20231012Final Approved Tariff.pdf

DONOVAN WALKER
Lead Counsel
[e-mail]

August 9, 2023

VIA ELECTRONIC FILING

Jan Noriyuki, Secretary
Idaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg 8,
Suite 201-A (83714)
PO Box 83720
Boise, Idaho 83720-0074

Re: Case No. IPC-E-21-42
In the Matter of Idaho Power Company’s Application for Approval of Special
Contract and Tariff Schedule 33 to Provide Electric Service to Brisbie, LLC’s
Data Center Facility

Dear Ms. Noriyuki:

Attached for electronic filing, please find Idaho Power Company’s Compliance
Filing in the above matter.

Please feel free to contact me directly with any questions you might have about
this filing.

Very truly yours,

Donovan E. Walker
DEW:sg
Enclosures
RECEIVED
2023 August 9 PM 4:19
IDAHO PUBLIC
UTILITIES COMMISSION

IDAHO POWER COMPANY’S COMPLIANCE FILING - 1
DONOVAN E. WALKER (ISB No. 5921)
MEGAN GOICOECHEA ALLEN (ISB No 7623)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]

Attorneys for Idaho Power Company

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF IDAHO POWER
COMPANY’S APPLICATION FOR
APPROVAL OF SPECIAL CONTRACT AND
TARIFF SCHEDULE 33 TO PROVIDE
ELECTRIC SERVICE TO BRISBIE, LLC’S
DATA CENTER FACILITY.
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CASE NO. IPC-E-21-42

IDAHO POWER COMPANY’S
COMPLIANCE FILING

Idaho Power Company (“Idaho Power” or “Company”) hereby respectfully submits
this Compliance Filing to effectuate updates to the replacement Special Contract for
Electric Service between the Company and Brisbie, LLC (“Brisbie”) and associated Tariff
Schedule 33 as directed by the Idaho Public Utilities Commission (“Commission”) in Order
No. 35777.
I. BACKGROUND
1. Brisbie is developing a new data center facility at which it anticipates energy
requirements will exceed the threshold for service under Schedule 19, Large Power

IDAHO POWER COMPANY’S COMPLIANCE FILING - 2
Service, necessitating special contract arrangements with the Company.1 In addition to
having large load service requirements in excess of 20 megawatts (“MW”), Brisbie has a
sustainability objective to support 100 percent of its operations with new renewable
resources.
2. As such, the Company and Brisbie entered into a Special Contract Agreement
(“Special Contract”) dated December 22, 2021, also referred to as the Brisbie Energy
Services Agreement (“Brisbie ESA”). The Brisbie ESA is consistent with and reflects the
regulatory framework set forth in the Clean Energy Your Way - Construction option, as
outlined in Idaho Power’s Application with the Commission in Case No. IPC-E-21-40 to
establish new clean energy offerings for customers under the Clean Energy Your Way
(“CEYW”) Program. This was also the approach taken with respect to the Micron Energy
Services Agreement (“Micron ESA”), which was submitted for Commission review in Case
No. IPC-E-22-06.2
3. On December 22, 2021, Idaho Power filed an application with the Commission
seeking approval of: (1) the Special Contract between Idaho Power and Brisbie; (2) the
rates and charges set out in Schedule 33; and (3) the regulatory framework for the
ongoing implementation and administration of the Special Contract without change or
condition.
4. On May 11, 2023, the Commission issued Order No. 35777 approving the
Special Contract contingent on the parties modifying the ESA and Schedule 33 as
directed by the Commission. The modifications required by the Commission for the

1 See I.P.U.C. No. 29, Tariff No. 101, Schedule 19 (requiring customers with an aggregate power
requirement of more than 20,000 kW at the same premises “make special contract arrangements with the
Company.”)
2 In the Matter of Idaho Power Company’s Application for Approval of a Replacement Special Contract
with Micron Technology, Inc. and a Power Purchase Agreement with Black Mesa Energy, LLC, Case No.
IPC-E-22-06, Application (Mar. 10, 2022).

IDAHO POWER COMPANY’S COMPLIANCE FILING - 3
Brisbie ESA mirror those directed by the Commission in relation to the similarly situated
Micron ESA3 regarding the treatment of Excess Generation Credits (“EGC”) and
Renewable Capacity Credits (“RCC”), and the Company was instructed to file updated
versions of the Brisbie ESA and Schedule 33 incorporating the necessary modifications
within 90 days of the order, or by August 9, 2023.
5. Thereafter, the Parties entered into the First Amendment to the ESA and
updated Schedule 33 to incorporate the direction from, and comply with, Commission
Order No. 35777. In addition, the First Amendment includes an update intended to correct
a discrepancy related to assessment of the Schedule 91, Energy Efficiency Rider charge
in relation to the Brisbie ESA, as more fully discussed in Section V below.
II. ALIGNMENT WITH CASE NO. IPC-E-22-06
6. As noted above, both the Brisbie and Micron ESAs submitted for Commission
review in this case and Case No. IPC-E-22-06, respectively, are representative of the
Company’s pending Clean Energy Your Way - Construction offering and contain a
number of comparable provisions including similar compensation mechanism for excess
generation and renewable capacity credits. In the Micron case, after approving the Micron
ESA and associated tariff schedule subject to certain modifications related to the
treatment of EGCs and RCCs,4 the Commission addressed the Company’s request for
clarification regarding how to calculate the RCCs under the ESA by instructing the
Company to work together with Staff to develop a rate structure for calculating RCCs
under the ESA.5

3 See, e.g., id., Order Nos. 35482 (Aug. 1, 2022), 35607 (Nov. 23, 2022), and 35735 (Apr. 12, 2023).
4 Case No. IPC-E-22-06, Order No. 35482.
5 Id., Order No. 35532 (Sep. 19, 2022).

IDAHO POWER COMPANY’S COMPLIANCE FILING - 4
7. As a result of the collaborative efforts undertaken by Staff and the Company
to fulfill the Commission’s directives in Case No. IPC-E-22-06, the Company submitted
its first Compliance Filing in that case on December 23, 2022, which included its proposal
to implement an RCC performance mechanism payment structure. In conjunction with its
proposed Renewable Capacity Credit Payment Performance Mechanism (“Proposed
Method”) the Company submitted a detailed description of the methodology for
Company’s proposed RCC performance mechanism for monthly payments under the
Micron ESA.6
8. In approving the Company’s Proposed Method for calculating RCC payments
under the Micron ESA in Case No. IPC-E-22-06, the Commission noted “the Proposed
Method may guide the Company and CEYW Construction customers when executing
future Energy Service Agreements.”7 Thereafter, the Company submitted its Second
Compliance Filing on June 1, 2023, including updates to the Micron ESA and associated
tariff schedule intended to incorporate the direction from, and comply with, Commission
Order Nos. 35482 and 35735.
9. Based on the Commission’s guidance related to executing future CEYW
Construction ESAs and because the Brisbie ESA being considered in the instant case
includes the same provisions at issue with respect to the Micron ESA in Case No. IPC-E-
22-06, the Company addressed the Commission-directed modifications to the Brisbie
ESA in the same manner. To that end, included herewith as Attachment 1 is a description
of the methodology for Company’s proposed RCC performance mechanism for monthly

