Errata to Application and Testimony.tif

ERRATA TO APPLICATION AND DIRECT TESTIMONY OF JESSICA G. BRADY - 1
MEGAN GOICOECHEA ALLEN (ISB No. 7623)
LISA C. LANCE (ISB No. 6241)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER
COMPANY’S APPLICATION FOR
AUTHORITY TO IMPLEMENT POWER
COST ADJUSTMENT (“PCA”) RATES
FOR ELECTRIC SERVICE FROM JUNE 1,
2026 THROUGH MAY 31, 2027.
)
)
)
)
)
)
)
)
CASE NO. IPC-E-26-10
ERRATA TO APPLICATION AND
DIRECT TESTIMONY OF JESSICA
G. BRADY
Idaho Power Company (“Idaho Power” or “Company”) hereby respectfully submits
to the Idaho Public Utilities Commission (“Commission”) this Errata to the Company’s
Application to implement Power Cost Adjustment (“PCA”) rates for electric service from
June 1, 2026 through May 31, 2027, and the Direct Testimony of Jessica G. Brady (“Brady
Testimony”) filed contemporaneously therewith on April 15, 2026, to correct a calculation
error and to ensure accuracy, consistency, and clarity of the record, as described below.
1. Following the filing of the PCA on April 15, 2026, the Company identified a
calculation error related to the Balancing Adjustment. Specifically, for the months of
ERRATA TO APPLICATION AND DIRECT TESTIMONY OF JESSICA G. BRADY - 2
January, February, and March 2026, base level costs associated with Federal Energy
Regulatory Commission (“FERC”) Account 557.4, Energy Storage Rents, were included
in the 95 percent sharing account category, while actual costs were recorded in a 100
percent sharing account.
2. Upon identification of this calculation error, the Company updated the
Balancing Adjustment calculation such that both base level and actual costs for FERC
Account 557.4 are reflected in a 100 percent sharing account. Exhibit 2 has been revised
to reflect these updated amounts. Incorporation of the revised Balancing Adjustment
results in a reduction to total PCA collection of $240,703.38.
3. The Company is also providing revised versions of Attachment 1 and
Attachment 2 with this Errata.
4. As a result of the correction described above, the Company provides the
following substitutions to the Application and the Brady Testimony for consistency and
clarity:
 Application, pages 2, 13, 15, and 17: replace “$51.6 million” with “$51.3
million”;
 Application, pages 2, 13, and 15: replace “3.02 percent” with “3.00 percent”;
 Application, page 11: replace “$75 million” with “negative $75.3 million”;
 Application, page 11: replace “$78.3 million ($75 + $3.3 = $78.3 million)”
with “negative $78.6 million ($75.3 + $3.3 = $78.6 million)”;
 Application, pages 13 and 15: replace “$86.8 million” with “$86.5 million”;
ERRATA TO APPLICATION AND DIRECT TESTIMONY OF JESSICA G. BRADY - 3
 Brady Testimony, page 2 (line 12), page 5 (line 24), page 6 (lines 2 and 4),
page 27 (line 16), and page 28 (line 7): replace “$51.6 million” with $51.3
million”;
 Brady Testimony, page 5 (line 23): replace “$86.8 million” with “$86.5
million”;
 Brady Testimony, page 2 (line 12), page 5 (line 25), page 27 (line 16), and
page 28 (line 8): replace “3.02 percent” with “3.00 percent”;
 Brady Testimony, page 13 (line 23): replace “$75,058,413” with
“$75,297,596”;
 Brady Testimony, page 14 (line 2) and page 23 (line 1): replace “$75 million”
with “$75.3 million”;
 Brady Testimony, page 23 (line 4): replace “$78,337,620” with
“$78,576,803”;
 Brady Testimony, page 27 (line 21): replace “$56.7 million” with “$56.4
million”;
 Brady Testimony, page 27 (line 22): replace “3.31 percent” with “3.30
percent”.
5. As a result of the correction described above, the Company has updated
the summary table that appears in both the Application (Table 2) and the Brady Testimony
(Table 1) to reflect the revised Balancing Adjustment. The revised table is provided below
and replaces the corresponding tables previously filed. In addition, the Company is
including with this filing replacement pages to the Brady Testimony reflecting the
substitutions noted herein for ease of reference and review.
ERRATA TO APPLICATION AND DIRECT TESTIMONY OF JESSICA G. BRADY - 4
Revised Table
Application page 14; Brady Testimony, page 6
Idaho Jurisdictional Revenue Impact by Component
Line
No.Rate Component 2025-2026 PCA 2026-2027 PCA Difference
1 PCA Forecast $ 88,931,875 $ 165,106,470 $ 76,174,596
2
PCA Balancing
Adjustment $ (53,722,317) $ (78,581,629) $ (24,859,313)
3 PCA Total $ 35,209,558 $ 86,524,841 $ 51,315,283
4 Revenue Sharing $ 0 $ 0 $ 0
5 Total Revenue Impact $ 35,209,558 $ 86,524,841 $ 51,315,283
These updates do not otherwise modify the Application or the Brady Testimony.
DATED at Boise, Idaho, this 4th day of May 2026.
MEGAN GOICOECHEA ALLEN
Attorney for Idaho Power Company
ERRATA TO APPLICATION AND DIRECT TESTIMONY OF JESSICA G. BRADY - 5
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on the 4th day of May 2026, I served a true and correct
copy of Idaho Power Company’s Errata to Application and Direct Testimony of Jessica G.
Brady upon the following named parties by the method indicated below, and addressed
to the following:
Commission Staff
Kelsea E. Ross
Deputy Attorney General
Idaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg No. 8
Suite 201-A (83714)
PO Box 83720
Boise, ID 83720-0074
Hand Delivered
U.S. Mail
Overnight Mail
FAX
FTP Site
X Email
[e-mail]

