engineers (ASHRAE)
American Society of Mechanical Engineers (ASME)
American Society for Nondestructive Testing (ASNT)
American Society for Testing and Materials (ASTM)
American Water Works Association (AWWA)
American Welding Society (AWS)
National Board Inspection Code
Cooling Tower Institute (CTI)
Compressed Gas Association (CGA)
Concrete Reinforcing Steel Institute (CRSI)
FM Global Property Loss Prevention Data Sheets
Hydraulic Institute (HI)
Illuminating Engineering Society (IES)
Institute of Electrical and Electronics Engineers (IEEE)
International Society of Automation (ISA)
Insulated Cable Engineers Association (ICEA)
International Building Code (when no local codes prevail)
International Plumbing Code (when no local codes prevail)
National Association of Corrosion Engineers (NACE)
National Electrical Safety Code (NESC)
National Electric Code (NEC)
National Fire Protection Association (NFPA)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1007 of 1056
30
National Sanitation Foundation (NSF)
National Electrical Manufacturers Association (NEMA)
National Electrical Testing Association (NETA)
Occupational Safety and Health Administration (OSHA)
Steel Structures Painting Council (SSPC)
Local Administrative Code Rules [LATER]
Local Department of Transportation Standard Specifications [LATER]

01100.11 Division of Responsibility
The Division of Responsibility Matrix defining the Contractor's scope of supply and the Owner's scope of
supply is included below and supplements the responsibility definition provided throughout the Contract
Documents. If responsibility is not explicitly identified as Owner’s, it shall be assumed to be the
Contractor’s.
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Engineering design X
Architectural X
Conformed to Construction Record
drawings
X Refer to Article [ ] and [ ]
Design documentation, calculations,
analysis
X
Engineered equipment specifications X X(1) (1)For equipment supplied by Owner.
Engineered equipment purchase and
expediting services
X All equipment including Owner
furnished Equipment.
Manufacturers' service representatives
and technical field assistance (TFA)
X For equipment supplied by Owner.
Technical field assistance/service
personnel shall be managed by
Contractor.
Construction specifications X
Equipment, pipeline, valve, and
instrument lists
X Contractor shall include equipment
supplied by Owner in the project
equipment list.
Obtain spare parts recommendations and
pricing from equipment vendors
X X(1) (1)For equipment supplied by Owner.
Purchase operating and maintenance
spare parts
X
Startup and commissioning spare parts X(1)X(2) (1)Contractor is responsible for spare
parts during commissioning.
Contractor may borrow and replace
from Owner's operating and
maintenance spares inventory, if
available.
(2)Owner to purchase and supply for
Owner-supplied equipment.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1008 of 1056
31
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Engineering and construction QA and QC
programs
X
Site acquisition, land purchase,
easements, and rights-of-way
X (1)Contractor is responsible for any
easements, rights of way and other
requirements associated with the
transportation of Contractor and
Owner-furnished equipment.
Contractor is also responsible for any
lay-down space or equipment storage
needed beyond that available on the
Jobsite.
Construction Permits X Contractor shall be responsible for
obtaining and paying for any
necessary construction permits.
Site survey X
Geotechnical
Soil borings X
Soils reports X
Soils resistivity X
Interior furnishings X
Steam cleaning of all systems X
Inert gas blow cleaning of all systems X
Chemical cleaning of HRSG and other
systems
X

Disposal of chemical cleaning waste
during construction
X Neutralized wastes shall be hauled
offsite and disposed of by a licensed
chemical cleaning subcontractor.
Fuses, lamps, filters, gaskets, and other
similar consumables required for startup
X(1)X(2) (1) Contractor shall provide all startup
consumables for Contractor furnished
Equipment and Materials
(2) Owner shall provide all startup
consumables for Owner Furnished
Equipment
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1009 of 1056
32
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Fuel gas supply X Refer to Section [ ] for fuel gas
properties.
Contractor to supply fuel gas
regulating station and supply piping
downstream of defined terminal point.
Contractor shall be responsible for
fuel gas line inert gas blowing and all
associated costs. Contractor is
responsible for providing fuel gas
which meets the requirements of the
CTG Supplier’s fuel specifications
and quality.
Fuel gas metering X Contractor shall install Owner-
furnished gas turbine meter tubes
and individual gas meters to the
auxiliary boiler. Contractor shall
provide and install revenue quality
fuel gas meters. Contractor will
supply revenue metering furnished by
fuel gas supplier that will be located
in the fuel gas metering and pressure
control station.
Fuel gas regulation and filtration
downstream of the fuel gas metering and
pressure control station.
X Contractor shall provide all filtration,
odorization and regulation
downstream of the fuel gas metering
and pressure control station as
required by equipment Suppliers.
Fuel gas compression and fuel gas
heating system with piping and
equipment
X Required
Site preparation and earthwork design
and construction

X Contractor shall be responsible for all
final earthwork design and
construction. All excess materials
must be moved and stored in an
orderly matter to an area designated
by the Owner
Site clearing and grubbing X
Site Earthwork and final stabilization X
Supply of Equipment and Materials for a
complete operating Facility within the
limits of the defined terminal points of the
work scope
X Except for Owner-furnished
equipment.
All Construction Works X
All construction craft and supervision X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1010 of 1056
33
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Purchase of CTG, ST, HRSG, and
accessories
X Owner has purchased CTG, ST, and
HRSG for assignment to Contractor.
Permitting
Conditional Use Permit X Contractor shall apply for the
conditional use permit to begin
construction with [ ] County
Attachment [ ]. LATER
Air Permit X Contractor shall apply for the air
permit. A copy is included in
Attachment [ ]. LATER
Storm Water Construction General Permit
(SWPPP)
X Contractor implementation,
maintaining, and monitoring,
Attachment [ ]. LATER
FAA Notice of Construction or Alteration X Contractor construction cranes or
lifts, Attachment [ ]. LATER
Potable Water System (treatment and
distribution)
X Contractor shall obtain plan approvals
from the State of [ ] for potable water
treatment and distribution systems
Dredging Permit X Contractor shall obtain all necessary
permits from the US Army Corps of
Engineers and the State of [ ]
Wastewater Facility Construction Permit X Contractor will obtain permit for
construction of new evaporation
ponds, Attachment [ ]. LATER
Local Road Closure and Access
Management Permits
X
Fire Safety Approval X
Local Construction Dewater or
Hydrostatic Testing
X
Local Notification of Demolition X If necessary.
Local Building Permits X Contractor to apply for permit and
notify the Owner for waiver
application, if required.
County Demolition Permit X If contractor is removing materials
from site
Concrete batch plant construction and
operating permits
X If required and needed by the
Contractor
Any additional permits to complete the
Work
X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1011 of 1056
34
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Department of Homeland Security (DHS)
Chemical Facility Anti -Terrorism
Standards (CFATS)
X X TBD
Checkout, Startup, Testing, and
Training

Checkout/commissioning procedures X
Checkout and turnover
X(1)X(2)
(1) Performed by Contractor.
(2) Witnessed by Owner.
Mechanical/electrical/control checkout
of systems X(1)X(2)
(1) Performed by Contractor.
(2)Witnessed by Owner.
Set, check out, and test all electric
protective and metering devices
including protective relays, breaker trip
devices, motor control center trip and
overload devices and metering
X Witnessed by Owner.
Startup procedures X
Startup of systems and plant X(1)X(2) (1)Supervision and craft labor.
(2)Witnessed by Owner.
Training of plant operators during
startup and commissioning
X Refer to Exhibit [ ] for training
requirements
Steam blow, Inert gas blow, and
Chemical cleaning
X
Performance testing procedures X
Test equipment X
Plant operations during testing X(1)X(2)Startup through Final Completion.
(1)Supervision and craft labor
(2)Witnessed by Owner
Performance Test X(1)X(2) (1) Supervision and craft labor through
Final Completion
(2) Witnessed by Owner.
Emission compliance testing X X(1) (1) Witnessed by Owner.
Calibration of emissions monitoring
equipment
X Witnessed by Owner
Performance test report X Reviewed by Owner
Water analysis and monitoring X(1)X(2)Startup through Substantial
Completion acceptance
(1) Supervision and craft labor.
(2) Witnessed by Owner.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1012 of 1056
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Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Operator training and training manuals
(including Owner-furnished
equipment)
X
Operating manuals (including Owner-
furnished equipment)
X
Engineered equipment instruction
manuals (including Owner-furnished
equipment)
X
Detailed operating procedures X
Operation and maintenance personnel X
(1)X(2)(1)Contractor to be responsible for
operation and maintenance until
Commercial Operation Date (COD).
(2)After COD, Contractor may utilize
Owner operations and maintenance
personnel.
Witness of performance tests X
Witness certification of emissions
monitoring equipment
X
Permanent power, fuel, and water for
startup and testing
X(1) (1)Contractor is responsible for supply
of demineralized water during steam
blows.
Chemicals and lubrications until Final
Completion
X First fill lubricants
Construction Facilities, Utilities, And
Services

