20211104Application.pdf

LISA D. NORDSTROM
Lead Counsel
[e-mail]
November 4, 2021
Jan Noriyuki, Secretary
Idaho Public Utilities Commission
11331 W. Chinden Boulevard
Building 8, Suite 201-A
Boise, Idaho 83714
Re: Case No. IPC-E-21-38
Application of Idaho Power Company for Modification of the Power Cost
Adjustment (“PCA”) Mechanism
Dear Ms. Noriyuki:
Attached for electronic filing, pursuant to Order No. 35058, is Idaho Power Company’s
Application in the above entitled matter.
If you have any questions about the attached documents, please do not hesitate to
contact me.
Sincerely,
Lisa D. Nordstrom
LDN:sg
Enclosures
RECEIVED
2021 NOV -4 PM 4:59
IDAHO PUBLIC
UTILITIES COMMISSION
APPLICATION -1
LISA D. NORDSTROM (ISB No. 5733)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
[e-mail]

Attorney for Idaho Power Company

BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION

IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
MODIFICATION OF THE POWER COST
ADJUSTMENT (“PCA”) MECHANISM.
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CASE NO. IPC-E-21-38

APPLICATION

Idaho Power Company (“Idaho Power” or “Company”), in accordance with Idaho
Code § 61-502 and RP 052, and in response to Idaho Public Utilities Commission’s
(“Commission”) directive in Order No. 35054,1 hereby respectfully applies to the
Commission for an order authorizing modifications to simplify the Power Cost Adjustment
(“PCA”) mechanism.
Order No. 35054 instructed Idaho Power “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 files next year’s PCA application in April 2022.2

1 In the Matter of Idaho Power Company’s Application to Implement Power Cost Adjustment Rates for
Electric Service from June 1, 2021 Through May 31, 2022, Case No. IPC-E-21-10, Order No. 35054, p. 5
(issued May 28, 2021).
2 Id.
APPLICATION -2
Since receiving that order, Idaho Power engaged in discussions with Commission Staff
(“Staff”)—the only party to file comments in the Company’s last three PCA cases— to
better understand their concerns and to explore methods of addressing those concerns.
Idaho Power believes the proposed PCA modification balances Staff’s desire to simplify
the PCA mechanism3 without impairing the intent or effectiveness of the PCA.4 As
discussed further below, the proposed modification has no material impact on overall cost
recovery.
In support of this Application, Idaho Power represents as follows:
I. BACKGROUND
1. On March 29, 1993, by Order No. 24806 issued in Case No. IPC-E-92-25,
the Commission approved the implementation of an annual power cost adjustment
procedure in order to provide consistency and stability to rates. 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 PCA filings—money collected from the surcharge can be used only to pay power
supply expenses.
2. Over time, the Commission has approved modifications to the PCA to
ensure the mechanism achieves its desired purpose and to incorporate other distinct
elements, such as revenue sharing, as circumstances dictated. In the Company’s most
recent filing in Case No. IPC-E-21-10, Staff Comments suggested simplifications that
could be made to the PCA. While Idaho Power Reply Comments did not necessarily

3 Case No. IPC-E-21-10, Staff Comments, p. 11.
4 Case No. IPC-E-21-10, Company Reply Comments, pp. 3-4.
APPLICATION -3
agree with each of Staff’s recommendations, the Company was open to discussing
modifications.
3. As noted above, the Commission ordered the Company to initiate
discussions with interested parties and to file a case with the Commission to review
whether the PCA mechanism should be modified.5
II. PROPOSED PCA MODIFICATION
4. Currently the PCA includes three separately calculated rates, 1) the forecast
rate, 2) the “true-up” rate and 3) the “true-up of the true-up,” designed to ensure that the
Company neither over- nor under-recovers its share of the variance in net power supply
expenses (“NPSE”) incurred.6 The forecast rate also helps ensure timely recovery or
return of NPSE.
5. The Company proposes to replace the “true-up” and “true-up of the true-up”
components of the PCA with a balancing account, as suggested in Staff Comments in the
most recent PCA filing7. Under the Company’s proposal, the two “true-up” rates would
be combined into one “balancing account” rate.
6. This proposed change does not affect overall cost recovery under the PCA,
with one immaterial exception. When the two true-up rates are combined into one
balancing account, a change results to the calculation of carrying charges. Under the
proposed method, carrying charges (interest) are calculated monthly on the cumulative
prior month balance of the balancing account, including interest. Under the existing
mechanism, the true-up portion of the mechanism interest charges are calculated monthly
on the cumulative prior month balance of the true-up account, excluding interest. Using