Stacy Gust
Regulatory Administrative Assistant

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-26-10

IDAHO POWER COMPANY

ATTACHMENT NO. 1

PROPOSED SCHEDULE 55
(CLEAN AND LEGISLATIVE FORMAT)
Idaho Power Company Third Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2026 1221 West Idaho Street, Boise, Idaho
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 four 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 negative 0.4897 cents per kWh.
EARNINGS SHARING
Order Nos. 30978, 32424, 33149, 34071, 36042, and 36892 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 2025 earnings were not above the prescribed threshold resulting in a credit
of 0.0000 cents per kWh.
Idaho Power Company Fourth Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2026 1221 West Idaho Street, Boise, Idaho
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:
Category Description
Base
Power
Cost
Projected
Power
Cost
Difference Sharing
% Rate
(¢ per kWh)
1
The sum of fuel expense and
purchased power expense
(excluding purchases from
cogeneration and small power
producers), less the sum of off-
system surplus sales revenue and
revenue from market-based
special contract pricing.
1.26276 2.34403 1.08127 95%1.02720
2
Purchased power expense from
cogeneration and small power
producers.
1.35535 1.34884 (0.00651)100%(0.00651)
3 Demand response incentive
payments. 0.05822 0.06640 0.00817 100%0.00817
4 Payments for battery energy
storage system leases 0.12880 0.12880 0.00000 100%0.00000
Total 2.80513 3.88807 1.08293 1.02887
Idaho Power Company Fourth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Third Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2026 1221 West Idaho Street, Boise, Idaho
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.
Schedule Category
Balancing
Adjustment
Earnings
Sharing
Total PCA
1 2 3 4
1 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
3 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
5 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
6 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
7 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
8 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
9S 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
9P 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
9T 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
15 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
19S 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
19P 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
19T 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
24 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
40 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000) 0.5392
41 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
42 1.0272 (0.0065)0.0082 0.0000 (0.4897)(0.0000)0.5392
26 1.0272 (0.0065)0.0082 0.0000 (0.4897)* 0.5392
29 1.0272 (0.0065)0.0082 0.0000 (0.4897)*0.5392
30 1.0272 (0.0065)0.0082 0.0000 (0.4897)* 0.5392
32 1.0272 (0.0065)0.0082 0.0000 (0.4897)*0.5392
33 1.0272 (0.0065)0.0082 0.0000 (0.4897)* 0.5392
34 1.0272 (0.0065)0.0082 0.0000 (0.4897)*0.5392
* 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)
33 Brisbie ($0.00)
34 Lamb Weston ($0.00)
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, 2027.
Idaho Power Company Second Third Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 30, Tariff No. 101 First Second Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36618 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 20256 1221 West Idaho Street, Boise, Idaho
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 four 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 belowis negative 0.4897 cents per kWh.
EARNINGS SHARING
Order Nos. 30978, 32424, 33149, 34071, and 36042, and 36892 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 20245 earnings were not above the prescribed threshold resulting in a
credit of 0.0000 cents per kWh.
Idaho Power Company Third Fourth Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Third Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36892 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026June 1, 2026 1221 West Idaho Street, Boise, Idaho
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:
Category Description
Base
Power
Cost
Projected
Power
Cost
Difference Sharing
% Rate
(¢ per kWh)
1
The sum of fuel expense and
purchased power expense
(excluding purchases from
cogeneration and small power
producers), less the sum of off-
system surplus sales revenue and
revenue from market-based
special contract pricing.
1.301811.2
6276
1.898972
.34403
0.597161.
08127 95%0.567301.
02720
2
Purchased power expense from
cogeneration and small power
producers.
1.397261.3
5535
1.399411
.34884
0.00215(0
.00651)100%0.00215(0
.00651)
3 Demand response incentive
payments.
0.060080.0
5822
0.066950
.06640
0.006870.
00817 100%0.006870.
00817
4 Payments for battery energy
storage system leases
0.132790.1
2880
0.110660
.12880
(0.02213)
0.00000 100%(0.02213)
0.00000
Total 2.891932.8
0513
3.475993
.88807
0.584061.
08293
0.554201.
02887
Idaho Power Company Third Fourth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Third Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36892 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026June 1, 2026 1221 West Idaho Street, Boise, Idaho
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.
Schedule Category
Balancing
Adjustment
Earnings
Sharing
Total PCA
1 2 3 4
1
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3351)(0.48
97)
(0.0000) 0.21910.53
92
3
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3351)(0.48
97)
(0.0000) 0.21910.53
92
5
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3351)(0.48
97)
(0.0000) 0.21910.53
92
6
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3350)(0.48
97)
(0.0000) 0.21920.53
92
7
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3353)(0.48
97)
(0.0000) 0.21890.53
92
8
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3355)(0.48
97)
(0.0000) 0.21870.53
92
9S
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3346)(0.48
97)
(0.0000) 0.21960.53
92
9P
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3350)(0.48
97)
(0.0000) 0.21920.53
92
9T
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3349)(0.48
97)
(0.0000) 0.21930.53
92
15
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3357)(0.48
97)
(0.0000) 0.21850.53
92
19S
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3350)(0.48
97)
(0.0000) 0.21920.53
92
19P
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3348)(0.48
97)
(0.0000) 0.21940.53
92
19T
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3348)(0.48
97)
(0.0000) 0.21940.53
92
24
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3340)(0.48
97)
(0.0000) 0.22020.53
92
40
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3349)(0.48
97)
(0.0000) 0.21930.53
92
41
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3354)(0.48
97)
(0.0000) 0.21880.53
92
42
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3352)(0.48
97)
(0.0000) 0.21900.53
92
26
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3347)(0.48
97)
* 0.21950.53
92
Idaho Power Company Third Fourth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 30, Tariff No. 101 Second Third Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 36892 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2026June 1, 2026 1221 West Idaho Street, Boise, Idaho
29
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3348)(0.48
97)
* 0.21940.53
92
30
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3348)(0.48
97)
* 0.21940.53
92
32
0.56731.
0272
(0.00220.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3348)(0.48
97)
* 0.21940.53
92
33 1.0272 (0.0065)0.0082 0.0000 (0.4897)* 0.5392
34
0.56731.
0272
0.0022(0.
0065)
0.00690.
0082
(0.0221)
0.0000
(0.3348)(0.48
97)
* 0.21940.53
92
* 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)
33 Brisbie ($0.00)
34 Lamb Weston ($0.00)
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31, 20267.