6 Id., Attachment 1 to Idaho Power’s Compliance Filing (Dec. 23, 2022).
7 Id., Order No. 35735 at 2.

IDAHO POWER COMPANY’S COMPLIANCE FILING - 5
payments under the Brisbie ESA, which is consistent with that provided for the Micron
ESA in Case No. IPC-E-22-06.8
III. COMPLIANCE - FIRST AMENDMENT TO ESA
10. Pursuant to Order No. 35777, the Company is submitting this Compliance
Filing to present the First Amendment to the Brisbie Special Contract, which addresses
the Commission-directed modifications to the ESA as well as updated Schedule 33. The
First Amendment and Schedule 33 are attached hereto as Attachments 2 and 3,
respectively.
Updates to Pricing
11. The First Amendment provides for the replacement of ESA Exhibit 3.1,
“Pricing”, in its entirety with the revised version of Exhibit 3.1 (Revised Exhibit 3.1)
provided with the First Amendment, which addresses the modifications directed by the
Commission in Order No. 35777, as well as Order Nos. 35482, 35607, and 35735 from
Case No. IPC-E-22-06, as follows.
12. Excess Generation Credits. In order to effectuate the Commission’s directives
related to the EGCs, Exhibit 3.1 has been revised to modify the definition of “Excess
Generation Price” to conform with Commission Order No. 35777, whereby it ordered the
Company to compensate Excess Generation at “the lower of the Excess Generation Price
(with the 85% adjustment in addition to the previously included 82.4% non-firm
adjustment) and the actual high- or low-load hour Mid-C market price (without any
adjustment) for each hour. . .”9

8 See id., Attachment 1 to Idaho Power’s Compliance Filing.
9 Order No. 35777 at 18. See also Case No. IPC-E-22-06, Order No. 35482 at 15.

IDAHO POWER COMPANY’S COMPLIANCE FILING - 6
13. Renewable Capacity Credits. Exhibit 3.1 of the ESA and Schedule 33 have
been modified to incorporate several revisions necessary to implement the Commission’s
orders. First, in Revised Exhibit 3.1, new definitions for “Monthly Adjusted Renewable
Capacity Credit,” “Monthly Unadjusted Renewable Capacity Credit,” and “Performance
Ratio Adjustment Factor” have been added. One previously defined term (Renewable
Capacity Credit) has been renamed to “Annual Capacity Credit” and is utilized in
determination of the “Monthly Unadjusted Renewable Capacity Credit.” Finally, Schedule
33 has been revised to align with the new/modified definitions contained within Revised
Exhibit 3.1 and a new table (Monthly Unadjusted Renewable Capacity Credit by Month)
has been included, consistent with the methodology approved by the Commission in Case
No. IPC-E-22-06 and presented in Attachment 1 hereto.
14. Pricing elements defined in Revised Exhibit 3.1 Schedule 33 has been
updated to remove pricing element definitions which may be found in Revised Exhibit 3.1,
consistent with Micron’s Schedule 26.
15. PCA Cost Sharing. In its order, the Commission found “it fair, just, and
reasonable that the credits for excess energy generation and capacity included in power
supply expense be subject to 95 percent sharing in the PCA.”10 The Company
understands the Commission will only allow recovery of 95 percent of the EGCs and
RCCs through amounts charged to PCA tracked accounts. In order to ensure the
Company remains indifferent to the negotiated ESA, Idaho Power and Brisbie have
agreed to modify Exhibit 3.1 of the ESA and Schedule 33 to include an “Administrative
Charge.” This charge will be recorded in Account 442xxx, Opr Rev Industrial-Brisbie LLC
and will not be subject to 95%/5% sharing under the PCA or any successor mechanism.

10 Order No. 35777 at 19. See also Case No. IPC-E-22-06, Order No. 35607 at 13.

IDAHO POWER COMPANY’S COMPLIANCE FILING - 7
IV. COMPLIANCE – REVIEW OF FUTURE PPAs
16. In reviewing the Brisbie ESA and the associated draft renewable resource
PPA, the question arose as to whether renewable resource PPAs associated with special
contracts or energy services agreements required Commission review and approval.
17. Ultimately, the Commission found it “fair, just, and reasonable that all future
CEYW-Construction project- associated PPAs, or resource construction agreements, be
reviewed and approved by the Commission.”11 In conformity with the Commission’s
directive, the Company will file future renewable resource PPAs or similar resource
construction agreements with the Commission for its review and approval.
V. CORRECTION OF THE RECORD
18. As it was developing the framework under which it will bill the new ESA and
related renewable elements, the Company became aware of a discrepancy between how
it described the way the Schedule 91, Energy Efficiency Rider (“Rider”) would be
assessed and how the charge should be assessed according to its tariff.
19. In its initial filing, Company witness Goralski explained that the Rider charge
will be “computed by multiplying the rider percentage times the sum of the monthly billed
charge components in block 1 and block 2, except for the Power Cost Adjustment and
the renewable resource PPA pass-through payment.”12 Likewise, the formula for
calculating “Monthly Contract Payment[s]” set forth in original Exhibit 3.1 includes the
renewable resource credits in the calculation of the Rider amount. However, the
description of the Rider computation in the Goralski testimony and incorporated in the
assessment of the Rider component of the Monthly Contract Payment calculation in

11 Order No. 35777 at 19. See also Case No. IPC-E-22-06, Order No. 35482 at 17-18.
12 Goralski Direct at 20.

IDAHO POWER COMPANY’S COMPLIANCE FILING - 8
Exhibit 3.1 is inconsistent with the language of Schedule 91, which states: “The Monthly
Charge is equal to the applicable Energy Efficiency Rider percentage times the sum of
the monthly billed charges for the base rate components.”13
20. The Company is bringing this discrepancy to the Commission’s attention to
ensure clarity and accuracy of the record and to verify that the Company will assess the
Rider in accordance with Schedule 91. The Company has also updated the formula for
calculating Monthly Contract Payments in Revised Exhibit 3.1 to ensure the Rider
component is computed consistent with Schedule 91 and has also spoken to Brisbie
representatives about the matter to ensure Brisbie understands how the Rider charge will
be assessed in line with the tariff.
VI. CONCLUSION
21. Idaho Power appreciates the Commission’s review and consideration of the
issues in this case and the opportunity to make this compliance filing to address the
Commission’s concerns. The Company believes the attached and executed First
Amendment makes the necessary changes to the ESA required to implement the
Commission’s directives and respectfully requests that the Commission approve: the
Brisbie ESA dated December 22, 2021; the First Amendment thereto dated August 3,
2023, including Revised Exhibit 3.1; and Schedule 33 as revised.
Respectfully submitted this 9th day of August 2023.

DONOVAN E. WALKER
Attorney for Idaho Power Company

13 See I.P.U.C. No. 29, Tariff No. 101, Schedule 91.

IDAHO POWER COMPANY’S COMPLIANCE FILING - 9
CERTIFICATE OF SERVICE

I HEREBY CERTIFY that on the 9th day of August 2023, I served a true and correct
copy of the foregoing Idaho Power Company’s Compliance Filing upon the following
named parties by the method indicated below, and addressed to the following:

Dayn Hardie
Deputy Attorney General
Idaho Public Utilities Commission
Po Box 83720
Boise, Idaho 83720-0074

Emailed to:
[e-mail]
Clean Energy Opportunities for Idaho
Michael Heckler
Courtney White
Clean Energy Opportunities for Idaho, Inc.
3778 Plantation River Drive, Suite 102
Boise, Idaho 83703

Emailed to:
[e-mail]
[e-mail]

Kelsey Jae
Law for Conscious Leadership
920 N. Clover Dr.
Boise, ID 83703

Emailed to:
[e-mail]

________________________________
Stacy Gust
Regulatory Administrative Assistant

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-42

IDAHO POWER COMPANY

ATTACHMENT 1

Proposed Payment Structure

Attachment 1 – Case No. IPC-21-42 – Proposed Brisbie, LLC
Renewable Capacity Credit Payment Structure for Pleasant
Valley Solar