EPC Contractor Field Offices Includes facilities for Technical Field
Assistance personnel for Owner
supplied equipment
Field office structure X
Field office furniture X
Field office equipment X
Field office supplies X
Craft change facilities X
Fabrication shops X
Training Facilities X
Owner Field Offices X Includes Owner’s Engineer offices
Tools
Erection tools X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1013 of 1056
36
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Special erection tools X
Test equipment for erection, testing,
startup and operation
X
Equipment
Construction equipment X
Subcontractor construction elevator X
Project construction elevator X
Heavy lift equipment/cranes X
Communication
Construction Site Internet Connection X Contractor to arrange means for
communication.
Construction Site Internet distribution
for Contractor and Subcontractors
X
Communication equipment and
system wiring for Contractor and
Subcontractors
X
Telephone
Construction telephone service trunk
line
X
Construction telephone trunk line
connection to Contractor and
Subcontractor field offices
X
Contractor and Subcontractor's
telephone equipment and system
wiring
X
Compressed Air
Construction compressed air source X
Construction compressed air
distribution
X
Electrical Power
Construction power source X Contractor to supply temporary power
source.
Construction power source
maintenance
X
Construction power primary
distribution system
X
Construction power primary
distribution system maintenance
X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1014 of 1056
37
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Construction power Subcontractor's
distribution system
X
Construction power Subcontractor's
distribution system maintenance
X
Construction power Subcontractor's
energy usage payment
X X
Lighting
General areas temporary lighting and
maintenance
X Contractor to supply general area
lighting at laydown, construction
parking, equipment storage and
badging/turnstile areas along with
maintenance of same.
Subcontractor specific work area
temporary lighting and maintenance
X
General areas site lighting and
maintenance
X Contractor to supply general area
lighting of any existing Owner
facilities per drawings listed in
Attachment [ ]
Subcontractor areas site temporary
lighting and maintenance
X
Water - potable and non-potable
Construction water source X Contractor to supply service water
source for construction usage,
Contractor to connect and distribute.
Construction water primary distribution
system
X Contractor to provide connection
source. Contractor to distribute.
Construction water Subcontractor's
distribution and maintenance system
X
Construction water Subcontractor's
usage payment
X
Drinking water supply X Contractor to supply potable water
source for construction usage and
distribute.
Drinking water distribution X
Heat
Temporary heating facilities/system X
Heating energy usage payment X
Sanitary Facilities
Construction primary sanitary facilities
and maintenance
X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1015 of 1056
38
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Subcontractor's construction sanitary
facilities and maintenance
X
Access Roads
Primary access roads X
Contractor specific access roads and
maintenance
X
Primary access road maintenance X Contractor to maintain existing Owner
or any new roadways.
Primary access road dust control X Contractor is responsible for dust
control on the Project.
General Work related dust control X
Material Delivery Access Improvement
Refurbishment of any existing
roadways used for construction
X Contractor to grade, and stone as
part of Site Preparation construction
Contractor construction parking area X Contractor will provide sufficient area
for Contractor to develop construction
parking. Contractor to develop entry
roadway and parking lot
Construction parking area
maintenance
X
Access road and parking area snow
removal
X Contractor will provide for any
existing Owner or new roadways.
Storage Facilities
Onsite laydown space X Contractor shall obtain, maintain and
provide housekeeping.
Subcontractor storage area
maintenance
X
Construction material receiving and
warehousing facilities
X
Tool storage facilities X
Climate controlled storage facilities X
Construction equipment fueling
facilities
X
Permanent Site Fencing X Contractor is responsible for
installation of all new permanent plant
fencing.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1016 of 1056
39
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Temporary Site Fencing X Contractor is responsible for
installation and removal of all other
temporary site fencing necessary for
construction and any fencing and
gates to isolate construction from any
existing facilities.
Security
Overall site security X Contractor will provide manpower and
facilities to provide site perimeter and
ingress/egress security to general
plant boundary and any Owner
facilities.
EPC Contractor specific on-site and
off-site laydown areas security
X Contractor to provide coordinated
effort with subcontractors for
construction security of laydown
areas.
Overall site security badging system
and materials
X(1)X(2) (1)Contractor is responsible for
operation and maintenance of
coordinated single source security
badging system for all construction
employees.
(2)Owner is responsible for operation
and maintenance of security badging
system for any existing Owner
facilities.
EPC Contractor and Subcontractor
badging and materials
X
Medical Facilities
Onsite first aid/medical services X X Contractor to provide first aide and
medical services/facilities for its craft
and staff personnel. Owner will
provide first aide and medical
services/facilities for its OE and
permanent plant personnel.
Project emergency ambulance X Contractor will provide and coordinate
use of emergency personnel,
ambulance or medivac services.
Drug sampling/testing facilities X(1)X(2) (1)Contractor to provide drug
sampling/testing services and
facilities for construction related
activities.
(2)Owner will provide drug
sampling/testing services and
facilities for permanent plant and OE
personnel.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1017 of 1056
40
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Emergency Medi-Vac Area X Contractor to final lighting and
provision per FAA circulars and any
heli-pad for landing emergency
medical helicopter.
Fire Protection
Construction fire protection - fire
extinguishers
X
Construction fire protection - stand
pipe
X
Overall site fire brigade participation X
Construction fire water wagon X Contractor is responsible for fire
watches and firefighting equipment in
their work areas, obtaining service
contractor to provide fire-fighting
equipment necessary to extinguish
and coordinate with local emergency
fire response agencies.
Cleanup
General trash collection and disposal X
Subcontractor specific trash collection
and disposal
X
Field office janitorial service X
Concrete
Concrete source X
Onsite concrete batch plant X Contractor is responsible for
establishing and maintaining any
necessary source of redi-mix
concrete for the Project.
Concrete usage payment X
Concrete test facilities and testing X
Scaffolding
Scaffolding supply/erection X
Welding
Welder testing X
Welder test facilities X Contractor will develop, staff,
oversee, and manage weld test and
training facility for the Project.
Welding/cutting consumables X
Railroad
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1018 of 1056
41
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Existing railroad onsite X(1)X(2) (1)Contractor is responsible for any
rail improvements required prior to
use.
(2)Owner will provide access to any
Owner rail spur on site for Contractor
use.
Railroad siding install and
maintenance
X
Food Services
Allowed in parking lot X
Lunch facility X
Survey Datum Points
Basic horizontal and vertical control
points
X Contractor will provide state plane
coordinate and plant grid monuments
at the Facility for baseline reference.
Detail layout control points X
General Work-related survey layout X
Personnel Camp
Personnel camp facilities X Craft housing is the responsibility of
the Contractor
Facility utilities X
Personnel camp usage fee payment X
Misc. Services & Materials
Bolting materials between any
equipment or materials installed
X
Solvents and cleaning materials X
Supply and placement of grout and
grouting materials
X
Touchup paint X
Coating of HRSG Exterior and
associated structure
X
Supply lubricants for installed
equipment
X Contractor to supply lubricants and
fluids for first fill and startup activities.
Application of lubricants for installed
equipment
X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1019 of 1056
42
Division of Responsibility Matrix
Engineering, Procurement, and
Construction Items Contractor Owner Remarks
Initial charge of resins, gases,
chemicals, desiccants, lubricants, and
hydraulic fluids
X

Contractor to provide initial charge
and additional supplies for all
equipment, including that required for
Owner-furnished equipment through
Commercial Operation Date (COD).
Fluid levels shall be full at time of
turnover of care, custody and control
to Owner.
Maintenance of traffic X
Dewatering System
Main site dewatering system X
EPC Contractor and Subcontractor
direct Work-related dewatering
X
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1020 of 1056
Idaho Power 2026 All Source RFP
Exhibit M – Mutual Non-Disclosure Agreement