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-26-10

IDAHO POWER COMPANY

ATTACHMENT NO. 2

2026 REVENUE IMPACT SUMMARY
Total Percent Rate Average Normalized Current Adjustments Proposed ChangeLine Sch. Number of Energy Billed Mills to Billed Billed Mills Billed to BilledNoTariff DescriptionNo.Customers (1)(kWh) (1)RevenuePer kWhRevenueRevenuePer kWhRevenue (2) Uniform Tariff Rates: 1 Residential Service 1 536,116 5,769,505,395 $738,403,238 127.98 $18,468,187 $756,871,424 131.18 2.50%2 Master Metered Mobile Home Park 3 18 4,630,264 $564,168 121.84 $14,821 $578,989 125.04 2.63%3 Residential Service Time-of-Day 5 1,015 18,319,326 $2,247,986 122.71 $58,640 $2,306,626 125.91 2.61%4 Residential Service On-Site Generation 6 21,008 176,566,444 $23,191,633 131.35 $565,013 $23,756,645 134.55 2.44%5 Small General Service 7 30,588 142,405,188 $22,142,402 155.49 $456,124 $22,598,526 158.69 2.06%6 Small General Service On-Site Generation 8 87 385,257 $61,107 158.61 $1,235 $62,342 161.82 2.02%7 Large General Service 9 41,066 4,140,314,151 $375,818,899 90.77 $13,235,012 $389,053,911 93.97 3.52%8 Dusk to Dawn Lighting 15 0 1,928,912 $1,394,337 722.86 $6,186 $1,400,523 726.07 0.44%9 Large Power Service 19 136 2,271,024,627 $167,490,781 73.75 $7,262,748 $174,753,529 76.95 4.34%10 Agricultural Irrigation Service 24 19,948 1,856,032,644 $200,660,331 108.11 $5,920,744 $206,581,075 111.30 2.95%11 Unmetered General Service 40 1,893 14,581,469 $1,546,870 106.08 $46,646 $1,593,516 109.28 3.02%12 Street Lighting 41 1,693 20,976,429 $4,114,222 196.14 $67,208 $4,181,431 199.34 1.63%13 Traffic Control Lighting 42 880 3,145,189 $275,151 87.48 $10,071 $285,221 90.69 3.66%14 Total Uniform Tariffs 654,448 14,419,815,296 $1,537,911,123 106.65 $46,112,636 $1,584,023,759 109.85 3.00% 15 Total Special Contracts 7 1,627,076,575 $171,567,129 105.45 $5,202,647 $176,769,776 108.64 3.03%16 Total Clean Energy Your Way Sales 62 20,079,805 $248,606 $0 $248,606 0.00%17Idaho Power Supplied Retail Sales (2)654,455 16,066,971,675 1,709,726,858 106.41 $51,315,283 $1,761,042,141 109.61 3.00%(1) Test Year Revenue Forecast Jun 2026 - May 2027(2) Impacts do not include Clean Energy Your Way and marginal energy sales Idaho Power CompanyCalculation of Revenue ImpactState of IdahoIPC-E-26-06Proposed June 1, 2026Summary of Revenue ImpactCurrent Billed Revenue to Proposed Billed Revenue
Percent Rate Average Normalized Current Adjustments Proposed ChangeLine Sch. Number of Energy Base Mills to Base Base Mills Base to BaseNoTariff DescriptionNo.Customers (1)(kWh) (1)RevenuePer kWhRevenueRevenuePer kWhRevenue Uniform Tariff Rates: 1 Large General Secondary 9S 40,763 3,495,766,996 $324,566,219 92.85 $11,172,471 $335,738,690 96.04 3.44%2 Large General Primary 9P 296 634,769,383 $50,417,057 79.43 $2,031,262 $52,448,319 82.63 4.03%3 Large General Transmission 9T 7 9,777,772 $835,623 85.46 $31,279 $866,902 88.66 3.74%4 Total Schedule 9 41,066 4,140,314,151 $375,818,899 90.77 $13,235,012 $389,053,911 93.97 3.52% 5 Large Power Secondary 19S 1 5,867,482 $474,280 80.83 $18,776 $493,056 84.03 3.96%6 Large Power Primary 19P 133 2,231,709,797 $164,652,330 73.78 $7,137,008 $171,789,338 76.98 4.33%7 Large Power Transmission 19T 2 33,447,348 $2,364,170 70.68 $106,965 $2,471,135 73.88 4.52%8 Total Schedule 19 136 2,271,024,627 $167,490,781 73.75 $7,262,748 $174,753,529 76.95 4.34% 9 Irrigation Secondary 24S 19,948 1,856,032,644 $200,660,331 108.11 $5,920,744 $206,581,075 111.30 2.95%10 Irrigation Transmission 24T 0 0 $0 0.00 $0 $0 0.00 0.00%11 Total Schedule 24 19,948 1,856,032,644 $200,660,331 108.11 $5,920,744 $206,581,075 111.30 2.95%(1) Test Year Revenue Forecast Jun 2026 - May 2027Proposed June 1, 2026 Summary of Revenue Impact - Rates 9, 19, and 24 Distribution Level DetailCurrent Billed Revenue to Proposed Billed RevenueIdaho Power CompanyCalculation of Revenue ImpactState of IdahoIPC-E-26-06
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-26-10
IDAHO POWER COMPANY
BRADY, DI
TESTIMONY
REPLACEMENT PAGES

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

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, 2026, THROUGH MAY 31, 2027.

