20250415APPLICATION.pdf

0IQAW POWER@
RECEIVED
April 15, 2025
IDAHO PUBLIC
MEGAN GOICOECHEA ALLEN UTILITIES COMMISSION
Corporate Counsel
mgoicoecheaal len(cDidahopower.com
April 15, 2025
Commission 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-25-20
Application of Idaho Power Company for Authority to Implement Power Cost
Adjustment ("PICK) Rates for Electric Service from June 1, 2025, through May
31, 2026
Dear Commission Secretary:
Attached for electronic filing is Idaho Power Company's Application and Direct
Testimony of Jessica G. Brady filed in support of the Application.
Exhibit Nos. 4 and 5 to the Direct Testimony of Jessica G. Brady contain
confidential information and will be provided separately via an encrypted email to the
parties who sign the Protective Agreement. A Word version of the testimony will also be
sent in a separate email for the convenience of the Reporter.
Accompanying this filing is the Company's Press Release, Customer Notice, and
Direct Mail Postcard.
If you have any questions about the attached documents, please do not hesitate
to contact me.
Sincerely,
T.Cm
Megan Goicoechea Allen
MGA:sg
Attachments
P.O.Box 70(83707)
1221 W.Idaho St.
Boise,ID 83702

CERTIFICATE OF ATTORNEY
ASSERTION THAT INFORMATION CONTAINED IN AN IDAHO PUBLIC UTILITIES
COMMISSION FILING IS PROTECTED FROM PUBLIC INSPECTION
Idaho Power Company's Application for Authority to Implement Power Cost
Adjustment ("PCA") Rates for Electric Service from June 1, 2025 through May 31,
2026
Case No. IPC-E-25-20
The undersigned attorney, in accordance with Commission Rules of Procedure
67, believes that Exhibit Nos. 4 and 5 to the Direct Testimony of Jessica G. Brady, dated
April 15, 2025, may contain information that Idaho Power Company and a third-party
claim constitutes confidential trade secrets, proprietary information, and/or private
business records required by law to be submitted to or inspected by a public agency as
described in Idaho Code§ 74-101, et seq., and §48-801, et seq., or is otherwise protected
from public disclosure and as such is exempt from public inspection, examination, or
copying.
DATED this 15th day of April 2025.
�_%r I
Megan Goicoechea Allen
Counsel for Idaho Power Company

MEGAN GOICOECHEA ALLEN (ISB No. 7623)
DONOVAN WALKER (ISB No. 5921)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
mgoicoecheaallen(a).idahopower.com
dwalker(a-)idahopower.com
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR ) CASE NO. IPC-E-25-20
AUTHORITY TO IMPLEMENT POWER )
COST ADJUSTMENT ("PCA") RATES ) APPLICATION
FOR ELECTRIC SERVICE FROM JUNE )
1, 2025, THROUGH MAY 31, 2026. )
Idaho Power Company ("Idaho Power" or "Company"), in accordance with Idaho
Code § 61-502 and Commission Rule of Procedure' 52, hereby respectfully requests the
Idaho Public Utilities Commission ("IPUC" or "Commission") approve an update to
Schedule 55 based on the quantification of the 2025-2026 Power Cost Adjustment
("PCA") to become effective June 1, 2025, for the period of June 1, 2025, through May
31, 2026. If the proposed rates and charges for electric service in the state of Idaho
' Hereinafter cited as RP.
APPLICATION - 1

included as Attachment 1 to this Application are approved, the 2025-2026 PCA will result
in an overall revenue decrease of approximately$94.8 million, or a 5.89 percent decrease
from current billed revenue.
In support of this Application, Idaho Power has filed the Direct Testimony of
Jessica G. Brady, Senior Regulatory Analyst ("Brady Testimony"). Ms. Brady's testimony
provides an overview of the PCA, details the 2025-2026 PCA amount in comparison to
last year's PCA amount, explains the factors impacting this year's PCA quantification,
presents the calculation of the proposed 2025-2026 PCA rates, and discusses the
additional PCA component related to revenue sharing. In addition, the Brady Testimony
details the net customer impact of the 2025-2026 PCA rates if approved as filed. In further
support of this Application, Idaho Power represents as follows:
L BACKGROUND
1. Idaho Power is an Idaho corporation whose principal place of business is
1221 West Idaho Street, Boise, Idaho 83702.
2. Idaho Power is a public utility supplying retail electric service to more than
600,000 customers in southern Idaho and eastern Oregon. Idaho Power is subject to the
jurisdiction of this Commission in Idaho and to the jurisdiction of the Public Utility
Commission of Oregon. Idaho Power is also subject to the jurisdiction of the Federal
Energy Regulatory Commission.
3. The Company is compensated for "normal" costs of generating electricity
through its base electricity rates established by the Commission in general rate cases.
However, though the power supply expense component embedded in base rates is static,
due to the Company's unique reliance on hydro generation, actual power supply
APPLICATION - 2

expenses vary from year to year with changes in streamflow conditions.
4. As a result of the Company's request to establish a permanent mechanism
to adjust rates annually to reflect variations in power supply costs in Case No. IPC-E-92-
25, the Commission issued Order No. 24806 on March 29, 1993, in which it approved the
implementation of an annual Power Cost Adjustment procedure in order to provide
consistency and stability to rates.2 The PCA is a cost recovery mechanism that passes
on both the benefits and costs of supplying energy to Idaho Power customers. Neither
Idaho Power nor its shareholders receive any financial return on this filing — money
collected from the surcharge can be used only to pay power supply expenses.
5. Since its establishment, the PCA mechanism has been incrementally
refined and modified through a series of Commission Orders, as more fully set forth
below, to ensure the mechanism achieves its desired purpose and to incorporate other
distinct elements, such as revenue sharing, as circumstances dictated.
Case No. IPC-E-08-19
6. For example, following several Commission orders addressing the need to
modify the Company's then-existing PCA methodology, the Company initiated Case No.
IPC-E-08-19 requesting the Commission approve a settlement stipulation that addressed
a number of issues and components of the PCA. In Order No. 30715, the Commission
approved the stipulation and changes to the PCA formula, which included, in pertinent
part, revising the PCA sharing methodology allocating non-PURPA3 power supply
2 In the Matter of the Application of Idaho Power Company for Authority to Implement a Power Cost
Adjustment Tariff for Electric Service to Customers in the State of Idaho and for Approval of New Rates
for Service Under the FMC Special Contract, Case No. IPC-E-92-25, Order No. 24806, p. 25-26 (Mar. 23,
1993).
3 Public Utility Regulatory Policies Act of 1978 ("PURPA").
APPLICATION - 3