The capacity contribution calculated at the time of contract execution was 31.21%.
The annual payment is determined by multiplying the average capacity contribution, as
calculated by the ELCC method (or NREL 8,760-based method for projects executed
before the 2021 IRP acknowledgement), by the avoided cost of capacity. The avoided
cost of capacity is the levelized fixed cost associated with the least-cost dispatchable
resource from the Company’s most recently acknowledged IRP; for the 2019 IRP the
identified resource was a reciprocating internal combustion engine (“RICE”), and for the
2021 IRP the identified resource was a simple-cycle combustion turbine. In the case of
Brisbie, LLC, the avoided cost of capacity at the time of contract execution was a RICE
with levelized capacity cost of $121.19 per kW per year. 
Determine Annual Payment
The annual payment is calculated by multiplying the capacity contribution by the
nameplate of the selected project by the avoided cost of capacity:
𝐴𝑛𝑛𝑢𝑎𝑙 𝑃𝑎𝑦𝑚𝑒𝑛𝑡 𝐶𝑎𝑝𝑎𝑐𝑖𝑡𝑦 𝐶𝑜𝑛𝑡𝑟𝑖𝑏𝑢𝑡𝑖𝑜𝑛 ∗ 𝑃𝑟𝑜𝑗𝑒𝑐𝑡 𝑁𝑎𝑚𝑒𝑝𝑙𝑎𝑡𝑒 ∗ 𝐴𝑣𝑜𝑖𝑑𝑒𝑑 𝐶𝑜𝑠𝑡 𝑜𝑓 𝐶𝑎𝑝𝑎𝑐𝑖𝑡𝑦  
Applying the annual payment calculation to the Pleasant Valley Solar project, the
resulting value is determined to be $7,564,680 per year:
𝐴𝑛𝑛𝑢𝑎𝑙 𝑃𝑎𝑦𝑚𝑒𝑛𝑡 31.21%∗200,000 𝑘𝑊∗ $121.19
𝑘𝑊 ∙ 𝑦𝑟 $7,564,680/𝑦𝑟 

Determine Months of Capacity Need
The annual payment will be calculated at the time of contract execution and
distributed proportionally over the months that capacity is expected to be needed. To
determine the months of capacity need, the Loss of Load Expectation (“LOLE”) per month
of the different historical years would be used to calculate an average LOLE for each
month. If a significant resource stack change is expected in the near future, an adjusted
case would be used to guide the monthly weighted average calculations. For the Pleasant
Valley Solar project, a forward period was utilized, 2025. The average monthly LOLE
values for the 2025 Load and Resource (“L&R”) year are listed in Table 1.
Table 1. 2025 L&R Average Monthly LOLE  
Month Average LOLE
January 0.000519
February 0.000041
March 0.000001
April 0.000021
May 0.000009
June 0.002826
July 0.059431
August 0.019593
September 0.003627
October 0.000899
November 0.006035
December 0.006498
For the Pleasant Valley Solar project, because the contract was executed prior to
the 2021 IRP acknowledgement the NREL 8,760-based method was used to determine
capacity contribution, there were no monthly LOLE values calculated. A 2025 L&R year
was used to determine the months of capacity need because it is the year the project is

expected to be online. Idaho Power is expecting a significant addition of ramping industrial
load during in 2025, meaning the load expected in January 2025 is significantly lower
than the load expected in December 2025. To annualize for the impact of the industrial
load ramp, the average LOLE value of months November and December was used for
January and February. Using the results from the 2025 L&R with industrial load
annualizing adjustment applied to January and February LOLE values, the monthly LOLE
weighted averages are listed in Table 2.
Table 2. Monthly LOLE Weighted Average
Month Weighted Average
January 5.62%
February 5.62%
March -
April -
May -
June 2.54%
July 53.33%
August 17.58%
September 3.25%
October 0.81%
November 5.42%
December 5.83%
The twelve months of the calendar year are grouped into three different periods
given their Loss of Load Probability (“LOLP”) profiles, as described in the list below:
 Summer: June, July, and August
 Winter: January, February, November, and December
 Off-season: September and October

Note that March through May remain at 0% LOLP. A weighted average per period
is calculated by adding the percentages of each month within the corresponding period
together, as shown in Table 3.
Table 3. LOLE Weighted Average per Period
Summer Winter Off-Season
June 2.54% January 5.62% September 3.25%
July 53.33% February 5.62% October 0.81%
August 17.58% November 5.42%
December 5.83%
Summer Total ~73% Winter Total ~22% Off-Season Total ~5%
For the winter and off-season periods, the total is spread out relatively equally over
the various the months; this means the approximate 22% for the winter total would be
divided by the 4 months for 5.50% in each month, and the approximate 5% for the off-
season total would be divided by the 2 months for 2.5% in each month.
For the summer period, the high LOLP hours span from the last 2 weeks of June
through the first 2 weeks of August (totaling 8 weeks), meaning there are 4 weeks in July,
2 weeks in June and 2 weeks in August that encompass the high LOLP hours. Because
the summer total is set to equal the approximate 73%, the high LOLP hours weekly
weighting can be used to smooth the summer period spread:
 June - 73%∗
18.25%
 July - 73%∗
36.50%
 August - 73%∗
18.25%
The final weights by month are shown in Table 4.

Table 4. Seasonal Monthly LOLE Weighted Average
Month Weighted Average
January 5.50%
February 5.50%
March -
April -
May -
June 18.25%
July 36.50%
August 18.25%
September 2.50%
October 2.50%
November 5.50%
December 5.50%
The monthly payment is calculated by taking the previously calculated annual
payment of $7,564,680 per year and multiplying it by the weighted average for each
month, as shown in Table 5.
Table 5. Seasonal Monthly Payment
Month Weighted Average Monthly Payment
January 5.50% $416,057
February 5.50% $416,057
March - -
April - -
May - -
June 18.25% $1,380,554
July 36.50% $2,761,108
August 18.25% $1,380,554
September 2.50% $189,117
October 2.50% $189,117
November 5.50% $416,057
December 5.50% $416,057
Total 100.00% $7,564,680

Performance Metric
The Performance Ratio (“PR”) is a metric widely used to track performance of
photovoltaic (“PV”) systems in the industry.123 The PR metric can be used to ensure a
project is being well maintained and is performing as expected. PR can be defined as the
ratio of measured output to the expected output for a given reporting period based on the
system nameplate rating. Traditionally, PR is mathematically expressed as
𝑃𝑅
𝑘𝑊ℎ
𝑘𝑊,
𝑘𝑊ℎ
𝑚1𝑘𝑊
𝑚

where
𝑘𝑊ℎ 𝐸𝑛𝑒𝑟𝑔𝑦 𝐺𝑒𝑛𝑒𝑟𝑎𝑡𝑒𝑑 𝑏𝑦 𝑡ℎ𝑒 𝑃𝑙𝑎𝑛𝑡 
𝑘𝑊, 𝑅𝑎𝑡𝑒𝑑 𝐷𝑖𝑟𝑒𝑐𝑡 𝐶𝑢𝑟𝑟𝑒𝑛𝑡 𝑃𝑜𝑤𝑒𝑟 𝑜𝑓 𝑡ℎ𝑒 𝑃𝑙𝑎𝑛𝑡 𝑎𝑡 𝑆𝑡𝑎𝑛𝑑𝑎𝑟𝑑 𝑇𝑒𝑠𝑡 𝐶𝑜𝑛𝑑𝑖𝑡𝑖𝑜𝑛𝑠 
𝑘𝑊ℎ 𝑃𝑙𝑎𝑛𝑒 𝑜𝑓 𝐴𝑟𝑟𝑎𝑦 “𝑃𝑂𝐴” 𝐼𝑟𝑟𝑎𝑑𝑖𝑎𝑛𝑐𝑒  
The PR metric is most often used by power plant operators to track plant
performance. Idaho Power proposes to modify the previously shown equation to consider
the contracted nameplate of the plant on the Alternating Current (“AC”) side and not on
the Direct Current (“DC”) side. The contract with Idaho Power is on the AC side and it has
the potential to be the limiting factor during operation. The proposed modification would
result in the following PR equation:
𝑃𝑅 𝑘𝑊ℎ
𝑘𝑊,∗ 𝑘𝑊ℎ 