)
)
)
)
)
)
)

CASE NO. IPC-E-26-10

IDAHO POWER COMPANY

DIRECT TESTIMONY

OF

JESSICA G. BRADY

BRADY, DI 2
Idaho Power Company
power supply expenses (“NPSE”) for ratemaking purposes, as 1
well as the determination of the marginal cost of energy 2
used in the Company’s marginal cost analyses. My duties 3
also include providing analytical support for other 4
regulatory activities within the Regulatory Affairs 5
Department. 6
Q. What is the Company requesting in this case? 7
A. The Company is requesting approval of its 8
2026-2027 Power Cost Adjustment (“PCA”) rates to become 9
effective June 1, 2026. If approved, the 2026-2027 PCA 10
will result in an increase in total billed revenue of 11
approximately $51.3 million, or 3.00 percent. 12
Q. How is your testimony organized? 13
A. My testimony consists of four sections. In the 14
first section, I provide an overview of the PCA. In the 15
second section, I detail the 2026-2027 PCA amount in 16
comparison to last year’s PCA amount, identify and discuss 17
the main factors contributing to this change, which 18
includes a discussion regarding the Company’s proposal to 19
return the balance of the Boardman Balancing Account, and 20
present the quantification of the 2026-2027 PCA rates to 21
become effective June 1, 2026. In the third section, I 22
discuss the additional PCA component related to revenue 23
sharing. In the fourth section, I detail the net customer 24
impact of the 2026-2027 PCA rates if approved as filed. 25

BRADY, DI 5
Idaho Power Company
incurred, to provide safe, reliable electric service to 1
customers. 2
Q. What are the components of the PCA base level 3
NPSE? 4
A. The PCA base level NPSE includes the following 5
Federal Energy Regulatory Commission (“FERC”) accounts: 6
Account 501, Fuel (steam); Account 536, Water for Power; 7
Account 547, Fuel (gas); Account 555, Purchased Power; 8
Account 565, Transmission of Electricity by Others; Account 9
577.4, Energy Storage Rents; and Account 447, Sales for 10
Resale (typically referred to as surplus sales). 11
The PCA base level expense component for FERC 12
Account 555 includes costs of both PURPA and non-PURPA 13
purchases. Per Order No. 32426, the Company adjusts FERC 14
Account 555 to also include demand response incentive 15
payments that the Company provides to customers who 16
participate in any of its three demand response programs. 17
II. 2026-2027 PCA 18
Q. What is the total PCA collection that would 19
result under the 2026-2027 PCA rates proposed by the 20
Company in this case? 21
A. The 2026-2027 PCA rates would result in total 22
PCA collection of $86.5 million. This represents an 23
increase in total billed revenue of $51.3 million for the 24
upcoming year, an increase of 3.00 percent. 25

BRADY, DI 6
Idaho Power Company
Q. Have you prepared a table that details the 1
$51.3 million revenue impact by component? 2
A. Yes. Table 1 presents a separation of the 3
$51.3 million increase into each component included in the 4
Company’s proposed rates. 5
Table 1 Idaho Jurisdictional Revenue Impact by Component

Line
No. Rate Component 2025-2026 PCA 2026-2027 PCA Difference
1 PCA Forecast $ 88,931,875 $ 165,106,470 $ 76,174,596
2 PCA Balancing Adjustment $ (53,722,317) $ (78,581,629)1 $ (24,859,313)
3 PCA Total $ 35,209,558 $ 86,524,841 $ 51,315,283
4 Revenue Sharing $ 0 $ 0 $ 0
5 Total Revenue Impact $ 35,209,558 $ 86,524,841 $ 51,315,283
6
Q. What are the main factors driving the revenue 7
change requested in this case? 8
A. The increase in this year’s filing is driven 9
by an increase to the forecast component, partially offset 10
by a decrease to the Balancing Adjustment. 11
The increase in the forecast component is largely 12
attributable to a 16 percent decrease in forecast hydro 13
generation compared to the prior PCA year. The decrease in 14
the Balancing Adjustment is driven primarily by increased 15
Renewable Energy Credit (“REC”) sales, the Sales Based 16
Adjustment (“SBA”), which reflects variances between actual 17
sales and the sales used to establish base-level NPSE, and 18

1 The 2026-2027 Balancing Adjustment amount includes the Idaho-
jurisdictional Boardman Balancing Account over-collection amount of
$3,279,207.