5 Order No. 35054, p. 5.
6 Id., pp. 1-2.
7 Case No. IPC-E-21-10, Staff Comments, p. 11.
APPLICATION -4
the 2020-2021 PCA as an example, this change resulted in a $505.38 change in carrying
charges over the entire PCA year.
7. To track the variance between actual and forecasted NPSE, the Company
uses and provides in its annual PCA filings a PCA spreadsheet that collects all relevant
information regarding actual NPSE and NPSE recovered in rates. A modified PCA
spreadsheet is provided as Attachment 1 to this Application. The modified spreadsheet
shows the new balancing account nomenclature and is also reorganized to present the
information in a more straightforward manner, enhance readability, and provide
consistency with other documents filed with the Commission.
8. The Company’s proposed changes also necessitate modifying its rate
Schedule 55 Power Cost Adjustment. The revised Schedule 55, provided as Attachments
2 (clean) and 3 (legislative format) to this Application, incorporates the “balancing
account” terminology to replace the “true-up” terminology and simplifies the presentation
of the various components of PCA rates.
9. Based on Staff’s comments in IPC-E-21-10 and discussions following the
issuance of Order No. 35054, Idaho Power believes the modification proposed in this
filing addresses Staff’s concerns.
III. MODIFIED PROCEDURE
10. 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.

APPLICATION -5
IV. COMMUNICATIONS AND SERVICE OF PLEADINGS
11. Communications and service of pleadings with reference to this Application
should be sent to the following:
Lisa D. Nordstrom Matt Larkin
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
[e-mail] [e-mail]
[e-mail] [e-mail]
V. REQUEST FOR RELIEF
12. Idaho Power and Staff have worked towards a solution to address Staff’s
concerns while maintaining the intent and effectiveness of the PCA mechanism. To
facilitate inclusion of the Commission’s decision in the Company’s annual PCA filing on
or before April 15, 2022, Idaho Power respectfully requests that the Commission issue an
order on or before March 31, 2022, authorizing this modification of the PCA mechanism
effective with the 2022-2023 PCA period.
DATED at Boise, Idaho, this 4th day of November 2021.
LISA D. NORDSTROM
Attorney for Idaho Power Company