1 IEC 61724-1: 2017 Photovoltaic System Performance
2 Performance of Photovoltaic Systems Recorded by oSPARC, NREL 2020
3 PV System Performance Assessment, Sunspec Alliance, San Jose State University, 2014

One of the interconnection requirements is for the project to provide Idaho Power
with weather data via Supervisory Control and Data Acquisition (“SCADA”). One of the
variables required is the Plane of Array (“POA”) irradiance (𝑘𝑊ℎ). The energy injected
into the system is also measured via SCADA, making the PR calculation relatively
straight-forward.
Performance Ratio Target
The PR metric is directly impacted by the energy output which is proportional to
irradiance and inversely proportional to module temperature. The PR equation accounts
for irradiation; changes in irradiation will have little effect on the PR. However, changes
in temperature are not accounted for in the PR calculation and the PR will decrease as
temperature increases. To account for the impact of temperature on the PR calculation,
Idaho Power proposes to set a different PR target for the summer months than the non-
summer months. The Company proposes to use the PR targets described in Table 7 and
graphically displayed in Figure 1.
Table 7. PR Targets by Period
Period Target
January through May 𝑃𝑅 1.0
June through September 𝑃𝑅 0.95
October through December 𝑃𝑅 1.0

Figure 1. PR Targets by Month
Hours of Need
Capacity is only avoided during certain hours of the calendar year. The hours
where capacity is needed are the hours which have high LOLP values. To provide
compensation for capacity when it is needed, the PR metric will be calculated based on
the high LOLP hours of each period for the 2025 L&R, which have been identified in Table
8.
Table 8. 2025 L&R High LOLP Hours
Period Identified High LOLP Hours
Summer + September 1:00 pm - 11:00 pm
Winter + October4 4:00 am - 11:00 am & 3:00 pm - 10:00 pm

4 Identified LOLP Hours for Winter + October are 4:00 am – 11:00 am & 4:00 pm – 10:00 pm for the 2025
L&R. Due to the limited solar PV generation possible in the 4:00 pm to 10:00 pm window in certain
months in the Winter + October period; the 3:00 pm – 4:00 pm hour is included to reduce the solar
generation measurement variability. For LOLP hours outside of solar PV generation hours, the
expectation of solar PV generation based on irradiance at the site is zero.
2 4 6 8 10 12
Month of the Year
0.5
0.6
0.7
0.8
0.9
1
Performance Metric Threshold by Month

For clarification, the hours presented in Table 8 are Hour Beginning (“HB”) for the
first interval and Hour Ending for the second interval (“HE”). Using the summer +
September period as an example, 1:00 pm HB represents the hour spanning from 1:00
pm to 2:00 pm while 11:00 pm HE represents the hour spanning from 10:00 pm to 11:00
pm; this means the identified summer period high LOLP hours begin at 1:00 pm and
conclude at 11:00 pm.
Reduction on Payment
To receive the full monthly payment, the project will have to meet the PR threshold
in the corresponding high LOLP hours (as set in Table 8). If the PR is not met, a reduction
in payment will be applied to the project. The reduction will be calculated based on the
impact to capacity as measured by the ELCC. The impact on capacity will be determined
by reducing the output of the project and calculating its ELCC. For the Pleasant Valley
Solar project, the relationship between output and ELCC reduction was calculated over
the range of 0.5 PR to 1.0 PR, as shown in Figure 2.

Figure 2. Relationship Between PR & ELCC
0
20
40
60
80
100 Performance RaƟo vs ELCC
0.5 0.6 0.7 0.8 0.9 1
PV Output

The results shown in Figure 2 will be used to determine the monthly payment
reduction if the project did not meet the monthly PR target. In any month where capacity
payments are applied do not meet the corresponding target PR, a reduction as presented
in Figure 2 would be applied (the reduction is calculated by interpolating between the
monthly PR value and the target PR value for that month). As an example of how the PR
versus ELCC approach would be implemented, data for a similar project near the
Pleasant Valley Solar site was collected for the 2021 L&R; the PRs were then calculated
for the corresponding high LOLP hours of each month with the results shown in Table 9
(bolded values represent calculated PR values that did not meet the targets identified in
Table 7).
Table 9. Monthly Performance Ratio & Payment Example
Month Performance Ratio Payment Reduction Monthly Payment
January 1.08 0.00% $416,057
February 1.13 0.00% $416,057
March - - -
April - - -
May - - -
June 0.98 0.00% $1,380,554
July 1.00 0.00% $2,761,108
August 0.99 0.00% $1,380,554
September 0.97 0.00% $189,117
October 1.01 0.00% $189,117
November 1.11 0.00% $416,057
December 0.98 1.80% $408,568
Total $7,557,189