expenses between customers and shareholders.4 More specifically, the PCA sharing
ratio was modified to 95 percent customer, 5 percent Idaho Power.5 In addition, the
Commission approved changes to the Load Growth Adjustment Rate ("LGAR"), third-
party transmission expense, the PCA forecast, and power supply expense distribution.6
Case No. IPC-E-09-30
7. Following the notice of intent to file a general rate case filed by the Company
in August 2009, the Company, Commission Staff, and other stakeholders worked together
to develop an approach that would allow the Company to implement a multi-year rate
case moratorium while at the same time giving the Company the opportunity to recover a
maintenance level of earnings over the term of the moratorium. This ultimately resulted
in the Company seeking approval of a settlement stipulation filed in lieu of a general rate
case in Case No. IPC-E-09-30, which was granted by the Commission in Order No.
30978.7 Through this stipulation, a revenue sharing mechanism was established
including provisions for the accelerated amortization of Accumulated Deferred Investment
Tax Credits ("ADITC") to help the Company achieve a minimum specified percent Idaho-
jurisdictional return on year-end equity ("Idaho ROE") and also provides for the potential
sharing between Idaho Power and its Idaho customers of Idaho jurisdictional earnings in
excess of a maximum specified Idaho ROE. Since then, the ADITC/Revenue Sharing
mechanism has been extended, and percentages, thresholds, and accounting modified
4 In the Matter of Idaho Power Company's Petition for Approval of Changes to its Power Cost Adjustment
(PCA) Mechanism, Case No. IPC-E-08-19, Order No. 30715, p. 4-5 (Jan. 9, 2009).
5 With respect to PUPRA expenses and demand response incentive payments, when actual annual
expenses deviate from base level NPSE, the Company is allowed to pass 100 percent of the difference
for recovery or credit through the PCA.
6 Case No. IPC-E-08-19, Order No. 30715, p. 5-7.
In the Matter of the Application of Idaho Power Company for an Accounting Order to Amortize Additional
Accumulated Deferral Income Tax Credit and Approving a Rate Case Moratorium, Case No. IPC-E-09-30,
Order No. 30978, p. 5-7 (Jan. 13, 2010).
APPLICATION -4

by numerous Commission Orders.$ The mechanism was most recently modified in the
Company's 2023 General Rate Case, effective January 1, 2024 (Order No. 36042).
Case No. GNR-E-10-03
8. At the Commission's request, Staff initiated Case No. GNR-E-10-03 to
explore issues related to the load growth adjustment portion of the utilities' power cost
adjustment mechanisms, particularly considering use of a LGAR in periods of declining
load. In that case, the Commission ultimately adopted a revised LGAR methodology and
changed the name of the methodology to the Load Change Adjustment Rate ("LCAR"),
as set forth in Order No. 32206.9
Case No. IPC-E-15-15
9. In 2014 and 2015, the Company and Staff considered potential ways to
improve the PCA's accuracy and, as a result of these efforts, agreed on a number of
changes to the calculation of the PCA true-up. The ensuing proposal, to convert the
PCA's existing Load Change Adjustment deferral calculation to a Sales-Based
Adjustment ("SBA"), and modify the PCA deferral balance's monthly interest calculation,
was set forth in a settlement agreement and submitted to the Commission in Case No.
IPC-E-15-15. On May 28, 2015, the Commission issued Order No. 33307 approving
changes to the PCA pursuant to the settlement agreement: (1) replacing the existing
LCAR with the SBA, calculated in the same manner as the LCAR but replacing the load-
' See, e.g., In the Matter of the Application of Idaho Power Company to Extend and Modify Accounting
Order to Amortize Additional Accumulated Deferred Income Tax Credits (ADITC), Case No. IPC-E-11-22,
Order No. 32424, p. 4 (Dec. 27, 2011); In the Matter of Idaho Power Company's Application to Extend its
Accumulated Deferred Investment Tax Credits/Revenue Sharing Mechanism Beyond 2014, Case No.
IPC-E-14-14, Order No. 33149, p. 4-5 (Oct. 9, 2014); In the Matter of the Investigation into the Impact of
Federal Tax Code Revisions on Utility Costs and Ratemaking, Case No. GNR-U-18-01, Order No. 34071,
p. 4-5 (May 31, 2018).
9 In the Matter of the Commission's Inquiry into Load Growth Adjustments that Are Part of Power Cost
Adjustment Mechanisms, Case No. GNR-U-10-03, Order No. 32206, p. 6-7 (Mar. 15, 2011).
APPLICATION - 5

based megawatt-hour ("MWh") denominator with the corresponding sales-based MWh
denominator; and (2) calculating monthly interest on the deferral balance by assigning
annual base Net Power Supply Expenses ("NPSE") to each month according to expected
base rate revenue collection as set in the Company's general rate case, Case No. IPC-
E-11-08.10
Case No. GNR-U-18-01
10. Following changes to federal and Idaho state tax rates implemented in
2018, the Commission opened a multi-utility case, Case No. GNR-U-18-01, to investigate
whether to adjust utilities' rates and charges to reflect the income tax and revenue
requirement reductions resulting from the tax changes. After considering the impacts of
tax reform on its operations, the Company worked together with Staff on a proposal that
would return to customers the tax benefits the Company was realizing under the tax law
changes with limited negative impact to the Company and entered into a settlement
stipulation reflecting the same. The settlement stipulation filed with the Commission on
April 12, 2018, included, among other things, extending and modifying the
ADITC/Revenue Sharing mechanism. On May 31, 2018, the Commission issued Order
No. 34071 approving the settlement stipulation that included modifications to the sharing
portion of the mechanism to allow for greater customer benefits."
Case Nos. IPC-E-21-10 and IPC-E-21-38
11. On May 28, 2021, the Commission issued Order No. 35054 approving the
Company's 2021 annual PCA filing and instructing it, based on Staff's recommendation
10 In the Matter of Idaho Power Company's Application for Approval of Computational Modifications to the
True-Up Portion of the Power Cost Adjustment, Case No. IPC-E-15-15, Order No. 33307, p. 4-5 (May 28,
2015).
"Case No. GNR-U-18-01, Order No. 34071, p. 4-5.
APPLICATION - 6

