20240819PAC to Staff 142-144 and 146-154.pdf

RECEIVED
Monday, August 19, 2024
IDAHO PUBLIC
UTILITIES COMMISSION
_ ROCKY MOUNTAIN
POWER
A DIVISION OF PACIFICORP
1407 W North Temple, Suite 330
Salt Lake City, Utah 84116
August 19, 2024
Monica Barrios-Sanchez
Commission Secretary
Idaho Public Utilities Commission
11331 W. Chinden Blvd.
Bldg. 8, Ste. 201-A
Boise, ID 83714
monica.barrio ssanchez(apuc.Idaho.gov
S ecretarygpuc.idaho.gov
RE: ID PAC-E-24-04
IPUC Set 8 (130-154)
Please find enclosed Rocky Mountain Power's Responses to IPUC 8t' Set Data Requests 142-
144 and 146-154. The remaining response will be provided under separate cover. Provided via
BOX are Confidential Attachments. Confidential information is provided subject to protection
under IDAPA 31.01.01.067 and 31.01.01.233, the Idaho Public Utilities Commission's Rules of
Procedure No. 67—Information Exempt from Public Review, and further subject to the non-
disclosure agreement(NDA)executed in this proceeding.
If you have any questions, please feel free to call me at [phone].
Sincerely,
/s/
Mark Alder
Manager, Regulation
Enclosures
C.c.: Eric L. Olsen/IIPA elo(&echohawk.com(C)
Lance Kaufman/IIPA lancekae.isg insi hg t.com(C)
Matthew Nykiel/ICL matthew.nykiel&amail.com
Brad Heusinkveld/ICL bheusinkveld(&idahoconservation.org
Thomas J. Budge/Bayer ti(&racineolson.com(C)
Brian C. Collins/Bayer bcollins(&consultbai.com
Greg Meyer/Bayer gmeyerkconsultbai.com
Kevin Higgins/Bayer khig gins kenergystrat.com(C)
Neal Townsend/Bayer ntownsendkenergystrat.com (C)
Ronald L. Williams/PIIC rwilliams(&hawleytroxell.com

Brandon Helgeson/PIIC bhelgeson(&hawleytroxell.com
Bradley Mullins/PIIC brmullinskmwanalytics.com
Val Steiner/PIIC val.steiner(a-)itafos.com
Kyle Williams/PIIC williamsknasbyui.edu

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 142
IPUC Data Request 142
Please provide documentation and explain the accounting treatment applied to any
fines or penalties assigned to the Company or representatives acting as the
Company's agent during the course of Capital Project related activities impacting
any Public Right-Of-Way.
Response to IPUC Data Request 142
The Company or representatives acting as the Company's agent have not been
subject to any fines or penalties during the course of capital project activities that
impact public rights-of-way.
Recordholder: Sheila Diver/Justus Evangelista/Zachary Rogala
Sponsor: Sheila Diver/Justus Evangelista/Zachary Rogala

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 143
IPUC Data Request 143
Please explain the accounting treatment applied to insurance settlements received
for the recovery cost of repairs to Company assets that were damaged due to
vehicle crashes or other human causes and how it impacts the customer rate base.
Response to IPUC Data Request 143
Recoveries from insurance reimbursing the Company for capital costs incurred to
replace damaged assets due to vehicle crashes or other human causes are credited
to accumulated depreciation which reduces rate base.
Recordholder: Justus Evangelista
Sponsor: Shelley McCoy

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 144
IPUC Data Request 144
Please describe if the Company has any criteria in place to determine if
Contractors are ineligible to bid on or be awarded a contract with the Company.
Response to IPUC Data Request 144
The Company's criteria for determining if contractors are ineligible to bid on or
be awarded a contract are unique to specific goods and/or services being procured
and can vary based upon the nature of the project and the risk potential. However
items that are typically considered include: a review of contractor for foreign
control or influence, contractor's information security policies, cyber security
score, financial stability, safety record and programs, environmental policies,
insurance, and past contractor performance.
Recordholder: Marion Stanwood
Sponsor: Marion Stanwood

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 146
IPUC Data Request 146
McCoy's work paper"3.5 —Wheeling Revenue. xlsx" lists the following items
that do not have proforma adjustments:
• Transmission Tariff True-up;
• Pre-Merger Firm Wheeling Revenue—PPD;
• Non-Firm Wheeling Revenue;
• Short-Term Firm Wheeling;
• Ancillary Rev Sch 6—Supp (Transm);
• Ancillary Rev Sch 6 —Supp (C&T);
• Ancil Revenue Sch 2 -Reactive (C&T);
• Ancil Revenue Sch 3a—Regulation (Trans);
• Primary Delivery and Distribution Sub Charges;
• Ancillary Revenue Sch 3 —Reg&Freq(Transm);
• Ancillary Revenue Sch 3 —Reg&Freq(C&T);
• Ancillary Rev Sch 5 —Spin (Transm);
• Ancillary Rev Sch 5 -Spin (C&T);
• Ancil Revenue Sch 3a-Regulation (C&T);
• I/C Anc Rev Sch 1- Scheduling -Nevada Pwr 302082;
• I/C Anc Rev Sch 1- Scheduling -Nevada Pwr 302092;
• I/C Anc Rev Sch 1- Scheduling -Nevada Pwr 302822;
• I/C Other Wheeling Revenue—Sierra Pac;
• Use of Facility Revenue;
• Transmission Capacity Resales;
• Transmission Capacity Resales;
• Transmission Resales to Other Parties;
• Transmission Rev-Unreserved Use Charges;
• Transmission Schedule 3 Refund Reserve;
• Transmission Schedule 3a Refund Reserve;
• Transmission Schedule 5 Refund Reserve;
• Transmission Schedule 6 Refund Reserve; and
• Transmission Revenue-Deferral Fees.
Please define these items and explain why they do not have proforma
adjustments.
Response to IPUC Data Request 146
Please refer to the explanations provided below:
• Transmission Tariff True-up; Account used to track transmission formula rate
impacts for the prior year. Of the $18,012,498 adjustment included in the