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-42

IDAHO POWER COMPANY

ATTACHMENT 2

First Amendment to ESA
FIRST AMENDMENT TO THE
SPECIAL CONTRACT
BETWEEN
IDAHO POWER COMPANY AND
BRISBIE, LLC
This First Amendment to the Special Contract (“First Amendment”) is effective as of August
3, 2023 (“Effective Date”) and is entered into by and between Brisbie LLC, a limited liability company
(“Brisbie”), and Idaho Power Company, an Idaho corporation (“Idaho Power”) (hereinafter each
individually referred to as a “Party” or collectively as the “Parties”).
WHEREAS, Brisbie is developing a data center campus and associated infrastructure and
facilities (“Data Facility”) in Idaho Power’s electric service territory and is anticipating that the Data
Facility’s annual aggregate energy requirements, which Brisbie desires be met with energy generated by
renewable resources, will exceed the threshold for Schedule 19, Large Power Service, necessitating
special contract arrangements with the Company; and
WHEREAS, on December 22, 2021, Idaho Power and Brisbie entered into a Special Contract
Agreement (“Special Contract”), and Idaho Power initiated Case No. IPC-E-21-42 with the Idaho Public
Utilities Commission (“Commission”) on December 22, 2021, requesting approval of the Special Contract
and the associated rates and charges proposed in tariff Schedule 33; and
WHEREAS, the Commission issued Order No. 35777 on May 11, 2023, directing Idaho Power
to update the Brisbie Special Contract and Schedule 33 to address Commission-directed modifications
relating to the treatment of Excess Generation Credits (“ECG”), Renewable Capacity Credits (“RCC”),
and cost sharing under the Power Cost Adjustment (“PCA”); and
WHEREAS, incidentally to the Commission’s mandate, the Company discovered a discrepancy
between how the Schedule 91 Energy Efficiency Rider was depicted in the description of the various rate
component monthly charges included in the pricing exhibit to the Special Contract and how the charge
should be assessed according to its tariff Schedule 91; and
WHEREAS, the Parties desire to enter into this First Amendment to the Special Contract to
incorporate the direction from, and comply with, Commission Order No. 35777, as well as make clear that
the Energy Efficiency Rider will be assessed consistent with Schedule 91, and hereby submit the same for
the Commission’s approval.
NOW, THEREFORE, in consideration of the premises and of the mutual covenants herein set
forth, and other good and valuable consideration, the receipt, sufficiency and adequacy of which are
hereby acknowledged, Brisbie and Idaho Power, each intending to be legally bound, agree as follows:
Page 1 of 3
First Amendment to the Special Contract
Page 2 of 3
1.Incorporation of Recitals. The above-stated recitals are incorporated into and made a part of this
First Amendment by this reference.
2.Amendment.
Exhibit 3.1: Pricing. Exhibit 3.1 to the Special Contract is hereby replaced in its entirety with the
revised version of Exhibit 3.1 (Revised Exhibit 3.1) included in the Attachment hereto, which is
incorporated by reference as if set forth fully.
3.IPUC Approval. The obligations of the Parties under this First Amendment are subject to the
Commission’s approval of this First Amendment and such approval being upheld on appeal, if any, by a
court of competent jurisdiction.
4.Effect of Amendment. Except as expressly amended by this First Amendment, the terms and
conditions of the Special Contract remain unchanged.
5.Capitalized Terms. All capitalized terms used in this First Amendment and not defined herein
shall have the same meaning as in the Special Contract.
6.Scope of Amendment. This First Amendment shall be binding upon and inure to the benefit of the
Parties hereto, and their respective heirs, executors, administrators, successors, and assigns, who are
obligated to take any action which may be necessary or proper to carry out the purpose and intent hereof.
7.Authority. Each Party represents and warrants that as of the Effective Date: (i) it is validly existing
and in good standing in the state in which it is organized, (ii) it is the proper party to amend the Special
Contract, and (iii) it has the requisite authority to execute this First Amendment.
8.Counterparts. This First Amendment may be executed in any number of counterparts, each of
which shall be deemed an original and all of which taken together shall constitute a single instrument. A
signature in “PDF” format or an electronic signature to this First Amendment shall be deemed an original
and binding upon the Party against which enforcement is sought.
9.Governing Law. Unless otherwise expressly provided herein, the terms and conditions of this First
Amendment shall be governed by, controlled, construed, and enforced in accordance with the laws and
decisions of the state of Idaho applicable to agreements to be made and to be performed in Idaho without
regard to principles of conflicts of law.
[Signatures appear on the following page]
First Amendment to the Special Contract