to simplify the PCA mechanism, "to initiate discussions with interested parties and to file
a case with the Commission to review whether the PCA mechanism should be modified"
before the Company's next PCA application.12
12. As a result of this endeavor, the Company proposed in Case No. IPC-E-21-
38 to simplify its PCA mechanism by replacing the "true-up" and "true-up of the true-up"
components of the PCA with a balancing account. On January 10, 2022, the Commission
issued Order No. 35290 approving the Company's request to modify the PCA mechanism
thereby combining the two true-up components into one balancing account rate, referred
to below as the "Balancing Adjustment."13 This modification was intended to make the
PCA more transparent and easier to understand and did not materially affect the overall
cost recovery of the PCA.
Case No. IPC-E-23-11
13. On December 28, 2023, the Commission issued Order No. 36042 approving
the settlement stipulation in the Company's 2023 General Rate Case ("GRC").14 The
stipulation included, among other things, modifications related to the ADITC/Revenue
Sharing mechanism. The mechanism was modified to include an additional amount of
Investment Tax Credits ("ITC") equal to the incremental ITC generated from the
Company's investment in 2023 battery storage projects, including augmentation costs. In
addition, the ADITC cap previously set at $25 million was removed. Next, it was modified
12 In the Matter of Idaho Power Company's Application for Authority to Implement Power Cost Adjustment
(PCA) Rates for Electric Service from June 1, 2021 through May 31, 2022, IPC-E-21-10, Order No.
35054, p. 5 (May 28, 2021).
13 Idaho Power Company's Application for Modification of the Power Cost Adjustment Mechanism, Case
No. IPC-E-21-38, Order No. 35290, p. 2-3 (Jan. 10, 2022).
14 In the Matter of the Application of Idaho Power Company for Authority to Increase its Rates and
Charges for Electric Service in the State of Idaho and for Associated Regulatory Accounting Treatment,
Case No. IPC-E-23-11, Order No. 36042 (Dec. 28, 2023).
APPLICATION - 7

so that potential revenue sharing between Idaho Power and customers of Idaho-
jurisdictional earnings will occur if earnings are in excess of 9.6 percent, and also provided
that all revenue sharing be implemented only through the PCA, rather than a portion
offsetting customer-funded pension obligations as was done previously. In addition to
updating the maximum Idaho ROE for earnings sharing to 9.6 percent, the minimum-
specified Idaho ROE was set at 9.12 percent (95 percent of the stipulated 9.6 percent).
This is the first PCA filing impacted by the stipulated modifications, which became
effective January 1, 2024.
14. The settlement stipulation in the Company's 2023 GRC also implemented
a Commission mandate stemming from the 2013 PCA case for the Company to include
third-party wheeling revenue differences in the PCA once a base level of revenue was
set in a general rate case.15 As part of the Commission-approved settlement in the 2023
GRC, the parties agreed that the Idaho-jurisdictional amount of$46,361,643 in third-party
point-to-point wheeling revenues would serve as the baseline for potential tracking of
these revenues.
Case No. IPC-E-24-38
15. Following the conclusion of the 2023 GRC, Idaho Power developed, with
input from Staff, a proposed methodology to track wheeling revenues in the PCA, which
it presented to the Commission in Case No. IPC-E-24-38 filed on October 7, 2024.
16. In Order No. 36502 issued on March 11, 2025, the Commission approved
the Company's request to track annual wheeling revenues in the PCA, and its proposal
15 In the Matter of the Application of Idaho Power Company for Authority to Implement Power Cost
Adjustment(PCA) Rates for Electric Service From June 1, 2013, Through May 31, 2014, Case No. IPC-E-
13-10, Order No. 32796 (Apr. 23, 2013).
APPLICATION - 8

to implement a transmission wheeling revenue tracking mechanism that would measure
the difference between actual wheeling revenues and a sales-adjusted baseline level of
wheeling revenues as a component of the Balancing Adjustment, effective April 2024.16
II. 2025-2026 PCA OVERVIEW
17. The PCA is a rate mechanism that quantifies and tracks annual differences
between actual NPSE and the normalized or "base level" of NPSE recovered in the
Company's base rates, resulting in a credit or surcharge that is updated annually on June
1. The PCA mechanism utilizes a 12-month test period of April through March ("PCA
Year") and consists of a forecast component and a Balancing Adjustment (formerly
referred to as the "true-up" and the "true-up of the true-up") as more fully described below.
18. The PCA mechanism allows the Company to pass to Idaho customers 95
percent of the annual differences in actual NPSE as compared to the base level NPSE,
whether positive or negative, with the exception of PUPRA expenses and demand
response incentive payments. With respect to those expenses, when actual annual
expenses deviate from base level NPSE, the Company is allowed to pass 100 percent of
the difference for recovery or credit through the PCA. In addition, beginning with this
year's PCA filing, Idaho Power is requesting to include recovery of the capital lease
payments associated with the Kuna Battery Energy Storage System ("BESS") at 100
percent.17 The PCA is also the rate mechanism used by the Company to provide
16 In the Matter of Idaho Power Company's Filing in Compliance with Order No. 36402 for Authority to
Track Annual Wheeling Revenues in the Power Cost Adjustment, Case No. IPC-E-24-38, Order No.
36502 (Mar. 11, 2025).
" In the Matter of the Application for CPCN to acquire resources to be online in both 2024 and 2025 and
for Approval of an Energy Storage Agreement with Kuna BESS LLC, Case No. IPC-E-23-20, Order No.
36011 (Nov. 27, 2023) (approving the Company's Application for a Certificate of Public Convenience and
Necessity for the Kuna BESS, acknowledging the expenses as prudently incurred for ratemaking
purposes, and acknowledging the necessary lease accounting necessary to facility the transaction).
APPLICATION - 9