IPC NDA LGL 016 4/13/09 -1-DR
This MUTUAL NONDISCLOSURE & CONFIDENTIALITY AGREEMENT (the “Agreement”) is entered into to be effective as
of the day of , 20 (“Effective Date”) betweenIdaho Power Company (“IPC”) and (“ ”). IPC and
may also be referred to individually as a “Party” and collectively as the “Parties.”
BACKGROUND
The Parties desire to share certain confidential and proprietary information in order to discuss (the “Discussion”).
Each Party may receive or review certain confidential and proprietary information of the other Party as part of that
Discussion.
Some or all of the confidential and proprietary information shared between the Parties may contain non-public
information about IPC’s transmission or generation system that may be considered CEII (as defined below). IPC generally
does not make such information available, consistent with certain regulatory and security requirements.
IPC and have agreed to disclose such confidential and proprietary information to each other on the condition that
the information be retained in confidence according to the terms and subject to the conditions included in this Agreement.
AGREEMENT
In consideration of the mutual obligations and undertakings in this Agreement, the sufficiency of which is acknowledged,
the Parties agree as follows:
1. In this Agreement these words and phrases shall have the following meanings:
1.1. Confidential Information.
(a) All non-public, confidential, or proprietary information disclosed by the Provider to Recipient or its
Representatives, whether disclosed orally or disclosed or accessed in written, electronic or other form or
media, and whether or not marked, designated or otherwise identified as “confidential” (in such cases where
not so marked or designated, where it would reasonably be expected in the industry that such information
would be deemed confidential), which may include (i) All information concerning Provider’s and its
affiliates’, and their customers’, suppliers’, and other third parties’ past, present, and future business affairs,
including, without limitation, finances, customer information, supplier information, products, services,
organizational structure and internal practices, forecasts, sales and other financial results, records and
budgets, and business, marketing, development, sales and other commercial strategies; (ii) Provider's
unpatented inventions, ideas, methods and discoveries, trade secrets, know-how, unpublished patent
applications and other confidential intellectual property; (iii) All designs, specifications, documentation,
components, source code, object code, images, icons, audiovisual components and objects, schematics,
drawings, protocols, processes, and other visual depictions, in whole or in part, of any of the foregoing; (iv)
Any third-party confidential information included with, or incorporated in, any information provided by
Provider to Recipient or its Representatives; and (v) All notes, analyses, compilations, reports, forecasts,
studies, samples, data, statistics, summaries, interpretations and other materials prepared by or for
Recipient or its Representatives that contain, are based on, or otherwise reflect or are derived from, in whole
or in part, any of the foregoing; and
(b) All Critical Energy/Electric Infrastructure Information (“CEII”), as defined by the Code of Federal
Regulations, Title 18, Section 388. CEII includes both Critical Energy Infrastructure Information and Critical
Electric Infrastructure Information. As used in this Agreement, Critical Energy Infrastructure Information
means specific engineering, vulnerability, or detailed design information about proposed or existing critical
infrastructure that: (i) Contains detail about the production, generation, transportation, transmission, or
distribution of energy; (ii) Could be useful to a person planning an attack on critical infrastructure; (iii) Is
exempt from mandatory disclosure under the Freedom of Information Act, 5 U.S.C. 552; (iv) Does not simply
give the general location of the critical infrastructure.
As used in this Agreement, Critical Electric Infrastructure Information means information related to critical
electric infrastructure, or proposed critical electrical infrastructure, generated by or provided to the Federal
Energy Regulatory Commission (“FERC”) or other Federal agency other than classified national security
information, that is designated as critical electric infrastructure information by FERC or the Secretary of the
Department of Energy pursuant to section 215A(d) of the Federal Power Act. Exhibit No. 4
Case No. IPC-E-24-16
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Page 2 of 5
CEII includes but is not limited to: transmission conductor details, transmission structure design details,
planned or expected transmission outages critical to the power system, substation design details, control
center locations or design details, power plant facility design details, geographic coordinates more specific
than line routes and natural gas line locations or design details.
(c) Confidential Information shall not include Non-proprietary Information.
1.2. Non-proprietary Information. The information with respect to which the Recipient is able to establish:
(a) At the time of disclosure was or thereafter became generally available to the public, other than as a result of
any act or omission by the Recipient or its Representatives or anyone to whom the Recipient or Recipient’s
Representatives disclosed such information in violation of this Agreement;
(b) Was or became lawfully known to the Recipient or Recipient’s Representatives on a non-confidential basis
and not in contravention of any applicable law from a source (other than the Provider or Provider’s
Representative) that is entitled to disclose the information;
(c) Was already lawfully in the possession of the Recipient or Recipient’s Representatives at the time of the
information’s disclosure under this Agreement and that was not acquired, directly or indirectly, from the
Provider or Provider’s Representative, provided that, the information is not subject to another
confidentiality agreement or other obligation of secrecy;
(d) Information that the Recipient can demonstrate is independently developed by the Recipient or the
Recipient’s Representatives without the use or knowledge of any Confidential Information; and
(e) Information approved for disclosure or release by the Recipient by written authorization from the Provider;
and provided that, any combination of the information which comprises part of the Confidential Information
shall not be deemed to be Non-proprietary Information merely because individual parts of that information
were within the scope of the above clauses unless the combination itself was within the scope of any of the
above clauses.
1.3. Provider. The Party or its Representative who is providing information to the other Party or its Representatives
on behalf of the first-mentioned Party, being IPC or , as the context requires;
1.4. Recipient. The Party or its Representative that is receiving information from the other Party or its
Representatives on behalf of the first-mentioned Party, being IPC or , as the context requires;
1.5. Representatives. With respect to any Party or its affiliates, such Party’s or its affiliates’ directors, officers,
employees, shareholders, agents, subcontractors, attorneys, engineers, accountants, consultants, and financial
advisers of such Party; and
1.6. Review. The Recipient’s review of any Confidential Information the Provider supplies, directly or indirectly, to
the Recipient or to Recipient’s Representatives under this Agreement for the purposes of the Discussion.
2. -Disclosure.
The Recipient shall:
(a) Keep the Confidential Information in strict confidence and not use the Confidential Information for any
purpose whatsoever, directly or indirectly, other than for the purpose of conducting the Review;
(b) Disclose only such portions of the Confidential Information to its Representatives as is required for the
purpose of conducting the Review and only to those Representatives who have a need to know;
(c) Be liable for any breach of this Agreement by it or any of its Representatives; and
(d) Shall in the case of disclosure of Confidential Information to any of its Representatives, inform the
Representatives at the time of disclosure of the confidential and proprietary nature of the Confidential
Information; and shall direct its Representatives not to disclose without the prior written consent of the
Provider (i) Any opinion or comment in respect of the Confidential Information; (ii) Any terms, conditions
or any facts with respect to the Discussion or the contents of this Agreement; or (iii) Any Confidential
Information to any person other than in accordance with the terms of this Agreement.
3. . If Recipient or its Representatives becomes legally obligated to disclose
Confidential Information to any government entity with jurisdiction over it, such Recipient shall give the Provider Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1022 of 1056
LGL 016 (6/1/2020)
Page 3 of 5
prompt written notice sufficient to allow the Provider to seek a protective order or other appropriate remedy. The
Recipient shall disclose only such information as is required by the governmental entity and shall use its
commercially reasonable efforts to obtain confidential treatment for any Confidential Information that is disclosed.
4. Limited Relationship. Nothing in this Agreement constitutes or implies any partnership, joint venture or any other
formal or informal business relationship between the Parties or is to be construed as making one Party the agent or
fiduciary of the other with respect to the Discussion.
5.
5.1. The Recipient acknowledges that:
(a) The Confidential Information is proprietary to the Provider, and provided to the Recipient solely for the
purpose of the Review, the unauthorized disclosure of which could result in financial loss to the Provider
and would reasonably be expected to harm the competitive position or negotiating position of the Provider;
(b) The provision by the Provider of any Confidential Information to any other third party does not render such
Confidential Information as Non-proprietary Information;
(c) Without prejudice to the terms and conditions of any eventual agreement or agreements relating to the
Discussion (if any), neither the Provider nor the Provider’s Representatives make any representation or
warranty, express or implied, as to the accuracy or completeness of the Confidential Information; each
Provider represents and warrants to the respective Recipient that the Provider has the right and authority
to disclose the Confidential Information being disclosed by it hereunder;
(d) It will rely upon its own investigations, due diligence and analysis in evaluating and in satisfying itself as to
all matters relating to the Discussion;
(e) The Provider shall have no liability to the Recipient or any of Recipient’s Representatives resulting from any
use of the Confidential Information by the Recipient or any of its Representatives, except as expressly
provided in this Agreement; and
(f) No commitment or contract relating to the Discussion shall exist unless and until definitive agreements have
been executed and delivered by or on behalf of the Parties.
6. . At any time upon the written request of the Provider, and within five (5)
business days of the request, the Recipient shall either return all copies, whether in written, electronic or other form
or media, of the Confidential Information to the Provider or shall destroy and verify in writing its destruction of, any
and all copies or other reproductions or extracts thereof, together with such documents, memoranda, notes and other
writings whatsoever prepared by Recipient and its Representatives based on the Confidential Information provided
that failure to destroy or return electronic copies of materials or summaries containing or reflecting Confidential
Information that are automatically generated through data backup, archiving, and/or other similar systems shall not
be deemed to violate this Agreement, so long as the Confidential Information is not disclosed or used in violation of
the other terms of this Agreement.
For clarity, the Parties covenant and agree that neither Party acquires any intellectual property rights under this
Agreement.
7. . It is understood and agreed by the Recipient that any failure or delay by the Provider
in exercising any right, power or privilege under this Agreement shall not operate as a waiver thereof, nor shall any
single or partial exercise thereof preclude any other or future exercise of any right (equitable or otherwise), power
or privilege hereunder. All waivers must be in writing and signed by the waiving Party.
8. . This Agreement governs disclosures of Confidential
Information by the Parties for a period of three years from the Effective Date (“Disclosure Period”). Notwithstanding,
and regardless that the Confidential Information may have been returned or copies destroyed prior to the expiration
of the Disclosure Period, the obligations of confidentiality and nondisclosure imposed by this Agreement shall survive
any termination or expiration of the Disclosure Period and shall be in effect in perpetuity.
9. . The Recipient acknowledges that monetary damages may not be a sufficient remedy for a
breach of this Agreement by the Recipient or any of its Representatives and agrees that in addition to any other
remedy to which Provider or its affiliates may be entitled under this Agreement, at law or in equity, Provider shall be
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1023 of 1056
LGL 016 (6/1/2020)
Page 4 of 5
entitled to seek injunctive relief to prevent breaches of this Agreement and to specifically enforce the terms and
provisions hereof.
The Recipient agrees, to the extent allowed by law, to indemnify, defend, and hold harmless the Provider and its and
their successors and their respective officers, directors, agents, and employees, from, for, and against any and all
allegations, liabilities, suits, losses, damages, claims, actions, costs, and expenses of any nature, including court costs
and attorneys’ fees, related to the receiving Party breaching any term or condition of this Agreement.
10. Notices. Notices, where required herein, shall be deemed to have been duly served when (i) delivered in person, or
(ii) sent by mail or courier, return receipt requested, at the address for each Party as follows:
1221 W. Idaho St.
Boise, ID USA 83702
Attention:
(Address)
(Address)
Attention:
11. If any provision of this Agreement is determined by a court of competent jurisdiction to be wholly or
partially unenforceable for any reason, such unenforceability will not affect the enforceability of the balance of this
Agreement and all provisions of this Agreement shall, if alternative interpretations are applicable, be construed so as
to preserve the enforceability hereof.
12. This Agreement expresses the entire agreement between the Parties with
respect to the disclosure, delivery and use of the Confidential Information and supersedes and cancels all prior
communications, understandings and agreements between the Parties, whether written or oral, express or implied,
with respect to such subject matter. This Agreement may not be modified except by a writing duly signed by both
Parties.
13. This Agreement shall be governed by and construed in accordance with the laws of the State of
Idaho without giving effect to the choice of law rules thereof, and may be executed in several counterparts. The
exclusive venue of any action shall be Ada County, Idaho.
14. . Unless agreed upon in writing by the Provider, neither Party intends to waive, nor cause
any of its Representatives to waive, the attorney-client, attorney work product, or other applicable privilege of the
Provider or any of its subsidiaries, affiliates, or joint ventures (“Privilege”) by providing any information subject to a
Privilege. Accordingly, each Party agrees that a production to any Recipient or any of its Representatives by the
Provider or any of its Representatives of Confidential Information protected by a Privilege shall not constitute a
waiver of any such Privilege by any person, and each Party hereto agrees that, upon request by the Provider or any
of its Representatives, Recipient will, and will cause its Representatives to, immediately return and/or destroy such
inadvertently produced information.
15. Neither Party may assign all or any part of this Agreement, by operation of law or otherwise, without
the other Party’s prior written consent, which consent shall not be unreasonably withheld or denied. This Agreement
shall be binding on and inure to the benefit of each Party’s successors and assigns.
16. In the event that Provider institutes any legal suit, action or proceeding, against Recipient to enforce
the covenants contained in this Agreement, Provider shall be entitled to receive in addition to all other damages to
which it may be entitled, the costs incurred by Provider in conducting the suit, action or proceeding, including
reasonable and actual attorneys' fees and expenses and court costs.
llows)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1024 of 1056
LGL 016 (6/1/2020)
Page 5 of 5
to be effective as of the Effective Date.
By:
Name:
Title:
By:
Name:
Title:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1025 of 1056
Idaho Power 2026 All Source RFP
Exhibit N – Counterparty Financial Questionnaire
Please provide the following information with your proposal to enable Idaho Power (IPC) to evaluate the financial
viability of the Respondent and any entity(ies) providing credit assurances on behalf of the Respondent, if
applicable.
Respondent’s Credit Information
1. Credit information for Respondent
a. Exact legal name and address of Respondent.
b. Attach copies of three years audited financial statements (including balance sheet, income
statement, notes and cash flow statement) for the three most recent fiscal years.
c. If Respondent is unable to provide audited financial statements or is relying upon another
entity(ies) to provide credit assurances on its behalf, Respondent must indicate so here and
complete the following section.
i. Is Respondent unable to provide audited financial statements?
ii. Is Respondent relying upon another entity(ies) to provide credit assurances on
Respondent’s behalf?
d. If available, provide Debt Ratings from S&P and/or Moody’s (please provide senior unsecured long-
term debt rating (or corporate rating if a debt rating is unavailable). Please indicate type of rating,
rating, and source.
e. Identify pending legal disputes (describe). Please provide contact name, phone number and e-mail
address that can assist with answering questions.
f. State whether Respondent is or has within the past five (5) years been the debtor in any
bankruptcy proceeding.
g. Respondent should demonstrate its ability and/or the ability of its credit support provider to
provide the required security equal to the value of the contract price set forth in the proposal,
including its plan for doing so including type of security, sources of security, and a description of
its credit support provider.
h. Respondent should provide a reasonable demonstration of its ability to finance the proposed
project based on past experience and a sound financial plan identifying the proposed sources for
debt and equity and evidence that the project is financeable.