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 146
work paper, approximately $3,942,935 represents reversing out the refunds
included in the account.
• Pre-Merger Firm Wheeling Revenue—PPD: This account represents revenues
under legacy agreements with static rates. Thus, usage changes were not
evaluated due to revenue impacts as minimal.
• Non-Firm Wheeling Revenue: represents customers who acquire short-term
non-firm transmission. Revenue impacts flow through the formula rate
process, so adjustments not considered as this just ends up impacting the rate
assessed to long-term customers. In addition, that Company does not have
information to be able to determine usage from customers in the future as
there are numerous factors that impact the decisions in customers purchasing
transmission.
• Short-Term Firm Wheeling: represents customers who acquire short-term firm
transmission. Revenue impacts flow through the formula rate process, so
adjustments not considered as this just ends up impacting the rate assessed to
long-term customers. In addition, the Company does not have information to
be able to determine usage from customers in the future as there are numerous
factors that impact the decisions in customers purchasing transmission.
• Ancillary Rev Sch 6—Supp (Transm): This account represents ancillary
services for non-spin reserves and account used for tracking purposes. The
account balance is zero as revenue reflected in the below account.
• Ancillary Rev Sch 6 —Supp (C&T); This account represents ancillary services
for non-spin reserves. Rates for service are hourly and usage changes have
minimal impacts therefore GRC does not model changes.
• Ancil Revenue Sch 2 -Reactive (Transm); This account represents ancillary
services for reactive supply used for tracking purposes. The account balance is
zero as revenue reflected in the below account.
• Ancil Revenue Sch 2 -Reactive (C&T); This account represents ancillary
services for reactive supply. Usage impacts do not materially impact revenues
therefore no adjustments proposed.
• Ancil Revenue Sch 3a—Regulation (Trans); This account represents ancillary
services for generation regulation used for tracking purposes. The account
balance is zero as revenue reflected in the below account.
• Ancil Revenue Sch 3a—Regulation (C&T); This account represents ancillary
services for generation regulation. No adjustments were modeled as new
resources were not identified as having a material impact for 2025 and thus,

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 146
not included in the adjustments.
• Primary Delivery and Distribution Sub Charges; This account is used to track
the customers with contracts serving load in the balancing area and the
contracts have additional charges for load served at primary delivery voltage
or distribution substation charges. The account is less than 0.5 million per year
and rates are changes in load volumes are not going to have a large impact on
the revenues.
• Ancillary Revenue Sch 3 —Reg&Freq(Transm); This account represents
ancillary services for regulation charges for customers serving load. This
account is used for tracking purposes. The account balance is zero as revenue
reflected in the below account.
• Ancillary Revenue Sch 3 —Reg&Freq(C&T); This account represents
ancillary services for regulation charges for customers serving load. There are
no adjustments to this account as the impact on revenues for changes in load is
not material.
• Ancillary Rev Sch 5 —Spin (Transm): This account represents ancillary
services for spin reserves and is the same activity as reported in account
below. The account balance is zero as revenue reflected in the below account.
• Ancillary Rev Sch 5 -Spin (C&T): This account represents ancillary services
for spin reserves. Rates for service are hourly and usage changes have
minimal impacts therefore GRC does not model changes.
• I/C Anc Rev Sch 1- Scheduling -Nevada Pwr 302082; This account is used to
track charges with Nevada Power covering Schedule 1 —Scheduling and
Dispatch Services of the tariff. No adjustments or made to this account as
similar to commentary for non-firm and short-term firm wheeling activity.
• I/C Anc Rev Sch 2- Scheduling -Nevada Pwr 302092; This account is used to
track charges with Nevada Power covering Schedule 2—Reactive Supply of
the tariff. No adjustments or made to this account as similar to commentary
for non-firm and short-term firm wheeling activity.
• I/C Anc Rev Sch 1- Scheduling -Nevada Pwr 302822; This account is used to
track charges with Nevada Power covering non-firm transmission service. No
adjustments or made to this account as similar to commentary for non-firm
and short-term firm wheeling activity.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 146
• I/C Other Wheeling Revenue—Sierra Pac; This account is used to track
activity with this customer, which is a fixed charge under $50k/year. No
anticipated changes in the next few years.
• Use of Facility Revenue; This account is used to track activity with customers
with fixed charges per the agreement. Balance is under $1.0m annually. No
adjustments identified to occur in the next several years.
• Transmission Capacity Resales; This account is used to manage the
accounting for resales where the transmission provider is the banker. There is
not financial impact as the transmission provider collects 100% of the tariff
rate and passes through the impacts between the seller and buyer. No
adjustments necessary as there is no financial impacts for these transactions.
• Transmission Capacity Resales; This account is used to manage the
accounting for resales where the transmission provider is the banker. There is
not financial impact as the transmission provider collects 100% of the tariff
rate and passes through the impacts between the seller and buyer.No
adjustments necessary as there is no financial impacts for these transactions.
• Transmission Resales to Other Parties; This account is used to track resale
activity and represent the amounts buyer paid for the capacity at tariff. No
adjustments necessary as we do not forecast resale activity as there is no
financial impact for the resale,just a transaction exchange between buyer and
seller.
• Transmission Rev-Unreserved Use Charges; This account is used to track
charges for unauthorized use of transmission by customers. Customers are
assessed 200% of the transmission charge with 100% representing a penalty
that is offset in transmission expense for refunds to 3rd parties or retained to
cover the portion of penalty refund to be allocated to retail customers.
Generally no adjustments are provided as the portion of 100% of the charge is
a revenue credit in the formula rate. However, in this case an out of period
adjustment of$558,661.36 was added as an adjustment in error.
• Transmission Schedule 3 Refund Reserve: Account used for tracking purposes
as a result of the ancillary rate case. Account not presently in use.
• Transmission Schedule 3a Refund Reserve: Account used for tracking
purposes as a result of the ancillary rate case. Account not presently in use.
• Transmission Schedule 5 Refund Reserve: Account used for tracking purposes
as a result of the ancillary rate case. Account not presently in use.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 146
• Transmission Schedule 6 Refund Reserve: Account used for tracking purposes
as a result of the ancillary rate case. Account not presently in use.
• Transmission Revenue-Deferral Fees: Transmission customers provide a
deposit for one month of transmission service and termination or delay in start
date results in one month of revenues. No adjustments provided as revenue
not material and not able to forecast whether customers will terminate or defer
service scheduled to begin in 2025. Assumption is additional revenue
assuming customer starts service scheduled for 2025.
Recordholder: Ernie Knudsen
Sponsor: Ernie Knudsen