Page 3 of 3
IN WITNESS WHEREOF, the Parties hereto have caused this First Amendment to the Special
Contract to be executed by the duly authorized representatives as of the date first set forth above.
BRISBIE LLC.
By:
Name:
Title:
IDAHO POWER COMPANY
By:
Name:
Title:
Revised Exhibit 3.1
Page | 1
ATTACHMENT TO
FIRST AMENDMENT TO THE SPECIAL CONTRACT
BETWEEN
IDAHO POWER COMPANY AND
BRISBIE, LLC
Revised Exhibit 3.1: Pricing
If energy output from all Projects in any Hour is greater than the energy requirement for the Total Supply
Obligation in such Hour, then Customer will be credited the amount of such excess times the Excess
Generation Price for Block 1 and Block 2.
“Block 1” means the first 20 MW of the Total Supply Obligation.
“Block 2” means Total Supply Obligation exceeding the first 20 MW.
Pricing components will be updated at the following intervals:
Block 1 (19-
T Rates)
Block 2 –
Billing
Demand
Charge
Block 2 –
Contract
Demand
Block 2 –
Daily Excess
Demand
Block 2 –
Supplement
Energy Price
Excess
Generation Price
Renewable
Capacity
Credit
General Rate
Case
Other
Revenue
Requirement
Filing
General
Rate Case
Other
Revenue
Requirement
Filing
General
Rate
Case
General Rate
case
Upon IPUC IRP
acknowledgment
Upon IPUC IRP
acknowledgment
Execution
of the
Renewable
Resource
PPA or the
Parties’
agreement
to procure
or
construct
the Idaho
Power-
owned
Renewable
Resource,
as
applicable,
subject to
IPUC
approval
Block 1
POWER FACTOR ADJUSTMENT Where the Customer’s Power Factor is less than 95 percent, as
determined by measurement under actual load conditions, the Company may adjust the kW measured to
determine the Billing Demand by multiplying the measured kW by 95 percent and dividing by the actual
Power Factor.
“Block 1 Pricing” means the retail rates as defined in Idaho Power Company’s current Idaho retail tariff
Schedule 19 Large Power Service – Transmission Service plus the Embedded Energy Fixed Cost Rate.
If energy output from all Projects in any Hour is less than the energy requirement for the Block 1 Total
Supply Obligation for such Hour, then Customer will be charged amount of such deficit times the
applicable Block 1 Pricing Energy Charge.
If energy output from all Projects in any Hour meets any portion of the energy requirement for the Block
1 Total Supply Obligation for such Hour, then Customer will be charged amount of such portion times the
Embedded Energy Fixed Cost Rate.
Block 1 Total Supply Obligation capacity requirements will be charged under the Basic Load Capacity;
Billing Demand, and On-Peak Billing Demand pricing components as defined under Block 1 Pricing.
Block 1 will also be subject to Service Charge and other Monthly Charges as defined under Block 1
Pricing.
“Embedded Energy Fixed Cost Rate” means the per kilowatt hour rate of cost-of-service classified fixed
costs embedded in Schedule 19 Large Power Service - Transmission Energy Charges. The Embedded
Energy Fixed Cost Rate is the difference between the Block 1 Pricing Energy Charge less the Embedded
Energy Rate.
“Embedded Energy Rate” means the per kilowatt hour rate of cost-of-service classified energy costs
included in Schedule 19 Large Power Service - Transmission Energy Charges. The rate will be reset with
each Idaho Power filing in Idaho which increases or decreases Schedule 19 - Transmission revenue
requirement.
Block 2
POWER FACTOR ADJUSTMENT Where the Customer’s Power Factor is less than 95 percent, as
determined by measurement under actual load conditions, the Company may adjust the kW measured to
determine the Billing Demand by multiplying the measured kW by 95 percent and dividing by the actual
Power Factor.
If energy output from all Projects in any Hour does not meet the energy requirement for the Block 2 Total
Supply Obligation for such Hour, then Customer will be charged amount of such deficit times the
Supplemental Energy Price.
Revised Exhibit 3.1
Page | 2
“Administrative Charge” is equal to 5 percent of the portion of the Excess Generation Credit and/or the
Monthly Adjusted Renewable Capacity Credit that is recovered through the Power Cost Adjustment and
that Idaho Power allocates to the State of Idaho. The Administrative Charge will be determined and
applied monthly.
“Annual Renewable Capacity Credit” means the product of the Renewable Capacity Contribution and the
Renewable Capacity Credit Rate.
“Block 2 Billing Demand” means the Block 2 Total Supply Obligation capacity requirement average kW
supplied during the 15-consecutive-minute period of maximum use during the Monthly billing period,
adjusted for Power Factor.
“Block 2 Billing Demand Charge” means the Block 2 Billing Demand Charge as defined in Schedule 33.
A steady-state Total Supply Obligation assumption is used to derive the initial Block 2 Billing Demand
Charge and the underlying Total Supply Obligation steady-state assumption will remain applicable until
the rate effective date following Idaho Power’s next Idaho general rate case. Alternatively, should
Brisbie’s Total Supply Obligation exceed 30 MW, either Party may propose to re-calculate the block 2
Billing Demand Charge based upon the then current load characteristics and steady-state operating
assumptions; subject to IPUC approval.
“Capacity Contribution Factor” is based on the capacity contribution methodology and preferred portfolio
resource addition timing of the most recently acknowledged IRP, is set at the time of execution of the PPA
or the Parties’ agreement to procure or construct the Idaho Power owned renewable resource. Capacity
Contribution Factor remains the same value for the duration of the term of the PPA or the period of time
during which the Idaho Power-owned resource will provide Project output to Brisbie, as applicable. For
the 2019 Second Amended IRP this value is 31.21% for a 200 megawatt, single-axis, utility scale solar
photovoltaic resource.
“Contract Demand Charge” is the sum of Idaho Power’s effective Open Access Transmission Tariff firm
point-to-point transmission service provided under its Schedule 7 plus (1) the product of Schedule 3
Compensation for Regulation and Frequency Response Service multiplied by the minimum requirement;
(2) the product of Schedule 5 Operating Reserves – Spinning Reserve Service Compensation multiplied
by the minimum requirements, and (3) the product of Schedule 6 Operating Reserves – Supplemental
Reserve Service Compensation multiplied by the minimum requirements. The Contract Demand Charge
will be reset by the then effective Idaho Power Open Access Transmission Tariff at the time of an Idaho
Power general rate case.
“Excess Demand” means Block 2 Billing Demand in excess of the Contract Demand.
“Daily Excess Demand Charge” is the annual incremental charge for 1 MW above Contract Demand,
recovered in a single month, computed as a daily rate.
“Embedded Generation and Transmission Charge” means the total amount of Block 2 Billing Demand for
the Month times the Block 2 Demand Charge, plus Block 2 Contract Demand for the Month times the
Contract Demand Charge, plus Daily Excess Demand for the Month times the Daily Excess Demand
Charge.
Revised Exhibit 3.1
Page | 3
“Excess Generation” means the amount for each Hour by which energy from all Projects exceeds the Total
Supply Obligation energy requirement.
“Excess Generation Credit” means the total amount of Excess Generation for the Month times the Excess
Generation Price.
“Excess Generation Price” means the lower of (1) 85 percent of the hourly Mid-Columbia price forecast
used in Idaho Power’s most recently IPUC acknowledged Integrated Resource Plan (IRP), with non-firm
adjustment of 82.4% applied to each hour’s price, or (2) the actual heavy or light load hour (as applicable)
Mid-Columbia market price for each hour of Excess Generation delivered. The non-firm adjustment will
be based on the rate contained within Schedule 86 or its successor schedule. Proposed Excess Generation
Price will be filed concurrent with IRP filing and will become effective the month following IPUC
acknowledgement of the corresponding IRP, and cover a twenty-four month term, or until IPUC
acknowledgement of the subsequent IRP. See Attachment No. 1 to the Special Contract for Effective
Excess Generation Price from the 2019 Second Amended IRP for the period 2024 through 2026. A sample
page of the Attachment is included as Exhibit 3.6.
“Monthly Adjusted Renewable Capacity Credit” is the product of the Monthly Unadjusted Renewable
Capacity Credit and the Performance Ratio Adjustment Factor. The Monthly Adjusted Renewable
Capacity Credit will be provided to Brisbie monthly, starting the month of the respective Project’s
Renewable Capacity Credit Eligibility Date (contained in Schedule 33) or the month following the
commercial operation date of the applicable Project, whichever is later, and will remain in effect for the
duration of the term of the Renewable Resource PPA or the period of time during which the Idaho Power-
owned Renewable Resource will provide Project Output to Brisbie, as applicable.
“Monthly Unadjusted Renewable Capacity Credit” is the maximum monthly payment available to Brisbie
with respect to a Renewable Resource PPA based on the Annual Renewable Capacity Credit, and is subject
to adjustment by applying the Performance Ratio Adjustment Factor. The Monthly Unadjusted Renewable
Capacity Credit will be determined at time of execution of the Renewable Resource PPA or the Parties’
agreement to procure or construct the Idaho Power-owned Renewable Resource, as applicable, and will
be subject to IPUC approval.
"Performance Ratio Adjustment Factor" is the adjustment to be applied to the Monthly Unadjusted
Renewable Capacity Credit and is determined at time of execution of the Renewable Resource PPA or the
Parties’ agreement to procure or construct the Idaho Power-owned renewable resource, as applicable, and
will be subject to IPUC approval. Idaho Power will provide the Performance Ratio Adjustment Factor to
Brisbie at least 5 days in advance of execution of the respective PPA or the Parties’ agreement to procure
or construct the Idaho Power owned renewable resource. Schedule 33 will include reference to the IPUC
docket where Performance Ratio Adjustment Factor methodology is detailed.
“REC Administrative Charge” means Idaho Power’s actual costs, if any, charged by WREGIS for
transferring WREGIS Certificates from Idaho Power’s WREGIS account to Customer’s WREGIS
Account, if any, the Parties acknowledging that no REC Administrative Charge is expected to be incurred
because Environmental Attributes are intended to be transferred directly from the projects to Customer.
Revised Exhibit 3.1
Page | 4
Revised Exhibit 3.1
Page | 5
“Renewable Capacity Contribution” means the Project MW AC nameplate capacity multiplied by the
Capacity Contribution Factor.
“Renewable Capacity Credit Rate” is based on the Avoided Levelized Capacity Costs included as part of
Demand-Side Management Assumptions in the most recently acknowledged IRP. Renewable Capacity
Credit Rate is set at the time of PPA execution and remains the same value for the duration of that PPA’s
term. For the 2019 Second Amended IRP this value is $121.19/kW-year for a Reciprocating Internal
Combustion Engine (RICE), found in the IRP Technical Appendix C, p.18, under Demand-Side Resource
Data.
“Supplemental Energy” means the amount for each Hour by which energy output from all projects is less
than (b) the Block 2 Total Supply Obligation energy requirement.
“Supplemental Energy Price” means the marginal price averages published in Idaho Power’s most recently
IPUC acknowledged Integrated Resource Plan (IRP) Technical Appendix C, excluding capacity costs in
any on the five seasonal time periods. Seasonal time periods for the Supplemental Energy Price match
the seasonal time periods used to determine the marginal price averages from the reference IRP. Proposed
Supplemental Energy Price will be filed concurrently to IRP filing and will become effective the month
following IPUC acknowledgement of the corresponding IRP, and cover a twenty-four month term, or until
IPUC acknowledgement of the subsequent IRP.
“Supplemental Energy Cost” means the total amount of Supplemental Energy for the Month times the
Supplemental Energy Price.
“Monthly Contract Payment” shall be
[A plus B plus C plus D minus E minus F plus G plus H]
plus
[Idaho Power’s Schedule 91 Energy Efficiency Rider multiplied by the sum of [C plus D ]] if more than
zero
plus
[Applicable charge from Idaho Power Schedule 95 Adjustments for Municipal Franchise Fees multiplied
by the sum of [A plus C plus D minus E minus F plus G plus H]]
where:
A = Tariff/PPA pass-through Payment
B = Block 1 Pricing
C = Embedded Generation and Transmission Charge
D = Supplemental Energy Cost
E = Excess Generation Credit
F = Monthly Adjusted Renewable Capacity Credit
G = REC Administrative Charge
H = Administrative Charge

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-42

IDAHO POWER COMPANY

ATTACHMENT 3

Schedule 33
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.

SPECIAL CONTRACT DATED DECEMBER 22, 2021, AMENDED AUGUST 3, 2023

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 95 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 95 percent and dividing by the actual Power Factor.