customer benefits resulting from the Revenue Sharing mechanism originally approved in
Order No. 34071.
PCA Forecast Component
19. The PCA forecast component represents the difference between the
Company's NPSE forecast from its March Operating Plan and the base level NPSE
recovered in the Company's base rates.
20. The Brady Testimony describes and computes the PCA rate to be effective
June 1, 2025, through May 31, 2026. The system-level forecast of NPSE for the 2025-
2026 PCA Year is $563,563,648, which is $78,656,404 higher than the currently approved
base level NPSE of $484,907,244, and $54,007,658 higher than last year's forecast
amount of $509,555,990.
21. As described in Ms. Brady's testimony, the difference between the system-
level forecast of NPSE and the currently approved base level NPSE is adjusted for the
PCA sharing provisions and allocated to Idaho customers to determine the 2025-2026
PCA forecast component to be collected from Idaho customers of $73,092,256.
PCA Balancing Adjustment
22. Per Order No. 35290,18 the "true-up" and the "true-up of the true-up" have
been combined into a single Balancing Adjustment, which includes a backward-looking
tracking of differences between the prior PCA Year's forecast and actual NPSE incurred
by the Company, and also tracks the collection of the prior year's Balancing Adjustment.
In addition, as approved by the Commission in Order No. 36502, beginning with this year's
PCA filing, the Balancing Adjustment tracks the annual variance between actual and
'$ Case No. IPC-E-21-38.
APPLICATION - 10

base-level wheeling revenues. However, this year's Balancing Adjustment did not include
Western Energy Imbalance Market ("EIM") participation costs because those were
included in base rates resulting from the Company's 2023 GRC, which went into effect
on January 1, 2024; as a result, EIM costs are no longer included in the PCA as of that
date. Benefits associated with EIM participation are embedded in actual NPSE.
23. The PCA Balancing Adjustment deferral balance at the end of March 2025,
with interest applied, was approximately negative $52 million, which represents a
decrease to customers rates in this year's PCA Balancing Adjustment. Actual power
supply expenses in the 2024-2025 PCA Year were just 2 percent lower than forecast
expenses. As a result, the variance between forecast and actual power supply expenses
for the 2024-2025 PCA Year had a relatively small impact on this year's deferral balance.
However, this year's deferral balance does include increased benefits associated with the
SBA, which accounts for the variance in actual sales and the sales used to set base level
NPSE, as well as increased Renewable Energy Credit ("REC") sales, wheeling revenues,
and liquidated damages associated with the delayed commissioning of BESS resources
as more fully discussed in the Brady Testimony.
24. This year's Balancing Adjustment also includes two other items that resulted
in an additional credit to customers: 1) in accordance with Order No. 36048 issued in
Case No. IPC-E-23-14, a one-time adjustment to recover the conversion of accumulated
kWh credits into a financial credit for commercial, irrigation, and industrial customers19
and 2) a one-time adjustment to credit the difference between February and January base
11 See, In the Matter of the Application of Idaho Power Company for Authority to Implement Changes to
the Compensation Structure Applicable to Customer On-Site Generation Under Schedules 6, 8, and 84
and to Establish and Export Credit Rate, Case No. IPC-E-23-14, Order No. 36048 (Dec. 29, 2023).
APPLICATION - 11

rates, as a result of the Errata issued on January 21, 2025 in the Company's filing to
recover incremental capital investments and certain ongoing operations and maintenance
expenses.20 A cents per kwh rate for these two adjustments was calculated for each
individual rate class and added to the overall Balancing Adjustment Rate as described in
the Brady Testimony.
Revenue Sharing
25. The Revenue Sharing mechanism allows the Company to amortize ADITC
when earnings fall below a certain Idaho ROE threshold or share a portion of revenues
with Idaho customers in the form of a rate reduction when earnings are above a certain
ROE threshold. The Company's earnings in each year from 2011 through 2015, as well
as 2018 and 2021, resulted in revenue sharing with Idaho customers totaling $126.7
million, either as a direct rate offset in the PCA or as an offset to amounts that would have
otherwise been collected in rates. The Company's earnings in 2016, 2017, 2019, 2020,
2022, and 2023 were below the revenue sharing threshold.
26. As a result of the Company's 2023 GRC, effective January 1, 2024,
potential revenue sharing between Idaho Power and customers will occur if earnings are
in excess of a 9.6 percent Idaho ROE. In addition, all revenue sharing will be implemented
through the PCA, rather than a portion offsetting customer-funded pension obligations.
Lastly, the minimum-specified Idaho ROE is 9.12 percent.
27. As described in greater detail in the Brady Testimony, the Company's
year-end 2024 financial results yielded an actual Idaho ROE of 8.19 percent, falling
20 In the Matter of the Application of Idaho Power Company to Increase Rates for Electric Service to
Recover Costs Associated with Incremental Capital Investments and Certain Ongoing Operations and
Maintenance Expenses, Case No. IPC-E-24-07, Errata to Order No. 36438 (Jan. 21, 2025).
APPLICATION - 12