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 147
IPUC Data Request 147
McCoy's work paper"3.6 —Fly Ash Revenues.xlsx" shows an ash sales revenue
of$7,649,442 in 2024. Please explain how this revenue is determined and provide
the work paper that calculates this amount.
Response to IPUC Data Request 147
The Test Period (12 months ending December 2024) total-Company forecasted
Fly Ash Revenues of$7,649,442, consists of projected fly ash revenues at the
following plants Craig, Huntington,Naughton Jim Bridger Unit 3 and Jim Bridger
Unit 4. The forecasted fly ash revenues at Craig, Huntington and Naughton have
not changed from the Base Period (12 months ended December 2023). As for, Jim
Bridger Unit 3 and Jim Bridger Unit 4, the fly ash revenues forecast is developed
based on projection of fly ash tons produced multiplied by the price per ton
($/ton) over the forecast period.
Please refer to Confidential Attachment IPUC 147 which provides additional
support of the 2024 test year fly ash revenue forecast.
Confidential information is provided subject to protection under IDAPA
31.01.01.067 and 31.01.01.233, the Idaho Public Utilities Commission's Rules of
Procedure No. 67—Information Exempt from Public Review, and further subject
to the Non-Disclosure Agreement (NDA)executed in this proceeding.
Recordholder: Colin Sutherland
Sponsor: Shelley McCoy

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 148
IPUC Data Request 148
McCoy's work paper"5.2 —BOSR& WRAP &COSR Fees.xlsx" shows the
forecasted BOSR fees ($87,654), WRAP fees ($1,354,358), and COSR Materials
fees ($60,186) in 2024. Please explain how these amounts are determined and
provide work papers that calculate these amounts.
Response to IPUC Data Request 148
Please refer to the Company's response to IPUC Data Request 112 for
information on the Western Power Pool's(WPP) Western Resource Adequacy
Program(WRAP) fees.
Please refer to the Company's response to IPUC Data Request 113 for
information on the Committee of State Representatives (COSR) materials fees.
PacifiCorp used the actual fees from the Board of State Regulators (BOSR) in
2023 as an estimation of the fee for 2024.
Recordholder: Ben Faulkinberry/Vijay Singh
Sponsor: Paul Wood

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 149
IPUC Data Request 149
Please respond to the following regarding Tab 7.3.1 of McCoy's workpaper"7.3
—Production Tax Credit.xlsx":
(a) Please explain whether $208,356,059 is the forecasted PTC value in 2024;
(b) Please explain whether"Calendar Year 2023" in Line 6 should have been
"Calendar Year 2024";
(c) Please explain how each wind facility's monthly generation amount is
determined;
(d) If the OFPC natural gas forecasts in Aurora are changed, please explain if
each wind facility's monthly generation amount will change; andl
(e) If coal prices in Aurora are changed, please explain if each wind facility's
monthly generation amount will change.
Response to IPUC Data Request 149
(a) The forecasted production tax credit (PTC) value of$208,356,059 for the test
period is based on the 2025 net power costs (NPC) forecast, adjusted to 2023
weather normalized loads. The Company listed the date as 2023 consistent
with the weather normalized load forecast use for NPC.
(b) Please refer to the Company's response to subpart(a) above.
(c) In the context of PTCs, the Company first creates a wind forecast using either
48 months of wind history to create an annual capacity factor(CF) for
resources that have been in-service for 48 months or more, or an estimated
CF based on the economic analysis produced during the initial phases of each
project's development for resources that do not have 48 months of generation
history, to scale an hourly calendar year generation profile.
Once the expected wind forecast has been input into the Aurora model, final
wind generation is determined in-model through the security constrained
economic dispatch which ensures that relevant generation stays within the
bounds of relevant transmission capacity, consistent with actual operations.
Then, the Company uses the monthly generation produced by the Aurora
simulation from the NPC report and adjusts Glenrock I, Rolling Hills and
Glenrock III as stated in McCoy's work paper"7.6.1" section (b).
(d) Yes. Because Aurora is a least-cost optimization model with perfect
foresight, any change to inputs will create a new optimizable problem for the

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 149
model to solve and creates a new solution which will include the redispatch
of every dispatchable resource .
(e) Please refer to the Company's response to subpart (d) above.
Recordholder: Isaiah Zacharia/Brian Keyser/Nick Highsmith
Sponsor: Ramon Mitchell/Brian Keyser/Nick Highsmith