BLOCK 1

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 1:00 p.m. to 9:00 p.m. Monday through Friday, except holidays
Mid-Peak: 7:00 a.m. to 1:00 p.m. and 9:00 p.m. to 11:00 p.m. Monday through Friday,
except holidays, and 7:00 a.m. to 11:00 p.m. Saturday and Sunday, except
holidays
Off-Peak: 11:00 p.m. to 7:00 a.m. Monday through Sunday and all hours on holidays

Non-summer Season
Mid-Peak: 7:00 a.m. to 11:00 p.m. Monday through Saturday, except holidays
Off-Peak: 11:00 p.m. to 7:00 a.m. Monday through Saturday and all hours on Sunday
and holidays
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveOct. 12, 2023 May 11, 2023 Per ON 35958 & 35777 Jan Noriyuki Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

TIME PERIODS (Continued)

The holidays observed by the Company are New Year’s Day, Memorial Day, Independence Day,
Labor Day, Thanksgiving Day, and Christmas Day. When New Year’s Day, Independence Day, or
Christmas Day falls on a Sunday, the Monday immediately following that Sunday will be considered a
holiday.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The
non-summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-summer

Service Charge, per month $299.00 $299.00

Basic Charge, per kW of
Basic Load Capacity $0.71 $0.71

Demand Charge, per kW of
Billing Demand $5.93 $4.41

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.97 n/a

Energy Charge, per kWh
On-Peak 5.2447¢ n/a
Mid-Peak 4.1889¢ 3.9577¢
Off-Peak 3.7394¢ 3.5383¢

Embedded Energy Fixed Cost Rate, per kWh
On-Peak 2.4311¢ n/a
Mid-Peak 1.3753¢ 1.1441¢
Off-Peak 0.9258¢ 0.7247¢

IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveOct. 12, 2023 May 11, 2023 Per ON 35958 & 35777 Jan Noriyuki Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

BLOCK 2

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).
Terms used below have the meanings given to them in the Special Contract referenced above.

Daily Excess Demand Charge
$1.196 per each kW over the Contract Demand.

Excess Generation Credit
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021 as
amended.

Monthly Contract Demand Charge
$2.99 per kW of Contract Demand.

Monthly Billing Demand Charge
$10.75 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.

Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos. 1, 2, 3, and Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated
December 22, 2021, as amended.

Renewable Resource Cost
As included in the Monthly Contract Payment listed in Revised Exhibit 3.1 of Brisbie, LLC’s Special
Contract, December 22, 2021, as amended.

Supplemental Energy Cost
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Administrative Charge
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveOct. 12, 2023 May 11, 2023 Per ON 35958 & 35777 Jan Noriyuki Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

Renewable Resource Agreements

Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the
tables below. The Monthly Adjusted Renewable Capacity Credit will be provided to Brisbie, LLC
monthly, starting the month of the Project’s Renewable Capacity Credit Eligibility Date (as defined in
Table 3) or the month following the respective Project’s commercial operation date, whichever is later,
and will remain in effect for the duration of the term of the Renewable Resource PPA or the period of
time during which the Idaho Power-owned Renewable Resource will provide Project Output to Brisbie,
LLC as applicable. The Monthly Adjusted Renewable Capacity Credit will be provided in accordance
with Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated December 22, 2021, as amended.

TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently
Acknowledged
IRP
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor

Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit Rate
($/kW-yr)
Renewable
Capacity
Credit
Adjustment

Annual
Renewable
Capacity
Credit*+
c*d*e
Pleasant
Valley
Solar
LLC
2019 200,000 0.3121 62,420 $121.19 1.0 $7,564,680
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
+Table 3 denotes each project’s date of eligibility for the Annual Renewable Capacity Credit.

TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Jan Feb June July Aug Sept

Oct Nov Dec
Pleasant
Valley
Solar LLC1
$416,057 $416,057 $1,380,554 $2,761,108 $1,380,554 $189,117 $189,117 $416,057 $416,057

TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Pro ect PPA Execution Date Capacit Deficienc Year Renewable Capacit Credit Eli ibilit Date
Pleasant
Valley
Solar LLC
10/27/2022 2023 6/1/2023

1 Amounts to be adjusted by the Performance Ratio Adjustment Factor, which is calculated pursuant to the methodology
detailed in Case No. IPC-E-21-42, Attachment 1 to Idaho Power Company’s Compliance Filing dated August 9, 2023, as
approved in Order No. 35777 (May 11, 2023), to determine the Monthly Adjusted Renewable Capacity Credit.
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveOct. 12, 2023 May 11, 2023 Per ON 35958 & 35777 Jan Noriyuki Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.

SPECIAL CONTRACT DATED DECEMBER 22, 2021, AMENDED AUGUST 3, 2023

POWER FACTOR ADJUSTMENT

Where the Customer’s Power Factor is less than 95 percent, as determined by measurement
under actual load conditions, the Company may adjust the kW measured to determine the Billing Demand
by multiplying the measured kW by 95 percent and dividing by the actual Power Factor.

BLOCK 1

BASIC LOAD CAPACITY

The Basic Load Capacity is the average of the two greatest monthly Billing Demands established
during the 12-month period which includes and ends with the current Billing Period, but not less than
1,000 kW for Large Power Service.

BILLING DEMAND

The Billing Demand is the average kW supplied during the 15-consecutive-minute period of
maximum use during the Billing Period, adjusted for Power Factor.

ON-PEAK BILLING DEMAND

The On-Peak Billing Demand is the average kW supplied during the 15-minute period of maximum
use during the Billing Period for the On-Peak time period.

TIME PERIODS

The time periods are defined as follows. All times are stated in Mountain Time.

Summer Season
On-Peak: 1:00 p.m. to 9:00 p.m. Monday through Friday, except holidays
Mid-Peak: 7:00 a.m. to 1:00 p.m. and 9:00 p.m. to 11:00 p.m. Monday through Friday,
except holidays, and 7:00 a.m. to 11:00 p.m. Saturday and Sunday, except
holidays
Off-Peak: 11:00 p.m. to 7:00 a.m. Monday through Sunday and all hours on holidays

Non-summer Season
Mid-Peak: 7:00 a.m. to 11:00 p.m. Monday through Saturday, except holidays
Off-Peak: 11:00 p.m. to 7:00 a.m. Monday through Saturday and all hours on Sunday
and holidays
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

TIME PERIODS (Continued)

The holidays observed by the Company are New Year’s Day, Memorial Day, Independence Day,
Labor Day, Thanksgiving Day, and Christmas Day. When New Year’s Day, Independence Day, or
Christmas Day falls on a Sunday, the Monday immediately following that Sunday will be considered a
holiday.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The
non-summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set
forth in Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy Efficiency Rider), and Schedule 95
(Adjustment for Municipal Franchise Fees).

Summer Non-summer

Service Charge, per month $299.00 $299.00

Basic Charge, per kW of
Basic Load Capacity $0.701 $0.701

Demand Charge, per kW of
Billing Demand $5.893 $4.3341

On-Peak Demand Charge, per kW of
On-Peak Billing Demand $0.957 n/a

Energy Charge, per kWh
On-Peak 5.15302447¢ n/a
Mid-Peak 4.11561889¢ 3.88859577¢
Off-Peak 3.67407394¢ 3.47645383¢

Embedded Energy Fixed Cost Rate, per kWh
On-Peak 2.39824311¢ n/a
Mid-Peak 1.36083753¢ 1.11337441¢
Off-Peak 0.91929258¢ 0.72167247¢

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

BLOCK 2

Capacity Contribution Factor is based on the capacity contribution methodology and preferred portfolio
resource addition timing of the most recently acknowledged IRP at the time the PPA is executed.
Capacity Contribution Factor is set at the time of PPA, or other renewable resource agreement execution
and remains the same value for the duration of that agreement’s term.