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-38

IDAHO POWER COMPANY

ATTACHMENT 1

PCA MODIFICATION WORKPAPER
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A B C D E F G H I J K L M N O
Idaho Power Company
Power Cost Adjustment
2020-2021
Unit April May June July August September October November December January February March TotalsIdaho Jurisdiction Net Power Supply Expense (Non-QF)Actual Non-QFTotal Actual NPSE $9,468,165.31 12,102,756.30 13,835,556.98 24,642,159.29 27,793,637.61 15,770,749.01 16,645,055.48 19,329,045.77 25,327,780.14 21,336,705.85 12,806,792.96 8,142,671.42 207,201,076.12
Idaho Allocation 95.2%95.2%95.7%95.8%95.7%95.7%95.6%95.1%95.1%95.1%95.7%95.3%
Net Idaho Jurisdictional Actual Non-QF $9,013,693.38 11,521,824.00 13,240,628.03 23,607,188.60 26,598,511.19 15,092,606.80 15,912,673.04 18,381,922.53 24,086,718.91 20,291,207.26 12,256,100.86 7,759,965.86 197,763,040.46
Base Non-QFIdaho Base NPSE $11,136,945.00 11,081,299.00 13,347,849.00 16,849,550.00 18,033,739.00 15,978,736.00 11,516,106.00 10,807,039.00 12,512,963.00 14,139,058.00 13,190,742.00 11,984,709.00 160,578,735.00 Idaho Allocation 95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0% Net Idaho Jurisdiction 95% Items $10,580,097.75 10,527,234.05 12,680,456.55 16,007,072.50 17,132,052.05 15,179,799.20 10,940,300.70 10,266,687.05 11,887,314.85 13,432,105.10 12,531,204.90 11,385,473.55 152,549,798.25
Idaho Jurisdiction Change From Base $(1,566,404.37) 994,589.95 560,171.48 7,600,116.10 9,466,459.14 (87,192.40) 4,972,372.34 8,115,235.48 12,199,404.06 6,859,102.16 (275,104.04) (3,625,507.69) 45,213,242.21
Sharing Percentage 95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%
Net Power Supply Expense Deferral ①$(1,488,084.15)944,860.45 532,162.91 7,220,110.30 8,993,136.18 (82,832.78) 4,723,753.72 7,709,473.71 11,589,433.86 6,516,147.05 (261,348.84) (3,444,232.31) 42,952,580.10
Idaho Jurisdictional Qualifying Facility NPSE
Actual QF (Incl Net Metering, Raft River 100% & Liquidated Damages)$14,041,211.36 15,232,386.02 19,248,614.42 24,205,952.70 21,553,290.83 15,201,424.15 17,106,901.83 15,489,843.77 14,785,243.49 14,050,373.70 17,607,218.41 13,054,900.86 201,577,361.54 Idaho Allocation 95.2%95.2%95.7%95.8%95.7%95.7%95.6%95.1%95.1%95.1%95.7%95.3%Idaho Jurisdictional Actual QF $13,367,233.21 14,501,231.49 18,420,924.00 23,189,302.69 20,626,499.32 14,547,762.91 16,354,198.15 14,730,841.43 14,060,766.56 13,361,905.39 16,850,108.02 12,441,320.52 192,452,093.69
Base QF $9,283,440.00 9,237,057.00 11,126,388.00 14,045,307.00 15,032,413.00 13,319,420.00 9,599,498.00 9,008,440.00 10,430,450.00 11,785,917.00 10,995,427.00 9,990,113.00 133,853,870.00
Idaho Allocation 95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%
Idaho Jurisdictional Base $8,819,268.00 8,775,204.15 10,570,068.60 13,343,041.65 14,280,792.35 12,653,449.00 9,119,523.10 8,558,018.00 9,908,927.50 11,196,621.15 10,445,655.65 9,490,607.35 127,161,176.50
Idaho Jurisdiction Change From Base $4,547,965.21 5,726,027.34 7,850,855.40 9,846,261.04 6,345,706.97 1,894,313.91 7,234,675.05 6,172,823.43 4,151,839.06 2,165,284.24 6,404,452.37 2,950,713.17 65,290,917.19Sharing Percentage 100.0%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$4,547,965.21 5,726,027.34 7,850,855.40 9,846,261.04 6,345,706.97 1,894,313.91 7,234,675.05 6,172,823.43 4,151,839.06 2,165,284.24 6,404,452.37 2,950,713.17 65,290,917.19
Idaho Revenue Adjustment (SBAR)
Actual Idaho Jurisdictional Billing Month Sales MWh 956,229 1,015,632 1,183,343 1,397,419 1,592,904 1,450,229 1,084,006 1,004,606 1,136,599.00 1,192,902.00 1,141,582.00 1,058,378.00 14,213,829
Normalized Idaho Jurisdictional Billing Month Sales MWh 947,192 953,286 1,131,686 1,370,142 1,428,766 1,300,608 1,045,495 957,864 1,081,014 1,177,663 1,101,149 1,004,027 13,498,892
Sales Change MWh 9,037 62,346 51,657 27,277 164,138 149,621 38,511 46,742 55,585 15,239 40,433 54,351 714,937
% of Prior Period Billings at Old Rate / Old Rate -$ 0.000%0.000%0.000%0.000%0.000%0.000%0.000%0.000%0.000%0.000%0.000%0.000%% of Current Period Billings at New Rate / New Rate 26.72$ 100.000%100.000%100.000%100.000%100.000%100.000%100.000%100.000%100.000%100.000%100.000%100.000%Sales Adjustment Prior To Sharing $(241,468.64)(1,665,885.12)(1,380,275.04)(728,841.44)(4,385,767.36)(3,997,873.12)(1,029,013.92)(1,248,946.24)(1,485,231.20)(407,186.08)(1,080,369.76)(1,452,258.72)(19,103,116.64)Sharing Percentage 95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%Idaho Revenue Adjustment (SBAR) ③$(229,395.21)(1,582,590.86) (1,311,261.29) (692,399.37) (4,166,478.99) (3,797,979.46) (977,563.22) (1,186,498.93) (1,410,969.64) (386,826.78) (1,026,351.27) (1,379,645.78) (18,147,960.80)
Idaho Jurisdictional Demand Response Incentive Payments
Idaho Actual Demand Response $- - 151,499.84 2,333,340.98 3,066,206.90 1,030,886.24 (55,727.77) 166.45 7,361.11 - 18,612.57 2,304.30 6,554,650.62
Idaho Base Demand Response $780,401.00 776,502.00 935,327.00 1,180,702.00 1,263,682.00 1,119,681.00 806,970.00 757,284.00 876,823.00 990,769.00 924,317.00 839,807.00 11,252,265.00
Change From Base $(780,401.00)(776,502.00) (783,827.16) 1,152,638.98 1,802,524.90 (88,794.76) (862,697.77) (757,117.55) (869,461.89) (990,769.00) (905,704.43) (837,502.70) (4,697,614.38)Sharing Percentage 100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0%