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 150
IPUC Data Request 150
Please respond to the following regarding Tab 7.6.1 of McCoy's work paper"7.6
—Wyoming Wind Generation Tax. xlsx":
(a) Please explain whether $4,047,681 is the forecasted Wyoming Wind
Generation Tax amount in 2024;
(b) Please explain whether"2023" in Line 6 should have been "2024";
(c) Please explain how each wind facility's generation amount in Column C is
determined;
(d) If the OFPC natural gas forecasts in Aurora are changed, please explain if
each wind facility's generation amount will change; and
(e) If coal prices in Aurora are changed, please explain if each wind facility's
generation amount will change.
Response to IPUC Data Request 150
Referencing Tab 7.6.1 of McCoy's work paper"7.6—Wyoming Wind Generation
Tax", the Company responds as follows:
(a) The $4,047,681 represents the forecasted Wyoming Wind Generation tax for
the test period based on the 2025 net power costs (NPC) forecast, adjusted to
2023 weather normalized loads. The Company listed the date as 2023
consistent with the weather normalized load forecast used for the NPC.
(b) Please refer to the Company's response to subpart (a) above.
(c) In the context of the Wyoming Wind Generation Tax, the Company first
creates a wind forecast using either 48 months of wind history to create an
annual capacity factor(CF) for resources that have been in-service for 48
months or more, or an estimated CF based on the economic analysis produced
during the initial phases of each project's development for resources that do
not have 48 months of generation history, to scale an hourly calendar year
generation profile.
Once the expected wind forecast has been input into the Aurora model, final
wind generation is determined in-model through the security constrained
economic dispatch which ensures that relevant generation stays within the
bounds of relevant transmission capacity, consistent with actual operations. .
Then, the Company uses the monthly generation produced by the Aurora

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 150
simulation from the NPC report as the forecasted amount of wind generation
to apply the Wyoming Wind Generation Tax.
(d) Please refer to the Company's response to IPUC Data Request 149, subpart
(d).
(e) Please refer to the Company's response to IPUC Data Request 149, subpart
(d).
Recordholder: Isaiah Zacharia/Brian Keyser/Nick Highsmith
Sponsor: Ramon Mitchell/Brian Keyser/Nick Highsmith

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 151
IPUC Data Request 151
Please provide the following information for the "U21 Major Inspection Overhaul
- CY23"project referenced in production response PAC-E-24-04 Attach IPUC
15. Please include any available workpapers with formulae intact. If any of the
information requested below cannot be provided or is not available, please explain
why it is not available or cannot be provided.
(a) Please provide a detailed explanation for the need of the project including the
analysis justifying the need.
(b) Please provide a list of all the potential alternatives the Company considered
to fulfill the need and explain why the project was selected among the
alternatives supported by the Company's economic analysis (costs and
benefits) comparing them.
(c) If a RFP or RFQ was submitted, please provide the following information:
i. A copy of the RFP or RFQ that was submitted;
ii. A detailed explanation of the selection process including the
scorecard and list of the criteria used to select the project;
iii. The short-list bidder scorecard; and
iv. A copy of the winning bid.
(d) Please provide the approved Initial Project Plan including the following:
i. Initial project scope;
ii. Initial project budget;
iii. Initial proposed schedule; and
iv. Evidence that the Initial Project Plan and budget were approved at
the appropriate level.
(e) Please provide the following for the Baseline Construction Project Plan
including the following:
i. Baseline project scope;
ii. Baseline project budget broken down by WBS;
iii. Baseline project schedule broken down by WBS;
iv. If the baseline construction project scope, budget, and/or schedule
deviated from the Initial Project Plan, please explain the
differences, explain the reason for the change, and provide
evidence that the changes were approved at the appropriate level;
V. Project status reports and action items; and
vi. Contractor change orders.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 151
(f) Please provide the following related to completion of the project:
i. Baseline construction budget-to-actual comparison by WBS and by
year;
ii. Baseline construction schedule-to-actual comparison by WBS;
iii. For any budget-to-actual cost overages by major WBS category
that is over 5%, please explain the reason for the differences and
provide evidence that the amount was approved at the appropriate
level; and
iv. Please explain any slips in schedule from the baseline construction
schedule.
Response to IPUC Data Request 151
(a) Please refer to Confidential Attachment IPUC 151 which provides a copy of
the project proposal document for the U21 Major Inspection Overhaul—CY23
project.
(b) Please refer to Confidential Attachment IPUC 151.
(c) This is not applicable for this project because the project is completed
pursuant to the terms of a long-term contract. Please refer to the discussion in
Confidential Attachment IPUC 151.
(d) Please refer to the Company's responses to subparts i. through iv. below:
i. This project is to perform the Unit 21 Major CT overhaul pursuant to the
Managed Long-Term Gas Turbine Parts and Service Contract(LTP)
between PacifiCorp and Siemens Energy, Inc. In accordance with the
LTP, major rotor-in overhaul is to be conducted when the combustion
turbine reaches 33,200 hours or 1,200 starts relative to the last combustion
inspection outage which was performed in 2018.
Combustion internal extension program parts are to be supplied and
delivered by Siemens for installation during this Rotor in Major scheduled
outage on Combustion Turbine 21 per the Managed Long Term Gas
Turbine Parts and Services Contract Change effective September 24,
2020. This project, according to the LTP, requires Siemens to prove the
equipment that will operate another 33,200 hours after completion of
Rotor in Major Outage.
ii. The initial project budget was $17,287,805, however additional hours
were run on the turbine. Because the fees are calculated by the number of
hours run, this resulted in an increased project amount of$18,359,458
Direct(excluding allowance for funds used during construction