BRADY, DI 13
Idaho Power Company
A. For the 2026-2027 PCA Year, Idaho Power has 1
forecast system-level firm sales to be 16,727,802 MWh and 2
Idaho jurisdictional firm sales to be 16,046,892 MWh, or 3
95.93 percent of the system level. 4
Q. What is the Company’s determination of the 5
2026-2027 PCA forecast component to be collected from Idaho 6
customers? 7
A. As shown in Table 1, the 2026-2027 PCA 8
forecast component to be collected from Idaho customers is 9
$165,106,470. 10
B. Balancing Adjustment. 11
Q. What is this year’s quantification of the 12
Balancing Adjustment, excluding amounts related to the 13
Boardman Balancing Account? 14
A. The Balancing Adjustment is detailed in the 15
PCA deferral report, attached hereto as Exhibit No. 2. This 16
report compares actual NPSE amounts to actual power cost 17
collections monthly, with the differences accumulated as a 18
deferral balance. The balance at the end of March 2026, 19
with interest applied, is negative $75,297,596 as shown in 20
row 104 of Exhibit No. 2. 21
Q. To what factors do you attribute the 22
accumulation of the approximate negative $75.3 million 23
deferral balance? 24

BRADY, DI 22
Idaho Power Company
$180,871,953 from Table 2 by 95 percent and then dividing 1
it by the System-level Sales Forecast of 16,727,802,226 kWh 2
(($180,871,953 * 0.95) / 16,727,802,226) = 0.0103 $/kWh). 3
The rate for PURPA expenses is negative $0.0001 per kWh, 4
which is calculated by dividing negative $1,088,465 from 5
Table 2 by the 16,727,802,226 kWh. The rate for demand 6
response incentive payments is $0.0001 per kWh, which is 7
calculated by dividing the $1,311,776 from Table 2 by the 8
Idaho Jurisdictional Sales Forecast of 16,046,891,871 kWh. 9
The rate for Energy Storage Rents is $0.0000 per kWh as 10
there is no difference between base level and forecast 11
expenses. 12
The total forecast portion of the PCA rate is 13
$0.0103 per kWh, which is calculated by adding the non-14
PURPA expense of $0.0103 per kWh to the PURPA expense of 15
negative $0.0001 per kWh to the demand response incentive 16
payment of $0.0001 per kWh to the Energy Storage Rents 17
expense of $0.0000 per kwh (0.0103 - 0.0001 + 0.0001 + 18
0.0000 = 0.0103 $/kWh). 19
Q. How did you compute this year’s Balancing 20
Adjustment rate? 21
A. As shown in Exhibit No. 2, this year’s 22
Balancing Adjustment of the PCA is approximately negative 23
$75.3 million, which, when added to the Boardman Balancing 24
Account amount of negative $3,279,207 and divided by the 25

BRADY, DI 27
Idaho Power Company
A. Yes. Exhibit No. 3 provides a step-by-step 1
calculation of the Idaho jurisdictional ROE based on year-2
end 2025 financial results utilizing the Commission-3
approved methodology from previous PCA filings. 4
IV. NET CUSTOMER IMPACT 5
Q. What is the revenue impact of the requested 6
PCA rate when compared with PCA rates currently in effect? 7
A. Attachment 2 to the Application filed 8
contemporaneously with my testimony provides a detailed 9
description of the overall revenue impact of this filing on 10
each customer class. As shown in Attachment 2, applying the 11
requested PCA rates to expected customer sales for the June 12
2026 through May 2027 test year results in a PCA increase 13
of $51.3 million, or 3.00 percent. 14
Q. What is the combined revenue impact of each of 15
the Company’s filings to be effective June 1, 2026? 16
A. If the proposed PCA and Fixed Cost Adjustment 17
(“FCA”) filings are approved as filed, the combined impact 18
is an overall increase in current billed revenue of $56.4 19
million, or 3.30 percent. 20
Q. Have you prepared a revised Schedule 55 that 21
includes the proposed PCA rates? 22
A. Yes. Attachment 1 to the Application is a 23
revised Schedule 55 and includes the proposed PCA rates in 24
clean and legislative formats. 25

BRADY, DI 28
Idaho Power Company
Q. Please summarize the Company’s request in this 1
filing. 2
A. If approved, the 2026-2027 PCA will result in 3
an increase in total billed revenue of approximately $51.3 4
million, or 3.00 percent. The Commission should approve the 5
Company’s computation of the PCA rates, the calculation of 6
which follows the methodology that was approved in Order 7
No. 30715. 8
Q. Does this conclude your testimony? 9
A. Yes, it does. 10
// 11
// 12
// 13
// 14
// 15
// 16
// 17
// 18
// 19
// 20
// 21
// 22
// 23
// 24
// 25