Excess Generation Price means the hourly Mid-Columbia price forecast used in Idaho Power’s most
recently IPUC acknowledged Integrated Resource Plan (IRP), with non-firm adjustment of 82.4% applied
to each hour’s price. Proposed Excess Generation Price will be filed concurrent with IRP filing and will
become effective the month following IPUC acknowledgement of the corresponding IRP, and cover a
twenty-four month term, or until IPUC acknowledgement of the subsequent IRP.

Metered Output means, for each Project, the electrical output and capacity of the Project delivered to, or
generated by, Idaho Power by the applicable Renewable Resource.

Project means a new Renewable Resource or the independently metered portions thereof, the Project
Output of which is either: (1) purchased as a simultaneously bundled product by Idaho Power under a
Renewable Resource PPA; or (2) provided as a simultaneously bundled product by Idaho Power from an
Idaho Power owned resource.

Project Output means for each Project, the Metered Output and Environmental Attributes as a
simultaneously bundled product of that Project, either owned by Idaho Power or to be purchased by Idaho
Power in accordance with the Renewable Resource PPA.

Renewable Capacity Contribution means the Project megawatts (MW) in alternating current (AC)
nameplate capacity multiplied by the Capacity Contribution Factor.

Renewable Capacity Credit means the product of the Renewable Capacity Contribution and the
Renewable Capacity Credit Rate.

Renewable Capacity Credit Rate is based on the Avoided Levelized Capacity Costs included as part of
Demand-Side Management Assumptions in the most recently acknowledged IRP. Renewable Capacity
Credit Rate is set at the time of PPA or other renewable resource agreement execution and remains the
same value for the duration of that PPA’s or agreement’s term.

Renewable Resource means an electric generating facility utilizing solar photovoltaic (PV), wind, energy
storage or other mutually-agreed technology or combination thereof from which Idaho Power either: (1)
purchases the bundled Metered Output and Environmental Attributes bundled under a Renewable
Resource PPA, and that will be newly constructed and made operational after the Renewable Resource
PPA execution date, or (2) provides the bundled Metered Output and Environmental Attributes from an
Idaho Power owned resource, that will be newly constructed and made operational for the purpose of
acquiring Project Output in connection with the Brisbie Special Contract.

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

Renewable Resource PPA means a power purchase agreement (PPA) entered into by Idaho Power for
the purpose of acquiring Project Output in connection with the Brisbie LLC Special Contract.

Supplemental Energy Cost means the total amount of Supplemental Energy for the month times the
Supplemental Energy Price.

Supplemental Energy means the amount for each hour by which energy output from all projects is less
than (b) the Block 2 Total Supply Obligation energy requirement.

Supplemental Energy Price means the marginal price averages published in Idaho Power’s most recently
IPUC acknowledged Integrated Resource Plan (IRP) Technical Appendix C, excluding capacity costs in
any of the seasonal time periods. Seasonal time periods for the Supplemental Energy Price match the
seasonal time periods used to determine the marginal price averages from the reference IRP. Proposed
Supplemental Energy Price will be filed concurrently to IRP filing and will become effective the month
following IPUC acknowledgement of the corresponding IRP, and cover a twenty-four month term, or until
IPUC acknowledgement of the subsequent IRP.

Total Supply Obligation means the aggregate electricity delivered to the Delivery Point for the full capacity
and energy requirements of the Data Facility adjusted for Line Losses.
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth in
Schedule 91 (Energy Efficiency Rider), and Schedule 95 (Adjustment for Municipal Franchise Fees).
Terms used below have the meanings given to them in the Special Contract referenced above.

Daily Excess Demand Charge
$1.196 per each kW over the Contract Demand.

Excess Generation Credit
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021 as
amended.

Monthly Contract Demand Charge
$2.99 per kW of Contract Demand.

Monthly Billing Demand Charge
$10.75 per kW of Billing Demand but not less than Minimum Monthly Billing Demand.

Minimum Monthly Billing Demand
The Minimum Monthly Billing Demand will be 20,000 kilowatts.

Monthly Adjusted Renewable Capacity Credit(s)
See Table Nos. 1, 2, 3, and Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated
December 22, 2021, as amended.

Renewable Capacity Credit
Renewable Resource Cost
As included in the Monthly Contract Payment listed in Revised Exhibit 3.1 of Brisbie, LLC’s Special
Contract, December 22, 2021, as amended.

Supplemental Energy Cost
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Administrative Charge
As defined in Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, December 22, 2021, as
amended.

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho

SCHEDULE 33
IDAHO POWER COMPANY
ELECTRIC SERVICE RATE
FOR
BRISBIE, LLC.
(Continued)

BLOCK 2

Renewable Resource Agreements

Calculation of the Monthly Unadjusted Renewable Capacity Credit for each Project is quantified in the
tables below. The Monthly Adjusted Renewable Capacity Credit will be provided to Brisbie, LLC
monthly, starting the month of the Project’s Renewable Capacity Credit Eligibility Date (as defined in
Table 3) or the month following the respective Project’s commercial operation date, whichever is later,
and will remain in effect for the duration of the term of the Renewable Resource PPA or the period of
time during which the Idaho Power-owned Renewable Resource will provide Project Output to Brisbie,
LLC as applicable. The Monthly Adjusted Renewable Capacity Credit will be provided in accordance
with Revised Exhibit 3.1 of Brisbie, LLC’s Special Contract, dated December 22, 2021, as amended.

(a) (b) (c) (d) (e)
Project PPA
Execution
Date
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor
(percent)
Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit Rate
($/kW-mo)
Renewable
Capacity
Credit; monthly
(c * d)
No. 1
TABLE 1: RENEWABLE CAPACITY CREDIT
a b c d e f
Project Most Recently
Acknowledged
IRP
Project
Nameplate
(kW AC)
Capacity
Contribution
Factor

Renewable
Capacity
Contribution
(a * b)
Renewable
Capacity
Credit Rate
($/kW-yr)
Renewable
Capacity
Credit
Adjustment

Annual
Renewable
Capacity
Credit*+
c*d*e
Pleasant
Valley
Solar
LLC
2019 200,000 0.3121 62,420 $121.19 1.0 $7,564,680
*Table 2 denotes the Monthly Unadjusted Renewable Capacity Credit.
+Table 3 denotes each project’s date of eligibility for the Annual Renewable Capacity Credit.

TABLE 2: MONTHLY UNADJUSTED RENEWABLE CAPACITY CREDIT BY MONTH
Jan Feb June July Aug Sept

Oct Nov Dec
Pleasant
Valley
Solar LLC1
$416,057 $416,057 $1,380,554 $2,761,108 $1,380,554 $189,117 $189,117 $416,057 $416,057

TABLE 3: ELIGIBILITY DATE FOR RENEWABLE CAPACITY CREDIT
Pro ect PPA Execution Date Capacit Deficienc Year Renewable Capacit Credit Eli ibilit Date

1 Amounts to be adjusted by the Performance Ratio Adjustment Factor, which is calculated pursuant to the methodology
detailed in Case No. IPC-E-21-42, Attachment 1 to Idaho Power Company’s Compliance Filing dated August 9, 2023, as
approved in Order No. 35777 (May 11, 2023), to determine the Monthly Adjusted Renewable Capacity Credit.
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 33-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35777 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – May 11, 2023 1221 West Idaho Street, Boise, Idaho
Pleasant
Valley
Solar LLC
10/27/2022 2023 6/1/2023