below the 9.6 percent ROE threshold for revenue sharing. Therefore, the 2025-2026
PCA will not include a revenue sharing component. Moreover, because the Company's
Idaho ROE was below the 9.12 percent minimum threshold, the Company utilized
approximately $30 million of ADITC to achieve the minimum specified ROE of 9.12
percent.
III. 2025-2026 PCA AND PROPOSED RATE CHANGES
28. The 2025-2026 PCA rates proposed in this case would result in total PCA
collection of $21.0 million. This represents a decrease in total billed revenue of $94.8
million for the upcoming year, a decrease of 5.89 percent. Table 1 below presents a
separation of the $94.8 million decrease into each component included in the Company's
proposed rates as more fully explained above.
Table 1 Revenue Impact by Component
Line
No. Rate Component 2024-2025 PCA 2025-2026 PCA Difference
1 PCA Forecast $ 23,342,867 $ 73,092,256 $ 49,749,389
2 PCA Balancing Adjustment $ 92,469,480 $ (52,064,539) $ (144,534,019)
3 PCA Total $ 115,812,347 $ 21,027,717 $ (94,784,630)
4 Revenue Sharing $ 0 $ 0 $ 0
5 Total Revenue Impact $ 115,812,347 $ 21,027,717 $ (94,784,630)
29. The decrease in this year's PCA is driven by a decrease in the Balancing
Adjustment, partially offset by an increase in the forecast component. The decrease in
this year's Balancing Adjustment is largely attributed to the completed recovery of the
2023 PCA balancing adjustment, which was recovered over two years per Order No.
35804. Additional factors as discussed above include the SBA, an increase in REC sales,
a credit related to the variance in actual wheeling revenues as compared to the levels
recovered in base rates, and a credit for liquidated damages associated with the delayed
commissioning of certain BESS resources.
APPLICATION - 13

PCA Rate Determination
30. The Brady Testimony describes in detail how this year's rates for the
forecast portion and the Balancing Adjustment were determined, and the resulting uniform
PCA rate when all components are combined, which for the 2025-2026 PCA Year is
comprised of (1) the 0.4700 cents per kilowatt-hour ("kWh") for the 2025-2026 projected
power cost of serving firm loads under the current PCA methodology and 95 percent
sharing, and (2) the negative 0.3347 cents per kWh for the 2024-2025 Balancing
Adjustment. The sum of these two components results in a summary rate of 0.1354 cents
per kWh. Additionally, the two one-time adjustments, as described above and in the Brady
Testimony, resulted in an additional decrease to the Balancing Adjustment of $13,372,
which was applied at the class level; more specifically, the cents per kwh rates associated
with these two adjustments were added to the Balancing Adjustment Rate of negative
0.3347 cents per kwh to determine class-specific Balancing Adjustment Rates.
Cumulative Proposed June 1, 2025, Rate Changes
31. PCA. The 2025-2026 total PCA amount, as measured from the currently
approved base level NPSE is $21.0 million. This represents a decrease in total billed
revenue of $94.8 million, or 5.89 percent, for Idaho customers, effective June 2025
through May 2026.
32. Fixed Cost Adjustment ("FCA"). On March 15, 2025, Idaho Power filed its
annual FCA in Case No. IPC-E-25-11. The Company's 2025 FCA filing proposes a $40.7
million decrease in current billed revenue, or a 5.28 percent decrease, for Idaho
Residential and Small General Service customers, effective June 2025 through May
2026.
APPLICATION - 14

33. Hells Canyon Complex Relicensing_ On March 14, 2025, Idaho Power filed
a request to increase rates to recover incremental Allowance for Funds Used During
Construction ("AFUDC") costs associated with the Hells Canyon Complex ("HCC")
relicensing project. The Company proposes a $29.7 million dollar increase, effective June
1, 2025, or a 1.85 percent increase to billed revenue.
34. Combined Effect of the PCA, FCA, and HCC Filings. If the proposed PCA,
FCA, and HCC rate changes are approved as filed, the combined impact is an overall
decrease in current billed revenue of $105.8 million, or 6.57 percent, for June 2025
through May 2026.
35. Attachment 1 to this Application is Idaho Power's proposed IPUC No. 30,
Tariff No. 101, in both clean and legislative formats, which contains the tariff sheets
specifying the proposed Schedule 55 rates for providing retail electric service to its
customers in the state of Idaho for June 1, 2025, through May 31, 2026.
36. Attachment 2 to this Application contains a summary of revenue impact
showing the effect to each customer class of applying the Company's proposed PCA
rates that collect $94.8 million less, from June 2025 through May 2026, than the PCA
rates currently in effect.
IV. MODIFIED PROCEDURE
37. Idaho Power believes that a technical hearing is not necessary to consider
the issues presented herein and respectfully requests that this Application be processed
under Modified Procedure, i.e., by written submissions rather than by hearing. RP 201,
et seq. If, however, the Commission determines that a technical hearing is required, the
Company stands ready to present its testimony, including but limited to the Brady
APPLICATION - 15

Testimony filed contemporaneously herewith, and support the Application in such
hearing.
V. COMMUNICATIONS AND SERVICE OF PLEADINGS
38. In conformance with RP 125, this Application will be brought to the attention
of Idaho Power's customers by means of a press release to media in the Company's
service area and a customer notice distributed in customers' bills, both of which
accompany this filing. The customer notice will be distributed over the course of the
Company's current billing cycles, and additionally, to ensure that all customers are
notified in a timely manner and have sufficient time to submit comments, Idaho Power is
sending a direct mail postcard to a subset of customers that receive their bill toward the
end of the processing time for this case. As such, a bill insert and/or the direct mail
postcard will be mailed no later than May 20, 2025.
39. The Company has also prominently displayed its intent to file the PCA on
its website since March 15, 2025. Upon filing of this Application, this web graphic will link
directly to the PCA press release and bill insert. Idaho Power will also keep its
Application, testimonies, and exhibits open for public inspection at its offices throughout
the state of Idaho. Idaho Power asserts that this notice procedure satisfies the Rules of
Procedure of this Commission; however, the Company will, in the alternative, bring the
Application to the attention of its affected customers through any other means directed by
this Commission.
40. Communications and service of pleadings with reference to this Application
should be sent to the following:
APPLICATION - 16