2. Credit information for entity(ies) providing credit assurances on behalf of Respondent, if applicable (e.g.
parent company, or financial institution)
a. Exact legal name and address of entity(ies) providing credit assurances on behalf of Respondent.
b. Describe relationship to Respondent and describe type of credit assurances to be provided (e.g.,
parental guaranty, cash deposit, or a letter of credit from a qualified financial institution). Qualified
Institution shall mean the United States office of a commercial bank or trust company organized
under the laws of the United States of America or a political subdivision thereof or a foreign bank
with a branch office located in the United States and, in either case, whose rating with respect to
its long term unsecured, unsubordinated indebtedness, is rated at least A by S&P and A2 by
Moody's. Respondent must provide to IPC from the entity(ies) providing the credit assurances on
behalf of the Respondent executed by an authorized signatory and indicating their form of credit
assurances it will provide. It should be noted that more than one commitment letter, or more than
one form of commitment letter, may be necessary.
c. Debt Ratings from S&P and/or Moody’s (please provide senior unsecured long-term debt rating
(or corporate rating if a senior unsecured long-term debt rating is unavailable). Please indicate
type of rating, rating, and source:
d. Attach copies of audited financial statements (including balance sheet, income statement, and
cash flow statement) for the three most recent fiscal years for parent companies, as applicable.
e. Describe any pending or threatened legal disputes or claims for parent companies, as applicable.
f. State whether entity(ies) providing credit assurances on behalf of the Respondent is or has within
the past five (5) years been the debtor in any bankruptcy proceeding.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1026 of 1056
Idaho Power 2026 All Source RFP
Exhibit N – Counterparty Financial Questionnaire
Credit Requirements
The Respondent may be required to post credit assurances equal to the value of the contract price set forth in the
proposal which is expected to have a commercial operation date of no later than June 1, 2026. IPC will require a
letter from the entity providing financial assurances at the proposal submittal stating that it will provide financial
assurances on behalf of the Respondent.
If necessary, the Respondent will be required to demonstrate the ability to post any required credit assurances in
the form of a commitment letter from a proposed guarantor or from a financial institution that would be issuing a
Letter of Credit. IPC will require each Respondent to provide an acceptable commitment letter(s), if applicable,
twenty (20) business days after the Respondent is notified that the Respondent has been selected for the Initial
Shortlist. Respondent will be required to provide any necessary guaranty commitment letter from the entity(ies)
providing guaranty credit assurances on behalf of the Respondent and/or any necessary letter of credit commitment
letter from the financial institution providing credit assurances in the form of a Letter of Credit. Forms of
commitment letters are part of this Exhibit N. The timing of when credit security must be posted is detailed in the
Credit Security Requirements Methodology section, which is also part of this Exhibit N.
IPC must approve the amount, substance and issuer of all provided credit assurance.
Amount of Credit Assurances to be Posted
The RFP selected resources have the potential to expose IPC and its ratepayers to credit risk in the event a selected
Respondent is unable to fulfill its obligations pursuant to the terms of an executed agreement. The credit risk profile
is a function of several factors:

1. Type of resource agreement.
2. Size of resource.
3. Expected energy delivery start date.
4. Term of underlying contract.
5. Creditworthiness of Respondent and Respondent’s credit support provider, if applicable.

Should the financial institution providing credit assurances on behalf of the Respondent fail to meet these minimum
requirements of a qualified institution IPC will require credit assurances from a replacement financial institution that
does meet the requirements.
Build Transfer Agreement
For all resources that involve a physical asset with appropriate step-in rights, IPC views potential credit
exposure as the cost it would incur in the event the resource failed to reach commercial operation by June
1, 2026 or the Bidder failed to fulfill its obligations at any time during the life of the contract. If the failure
occurred near the expected commercial operation date, IPC would also potentially have to procure energy,
capacity and other environmental attributes associated with the energy in the open market at then-
prevailing market prices. IPC has determined the amount of credit assurances required for these types of
transactions to be up to 100% of the purchase price, based upon nameplate project size. The credit
assurance requirement will be terminated upon the project achieving commercial operation date with
proven tax credit eligibility of the appropriate resource technology.

The above descriptions of IPC’s potential credit exposures are not in any way intended to limit Respondent’s liability
with respect to obligations under any contract entered into with IPC, including without limitation, attorney’s fees or
other damages incurred by IPC in the event of a breach of contract by Respondent.

IPC will also explore with a Respondent, if selected, other commercial avenues to reduce security requirements, such
as, but not limited to, reduction in security amounts as project development milestones are met, a stipulated
acceleration of commercial operation date(s) (i.e., prior to June 1, 2026) or IPC’s review of Respondent’s underlying
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1027 of 1056
Idaho Power 2026 All Source RFP
Exhibit N – Counterparty Financial Questionnaire
third-party contractual terms, provisions and/or incentives that further support Respondent achieving commercial
operations prior to June 1, 2026.

Posting of Credit Security
Terms and conditions for the posting of security are set forth in the applicable Exhibit H - Draft Agreements for
Resource Based Bids which as noted above can be negotiated relative to milestones and amounts. If applicable, the
Respondent will be required to demonstrate the ability to post any required credit assurances in the form of a
commitment letter from a proposed guarantor or from a financial institution that would be issuing a Letter of Credit.
Forms of commitment letters are a part of this Exhibit N.

Idaho Power Company’s Security
Please note that IPC will not post security to support its obligations under any definitive agreement. Respondents
who will require such security from IPC should not submit a proposal in response to this RFP.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1028 of 1056
Idaho Power 2026 All Source RFP
Exhibit N – Counterparty Financial Questionnaire
FORM OF GUARANTY COMMITMENT LETTER

(Must be on letterhead of Respondent’s guarantor)

Idaho Power (IPC)
1221 W. Idaho Street
Boise, ID 8370s
Attn: Credit Department
Email: [e-mail]
To Whom It May Concern:

[NAME OF GUARANTOR] (“Guarantor”) is [INSERT RELATIONSHIP TO RESPONDENT] (“Respondent”).

In connection with Respondent’s submittal in Idaho Power (IPC)’s 2026 All Source Request for Proposals (RFP) for
Peak Capacity and Energy Resources, this commitment letter contains Guarantor’s assurance to Idaho Power (IPC)
that, should Idaho Power (IPC) enter into a transaction with Respondent arising out of any proposal submitted by
Respondent in the RFP, with terms and conditions mutually acceptable to Idaho Power (IPC) and Respondent,
Guarantor will at that time issue an unconditional guaranty in form and substance reasonably satisfactory to Idaho
Power (IPC), and that Guarantor will guarantee all obligations of payment and performance of Respondent to Idaho
Power (IPC) as Guarantor’s independent obligation (up to a maximum amount of $______, plus expenses of
enforcing the guaranty).

Guarantor understands that Idaho Power (IPC) will not enter into a transaction with Respondent without said
guaranty. Guarantor further understands that Idaho Power (IPC) is under no obligation to enter into any transaction
with Respondent, under the RFP or otherwise.

Yours truly,

(name of committing guarantor)
(name and title of authorized officer)

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1029 of 1056
Idaho Power 2026 All Source RFP
Exhibit N – Counterparty Financial Questionnaire
FORM OF LETTER OF CREDIT COMMITMENT LETTER

(Must be on letterhead of entity(ies) providing the letter of credit on behalf of the Respondent)

Idaho Power (IPC)
1221 W. Idaho Street
Boise, ID 83702
Attn: Credit Department
Email: [e-mail]
To Whom It May Concern:

In connection with Respondent’s submittal in Idaho Power (IPC)’s 2026 All Source Request for Proposals (RFP) for
Peak Capacity and Energy Resources, this commitment letter contains [ISSUING BANK]’s assurance to Idaho Power
(IPC) that, should Idaho Power (IPC) enter into a transaction with Respondent arising out of any proposal submitted
by Respondent in the RFP, with terms and conditions mutually acceptable to Idaho Power (IPC) and Respondent,
[ISSUING BANK] will at that time issue an irrevocable standby letter of credit in form and substance reasonably
satisfactory to Idaho Power (IPC), up to a maximum amount of $______.

[ISSUING BANK] understands that Idaho Power (IPC) will not enter into a transaction with Respondent without said
letter of credit. [ISSUING BANK] further understands that Idaho Power (IPC) is under no obligation to enter into any
transaction with Respondent, under the RFP or otherwise.

Yours truly,

(name of entity(ies) providing the letter of credit)
(name of authorized officer)

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1030 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
IRREVOCABLE STANDBY LETTER OF CREDIT No.
Date:
BENEFICIARY:
Idaho Power Company
1221 W. Idaho Street
Boise, Idaho 83702
Attention: Corporate Treasurer

APPLICANT:
PROJECT NAME
________________
________________
Attention: ________________

Ladies and Gentlemen:
[BANK], [ADDRESS] (the “Bank”) hereby establishes this Irrevocable Standby Letter of Credit (this
“Letter of Credit”) in favor of Idaho Power Company, an Idaho corporation (the “Beneficiary”), for the
account of [APPLICANT], a [STATE OF ORGANIZATION AND FORM OF ENTITY] (the
“Applicant”), in the amount of US$_______________.00 (______________________ United States
Dollars and 00/100 only) (the “Available Amount”), effective immediately and expiring at 5:00 p.m. New
York time on ___________, 20__, or, if such day is not a Business Day (as hereinafter defined), on the next
preceding Business Day (the “Expiration Date”).
For the purposes hereof, the term “Business Day” shall mean any day, other than a Saturday or Sunday, on
which commercial banks are not authorized or required to be closed in the City of New York, New York.
Subject to the terms and conditions herein, funds under this Letter of Credit are available to the Beneficiary
by presentation of the following documents at [BANK], [ADDRESS], ATTENTION:
___________________, on or prior to 5:00 p.m. New York time on any Business Day, on or prior to the
Expiration Date:
1.The original of this Letter of Credit and all amendments thereto for endorsement thereto (or
photocopies of the originals for partial drawings or for facsimile transmittals); and

2. The Drawing Certificate duly dated and issued in substantially the form of Attachment A attached
hereto, duly completed and purportedly bearing the signature of an officer of the Beneficiary.