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 151
(AFUDC)). Overhauls are intended to occur at specific hours intervals
based on total run hours incurred on the combustion turbines. These hours
are prepaid in the form of Equivalent Base Hours (EBH) fees and paid
quarterly per total hours run and booked to a prepaid account. The prepaid
account is cleared and booked to capital at every Major inspection. In the
case of Lake Side's CT21 turbine, the outage was intended to occur
33,200 hours or 1,350 starts after the 2018 Hot Gas Path. In Early 2023
Siemens granted an engineering departure allowing for additional run
hours above the contractual 33,200. The additional hours are predicted to
be 5,155 hours above the 33K. on CT21. These additional hours result in a
total increase over budget of$1,071,653. The benefits associated with the
expenditure including continued operation are also included in the 2023
budget plan.
iii. The initial proposed schedule for the project was approximately 37 days
from going offline to coming back online: October 1, 2023 to November
7, 2023.
iv. Evidence that the Initial Project Plan and budget were approved at the
appropriate level.
QRDroye ap�pr oriation request 10016321 Completed Approved 05/05/2023- 05/09/2023- Rodney Baisch
05:37:21 08:19:31
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Next agent 023 23- 07/12/20 22
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Approve app-mQ ation request 100163-- Completed Approved 07/12/2023- 07/12/2023- Jayson Branch
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Approve ap2rQAr4tion request 10016321 Completed Approved 07/12/2023- 07/12/2023- Joelle Steward
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Approve appngpriation request 100163-- Completed Approved 07/12/2023- 07/21/2023• Nikki Kobliha
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PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 151
(e) Please refer to the Company's responses to subparts i. through vi. below:
i. Please refer to the initial project scope provided in the Company's
response to subpart(d) i. above.
I The project is defined in one WBS (OLSP/2023/C/017) in the budgeted
amount of$17,287,805 Direct (excluding AFUDC).
iii. The project is defined in one WBS (OLSP/2023/C/017), scheduled to take
place over approximately 37 days, from October 1, 2023 to November 7,
2023.
iv. The baseline construction project scope, budget, and/or schedule
did not deviate from the initial project plan.
V. Not applicable
vi. Siemens Energy, Inc. issued the following four change orders
(extra work orders) pursuant to the original contract:
Change Orders(Extra Work Orders)
Reference Short Description Amount Date
CT21-01 R4 Vane CoolingAirTube $14,025.00 10/8/2023
CT21-02 Trunnion Maintenance $24,750.00 10/9/2023
CT21-03 RAC Pipe Stub Indication $ 2,000.00 10/10/2023
CT21-04 SPEX Outer Wear Ring Segment Hardware $ 4,000.00 10/13/2023
Please refer to the Company's responses to subparts i. through vi. below:
i. The baseline construction budget(excluding AFUDC)was
$17,287,805, with actuals (excluding AFUDC) amounting to
$19,299,908.
ii. The baseline construction schedule was estimated to last
approximately 37 days, from October 1, 2023, to November 7,
2023. The actual construction schedule was approximately 40 days
from going offline to coming back online, from October 1, 2023, to
November 11, 2023.
iii. There was a budget-to-actuals cost overage of$2,012,103 Direct
(excluding AFUDC), or 11.64%. This overage is due to the
additional run hours granted by Siemens in the engineering
departure, and the costs for part of the scaffolding and crane
support during the outage. The additional run hours incurred a cost
of$1,071,653, and the costs for scaffolding and crane support
account for the remainder of the overage in the amount of
$940,450.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 151
iv. Extra work driven by discovery resulted in approximately 4 days
added to the schedule.
Recordholder: Matt Murray
Sponsor: Brad Richards

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 152
IPUC Data Request 152
Please provide the following information for the "U2 CSA Variable fee - CT2 -
HGP"project referenced in production response PAC-E-24-04 Attach IPUC
15. Please include any available workpapers with formulae intact. If any of the
information requested below cannot be provided or is not available, please explain
why it is not available or cannot be provided.
(a) Please provide a detailed explanation for the need of the project including the
analysis justifying the need.
(b) Please provide a list of all the potential alternatives the Company considered
to fulfill the need and explain why the project was selected among the
alternatives supported by the Company's economic analysis (costs and
benefits) comparing them.
(c) If a RFP or RFQ was submitted, please provide the following infonnation:
i. A copy of the RFP or RFQ that was submitted;
ii. A detailed explanation of the selection process including the
scorecard and list of the criteria used to select the project;
iii. The short-list bidder scorecard; and
iv. A copy of the winning bid.
(d) Please provide the approved Initial Project Plan including the
i. Initial project scope;
ii. Initial project budget;
iii. Initial proposed schedule; and
iv. Evidence that the Initial Project Plan and budget were approved at
the appropriate level.
(e) Please provide the following for the Baseline Construction Project Plan:
i. Baseline project scope;
ii. Baseline project budget broken down by WBS;
iii. Baseline project schedule broken down by WBS;
iv. If the baseline construction project scope, budget, and/or schedule
deviated from the Initial Project Plan, please explain the
differences, explain the reason for the change, and provide
evidence that the changes were approved at the appropriate level;
V. Project status reports and action items; and
vi. Contractor change orders.
(f) Please provide the following related to completion of the project:

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 152
i. Baseline construction budget-to-actual comparison by WBS and by
year;
ii. Baseline construction schedule-to-actual comparison by WBS;
iii. For any budget-to-actual cost overages by major WBS category
that is over 5%, please explain the reason for the differences and
provide evidence that the amount was approved at the appropriate
level; and
iv. Please explain any slips in schedule from the baseline construction
schedule.
Response to IPUC Data Request 152
(a) Please refer to Confidential Attachment IPUC 152 which provides a copy of
the appropriation request(APR).
(b) Please refer to Confidential Attachment IPUC 152 which provides a copy of
the APR.
(c) Not applicable. This is under a long-term contract.
(d) Please provide the approved Initial Project
i. Initial project scope:
This project is to perform the hot gas path overhaul on combustion
turbine 2 pursuant to the Contractual Service Agreement(CSA)
between PacifiCorp and General Electric International, Inc. (GE)
amended and restated as of January 15, 2016. Performing the
necessary overhaul will result in the units being able to operate an
additional 32,000 hours or 1,200 starts before the next scheduled
outage. The major inspection overhaul includes the removal and
replacement of the following combustion program parts as outlined in
the CSA:
Program Parts
• FUEL NOZZLE ASMBY
• COMBUSTION LINERS
• TRANSITION PIECES
• BUCKETS: STAGE 1
• BUCKETS: STAGE 2
• BUCKETS: STAGE 3
• NOZZLES: STAGE 1
• NOZZLES: STAGE 2
• NOZZLES: STAGE 3

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 152
• SHROUDS: STAGE 1
• SHROUDS: STAGE 2
• SHROUDS: STAGE 3
ii. Initial project budget:
This project is in the approved 2022 budget for $11,664,460 excluding
allowance for funds used during construction (AFUDC).
CAPITAL]EXPENDITURES-$000-PACMCORP SHARE
PRIOR CY22 CY23 CY24 FUTURE TOTAL
Budget withoutAFUDC 11,664 - 11,664
Budget Escalated(withoutAFUDQ 11,664 - 11,664
APR Requested WthoutAFUDC - 11,664 - 11,664
Difference - - - -
Re estedAFUDC - 59 - 59
TOTAL Requested Funds - 11,723 - 11,723
iii. Initial proposed schedule:
This outage was anticipated to be for 1,115 hours or 47 days.
Starting April 18, 2022 through June 3, 2022.
iv. Evidence that the Initial Project Plan and budget were approved at
the appropriate level.
Approve pmadation request 10009802 Completed Approved 04/15/2022- 04/16/2022- Rodney Baisch
12:20:20 08:50:27
Next agent 04/162022- 04/16/2022-
Index access to agent tables Completed retrieved from 08:50:27 08;50;27 -batch
table
Approve appropriation request 10009802 Completed Approved 04/16/2022- 04/20/2022- Payson Branch
08:50:27 16:16:09
Next agent 0420/2022- 04/20/2022-
Index access to agent tables Completed retrieved from 16:16:09 16:16:10 -batch
table
Approve p poriation request 10009802 Approved Completed A 04/20/2022- 04/21/2022-
p 16:16:10 17:45:30 Nikki Kobliha
le,agent 04/2L2022- 04/21/2022-
Index access to agent tables Completed retrieved from 17:45:30 17:45:31 wf-batch
table
Ap ro ove appropriation request 10009802 Completed Approved 0421/2022- 04/2612022- Bradley Richards
17:45:31 07:38:53
Wart For Approver Logic Completed 04/26/2022- 04/26/2022- wf-batch
07:38:54 07:39:24
Status changed 04/26/2022- 04/26/2022-
New status for ap�priation requests Completed successfullyl 07:39:24 07:39:24 wf-batch
Lock Completed 04/262022- 04/26/2022- wf-batch
07:39:24 07:39:24
WBSUpdate Completed 04/262022- 04/26/2022- wf-batch
07:39:24 07:39:24
Plan Version Update For APR Approval Completed 04/262022- 04/26/2022- batch
07:39:24 07:39:24
RC 1MS U date From APR Completed 04/26/2022- 04/26/2022- batch
07:39:24 07:39:24
App_rgoriation request 10009802 was approved! Completed Message was 04262022- 04/26/2022- batch
sent 07:39:24 07:39:25
(e) Please provide the following for the Baseline Construction Project Plan:
i. Please refer to the Company's response to subpart(d) i. above.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 152
ii.
Project _OCLS2022/CA011 v m APR 10989802 Total Project Forecast(AIL Years-300%) 11,575,772
Description U2 CSA Variable fee-CT2-HGP APR Approved Amoant(ALL Years-100%) 11,722,700 Total Project Actuals(ALL Years-100%) 11,575,772
Fiscal Year E 2823 O Costs Thru Period OAll O
Change Forecast
WBS Element WBS Short Text Attachment Est.TECO Est.Comp. Last Forecast Forecast Last-N- YTD Actual J
basumZcAllf ';U2 CSA Variable lee-CT2-HGP 61 06/252022 11/302022 ® 10,932.725 10,932.725 0 10,932,725
................................................
..00LS/2022/C/O11/REM U2 CSA Vanalble Fee-CT2-HGP Removal 302695 302,695 0 302,695
Total Direct 11,235.420 11,235,420 0 11.235.420
....CAP Sur Charges 336,962 336,962 0 336,962
100%Total Project(ex i AFUDC) 11,572,332 11,572,382 0 11,572,382
AFUDC 3,392 3,392 0 3,392
100%Total Project 11,575,T74 11,575,774 0 11,575,774
_..NA Cutback 0 0 0 0
_..CIAC/Reimb. 0 0 0 0
Net Total Project 11,575,774 11,575,774 0 11.575,774
Net Total Project(excl AFUDC) 11 572,382 11 572,382 0 11572382
iii.
Project MLV2022 Mil -[HA] APR 11NO9802 7,RL Project Fore 9 ALL Years-I(M) 11,575,772
Descrlptlon U2 CSA Variable fee-172-XGP APR Approved A—t(ALL Years-1N%) 11,722,708 Total Project Actu,L(AU Years-10095) 11,575,772
Fiscal Year E 2823 O Costs Thru Period OAll ❑
Change Forecast
MS Element Attachment Est.TECO Est.Corp. Last Forecast Forecast Last-N... YTDActual J. F.M... APR MAY JUN J...A. S...0... NOV D...
OCL3/2022/C,Vtt ®R 06/25/2022 11/30/2022 9 10,932,725 10,932.725 0 10,932J25 0 0 0 1,117,446 6,704.676 3,049,643 0 0 0 0 60,960 0
OCLS2022/C/011/REM 61 9 302.695 302.695 0 302695 0 0 0 0 0 302.695 0 0 0 0 0 0
Total Direct 11,235,420 11,235,420 0 11.235,420 0 0 0 1117.446 6.704.676 3,352,338 0 0 0 0 60,960 0
--CAP Sur Charges 33 W 3%.962 0 W6,962 0 0 0 26260 151.870 158,832 0 0 0 0 0 0
100%Total Project(—I AFUDC) 11572,382 11572,382 0 11572,382 0 0 0 1,143,7% 6,8%,546 3,511,170 0 0 0 0 60,!)W 0
-.AFUDC 3,392 3,392 0 3,3W 0 0 0 5 3W 3,081 0 0 0 0 0 0
IN%Total Project 11,575,714 11,575,T74 0 11,575,T74 0 0 0 1,143,711 6,8W,852 3,514,251 0 0 0 0 60.51W 0
....NA Cutback 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
....GACA2ent, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
NO Total Project 11,575.774 11,575,774 0 11.575,774 0 0 0 1,143,711 6,856,852 3,514,251 0 0 0 0 60,960 0
)Net Total Project(ml AFUDC) 11572,382 11572,382 0 11,572,382 0 0 0 1,143,706 6,8%,546 3,511JM 0 0 0 0 60,9600
Iv.
See Attach IPUC 152-CONF for approvals.
Change orders
Contractor Will Will this Days Request Change to work of Cost
Contract work Added/ Date Scope:
Performance extend a Removed
period be unit/ to
impacted? equipment Schedule
outage?
GE No No 0 05/19/2022 Minor Repairs on CT2 $20,982
generator. Various
dusting and greasing to
clean and repair.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 152
GE Yes Yes 8 06/03/2022 Repairs of generator $189,747
terminal studs. Terminal
stud removal and
installation followed by
electrical and pressure
testing. One stud will be
machined out due to it
being stuck in place.
Machining of new stud
may need to be required
to adjust for deviated
copper bore.
GE No No 0 06/08/2022 GT to Generator
Alignment. Projection of $31,350.90
3 shifts (3 days single
shift)
v. Not applicable.
vi. Please refer to the response to (e), subpart iv above.
i. This project is in the approved 2022 budget for$11,664,460 excluding
AFUDC. Actuals show us at $11,572,382 excluding AFUDC translating to
the project coming in at $92,078 under budget.
ii. The baseline construction schedule was estimated to be about 47 days,
from 04/18/2022 —06/03/2022. The actual schedule was 8 days longer
than that due to change orders documented in (e) iv. leaving us at a 55
day outage encompassing 04/18/2022—06/11/2022.
iii. Not Applicable.
iv. Repairs to the generator studs lead to an increase in the outage time by
8 days
Recordholder: Matt Murray
Sponsor: Brad Richards