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-26-10

IDAHO POWER COMPANY

BRADY, DI
TESTIMONY

EXHIBIT NO. 2

Power Cost Adjustment April 2025 thru March 2026April May June July August September October November December January February March TotalsIdaho Jurisdiction Net Power Supply Expense (Non-QF)Actual Non-QFFuel Expense-Steam $ 4,185,189.51 5,079,870.13 7,393,303.75 12,948,986.00 12,469,922.08 11,677,955.31 12,442,290.10 12,110,829.68 6,120,652.98 8,820,091.36 4,622,863.37 3,349,823.58 101,221,777.85 Fuel Expense-Gas$ 4,171,864.78 5,033,712.69 8,758,307.31 12,555,793.34 14,337,608.49 10,680,723.95 7,668,317.32 13,768,782.83 21,651,445.71 20,099,279.17 16,547,761.71 9,951,991.09 145,225,588.39 Non-Firm Purchases $ 5,024,525.17 9,140,929.96 14,361,687.80 17,976,943.09 10,895,348.01 10,675,570.30 16,084,450.58 18,695,786.80 18,807,296.43 8,388,954.11 7,089,137.09 7,121,436.81 144,262,066.15 Third Party Transmission $ 906,827.13 888,490.62 162,163.74 1,242,859.85 1,252,117.18 1,107,583.76 934,454.29 1,001,700.32 1,196,143.89 1,887,949.86 2,497,850.46 (976,184.90) 12,101,956.20 Surplus Sales & Transmission Losses $(9,199,561.59) (7,136,761.59) (4,424,969.98) (4,811,109.30) (736,555.23) (8,109,961.57) (15,074,008.68) (17,500,833.78) (12,410,460.86) (2,727,638.85) (4,432,396.77) (1,651,982.88) (88,216,241.08) Water for Power (Leases) $ - - - - - - - - - - - - - Total Actual NPSE $ 5,088,845.00 13,006,241.81 26,250,492.62 39,913,472.98 38,218,440.53 26,031,871.75 22,055,503.61 28,076,265.85 35,365,078.15 36,468,635.65 26,325,215.86 17,795,083.70 314,595,147.51 Idaho Allocation95.6% 95.9% 96.1% 96.1% 96.0% 95.9% 96.1% 95.2% 95.4% 95.6% 95.5% 96.2% Net Idaho Jurisdictional Actual Non-QF $ 4,864,935.82 12,472,985.90 25,226,723.41 38,356,847.53 36,689,702.91 24,964,565.01 21,195,338.97 26,728,605.09 33,738,284.56 34,864,015.68 25,140,581.15 17,118,870.52 301,361,456.55Base Non-QFFuel Expense-Steam $ 4,321,401.00 4,578,880.00 5,597,322.00 7,146,746.00 7,643,877.00 6,655,023.00 4,655,438.00 4,397,909.00 5,020,646.008,708,206.93 8,312,454.26 7,916,325.64 74,954,228.82Fuel Expense-Gas$ 7,891,450.00 8,361,642.00 10,221,452.00 13,050,904.00 13,958,732.00 12,152,953.00 8,501,447.00 8,031,165.00 9,168,364.00 4,074,939.11 3,889,749.66 3,704,384.29 103,007,182.06Non-Firm Purchases $ 6,559,959.00 6,950,818.00 8,496,830.00 10,848,881.00 11,603,535.00 10,102,437.00 7,067,034.00 6,676,100.00 7,621,425.00 10,064,225.87 9,606,847.65 9,149,034.92 104,747,127.44Third Party Transmission $ 676,879.00 717,209.00 876,732.00 1,119,424.00 1,197,292.00 1,042,404.00 729,201.00 688,863.00 786,405.00 996,321.87 951,043.08 905,721.29 10,687,495.24Surplus Sales & Transmission Losses $(2,287,649.00) (2,423,953.00) (2,963,092.00) (3,783,321.00) (4,046,491.00) (3,523,014.00) (2,464,481.00) (2,328,151.00) (2,657,813.00) (6,812,498.23) (6,502,897.83) (6,193,003.31) (45,986,364.37)Water for Power (Leases) $ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Idaho Base NPSE $ 17,162,040.00 18,184,596.00 22,229,244.00 28,382,634.00 30,356,945.00 26,429,803.00 18,488,639.00 17,465,886.00 19,939,027.00 17,031,195.55 16,257,196.82 15,482,462.82 247,409,669.20 Idaho Allocation95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.83% 95.83% 95.83% Net Idaho Jurisdiction 95% Items $ 16,401,761.63 17,379,018.40 21,244,488.49 27,125,283.31 29,012,132.34 25,258,962.73 17,669,592.29 16,692,147.25 19,055,728.10 16,320,994.70 15,579,271.72 14,836,844.12 236,576,225.08 Idaho Jurisdiction Change From Base$ (11,536,825.81) (4,906,032.50) 3,982,234.92 11,231,564.22 7,677,570.57 (294,397.72) 3,525,746.68 10,036,457.84 14,682,556.46 18,543,020.98 9,561,309.43 2,282,026.40 64,785,231.47 Sharing Percentage95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0%Net Power Supply Expense Deferral (1)$(10,959,984.52)(4,660,730.88) 3,783,123.17 10,669,986.01 7,293,692.04 (279,677.83) 3,349,459.35 9,534,634.95 13,948,428.64 17,615,869.93 9,083,243.96 2,167,925.08 61,545,969.90Idaho Jurisdictional Qualifying Facility NPSEActual QF (Includes Net Metering, Raft River 100% & Liquidated Damages)$ 15,271,159.83 19,728,567.80 25,896,598.28 29,675,207.47 25,830,625.92 19,758,505.60 19,793,108.70 16,045,670.56 18,716,957.07 11,820,456.43 15,264,281.99 16,148,971.47 233,950,111.12 Idaho Allocation95.6% 95.9% 96.1% 96.1% 96.0% 95.9% 96.1% 95.2% 95.4% 95.6% 95.5% 96.2%Idaho Jurisdictional Actual QF $ 14,599,228.80 18,919,696.52 24,886,630.95 28,517,874.38 24,797,400.88 