Notwithstanding the foregoing, any drawing hereunder may be requested by transmitting the requisite
documents as described above to the Bank by facsimile at (___) ___-____ to the attention of the [BANK
DEPARTMENT]. Any claims made by facsimile must be confirmed by such person as shall be specified
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1031 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
from time-to-time by the Bank. The facsimile transmittal shall be deemed received when confirmed to
Bank by telephone at (___) ___-____. Drawings made by facsimile transmittal are deemed to be the actual
presentation without the need of original signed documents.
In the event of any non-conforming presentation, we shall immediately notify Beneficiary in writing by
facsimile to (___) ___-____ that the presentation has been rejected, which notice shall indicate the reason
for dishonoring such presentation and shall place at the disposal of beneficiary the documents presented by
Beneficiary in support of its demand for payment. Beneficiary may thereafter present documents and
receive payment hereunder in the event a conforming presentation is made in accordance with the terms
herein.
Partial drawing of funds shall be permitted under this Letter of Credit, and this Letter of Credit shall remain
in full force and effect with respect to any continuing balance; provided, that the Available Amount shall
be reduced by the amount of each such drawing.
This Letter of Credit is not transferable or assignable. Any purported transfer or assignment shall be null
and void and of no force or effect.
Banking charges and all other costs and fees associated with this Letter of Credit shall be the sole
responsibility of the Applicant.
This Letter of Credit sets forth in full our obligations and such obligations shall not in any way be modified,
amended, amplified, or limited by reference to any documents, instruments, or agreements referred to
herein, except only the attachment referred to herein; and any such reference shall not be deemed to
incorporate by reference any document, instrument, or agreement except for such attachment.
The Bank engages with the Beneficiary that Beneficiary’s drafts drawn under and in compliance with the
terms of this Letter of Credit will be duly honored if presented to the Bank on or before the Expiration Date.
Except so far as otherwise stated herein, this Letter of Credit is subject to the International Standby Practices
ISP 98 (also known as ICC Publication No. 590), or revision currently in effect (the “ISP”), and as to
matters not covered by the ISP, the laws of the State of Idaho (without regard to the principles of conflicts
of laws thereunder).
[BANK]

By:_________________________________
Name:
Title:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1032 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
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ATTACHMENT A
FORM OF DRAWING CERTIFICATE
To:
[BANK]
________________
________________
________________
Attn: _____________________

Subject: Irrevocable Standby Letter of Credit No.
The undersigned __________________, an authorized representative of Idaho Power Company, an Idaho
corporation (the “Beneficiary”), hereby certifies to [BANK] (the “Bank”), with reference to Irrevocable
Standby Letter of Credit No. __________, dated ___________, 20__ (the “Letter of Credit”), issued by the
Bank in favor of the Beneficiary, as follows as of the date hereof:
1. The Beneficiary is entitled to draw under the Letter of Credit an amount equal to
$________________, pursuant to the terms of that certain [NAME OF AGREEMENT] between
__________________ and Beneficiary, dated as of ___________, 20__.
2. Based upon the foregoing, the Beneficiary hereby makes demand under the Letter of Credit for
payment of XXX AND XX/100 Dollars ($_____________), which amount does not exceed (i) the
amount set forth in paragraph 1 above, and (ii) the Available Amount under the Letter of Credit as
of the date hereof.
3. Funds paid pursuant to the provisions of the Letter of Credit shall be wire transferred to the
Beneficiary in accordance with the following instructions:
______________________________________________________________________________
______________________________________________________________________________
____________________________________________________________

Unless otherwise provided herein, capitalized terms which are used and not defined herein shall have the
meaning given each such term in the Letter of Credit.
IN WITNESS WHEREOF, this Certificate has been duly executed and delivered on behalf of the
Beneficiary by its authorized representative as of this ___ day of _____________, 20__.

IDAHO POWER COMPANY

By:_________________________________
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1033 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
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Name:
Title:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1034 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
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PARENT GUARANTY OF PAYMENT
THIS GUARANTY (the “Guaranty”) is made as of the day of , 20 (the
“Effective Date”) by , , a formed under the laws of the State of
(“Guarantor”) to and in favor of Idaho Power Company, a corporation formed under the laws of
the State of Idaho (the “Beneficiary”).
RECITALS:
A. , , a formed under the laws of the State of (“Obligor”), a wholly-owned
subsidiary of Guarantor, and the Beneficiary entered into that certain [insert contract name, i.e. PPA] made
the day of , 20 (which agreement, as amended from time to time after the Effective Date, is
herein referred to as the “[insert contract name, i.e. PPA]”) pursuant to which, inter alia, Obligor agreed to
provide to the Beneficiary for a [insert project generation] project to be constructed in (the
“Project”).
B. Guarantor has agreed to guarantee to the Beneficiary the proper performance, payment and discharge
of Obligor’s Obligations (as defined in Section 1 hereof) by Guarantor.
C. Unless otherwise defined herein, all words and phrases used herein which are defined in the [insert
contract name, i.e. PPA] shall, for the purposes hereof, have the same meanings as are respectively given
thereto in the [insert contract name, i.e. PPA].
IN CONSIDERATION OF the Beneficiary entering into the [insert contract name, i.e. PPA]
and other good and valuable consideration, the receipt and sufficiency of which is hereby
acknowledged by Guarantor, and intending to be legally bound hereby, Guarantor covenants to,
and agrees with, the Beneficiary as follows:
1.Guaranty. Guarantor hereby absolutely, unconditionally and irrevocably guarantees to the
Beneficiary and its successors and permitted assigns, the due, punctual and complete performance, payment
and discharge by Obligor of each and all of the performance, payment, indemnification and other
obligations and liabilities of any and every nature and kind whatsoever, whether now in existence or
hereafter arising, on the part of Obligor arising under the [insert contract name, i.e. PPA] or otherwise in
relation to the transactions therein provided for (collectively, the “Obligor’s Obligations”).
2.Absolute Liability of Guarantor. The obligations of Guarantor hereunder are absolute, primary,
direct and independent obligations and are not subject to any right of set-off, recoupment or counterclaim
as against the Beneficiary. The Beneficiary is not required to exhaust its recourse against Obligor, or any
other Person, or any security it may hold, or to take any other action before being entitled to demand, by
written notice, payment or performance of Obligor’s Obligations from Guarantor.
3.Payment; Currency. All sums payable by Guarantor hereunder shall be made in freely transferable
and immediately available funds and shall be made in the currency in which Obligor’s Obligations were
due. If Obligor fails or refuses to pay any Obligor’s Obligations when due and owing, Beneficiary may
make a demand upon Guarantor (hereinafter referred to as a “Payment Demand”). A Payment Demand
shall be in writing and shall specify in what manner and what amount Obligor has failed to pay and an
explanation of why such payment is due and owing, with a specific statement that Beneficiary is calling
upon Guarantor to pay under this Guarantee. A Payment Demand satisfying the foregoing requirements
shall be deemed sufficient notice to Guarantor that it must pay such amount and such payment shall be
made to Beneficiary by Guarantor within three business (3) days after receipt of such Payment Demand. A
single written Payment Demand shall be effective as to any specific default under the [insert contract name,
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1035 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
i.e. PPA] that is capable of being cured by the payment of money during the continuance of such default
and additional written demands concerning such default shall not be required until such default is cured.
Beneficiary shall promptly return to Guarantor any amount paid by Guarantor if and to the extent a court
of competent jurisdiction (upon final appear thereof, if any) shall have determined that such Obligor’s
Obligation was not payable by Guarantor.
4.No Release of Guarantor.Guarantor has no right either to terminate this Guaranty or to be released
or discharged from its obligations hereunder, which obligations shall not be affected, released nor
diminished for any reason whatsoever including:
(a)any release or discharge, in whole or in part, of Obligor’s Obligations or any amendment or
supplement to or any modification of, assignment or termination, in whole or in part, the [insert
contract name, i.e. PPA];
(b)any extension or renewals of Obligor’s Obligations or any change in the time, manner or place of
payment or performance of Obligor’s Obligations or any course of dealing by the Beneficiary with
Obligor (including accepting any compromises from Obligor);
(c)the occurrence of any event of default by Obligor under the [insert contract name, i.e. PPA] or
otherwise in relation to Obligor’s Obligations;
(d)any taking (or any abstaining from taking) of any security or guarantee for the performance of
Obligor’s Obligations, in whole or in part, or the perfecting (or the failing to perfect) any such
security;
(e)any exchange, surrender, substitution, loss or release of, or other dealing with, any security or
guarantee from time to time held by the Beneficiary for the performance of all or any part of Obligor’s
Obligations;
(f)any waiver, consent or other action or inaction or any exercise or non-exercise of any right, remedy
or power with respect to Obligor’s Obligations;
(g)any merger, amalgamation or consolidation of Obligor into or with any other Person or any change
in the corporate existence, financial condition, constitution, name, structure, business, control or
ownership of Obligor;
(h)any bankruptcy, winding-up, liquidation, dissolution, insolvency, reorganization or other similar
proceeding affecting Obligor or its assets or any release, stay or discharge of any Obligor’s
Obligations resulting therefrom;
(i) any invalidity, illegality, irregularity or unenforceability for any reason of the [insert contract name,
i.e. PPA], Obligor’s Obligations or any part thereof as regards Obligor;
(j) any provision of applicable Laws purporting to prohibit the payment by Obligor or Guarantor of any
amount payable by Obligor in connection with Obligor’s Obligations;
(k)any force majeure (other than a force majeure which, pursuant to the [insert contract name, i.e. PPA],
relieves Obligor of liability for the performance of any Obligor’s Obligations);
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1036 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
(l)any lack or limitation of power, incapacity or disability on the part of Obligor to enter into the [insert
contract name, i.e. PPA] or of its directors, partners or agents or any other irregularity, defect or
informality on the part of Obligor in relation to Obligor’s Obligations; and
(m)any other Laws or other circumstances or matters that might otherwise constitute a legal or equitable
discharge or release of a surety or guarantor.
5.Waiver of Notice & Defences. Guarantor hereby waives: (a) diligence, presentment, protest, demand
for payment, notice of dishonour or non-payment, notice of acceptance of this Guaranty and any other
notice not expressly granted to Guarantor by this Guaranty; and (b) all defences (legal or equitable) which,
if asserted, would diminish the liability of Guarantor under this Guaranty.
6.No Subrogation against Obligor. Until all obligations of Guarantor under this Guaranty are
discharged: (a) Guarantor shall not assert against Obligor any claim that Guarantor now has or may
hereafter have against Obligor in connection with this Guaranty or the performance by Guarantor of its
obligations hereunder (provided that, Guarantor may assert any such claim if required due to the imminent
expiry of an applicable limitation period or otherwise to preserve such claim but only to the extent required
to preserve such claim); (b) the Beneficiary shall not be subrogated to any of Guarantor’s rights in Obligor’s
Obligations; and (c) Guarantor agrees that it shall not exercise any rights of subrogation, reimbursement,
contribution or indemnity from Obligor with respect to this Guaranty to the extent the exercise of such
rights would be reasonably likely to impair the ability of Obligor to perform Obligor’s Obligations.
7.Continuing Guaranty. This Guaranty is a continuing guarantee and, in the case of each of Obligor’s
Obligations requiring the payment of monies, this Guaranty applies to and secures any ultimate balance due
or remaining due to the Beneficiary; and if, at any time, all or any part of any monies paid previously
applied by the Beneficiary to any Obligor Obligation is or must be rescinded or returned by the Beneficiary
for any reason whatsoever, such Obligor Obligation will, for the purposes hereof, to the extent such payment
is or must be rescinded or returned, be deemed to have continued in existence and this Guaranty shall
continue to be effective or be reinstated, as applicable, to such Obligor Obligation as if such application
had not been made.
8.Recovery Limitation under [insert contract name, i.e. PPA]. Notwithstanding any other provision
of this Guaranty all limitations of liability (including requirements to file notice of claims prior to certain
specified dates in order to permit the same to be proceeded with) in favour of Obligor contained in the
[insert contract name, i.e. PPA] shall apply equally to the liability of Guarantor under this Guaranty such
that the Beneficiary shall not be entitled to claim any liability against (or to receive any recovery from)
Guarantor in excess of that which the Beneficiary would have been entitled to recover from Obligor, in the
aggregate, under the [insert contract name, i.e. PPA]. For purposes of clarity, the guaranteed obligations
include to Obligor’s Obligations as set forth in Section 1, together with all reasonable costs and expenses
(including attorney’s fees), if any, incurred by Beneficiary in enforcing its rights under this Guaranty and
under the [insert contract name, i.e. PPA].
9.Entire Guaranty and No Representations. This Guaranty constitutes the entire agreement between
the Beneficiary and Guarantor with respect to the guarantee by Guarantor of Obligor’s Obligations herein
provided for and cancels and supersedes any prior understandings and agreements with respect thereto.
There are no representations, warranties, terms, conditions, undertakings or collateral agreements,
expressed, implied or statutory, regarding the guarantee by Guarantor of Obligor’s Obligations herein
provided for other than as expressly stated and set forth in this Guaranty.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1037 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
10.No Assignment.Neither Guarantor nor the Beneficiary may assign its interest in this Guaranty or any
of its rights and obligations hereunder without the prior written consent of the other, and, subject to the
foregoing, this Guaranty enures to the benefit of, and is binding upon, Guarantor and the Beneficiary and
their respective successors and permitted assigns; provided, however, that Beneficiary may assign its
interest in this Guaranty, or any of its rights and obligations hereunder, to any Person that Beneficiary has
the right to make an assignment to pursuant to the terms of the [insert contract name, i.e. PPA].
11.Governing Law. This Guaranty shall be governed by and construed in accordance with the laws of
the State of New York (without reference to conflict of laws rules). THE GUARANTOR AND
BENEFICIARY IRREVOCABLY WAIVE ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY
LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS GUARANTY OR THE
TRANSACTIONS CONTEMPLATED BY THIS GUARANTY.
12.Notices.All notices sought or required to be given hereunder shall be in writing and shall be
effectively given or made if delivered personally, sent by prepaid courier service, sent by
registered/certified mail (postage fully prepaid) or sent by facsimile (with transmission confirmed), in each
case to the applicable address and/or facsimile number set out below:
If to the Beneficiary:
Idaho Power Company
Attn: Legal Department
1221 W. Idaho Street
Boise, ID 83702