Megan Goicoechea Allen Matthew T. Larkin
Donovan Walker Timothy E. Tatum
Regulatory Dockets Jessi Brady
Idaho Power Company Idaho Power Company
1221 West Idaho Street (83702) 1221 West Idaho Street (83702)
P.O. Box 70 P.O. Box 70
Boise, Idaho 83707 Boise, Idaho 83707
mgoicoecheaallen(o-)idahopower.com mlarkin(cDidahopower.com
dwalker .idahopower.com ttatum idahopower.com
dockets(a)idahopower.com jbrady(a)idahopower.com
VI. REQUEST FOR RELIEF
41. As discussed in greater detail above, Idaho Power respectfully requests that
the Commission issue an order: (1) authorizing that this matter be processed by Modified
Procedure and (2) approving an update to Schedule 55 based on the quantification of the
2025-2026 PCA, resulting in an overall decrease to current billed revenue of
approximately $94.8 million to become effective June 1, 2025.
DATED at Boise, Idaho, this 15' day of April 2025.
Awrt,
I
MEGAN GOICOECHEA ALLEN
Attorney for Idaho Power Company
APPLICATION - 17

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-20
IDAHO POWER COMPANY
ATTACHMENT NO. 1
PROPOSED SCHEDULE 55
(CLEAN AND LEGISLATIVE FORMAT)