18,948,406.87 19,021,177.46 15,275,478.37 17,855,977.04 11,300,356.35 14,577,389.30 15,535,310.55 224,234,927.47Base QF$ 14,143,416.00 14,986,115.00 18,319,351.00 23,390,424.00 25,017,474.00 21,781,075.00 15,236,680.00 14,393,818.00 16,431,959.00 20,017,084.96 19,107,389.67 18,196,830.20 221,021,616.83Idaho Allocation95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.57% 95.83% 95.83% 95.83%Idaho Jurisdictional Base $ 13,516,862.67 14,322,230.11 17,507,803.75 22,354,228.22 23,909,199.90 20,816,173.38 14,561,695.08 13,756,171.86 15,704,023.22 19,182,372.52 18,310,611.52 17,438,022.38 211,379,394.61Idaho Jurisdiction Change From Base $ 1,082,366.13 4,597,466.41 7,378,827.20 6,163,646.16 888,200.98 (1,867,766.51) 4,459,482.38 1,519,306.51 2,151,953.82 (7,882,016.17) (3,733,222.22) (1,902,711.83) 12,855,532.86Sharing Percentage100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0%QF Deferral (2)$ 1,082,366.13 4,597,466.41 7,378,827.20 6,163,646.16 888,200.98 (1,867,766.51) 4,459,482.38 1,519,306.51 2,151,953.82 (7,882,016.17) (3,733,222.22) (1,902,711.83) 12,855,532.86 Idaho Revenue Adjustment (SBAR) Actual Idaho Jurisdictional Billing Month Sales MWh 1,041,992 1,154,889 1,398,929 1,671,616 1,671,846 1,500,405 1,180,713 1,028,839 1,118,516 1,210,052 1,244,813 1,091,459 15,314,069 Normalized Idaho Jurisdictional Billing Month Sales MWh 1,017,495 1,092,040 1,256,135 1,544,353 1,630,099 1,445,881 1,124,956 1,049,883 1,166,688 1,311,041 1,235,222 1,183,031 15,056,824 Sales Change MWh 24,497 62,849 142,794 127,263 41,747 54,524 55,757 (21,044) (48,172) (100,989) 9,591 (91,572) 257,245 % of Prior Period Billings at Old Rate-effective thru 12/31/2530.90$ 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 58.605% 0.157% 0.000% % of Current Period Billings at New Rate-effective 01/01/2627.82$ 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 41.400% 99.800% 100.000%Sales Adjustment Prior To Sharing @ $(756,959.52) (1,942,037.56) (4,412,343.19) (3,932,441.41) (1,289,992.71) (1,684,784.77) (1,722,880.95)650,261.36 1,488,509.45 2,991,935.11(266,747.00)2,547,541.91(8,329,939.28)Sharing Percentage95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0%Idaho Revenue Adjustment (SBAR) (3)$(719,111.54) (1,844,935.68) (4,191,726.03) (3,735,819.34) (1,225,493.07) (1,600,545.53) (1,636,736.90)617,748.29 1,414,083.98 2,842,338.35(253,409.65)2,420,164.81(7,913,442.31)Idaho Jurisdcitional Demand Response Incentive PaymentsIdaho Actual Demand Response $- 1,393.75 268,711.74 2,533,952.43 2,565,639.99 1,857,990.03 1,683,158.38 25,873.69 - 4,161.83 - 163.29 8,941,045.13 Idaho Base Demand Response$ 675,353.00 715,592.00 874,755.00 1,116,901.00 1,194,593.00 1,040,054.00 727,557.00 687,310.00 784,632.00 753,285.61 719,051.83 684,785.54 9,973,869.98Change From Base $(675,353.00) (714,198.25) (606,043.26) 1,417,051.43 1,371,046.99 817,936.03 955,601.38 (661,436.31) (784,632.00) (749,123.78) (719,051.83) (684,622.25) (1,032,824.85) Sharing Percentage100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0%Change From Base (4)$(675,353.00) (714,198.25) (606,043.26)1,417,051.43 1,371,046.99 817,936.03 955,601.38(661,436.31) (784,632.00) (749,123.78) (719,051.83) (684,622.25) (1,032,824.85)Idaho Miscellaneous Revenue System Emission Allowance Sales Credit $ - - - - - - - - - - - - - System Renewable Energy Credit Sales $502.69 (24,886.92) - (9,439,816.33) 50,792.82 837.21 112.23 125.01 (17,170.11) (24,346,168.81) (6,267,604.26) (8,848,382.00) (48,891,658.47)Revenue Subtotal $ 502.69(24,886.92)0.00(9,439,816.33)50,792.82 837.21 112.23 125.01(17,170.11) (24,346,168.81) (6,267,604.26) (8,848,382.00) (48,891,658.47)Idaho Allocation95.6% 95.9% 96.1% 96.1% 96.0% 95.9% 96.1% 95.2% 95.4% 95.6% 95.5% 96.2%Sharing Percentage95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0%Miscellaneous Revenue Deferral (5)$ 456.54(22,673.23)0.00(8,618,080.32)46,323.05 762.74 102.46 113.06(15,561.27) (22,111,190.51) (5,686,283.96) (8,086,536.31) (44,492,567.75)Idaho PTP Wheeling RevenuesExhibit 2Case No. IPC-E-26-10J. Brady, IPC1 of 2