If to Guarantor:

or at such other address and/or facsimile number as may be given by Guarantor or the Beneficiary to the
other by notice in writing from time to time and such notices shall be deemed to have been received, if
delivered personally or by prepaid courier service, upon delivery, if transmitted by facsimile on or prior to
5:00 p.m. (New York, New York local time) on a Business Day, upon the completion of its transmission
(and if not transmitted on a Business Day or transmitted after 5:00 p.m. (New York, New York local time)
on a Business Day, then on the first Business Day following the completion of the transmission) or, if sent
by registered/certified mail, four Business Days following the day of the mailing thereof; provided that if
any such notice shall have been mailed and if regular mail service shall be interrupted by strikes or other
irregularities, such notice shall be deemed to have been received four Business Days following the
resumption of normal mail service.
13.Payment of Legal Expenses. Guarantor shall reimburse the Beneficiary for all attorney’s fees,
disbursements and other expenses reasonably incurred by the Beneficiary in enforcing the payment,
performance or discharge of Obligor’s Obligations and the obligations of Guarantor hereunder.
14.Severability. If any provision of this Guaranty is determined to be invalid or unenforceable in whole
or in part, such invalidity or unenforceability will apply only to that provision and all other provisions of
this Guaranty shall continue in full force.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1038 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
15.No Waiver, Remedies.No failure on the part of the Beneficiary to exercise, and no delay in
exercising, any right under this Guaranty shall operate as a waiver of it, nor does any single or partial
exercise of any right under this Guaranty preclude the other or further exercise of it or any other right.
16.Termination.The liability of Guarantor under this Guaranty shall terminate and this Guaranty shall,
automatically and without the need for any further act or formality whatsoever, be of no further force or
effect immediately upon all of Obligor’s Obligations arising at any time under the [insert contract name,
i.e. PPA] having been performed, paid and discharged in full or otherwise ceasing to exist in accordance
with the applicable provisions of the [insert contract name, i.e. PPA].
17.Counterparts. The Guaranty may be executed in counterparts, each of which when executed and
delivered shall constitute one and the same instrument. This Agreement may be duly executed and
delivered by execution and facsimile or electronic format (including portable document format (.pdf))
delivery of the signature page of a counterpart to the other Party, and, if delivery is made by facsimile or
other electronic format, the executing Person shall promptly deliver, via overnight delivery, a complete
original counterpart that it has executed to the other executing Persons, but this Agreement shall be binding
on and enforceable against the executing Person whether or not it delivers such original counterpart.
18.Further Assurances. Guarantor shall cause to be promptly and duly taken, executed and
acknowledged and delivered, such further documents and instruments as Beneficiary may from time to time
reasonably request in order to carry out the intent and purposes of this Guaranty.
19.Authority of Guarantor. Guarantor represents and warrants to Beneficiary that (a) it has the
corporate power and authority to execute, deliver and carry out the terms and provisions of this Guaranty;
(b) Guarantor has obtained any authorization, approval, consent or order of, or registration or filing with,
any court or other governmental body having jurisdiction over Guarantor that is required on the part of
Guarantor for the execution and delivery of this Guaranty; and (c) this Guaranty constitutes a valid and
legally binding agreement of Guarantor enforceable against Guarantor in accordance with its terms, except
as the enforceability of this Guaranty may be limited by the effect of any applicable bankruptcy, insolvency,
reorganization, moratorium or similar laws affecting creditors’ rights generally and by general principles
of equity.
AGREED AND ACCEPTED as of the Effective Date.
(COMPANY NAME)
By:
Name:
Title:
IDAHO POWER COMPANY
By
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1039 of 1056
Idaho Power 2026 All Source RFP
Exhibit O – Draft Form Letter of Credit
{00059905.DOC; 1}
|
Name:
Title:
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1040 of 1056
Idaho Power 2026 All Source RFP
Exhibit P - Bid Format and Requirements
This Exhibit P Bid Format and Requirements, further outlines the content and format requirements for all
proposals Bids that do not include the information requested as described in this
exhibit may be deemed ineligible for further evaluation. Further, if the Bidder does not provide information within
two (2) business days of a request by IPC, Bidder may be deemed inel sole discretion.
All sections must be complete and in compliance with the RFP for the bid to be considered further.
GENERAL ORGANIZATION OF THE BID SUBMITTAL
All proposals must contain the following information and be organized as indicated below to facilitate timely
evaluations. Each bid proposal must be as follows:
A. Section 1: Executive Summary of Proposal
Bidder shall submit a full narrative of the proposal, including but not limited to:
Cover Letter and General introduction and information about your company, company
organization chart, and business classification;
Summary of project(s) contained in the proposal identifying key dates and construction
milestones;
Project team identification describing how your project team is organized along with a
description of the key personnel and how each will contribute to the project;
Supplemental Information including any information assumptions to successfully complete the
project(s)

B. Section 2: Resource Based Product Non-Price Factor Narrative
Contract Progress and Viability including descriptive narrative as it relates to Bidder submittal
relative to Exhibit B Bid Entry Form.
Project Readiness and Deliverability including descriptive narrative as it relates to Bidder
submittal relative to the Exhibit B Bid Entry Form.
o Interconnection and Transmission Service Further identify specific steps taken and
what state the project development is currently in as it relates to Interconnection and
Transmission Service requirements
o Environmental and Siting Further describe what stage of development the project is
in, including site control parameters, permits, jurisdictional requirements, and
environment mitigation.