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 153
IPUC Data Request 153
Please provide the following information for the "ACQUIRE REPOWER SAFE
HARBOR -FC II-IV R"project referenced in production response PAC-E-
24-04 Attach IPUC 15. Please include any available workpapers with formulae
intact. If any of the information requested below cannot be provided or is not
available, please explain why it is not available or cannot be provided.
Please provide a detailed explanation for the need of the project including the
analysis justifying the need.
(a) Please provide a detailed explanation for the need of the project including the
analysis justifying the need.
(b) Please provide a list of all the potential alternatives the Company considered
to fulfill the need and explain why the project was selected among the
alternatives supported by the Company's economic analysis (costs and
benefits) comparing them.
(c) If a RFP or RFQ was submitted, please provide the following information:
i. A copy of the RFP or RFQ that was submitted;
ii. A detailed explanation of the selection process including the
scorecard and list of the criteria used to select the project;
iii. The short-list bidder scorecard; and
iv. A copy of the winning bid.
(d) Please provide the approved Initial Project Plan including the following:
i. Initial project scope;
ii. Initial project budget;
iii. Initial proposed schedule; and
iv. Evidence that the Initial Project Plan and budget were approved at
the appropriate level.
(e) Please provide the following for the Baseline Construction Project Plan:
i. Baseline project scope;
ii. Baseline project budget broken down by WBS;
iii. Baseline project schedule broken down by WBS;
iv. If the baseline construction project scope, budget, and/or schedule
deviated from the Initial Project Plan, please explain the
differences, explain the reason for the change, and provide
evidence that the changes were approved at the appropriate level;
Project status reports and action items; and

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 153
V. Contractor change orders.
(f) Please provide the following related to completion of the project:
i. Baseline construction budget-to-actual comparison by WBS and by
year;
ii. Baseline construction schedule-to-actual comparison by WBS;
iii. For any budget-to-actual cost overages by major WBS category
that is over 5%, please explain the reason for the differences and
provide evidence that the amount was approved at the appropriate
level; and
iv. Please explain any slips in schedule from the baseline construction
schedule.
Response to 1PUC Data Request 153
(a) The Foote Creek II-IV wind project was reviewed as part of the Company's
2021 Integrated Resource Plan (IRP)and the project was made available as a
potential resource that could meet customer energy and capacity needs in the
model used to develop the 2021 IRP. The Company's 2021 IRP showed a
need for additional resources to meet energy and capacity needs. Because the
resource was found to be beneficial to customers it was included as part of a
least-cost, least-risk portfolio, and was identified as a resource in the preferred
portfolio. Action Item 2b of the 2021 IRP included acquisition and repowering
of the Rock River I project consistent with the current timeframe of the
project.
(b) The alternative of not pursuing the acquisition and repowering of the Foote
Creek II-IV wind project was considered, but this would not allow the benefits
of the project to flow to customers, resulting in increased customer costs. As
mentioned in the Company's response to subpart (a) above, the project was
reviewed in the 2021 IRP and compared against other resource alternatives
and selected as a component of the least-cost, least-risk portfolio. Please refer
to Table 7.1 of the 2021 IRP for a list of alternative resources available for
selection by the IRP planning model.
(c) A request for proposals (RFP)was submitted for both the turbine supply and
balance of plant(BOP)construction components of the project.
Please refer to Confidential Attachment IPUC 153-1 which provides
information related to the wind turbine RFP for the project, specifically
confidential folders (1) "TSA RFP Package CONF", (2) "TSA Bids and
evaluation scorecard matrix CONF"which provides the selection criteria and
result, and(3) "TSA Accepted bid CONF"which provides the winning bid