Actual PTP Revenue Booked $(3,717,491.44) (3,697,939.82) (4,224,636.74) (4,237,448.38) (4,296,468.51) (4,012,888.78) (4,265,349.50) (4,177,519.48) (4,502,524.42) (4,324,917.60) (4,040,473.68) (4,380,435.38) (49,878,093.73) Idaho Allocation95.6% 95.9% 96.1% 96.1% 96.0% 95.9% 96.1% 95.2% 95.4% 95.6% 95.5% 96.2%ID PTP Revenue $(3,553,921.82) (3,546,324.29) (4,059,875.91) (4,072,187.89) (4,124,609.77) (3,848,360.34) (4,099,000.87) (3,976,998.54) (4,295,408.30) (4,134,621.23) (3,858,652.36) (4,213,978.84) (47,783,940.16) % of Prior Period Billings at Old Rate-effective through 12/31/253.11$ 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 100.000% 58.605% 0.157% 0.000% % of Current Period Billings at New Rate-effective 01/01/263.38$ 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 0.000% 41.400% 99.800% 100.000%OATT Revenue Credited in Base Rates $(3,240,595.34) (3,591,705.14) (4,350,670.05) (5,198,727.24) (5,199,442.11) (4,666,258.86) (3,672,016.39) (3,199,689.11) (3,478,585.30) (3,898,695.61) (4,205,129.45) (3,689,130.91) (48,390,645.52)OATT Revenue Difference(313,326.48)45,380.85 290,794.14 1,126,539.35 1,074,832.34 817,898.52(426,984.48) (777,309.43) (816,823.00) (235,925.62)346,477.09(524,847.93)606,705.36Sharing Percentage95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0% 95.0%OATT Revenue Deferral (6)$(297,660.15)43,111.81 276,254.44 1,070,212.38 1,021,090.72 777,003.60(405,635.26) (738,443.96) (775,981.85) (224,129.34)329,153.24(498,605.53)576,370.10TOTAL DEFERRAL (Sum of 1-6) $(11,569,286.54) (2,601,959.82)6,640,435.52 6,966,996.32 9,394,860.71(2,152,287.50)6,722,273.41 10,271,922.54 15,938,291.32(10,508,251.52) (979,570.46) (6,584,386.03)21,539,037.95PCA Forecasted Revenues Actual Idaho Jurisdictional Billing Month Sales MWh 1,041,992 1,154,889 1,398,929 1,671,616 1,671,846 1,500,405 1,180,713 1,028,839 1,118,516 1,210,052 1,244,813 1,091,459 15,314,069 % of Prior Period Billings at Old Rate0.000% 0.000% 55.399% 0.3101% 0.000% 0.000% 0.000% 0.000% 0.000% 58.605% 0.157% 0.000%% of Current Period Billings at New Rate 100.000% 100.000% 44.600% 99.700% 100.000% 100.000% 100.000% 100.000% 100.000% 41.400% 99.800% 100.000%Forecast Rate Revenues (7)(1,564,030.09) (1,733,488.58) (3,911,782.01) (7,837,195.92) (7,858,311.56) (7,052,467.60) (5,549,786.82) (4,835,919.55) (5,257,438.44) (6,087,374.53) (6,895,347.54) (6,048,864.98) (64,632,007.62)PCA Balancing Account BalanceMonthly Interest Rate 5% for 2025, 4% for 2026 % 0.4167% 0.4167% 0.4167% 0.4167% 0.4167% 0.4167% 0.4167% 0.4167% 0.4167% 0.3333% 0.3333% 0.3333% 4.7500%Beginning Balance(52,045,993.74)$ (71,591,928.94) (83,092,625.71) (83,618,004.78) (79,339,339.74) (72,538,256.58) (76,765,014.42) (72,222,791.17) (63,642,103.39) (49,480,543.82) (62,189,896.00) (66,099,505.22) (52,045,993.74)2025-2026 Incremental Deferral (Sum of 1-6 above)(11,569,286.54) (2,601,959.82)6,640,435.52 6,966,996.32 9,394,860.71 (2,152,287.50) 6,722,273.41 10,271,922.54 15,938,291.32 (10,508,251.52) (979,570.46) (6,584,386.03) 21,539,037.952025-2026 PCA Forecast Revenues (Collections) 7 above(1,564,030.09) (1,733,488.58) (3,911,782.01) (7,837,195.92) (7,858,311.56) (7,052,467.60) (5,549,786.82) (4,835,919.55) (5,257,438.44) (6,087,374.53) (6,895,347.54) (6,048,864.98) (64,632,007.62)2025-2026 PCA Prior Balance Revenues (Collections)(6,195,760.26) (6,866,948.67) (2,907,813.31)5,497,272.99 5,595,114.59 5,280,240.00 3,689,590.89 3,445,613.09 3,745,882.12 4,051,209.02 4,172,608.43 3,655,491.66 23,162,500.552025-2026 Ending Balance Without Current Month Interest(71,375,070.63) (82,794,326.01) (83,271,785.51) (78,990,931.39) (72,207,676.00) (76,462,771.68) (71,902,936.94) (63,341,175.09) (49,215,368.39) (62,024,960.85) (65,892,205.57) (75,077,264.57) (71,976,462.86)Current Month Interest (216,858.31) (298,299.70) (346,219.27) (348,408.35) (330,580.58) (302,242.74) (319,854.23) (300,928.30) (265,175.43) (164,935.15) (207,299.65) (220,331.68) (3,321,133.39)2025-2026 Ending Deferral Balance (71,591,928.94)$ (83,092,625.71) (83,618,004.78) (79,339,339.74) (72,538,256.58) (76,765,014.42) (72,222,791.17) (63,642,103.39) (49,480,543.82) (62,189,896.00) (66,099,505.22) (75,297,596.25) (75,297,596.25)Tab is 100% locked down, with no manual inputs.Idaho Billed Sales MWh 1,041,992 1,154,889 1,398,929 1,671,616 1,671,846 1,500,405 1,180,713 1,028,839 1,118,516 1,210,052 1,244,813 1,091,459 15,314,069 Oregon Billed Sales MWh 47,806 49,780 57,526 67,705 70,248 64,187 47,932 52,146 54,307 56,256 58,744 42,982 669,619 TotalMWh 1,089,798 1,204,669 1,456,456 1,739,321 1,742,094 1,564,592 1,228,645 1,080,985 1,172,823 1,266,308 1,303,557 1,134,441 15,983,688 Idaho % Billed Sales95.6% 95.9% 96.1% 96.1% 96.0% 95.9% 96.1% 95.2% 95.4% 95.6% 95.5% 96.2%Oregon % Billed Sales4.4% 4.1% 3.9% 3.9% 4.0% 4.1% 3.9% 4.8% 4.6% 4.4% 4.5% 3.8%Exhibit 2Case No. IPC-E-26-10J. Brady, IPC2 of 2