C. Section 3: Resource Based Product Pricing Narrative
In narrative form, detail the selectable portfolio(s) as entered in the Exhibit B Bid Entry Form.
Specifically, describe what resources are available for IPC to model in our long-term capacity
expansion tool. Bidder shall describe specific pricing inputs related to the proposal(s) including:
o Asset Purchase Options with price
o Operations and Maintenance Package Pricing and Terms
o Power Purchase Agreement Pricing with specific terms identified
o Battery Storage Agreement Pricing with specific terms identified

D. Section 4: Market Purchase Product Narrative
In narrative form, describe the products being offered as entered into the Exhibit B Bid Entry
Form
o Term
o Product being offered (WSPP Schedule C or equivalent preferred; heavy load hour or
light load hour; slice; other attributes)
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1041 of 1056
Idaho Power 2026 All Source RFP
Exhibit P - Bid Format and Requirements
o Point of Delivery, including whether bid is contingent on transmission capacity listed in
Exhibit E, Table 4
o Volume
o Pricing
o Western Resource Adequacy Program eligibility
o Shaping optionality
o Description of form of agreement

E. Section 5: Project Financing strategy, including tax credit strategy
Plan for financing the project
o Describe how you have or how you will obtain sufficient funding to complete the project
1. Level of debt and equity to be raised
a. Describe existing relationships with large banks to help you acquire
the necessary funding
2. Is a parent guarantee necessary to receive the funding?
3. Describe plan for monetizing the tax credits
For the asset purchase option, describe your plan to comply with the Inflation Reduction Act
(IRA) requirements to ensure the 30% Investment Tax Credit. Specifically, describe your plan to
comply with prevailing wage and apprenticeship requirements and how you will document proof
of your compliance.

F. Section 6: Contract Terms
In addition to redlined contract terms submitted with the proposal, bidder shall provide a
detailed issues list in narrative form.

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1042 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

IRP public presentations can be found online at: https://www.idahopower.com/IRP
Key Assumption Consistent with
acknowledged
2021 IRP?
Notes, if
applicable
Related Figure, if
applicable
Carbon Price Forecast Forecast uses the same
basis as used in the
2021 IRP
The planning case
carbon price forecast
has been moved back
from starting in 2024 to
2027. This is consistent
with the DRAFT 2023
IRP carbon price
forecast. This was
presented to the IRP
Advisory Committee
(IRPAC) in the
September 8, 2022
public meeting.
See Figure Q.1
Transmission Changes made for CBM
and Winter B2H
capacity
CBM capacity credit for
the target Planning
Reserve Margin has
been adjusted down
from 330 MW in all
months to 200 MW in
the summer months
and 0 MW in the
winter months.
Additionally, B2H
capacity credit for the
target Planning
Reserve Margin in the
winter months has
been adjusted from
200 MW to 0 MW.
These are consistent
with the DRAFT 2023
IRP assumptions for
transmission. These
changes were
presented to the IRPAC
in the April 27, 2023
public meeting.
See Figure Q.2
Load Forecast Forecast updated from
the 2021 IRP
Load Forecast has been
updated based on
more recent historical
information and class
See Figure Q.3
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1043 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

level forecasted
growth. The load
forecasting
methodology is
consistent with the
methodology used in
the 2021 IRP. This is
consistent with the
DRAFT 2023 IRP load
forecast. This was
presented to the IRPAC
in the March 9, 2023
public meeting.
Natural Gas Price
Forecast
Forecast coming from
Platts, which is the
same source used as
the 2021 IRP
The RFP will use the
June 2023 Platts
natural gas price
forecast when it
becomes available.

Hydro Forecast Forecast updated from
the 2021 IRP
The Hydro forecast has
been updated to
incorporate more
recent data. The
underlying hydro
forecasting
methodology is
consistent with the
2021 IRP. This is
consistent with the
DRAFT 2023 IRP hydro
forecast. This was
presented to the IRPAC
in the November 10,
2022 public meeting.
See Figure Q.4
Future Supply-Side
Resources
Updated cost
assumptions and list of
potential resources
from the 2021 IRP
Future proxy supply-
side resource cost
information has been
updated from the 2021
IRP based on more
recent estimates. The
list of potential future
supply-side resources
has also been updated
to include hydrogen
SCCTs and multi-day
100-hr storage. These
are consistent with the
DRAFT 2023 IRP future
See Figure Q.5
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1044 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

supply-side resources
and costs. These were
presented to the IRPAC
in the November 10
and December 8, 2022
public meetings. Please
note that future proxy
supply side resources
are only available for
the AURORA LTCE
model to select for
years beyond the RFP
period.
Future Potential
Demand Response
Updated selectable list
of future potential
demand response
programs from the
2021 IRP
Future proxy demand
response program
information has been
updated from the 2021
IRP based on a demand
response potential
study. This is consistent
with DRAFT 2023 IRP
future potential
demand response. This
was presented to the
IRPAC in the November
10, 2022 public
meeting. Please note
that future potential
demand response
programs are only
available for the
AURORA LTCE model to
select for years beyond
the RFP period.
See Figure Q.6
Planning Reserve
Margin and LOLE
Updated from the 2021
IRP
The planning reserve
margin (PRM) has been
preliminarily changed
from 15.5% to 12.44%
due to the inclusion of
more recent data. The
PRM calculation
methodology is
consistent with the
2021 IRP. The LOLE
threshold used in the
PRM calculation has
been updated from
See Figure Q.7
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1045 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

0.05 event-days /year
with a 50th percentile
peak load to 0.1 event-
days/year with a 70th
percentile peak load.
These are consistent
with the DRAFT 2023
IRP PRM and LOLE.
These were presented
to the IRPAC in the
December 8, 2022 and
March 9, 2023 public
meetings.
Effective Load Carrying
Capability (ELCC)
Updated from the 2021
IRP.
The future proxy new
resource ELCCs have
been changed from the
2021 IRP because of
more recent data. ELCC
calculation
methodology is
consistent with the
2021 IRP. These are
consistent with DRAFT
2023 IRP ELCCs for
future proxy new
resources. These were
presented to the IRPAC
in the March 9, 2023
public meeting. Please
note for the RFP
shortlist modeling,
each project will get a
unique project-specific
ELCC that may differ
from the ELCCs
included in Figure Q.8.
See Figure Q.8

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1046 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.1 DRAFT 2023 IRP Carbon Price Forecast

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1047 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.2 DRAFT 2023 IRP Transmission Updates

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1048 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.3 DRAFT 2023 IRP Load Forecast

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1049 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.4 DRAFT 2023 IRP Hydro Forecast

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1050 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.5 DRAFT 2023 IRP Future Supply-Side Resources

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1051 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.6 DRAFT 2023 IRP Future Potential Demand
Response Programs

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1052 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.7 DRAFT 2023 IRP Planning Reserve Margin and
LOLE

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1053 of 1056
Idaho Power 2026 All Source RFP
Exhibit Q IRP Modeling Assumptions

Figure Q.8 DRAFT 2023 IRP Future Proxy New Resource
ELCCs

Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1054 of 1056
Idaho Power 2026 All Source RFP
Exhibit R - Levelized PVRR Scenarios
2026 RFP - Levelized Present Value of the Revenue Requirement Scenarios
Scenario 1 Scenario 2 Scenario 3 Scenario 4 Scenario 5 Scenario 6
PPA (w/ 2%
esc.)
BTA ( 20 year
life)
Self Build (20
year life)
PPA (w/ 2%
esc.)
BTA ( 35 year
life)
Self Build (35
year life
1 $6,000,000 $17,621,044 $17,621,044 $8,000,000 $16,296,611 $16,296,611
2 $6,120,000 $11,865,378 $11,865,378 $8,160,000 $10,702,669 $10,702,669
3 $6,242,400 $11,585,370 $11,585,370 $8,323,200 $10,584,384 $10,584,384
4 $6,367,248 $11,283,333 $11,283,333 $8,489,664 $10,444,070 $10,444,070
5 $6,494,593 $10,868,975 $10,868,975 $8,659,457 $10,191,436 $10,191,436
6 $6,624,485 $10,351,480 $10,351,480 $8,832,646 $9,835,664 $9,835,664
7 $6,756,975 $10,128,765 $10,128,765 $9,009,299 $9,774,672 $9,774,672
8 $6,892,114 $9,992,757 $9,992,757 $9,189,485 $9,800,387 $9,800,387
9 $7,029,956 $9,649,646 $9,649,646 $9,373,275 $9,618,999 $9,618,999
10 $7,170,555 $9,307,562 $9,307,562 $9,560,741 $9,438,638 $9,438,638
11 $7,313,967 $8,966,536 $8,966,536 $9,751,955 $9,259,335 $9,259,335
12 $7,460,246 $8,626,600 $8,626,600 $9,946,994 $9,081,123 $9,081,123
13 $7,609,451 $8,287,786 $8,287,786 $10,145,934 $8,904,032 $8,904,032
14 $7,761,640 $7,950,129 $7,950,129 $10,348,853 $8,728,098 $8,728,098
15 $7,916,873 $7,613,663 $7,613,663 $10,555,830 $8,553,355 $8,553,355
16 $8,075,210 $7,278,423 $7,278,423 $10,766,947 $8,379,838 $8,379,838
17 $8,236,714 $6,944,447 $6,944,447 $10,982,286 $8,207,585 $8,207,585
18 $8,401,449 $6,611,772 $6,611,772 $11,201,931 $8,036,633 $8,036,633
19 $8,569,477 $6,280,437 $6,280,437 $11,425,970 $7,867,022 $7,867,022
20 $8,740,867 $5,950,483 $5,950,483 $11,654,489 $7,698,791 $7,698,791
21 $11,887,579 $7,531,982 $7,531,982
22 $12,125,331 $7,366,638 $7,366,638
23 $12,367,837 $7,202,803 $7,202,803
24 $12,615,194 $7,040,521 $7,040,521
25 $12,867,498 $6,879,840 $6,879,840
26 $6,720,807 $6,720,807
27 $6,563,472 $6,563,472
28 $6,407,886 $6,407,886
29 $6,254,102 $6,254,102
30 $6,102,173 $6,102,173
31 $5,952,155 $5,952,155
32 $5,804,105 $5,804,105
33 $5,658,083 $5,658,083
34 $5,514,149 $5,514,149
35 $5,372,365 $5,372,365
Total $145,784,219 $187,164,585 $187,164,585 $256,242,398 $287,774,423 $287,774,423
MW 50 50 50 75 75 75
MWhs 131,400 197,100 197,100 197,100
PV (with Discount Delay)$75,746,001 $111,845,100 $111,845,100 $114,183,833 $125,901,537 $125,901,537
Levelized Payment $7,216,708 $10,656,053 $10,656,053 $9,904,327 $9,851,403 $9,851,403
Levelized $/kw-month $12.03 $17.76 $17.76 $11.00 $10.95 $10.95
Levelized $/MWh $54.92 $50.25 $49.98 $49.98
Number of Years 20 20 20 25 35 35
Product Type Solar BESS BESS Solar Solar Solar
Escalation 2.00%
Discount Rate 7.12%
Discount Delay 0.50
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1055 of 1056
Idaho Power 2026 All Source RFP
Exhibit S – Benchmark Bids
Page 1 of 1