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 153
documentation.
Please refer to Confidential Attachment IPUC 153-1 which provides the
requested BOP RFP documentation, specifically confidential folders (1) "BOP
RFP Package CONF". Note: the RFP package was issued to potential bidders
that included all firms that had previously provided wind repower services of
field work to PacifiCorp, (2) "BoP Bidder Scorecard CONF"which provides
the selection process scorecards, and(3) `BoP Accepted Proposal CONF"
which provides the auction report.
(d) Please refer to Confidential Attachment IPUC 153-2 which provides the
Appropriation Request (APR) 10029398 which includes the requested detailed
project scope, project budget, initial proposed project schedule. The special
delegation of authority document is the evidence of the project plan and
budget at the appropriate level. Please also refer to Confidential Attachment
IPUC 153-2 which provides the other supporting documents.
(e) Please refer to Confidential Attachment IPUC 153-2 which provides the APR
and includes the baseline construction project plan, scope, budget and
schedule. A more refined description of the project's construction scope and
schedule is provided in Confidential Attachment IPUC 153-3. The Foote
Creek II-IV wind project was completed within the cost and schedule
consistent with the approved APR. Please refer to Confidential Attachment
IPUC 153-4 which provides copies of the change orders for the BOP and
TSA.
(f) The Foote Creek II-IV repowering project was completed within the project
schedule and budget approved in the APR(please refer to Confidential
Attachment IPUC 153-2 which provides the supporting documents). The
Foote Creek II-IV wind project achieved commercial operation on November
21, 2023.
Confidential information is provided subject to protection under IDAPA
31.01.01.067 and 31.01.01.233, the Idaho Public Utilities Commission's Rules of
Procedure No. 67—Information Exempt from Public Review, and further subject
to the Non-Disclosure Agreement(NDA) executed in this proceeding.
Recordholder: Tim Hemstreet/Brent Denham
Sponsor: Tim Hemstreet

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 154
IPUC Data Request 154
Please provide the following information for the "Idaho—New Revenue -
Residential"project referenced in production response PAC-E-24-04 Attach
IPUC 15. Please include any available workpapers with formulae intact. If any of
the information requested below cannot be provided or is not available, please
explain why it is not available or cannot be provided.
(a) Please provide a detailed explanation for the need of the project including the
analysis justifying the need.
(b) Please provide a list of all the potential alternatives the Company considered
to fulfill the need and explain why the project was selected among the
alternatives supported by the Company's economic analysis (costs and
benefits) comparing them.
(c) If a RFP or RFQ was submitted, please provide the following information:
i. A copy of the RFP or RFQ that was submitted;
ii. A detailed explanation of the selection process including the
scorecard and list of the criteria used to select the project;
iii. The short-list bidder scorecard; and
iv. A copy of the winning bid.
(d) Please provide the approved Initial Project Plan including the
i. Initial project scope;
ii. Initial project budget;
iii. Initial proposed schedule; and
iv. Evidence that the Initial Project Plan and budget were approved at
the appropriate level.
(e) Please provide the following for the Baseline Construction Project Plan:
i. Baseline project scope;
ii. Baseline project budget broken down by WBS;
iii. Baseline project schedule broken down by WBS;
iv. If the baseline construction project scope, budget, and/or schedule
deviated from the Initial Project Plan, please explain the
differences, explain the reason for the change, and provide
evidence that the changes were approved at the appropriate level;
V. Project status reports and action items; and
vi. Contractor change orders.

PAC-E-24-04/Rocky Mountain Power
August 19, 2024
IPUC Data Request 154
(f) Please provide the following related to completion of the project:
i. Baseline construction budget-to-actual comparison by WBS and by
year;
ii. Baseline construction schedule-to-actual comparison by WBS;
iii. For any budget-to-actual cost overages by major WBS category
that is over 5%, please explain the reason for the differences and
iv. Please explain any slips in schedule from the baseline construction
schedule.
Response to IPUC Data Request 154
(a) Idaho—New Revenue—Residential is a placeholder for funding available for all
smaller residential new connect requests, it is not one specific project.
(b) Idaho—New Revenue—Residential is a placeholder for funding available for all
smaller residential new connect requests, it is not one specific project.
(c) Idaho—New Revenue—Residential is a placeholder for funding available for all
smaller residential new connect requests, it is not one specific project.
(d) Idaho—New Revenue—Residential is a placeholder for funding available for all
smaller residential new connect requests, it is not one specific project.
(e) Idaho—New Revenue—Residential is a placeholder for funding available for all
smaller residential new connect requests, it is not one specific project.
(f) Idaho—New Revenue—Residential is a placeholder for funding available for all
smaller residential new connect requests, it is not one specific project.
Recordholder: Thomas Turner
Sponsor: Allen Berreth