Idaho Power Company Second Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company's schedules and Special Contracts listed within this schedule. These loads are
referred to as "firm" load for purposes of this schedule.
BASE POWER COST AND PROJECTED POWER COST
The Base Power Cost of the Company's rates, expressed in cents per kWh, is computed by
dividing the sum of the Company's power cost components by firm kWh sales. The power cost
components are segmented into three categories as described in the table below:
The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31.
BALANCING ADJUSTMENT
The Balancing Adjustment is based upon the differences between previous Projected Power Cost
and the power costs actually incurred. The Balancing Adjustment varies by rate class and is included in
the table below.
EARNINGS SHARING
Order Nos. 30978, 32424, 33149, 34071, and 36042 directed the Company to share a portion of
its earnings above a certain threshold with customers through the annual Power Cost Adjustment. The
Company's 2024 earnings were not above the prescribed threshold resulting in a credit of 0.0000 cents
per kWh.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective — June 1, 2025 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT
The Power Cost Adjustment (PCA) is the sum of: 1) 95 percent of the difference between the
Projected Power Costs in Category 1 and the Base Power Costs in Category 1; 2) 100 percent of the
difference between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2;
3) 100 percent of the difference between the Projected Power Costs in Category 3 and the Base Power
Costs in Category 3; 4) 100 percent of the difference between the Projected Power Costs in Category 4
and the Base Power Costs in Category 4; 5) the Balancing Adjustment; and 6) Earnings Sharing. The
following table calculates the rates for Categories 1, 2, 3, and 4.
The following table shows the determination of PCA rates for Categories 1, 2, 3, and 4:
Base Projected Sharing
Category Description Power Power Difference % Rate
Cost Cost
(¢ per kWh)
The sum of fuel expense and
purchased power expense
(excluding purchases from
1 cogeneration and small power 1.60371 1.89897 0.29526 95% 0.28050
producers), less the sum of off-
system surplus sales revenue and
revenue from market-based
special contract pricing.
Purchased power expense from
2 cogeneration and small power 1.32163 1.39941 0.07778 100% 0.07778
producers.
3 Demand response incentive 0.06585 0.06695 0.00110 100% 0.00110
payments.
4 Payments for battery energy 0.00000 0.11066 0.11066 100% 0.11066
storage system leases
Total 2.99119 3.47599 0.48480 0.47004
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective —June 1, 2025 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Second Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules and
Special Contracts are shown below. The monthly Power Cost Adjustment applied to the per unit charges
of the nonmetered schedules is the monthly estimated usage times the cents per kWh rates shown below.
Totals may not tie due to rounding.
Balancing Earning Total PCA
Schedul Adjustment s
e Cate or Sharin
1 2 3 4
1 0.2805 0.0778 0.0011 0.1107 0.3351 0.0000 0.1349
3 0.2805 0.0778 0.0011 0.1107 0.3351 0.0000 0.1349
5 0.2805 0.0778 0.0011 0.1107 0.3351 0.0000 0.1349
6 0.2805 0.0778 0.0011 0.1107 0.3350 0.0000 0.1350
7 0.2805 0.0778 0.0011 0.1107 0.3353 0.0000 0.1347
8 0.2805 0.0778 0.0011 0.1107 0.3355 0.0000 0.1345
9S 0.2805 0.0778 0.0011 0.1107 0.3346 0.0000 0.1354
9P 0.2805 0.0778 0.0011 0.1107 0.3350 0.0000 0.1350
9T 0.2805 0.0778 0.0011 0.1107 0.3349 0.0000 0.1351
15 0.2805 0.0778 0.0011 0.1107 0.3357 0.0000 0.1343
19S 0.2805 0.0778 0.0011 0.1107 0.3350 0.0000 0.1350
19P 0.2805 0.0778 0.0011 0.1107 0.3348 0.0000 0.1352
19T 0.2805 0.0778 0.0011 0.1107 0.3348 0.0000 0.1352
24 0.2805 0.0778 0.0011 0.1107 0.3340 0.0000 0.1360
40 0.2805 0.0778 0.0011 0.1107 0.3349 0.0000 0.1351
41 0.2805 0.0778 0.0011 0.1107 0.3354 0.0000 0.1346
42 0.2805 0.0778 0.0011 0.1107 0.3352 0.0000 0.1348
26 0.2805 0.0778 0.0011 0.1107 0.3347 0.1353
29 0.2805 0.0778 0.0011 0.1107 0.3348 0.1352
30 0.2805 0.0778 0.0011 0.1107 0.3348 0.1352
32 0.2805 0.0778 0.0011 0.1107 0.3348 0.1352
34 0.2805 0.0778 0.0011 0.1107 (0.3348) 0.1352
* Earnings Sharing Credits are applied as monthly amounts per the table below.
Schedule Special Contract Monthly Credit
26 Micron $0.00
29 Simplot $0.00
30 DOE $0.00
32 Simplot-Caldwell $0.00
34 Lamb Weston $0.00
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, 2026.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective - June 1, 2025 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Forst Second Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 94q+aa4-First Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all Idaho retail Customers served
under the Company's schedules and Special Contracts listed within this schedule. These loads are
referred to as "firm" load for purposes of this schedule.
BASE POWER COST AND PROJECTED POWER COST
The Base Power Cost of the Company's rates, expressed in cents per kWh, is computed by
dividing the sum of the Company's power cost components by firm kWh sales. The power cost
components are segmented into three categories as described in the table below:
The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the power
cost components for the forecasted time period beginning April 1 each year and ending the following
March 31.
BALANCING ADJUSTMENT
The Balancing Adjustment is based upon the differences between previous Projected Power Cost
and the power costs actually incurred. The Balancing Adjustment is 0.5946 GeRtS per 1AA"varies by rate
class and is included in the table below.
EARNINGS SHARING
Order Nos. 30978, 32424, 33149, a d-34071, and 36042 -directed the Company to share a
portion of its earnings above a certain threshold with customers through the annual Power Cost
Adjustment. The Company's 20234 earnings were not above the prescribed threshold resulting in a
credit of 0.0000 cents per kWh.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.-36202 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective— duae-1, 2024June 1, 2025 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Forst Second Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Q4g+Ra4-First Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT
The Power Cost Adjustment (PCA) is the sum of: 1) 95 percent of the difference between the
Projected Power Costs in Category 1 and the Base Power Costs in Category 1; 2) 100 percent of the
difference between the Projected Power Costs in Category 2 and the Base Power Costs in Category 2;
3) 100 percent of the difference between the Projected Power Costs in Category 3 and the Base Power
Costs in Category 3; 4) 100 percent of the difference between the Protected Power Costs in Category 4
and the Base Power Costs in Category 4; 5) the Balancing Adjustment; and 56) Earnings Sharing. The
following table calculates the rates for Categories 1, 2.3 -and 43.
The following table shows the determination of PCA rates for Categories 1, 2,3 and 48:
Base Projected Sharing
Category Description Power Power Difference % Rate
Cost Cost
(¢ per kWh)
The sum of fuel expense and
purchased power expense
(excluding purchases from
cogeneration and small power 1�48241_6 91 0.122450. ° Q.i 16330.
1 producers), less the sum of off- 0371 .89897 29526 95/0 28050
system surplus sales revenue and
revenue from market-based
special contract pricing.
Purchased power expense from 81_3 1.390921 0.032590. 0.v 032590.
2 cogeneration and small power 2163 .39941 07778 100% 07778
producers.
Demand response incentive 0.067670_0 0.068910 0.001130. ° 0.001130.
3 payments. 6585 .06695 00110 100/° 00110
4 Payments for battery energy 0.00000 0.11066 0.11066 100% 0.11066
storage system leases
�.^�42_9 3.'�r3 0�0. 0A 50050.
Total 9119 .47599 48480 47004
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.-36202 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—iURe 1, 2024June 1, 2025 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Forst Second Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Orig1Pa4First Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
The monthly Power Cost Adjustment rates applied to the Energy rate of all metered schedules and
Special Contracts are shown below. The monthly Power Cost Adjustment applied to the per unit charges
of the nonmetered schedules is the monthly estimated usage times the cents per kWh rates shown below.
Totals may not tie due to rounding.
Balancing Earning Total PCA
Schedul Adjustment s
e Cate [y Sharing
1 2 3 4
9.1630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3351 (0.0000)
05 778 0.74470.134
1 9
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3351 (0.0000) 0.74470.134
3 05 778 9
0.11630.28 0.03260_0 0.0011 0.1107 9.5946 0.3351 (0.0000) 0.74470.134
5 05 778 9
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3350 (0.0000) 0.74470.135
6 05 778 0
0.11630.28 0.03260_0 0.0011 0.1107 9.5946 0.3353 (0.0000) 0.74470.134
7 05 778 7
0.11630.28 0.03260_0 0.0011 0.1107 8.5946 0.3355 (0.0000) 0.74470.134
8 05 778 5
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3346 (0.0000) 9:74470.135
9S 05 778 4
9.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3350 (0.0000) 0.74470.135
9P 05 778 0
0.11630.28 0.03260_0 0.0011 0.1107 9.5946 0.3349 (0.0000) 0.74470.135
9T 05 778 1
0.11630.28 0.03260_0 0.0011 0.1107 �0-.59460.3357 (0.0000) 0.74470.134
15 05 778 3
0.11630.28 0.03260_0 0.0011 0.1107 9.5946 0.3350 (0.0000) 0.74470.135
19S 05 778 0
0.11630.28 0.03260_0 0.0011 0.1107 8.5946 0( 3348 (0.0000) 0.74470.135
19P 05 778 2
0.11630.28 0.03260_0 0.0011 0.1107 9.5946 0.3348 (0.0000) 9:74470.135
19T 05 778 2
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3340 (0.0000) 9:74470.136
24 05 778 0
0.11630.28 0.03260_0 0.0011 0.1107 8.5946 0( 3349 (0.0000) 0.74470.135
40 05 778 1
0.11630.28 0.03260_0 0.0011 0.1107 8.5946 0.3354 (0.0000) 0.74470.134
41 05 778 6
0.11630.28 0.03260_0 0.0011 0.1107 8.5946 0.3352 (0.0000) 9 4470.134
42 05 778 8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36202 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective-iURe 1, 2024June 1, 2025 1221 West Idaho Street, Boise, Idaho