Demand Response Incentive Payment Deferral ④$(780,401.00)(776,502.00) (783,827.16) 1,152,638.98 1,802,524.90 (88,794.76) (862,697.77) (757,117.55) (869,461.89) (990,769.00) (905,704.43) (837,502.70) (4,697,614.38)
Idaho Miscellaneous RevenueSystem Emission Allowance Sales Credit $- - - - - - - - - - - - -
System Renewable Energy Credit Sales $(72,324.46) (349,165.81) 385.24 (556,713.46) 466.62 (1,351.09) (383,416.22) 559.50 (992,878.14) 287.73 (3,146.64) (2,872,593.54) (5,229,890.27)
Revenue Subtotal $(72,324.46)(349,165.81) 385.24 (556,713.46) 466.62 (1,351.09) (383,416.22) 559.50 (992,878.14) 287.73 (3,146.64) (2,872,593.54) (5,229,890.27)
Idaho Allocation 95.2%95.2%95.7%95.8%95.7%95.7%95.6%95.1%95.1%95.1%95.7%95.3%
Sharing Percentage 95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%Miscellaneous Revenue Deferral ⑤$(65,410.24)(315,785.56)350.24 (506,664.92)424.23 (1,228.34)(348,218.61)505.48 (897,015.76)259.95 (2,860.77)(2,600,702.56)(4,736,346.86)
Idaho EIM Participation CostsReturn on EIM Capital Investment $51,974.63 50,918.16 49,861.68 48,805.21 47,748.74 46,692.27 45,635.80 44,579.33 43,574.15 42,517.49 41,460.83 40,404.18 554,172.46
Operating Expenses $209,482.94 227,928.59 227,248.71 213,226.63 219,649.20 243,047.35 227,600.14 199,218.43 204,161.58 199,647.80 208,398.43 251,944.06 2,631,553.84
Revenue Subtotal $261,457.56 278,846.75 277,110.40 262,031.85 267,397.94 289,739.62 273,235.94 243,797.76 247,735.72 242,165.29 249,859.26 292,348.23 3,185,726.31
Sharing Percentage 95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%95.0%
EIM Revenue Requirement ⑥$248,384.69 264,904.41 263,254.88 248,930.25 254,028.04 275,252.64 259,574.14 231,607.87 235,348.94 230,057.02 237,366.30 277,730.82 3,026,440.00
TOTAL DEFERRAL (Sum of ①-⑥)$2,233,059.30 4,260,913.78 6,551,534.98 17,268,876.28 13,229,341.33 (1,801,268.79)10,029,523.31 12,170,794.01 12,799,174.57 7,534,152.48 4,445,553.36 (5,033,639.36)83,688,015.25
PCA Forecast Rate RevenuesActual Idaho Jurisdictional Billing Month Sales Mwh 956,229 1,015,632 1,183,343 1,397,419 1,592,904 1,450,229 1,084,006 1,004,606 1,136,599 1,192,902 1,141,582 1,058,378 14,213,829 % of Prior Period Billings at Old Rate / Old Rate 5.84$ 100.000%100.000%66.050%13.990%0.000%0.000%0.000%0.000%0.000%0.000%0.000%0.000%% of Current Period Billings at New Rate / New Rate 7.83$ 0.000%0.000%33.950%86.010%100.000%100.000%100.000%100.000%100.000%100.000%100.000%100.000%Forecast Rate Revenues ⑦$(5,580,554.66)(5,927,228.32) (7,661,693.07) (10,915,477.70) (12,477,217.46) (11,359,644.18) (8,491,020.09) (7,869,081.39) (8,902,981.87) (9,344,006.92) (8,942,014.48) (8,290,278.48) (105,761,198.62)
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A B C D E F G H I J K L M N O
PCA Balancing Account Balance
Monthly Interest Rate (Annual 1%)%0.1667%0.1667%0.1667%0.1667%0.1667%0.1667%0.1667%0.1667%0.1667%0.0833%0.0833%0.0833%1.7502%
Beginning Balance $(42,648,446.68)(41,409,960.47)(38,172,322.94)(34,335,283.56)(23,842,201.81) (18,397,739.75) (27,279,538.85) (22,565,814.45) (15,317,203.12) (8,069,711.73) (6,342,161.15) (7,452,135.53) (42,648,446.68)
2021-2022 Incremental Deferral (Sum of ①-⑥ above $2,233,059.30 4,260,913.78 6,551,534.98 17,268,876.28 13,229,341.33 (1,801,268.79) 10,029,523.31 12,170,794.01 12,799,174.57 7,534,152.48 4,445,553.36 (5,033,639.36) 83,688,015.25
2021-2022 PCA Forecast Revenues (Collections) ⑦ above $(5,580,554.66)(5,927,228.32) (7,661,693.07) (10,915,477.70) (12,477,217.46) (11,359,644.18) (8,491,020.09) (7,869,081.39) (8,902,981.87) (9,344,006.92) (8,942,014.48) (8,290,278.48) (105,761,198.62)
2021-2022 PCA Prior Balance Revenues (Collections)$4,657,076.53 4,972,982.47 5,010,830.73 4,196,920.09 4,732,083.14 4,309,782.90 3,220,696.17 2,984,515.92 3,376,832.47 3,544,127.09 3,391,769.76 3,144,583.97 47,542,201.24Revenue Sharing - Order No. $0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - DSM Rider Forecasted Surplus Funds - Order No. $0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - 2020-2021 Ending Balance Without Current Month Interest $(41,338,865.51)(38,103,292.54)(34,271,650.30)(23,784,964.89)(18,357,994.80) (27,248,869.82) (22,520,339.46) (15,279,585.91) (8,044,177.95) (6,335,439.08) (7,446,852.51) (17,631,469.40) (17,179,428.81)Current Month Interest $(71,094.96)(69,030.40)(63,633.26)(57,236.92)(39,744.95)(30,669.03)(45,474.99)(37,617.21)(25,533.78)(6,722.07)(5,283.02)(6,207.63)(458,248.22)
2020-2021 Ending Deferral Balance $(41,409,960.47)(38,172,322.94)(34,335,283.56)(23,842,201.81)(18,397,739.75) (27,279,538.85) (22,565,814.45) (15,317,203.12) (8,069,711.73) (6,342,161.15) (7,452,135.53) (17,637,677.03) (17,637,677.03)
Idaho Billed Sales Mwh 956,229 1,015,632 1,183,343 1,397,419 1,592,904 1,450,229 1,084,006 1,004,606 1,136,599 1,192,902 1,141,582 1,058,378 14,213,829
Oregon Billed Sales Mwh 48,443 50,745 53,459 60,630 71,797 64,779 50,378 52,136 58,352 60,953 51,389 52,161 675,222
Total Mwh 1,004,672 1,066,377 1,236,802 1,458,049 1,664,701 1,515,008 1,134,384 1,056,742 1,194,951 1,253,855 1,192,971 1,110,539 14,889,051
Idaho % Billed Sales 95.2%95.2%95.7%95.8%95.7%95.7%95.6%95.1%95.1%95.1%95.7%95.3%Oregon % Billed Sales 4.8%4.8%4.3%4.2%4.3%4.3%4.4%4.9%4.9%4.9%4.3%4.7%