Proposed 2026 AS RFP Benchmark Bids
Idaho Power intends to submit the following three (3) individual Benchmark Bids:
No.Bidder Resource
Type
Facility Name Structure Ownership Capacity
(MW)
Contract
Term
(Years)
COD Existing or
New
Point of Delivery County, State Transmission
Rights
Contingent as
described in
Exhibit E?
GIA Status
1 IPC BESS Hemingway Storage 3 Asset Purchase IPC 100 N/A 6/1/2026 New Hemingway 34.5 kV Substation Owyhee, Idaho No Feasibility
Study
2 IPC BESS Boise Bench Energy
Storage
Asset Purchase IPC 150 N/A 6/1/2026 New Boise Bench 138kV Substation Ada, Idaho No LGIA
signed
3 IPC Wind Jackalope Wind PPA / Asset Purchase Mix 300 PPA /
300 AP
35 6/1/2027 New Jim Bridger 345kV Substation Sweetwater
County, Wyoming
No LGIA
Signed
To be built on property with current or pending land rights (ownership, lease, etc) by Idaho Power or its partners.
Benchmark Bids will be submitted in accordance with the RFP. Benchmark Bids will be subject to the requirements, evaluation methodology and other standards specified in the RFP. The Benchmark Bid scores will be
assigned using the same bid scoring and evaluation criteria that will be used to score market bids.
Idaho Power and its partners will administer a competitive supply and engineer, procure, construct solicitation(s), on a case-by-case basis, for the applicable systems required for all Benchmark Bids.

Benchmark Bid efficiencies will be evaluated as submitted by the IPC Internal Team.

Transmission requirements, operating requirements, and dispatch requirements for Benchmark Bids will be evaluated pursuant to applicable Large Generator Interconnection Agreements and necessary Transmission Service
Agreements for each resource.

The Benchmark Bids will be constructed in compliance with applicable Idaho Power technical specifications as defined in the RFP.

Operations & Maintenance costs will be evaluated consistent with the RFP over the life of the resource.
OAR 860-089-0300 requires that utilities specify what utility assets, such as transmission rights or sites, are being made available to benchmark resources and either offer those assets to third-party bidders or provide a
justification for why those assets were not made available. Benchmark Bids No. 1 and No. 2 are located on Idaho Power owned property and are intended to be incorporated into existing substations, thus these sites are are
only available to third-part bidders proposing a Build Transfer Agreement (Asset Purchase) based on access control and ongoing utility operations. Benchmark Bid No. 3 is located on property that Idaho Power has no
current rights directly and is relying on partnership site control and thus cannot offer site access as Idaho Power has no authority to do so. To the extent that any of the Benchmark Bids has or obtains transmission capacity
and is ultimately not the successful bid(s) in the RFP, that transmission capacity may become available to other requestors or successful bids consistent with Transmission Provider and Open Access Transmission Tariff
requirements.
Exhibit No. 4
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1056 of 1056

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

CONFIDENTIAL
EXHIBIT NO. 5

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

EXHIBIT NO. 6
AURORA Modeling
Idaho Power Company
Docket No. UM 2255
Idaho Power Company
Attachment 2
Page 1 of 9
Exhibit No. 6
Case No. IPC-E-24-12
E. Hackett, IPC
Page 1 of 9
Exhibit No. 6
Case No. IPC-E-24-16
E. Hackett, IPC
Page 1 of 9
RFP Initial Shortlist Modeling
RFP
Initial Shortlist
AURORA
LTCE
Get Updated:
➢Project Pricing
➢COD/Schedule
➢Interconnection
Study Results
➢Etc.
2
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What RFP Project Info Goes
Into AURORA?
Resource
Characteristics
Cost
ELCC
•Nameplate Capacity
•Solar/Wind Shapes
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•Ancillary Services
3
Docket No. UM 2255
Idaho Power Company
Attachment 2
Page 3 of 9
Exhibit No. 6
Case No. IPC-E-24-12
E. Hackett, IPC
Page 3 of 9
Exhibit No. 6
Case No. IPC-E-24-16
E. Hackett, IPC
Page 3 of 9
RFP Initial Shortlist Modeling
RFP
Initial Shortlist
AURORA
LTCE
Get Updated:
➢Project Pricing
➢COD/Schedule
➢Interconnection
Study Results
➢Etc.
4
AURORA LTCE
Scenarios
▪July 2026 B2H –No SWIP
▪July 2026 B2H –SWIP
▪November 2026 B2H –No SWIP
▪November 2026 B2H –SWIP
▪June 2027 B2H –No SWIP
▪June 2027 B2H –SWIP
▪High Gas Price + High Carbon Price
▪Low Gas Price + Zero Carbon Price
▪Large Load –100 MW
▪Large Load –200 MW
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RFP Initial Shortlist Modeling: Example
5
AURORA LTCE
Scenarios
▪July 2026 B2H
▪November 2026 B2H
▪June 2027 B2H
▪High Gas + High Carbon
▪Low Gas + Zero Carbon
▪SWIP Transmission Runs
▪Project 1 (2026 COD), Project 7 (2027 COD)
▪Project 1 (2026 COD), Project 2 (2026 COD),
Project 3 (2026 COD), Project 6 (2027 COD)
▪Project 1 (2026 COD), Project 2 (2026 COD),
Project 4 (2026 COD), Project 7 (2027 COD)
▪Project 1 (2026 COD), Project 2 (2026 COD),
Project 7 (2027 COD), Project 8 (2027 COD)
▪Project 9 (2026 COD), Project 8 (2027 COD),
Project 10 (2027 COD)
▪Project 1 (2026 COD), Project 7 (2027 COD)
AURORA LTCE Scenarios:
Project Selections
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RFP Initial Shortlist Modeling: Example
RFP
Initial
Shortlist
AURORA
LTCE
6
AURORA LTCE
Scenarios
▪July 2026 B2H –No SWIP
▪July 2026 B2H –SWIP
▪November 2026 B2H –No SWIP
▪November 2026 B2H –SWIP
▪June 2027 B2H –No SWIP
▪June 2027 B2H –SWIP
▪High Gas Price + High Carbon Price
▪Low Gas Price + Zero Carbon Price
▪Large Load –100 MW
▪Large Load –200 MW
RFP Final
Shortlist
▪Project 1 (2026 COD)
▪Project 7 (2027 COD)
▪Project 2 (2026 COD)
▪Project 3 (2026 COD)
▪Project 6 (2027 COD)
▪Project 4 (2026 COD)
▪Project 8 (2027 COD)
▪Project 9 (2026 COD)
▪Project 10 (2027 COD
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RFP Final Shortlist: Sensitivities
RFP
Final
Shortlist
AURORA
LTCE
7
AURORA LTCE Final
Shortlist Portfolios
(Example)
▪Portfolio A
▪Project 1 (2026 COD)
▪Project 2 (2026 COD)
▪Project 6 (2027 COD)
▪Portfolio B
▪Project 1 (2026 COD)
▪Project 2 (2026 COD)
▪Project 7 (2027 COD)
▪Portfolio C
▪Project 4 (2026 COD)
▪Project 2 (2026 COD)
▪Project 10 (2027 COD)
▪Portfolio D
▪Project 9 (2026 COD)
▪Project 3 (2026 COD)
▪Project 8 (2027 COD)
▪Project 1 (2026 COD)
▪Project 7 (2027 COD)
▪Project 2 (2026 COD)
▪Project 3 (2026 COD)
▪Project 6 (2027 COD)
▪Project 4 (2026 COD)
▪Project 8 (2027 COD)
▪Project 9 (2026 COD)
▪Project 10 (2027 COD
AURORA
Sensitivities
(Stochastic
Modeling)
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RFP Final Shortlist: Sensitivities
8
AURORA LTCE Final
Shortlist Portfolios
(Example)
▪Portfolio A
▪Project 1 (2026 COD)
▪Project 2 (2026 COD)
▪Project 6 (2027 COD)
▪Portfolio B
▪Project 1 (2026 COD)
▪Project 2 (2026 COD)
▪Project 7 (2027 COD)
▪Portfolio C
▪Project 4 (2026 COD)
▪Project 2 (2026 COD)
▪Project 10 (2027 COD)
▪Portfolio D
▪Project 9 (2026 COD)
▪Project 3 (2026 COD)
▪Project 8 (2027 COD)
AURORA Sensitivities (Stochastic Modeling)
60 Stochastic Iterations
-Varying: Hydro, Load, Natural Gas Price and Carbon Price
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RFP Final Project Contracting
RFP
Final
Shortlist
AURORA
LTCE
9
AURORA LTCE Final
Shortlist Portfolios
(Example)
▪Portfolio A
▪Project 1 (2026 COD)
▪Project 2 (2026 COD)
▪Project 6 (2027 COD)
▪Portfolio B
▪Project 1 (2026 COD)
▪Project 2 (2026 COD)
▪Project 7 (2027 COD)
▪Portfolio C
▪Project 4 (2026 COD)
▪Project 2 (2026 COD)
▪Project 10 (2027 COD)
▪Portfolio D
▪Project 9 (2026 COD)
▪Project 3 (2026 COD)
▪Project 8 (2027 COD)
AURORA
Sensitivities
(Stochastic
Modeling)
RFP
Final
Shortlist
Project
Ranking
1.Project 2
2.Project 6
3.Project 1
4.Project 9
5.Project 7
6.Project 4
7.Project 3
8.Project 10
9.Project 8
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BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

CONFIDENTIAL
EXHIBIT NO. 7

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-24-16

IDAHO POWER COMPANY

HACKETT, DI
TESTIMONY

CONFIDENTIAL
EXHIBIT NO. 8