Idaho Power Company Forst Second Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30 Tariff No. 101 First Revised Sheet No. 55-3
0-1630.28 0.03260.0 0.0011 0.1107 0.5946 0( 3347 0.74470.135
26 05 778 3
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0.3348 0.74470.135
29 05 778 2
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3348 0.74470.135
30 05 778 2
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0( 3348 0.74470.135
32 05 778 2
0.11630.28 0.03260_0 0.0011 0.1107 0.5946 0.3348 0.74470.135
34 05 778 2
* Earnings Sharing Credits are applied as monthly amounts per the table below.
Schedule Special Contract Monthly Credit
26 Micron $0.00
29 Simplot $0.00
30 DOE $0.00
32 Simplot-Caldwell $0.00
34 Lamb Weston $0.00
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, 20256.
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No.-36202 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective—iURe 1, 2024June 1, 2025 1221 West Idaho Street, Boise, Idaho

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-20
IDAHO POWER COMPANY
ATTACHMENT NO. 2
2025 REVENUE IMPACT SUMMARY

Idaho Power Company
Calculation of Revenue Impact
State of Idaho PC
Filed A 15,2025
Summary of Revenue Impact
Current Billed Revenue to Proposed Billed Revenue
Total Percent
Rate Average Normalized Current Adjustments Proposed Change
Line Sch. Number of Energy Billed Mills to Billed Billed Mills Billed to Billed
No Tariff Description No. Customers l'I (kWh) Revenue Per kWh Revenue Revenue Per kWh Revenuer)
Uniform Tariff Rates:
1 Residential Service 1 524,237 5,615,942,611 $714,057,042 127.15 ($34,246,018) $679,811,024 121.05 (4.80)%
2 Master Metered Mobile Home Park 3 19 5,043,898 $613,244 121.58 ($30,758) $582,486 115.48 (5.02)%
3 Residential Service Time-of-Day 5 990 17,907,943 $2,197,568 122.71 ($109,203) $2,088,366 116.62 (4.97)%
4 Residential Service On-Site Generation 6 19,350 258,375,457 $31,811,157 123.12 ($1,575,316) $30,235,841 117.02 (4.95)%
5 Small General Service 7 30,219 139,926,373 $21,483,300 153.53 ($853,551) $20,629,749 147.43 (3.97)%
6 Small General Service On-Site Generation 8 87 768,473 $94,452 122.91 ($4,689) $89,763 116.81 (4.96)%
7 Large General Service 9 40,122 4,068,443,436 $373,765,920 91.87 ($24,791,657) $348,974,263 85.78 (6.63)%
8 Dusk to Dawn Lighting 15 0 1,937,298 $1,357,634 700.79 ($11,825) $1,345,809 694.68 (0.87)%
9 Large Power Service 19 134 2,192,917,988 $166,776,995 76.05 ($13,365,848) $153,411,147 69.96 (8.01)%
10 Agricultural Irrigation Service 24 19,847 1,770,258,152 $183,663,718 103.75 ($10,775,561) $172,888,157 97.66 (5.87)%
11 Un m,tered General Service 40 1,857 14,484,473 $1,531,179 105.71 ($88,297) $1,442,882 99.62 (5.77)%
12 Street Lighting 41 1,687 20,419,614 $4,014,958 196.62 ($124,587) $3,890,371 190.52 (3.10)%
13 Traffic Control Lighting 42 859 3,056,155 $257,756 84.34 ($18,639) $239,117 78.24 (7.23)%
14 Total Uniform Tariffs 639,408 14,109,481,872 $1,501,624,923 106.43 ($85,995,950) $1,415,628,973 100.33 (5.73)%
15 Total Special Contracts 7 1,442062,021 $106,512,215 73.86 ($8,788,680) $97,723,535 67.77 (8.25)%
16 Total Clean Energy Your Way Sales 18:839,401 $253,654 $0 $253,654 0.00%
17 Idaho Power Supplied Retail Sales Rt 639,415 15,570,383,294 1,608,390,792 103.30 (94,794,630) 1,513,606,162 97.21 (5.89)%
(1)Test Year Revenue Forecast Jun 2025-May 2026
(2)Impacts do not include Clean Energy Your Way and marginal energy sales

Idaho Power Company
Calculation of Revenue Impact
State of Idaho PC
Filed A 15,2025
Summary of Revenue Impact-Rates 9,19,and 24 Distribution Level Detail
Current Billed Revenue to Proposed Billed Revenue
Percent
Rate Average Normalized Current Adjustments Proposed Change
Line Sch. Number of Energy Base Mills to Base Base Mills Base to Base
No Tariff Description No. Customers(1) k((kWh) Revenue Per kWh Revenue Revenue Per kWh Revenue
Uniform Tariff Rates:
1 Large General Secondary 9S 39,824 3,409,784,142 $319,189,998 93.61 ($20,775,815) $298,414,183 87.52 (6.51)%
2 Large General Primary 9P 292 655,067,733 $54,240,339 82.80 ($3,993,948) $50,246,391 76.70 (7.36)%
3 Large General Transmission 9T 6 3,591,562 $335,584 93.44 ($21,894) $313,689 87.34 (6.52)%
4 Total Schedule 9 40.122 4,068,443,436 $373,765,920 91.87 ($24,791,657) $348,974,263 85.78 (6.63)%
5 Large Power Secondary 195 1 6,446,801 $531,259 82.41 ($39,306) $491,953 76.31 (7.40)%
6 Large Power Primary 19P 130 2,147,461,978 $163,389,724 76.09 ($13,088,781) $150,300,943 69.99 (8.01)%
7 Large Power Transmission 19T 3 39,009,209 $2,856,012 73.21 ($237,761) $2,618,251 67.12 (8.32)%
8 Total Schedule 19 134 2,192,917,988 $166,776,995 76.05 ($13,365,848) $153,411,147 69.96 (8A1)%
9 Irrigation Secondary 24S 19,847 1,770,258,152 $183,663,718 103.75 ($10,775,561) $172,888,157 97.66 (5.87)%
10 Irrigation Transmission 24T 0 0 $0 0.00 $0 $0 0.00 0.00%
11 Total Schedule 24 19,847 1,770,258,152 $183,663,718 103.75 ($10,775,561) $172,888,157 97.66 (5.87)%
(1)Test Year Revenue Forecast Jun 2025-May 2026