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-38

IDAHO POWER COMPANY

ATTACHMENT 2

PROPOSED SCHEDULE 55
(CLEAN)
Idaho Power Company Sixteenth Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Fifteenth Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 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. 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 (0.1222) cents per kWh.

EARNINGS SHARING

Order Nos. 30978, 32424, 33149, and 34071 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 2020 earnings were below the prescribed threshold resulting in a credit of 0.0000 cents per
kWh.

Idaho Power Company Eleventh Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Tenth Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 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) the Balancing Adjustment; and 5) Earnings Sharing. The following table calculates
the rates for Categories 1, 2 and 3.

The following table shows the determination of PCA rates for Categories 1, 2, and 3:

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.
1.0612 1.5174 0.4562 95% 0.4334
2
Purchased power expense from
cogeneration and small power
producers.
0.8846 1.3557 0.4711 100% 0.4711
3 Demand response incentive
payments. 0.0779 0.0527 -0.0252 100% -0.0252
Total 2.0237 2.9258 0.9021 0.8793

Idaho Power Company Tenth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Ninth Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – 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.

Schedule Category
Balancing
Adjustment
Earnings
Sharing
Total PCA
1 2 3
1 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
3 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
5 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
6 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
7 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
8 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
9S 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
9P 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
9T 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
15 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
19S 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
19P 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
19T 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
24 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
40 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
41 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
42 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
26 0.4334 0.4711 (0.0252) (0.1222) * 0.7571
29 0.4334 0.4711 (0.0252) (0.1222) * 0.7571
30 0.4334 0.4711 (0.0252) (0.1222) * 0.7571

* Earnings Sharing Credits are applied as monthly amounts, and are currently $0.00 per month.

EXPIRATION

The Power Cost Adjustment included on this schedule will expire May 31, 2022.

BEFORE THE

IDAHO PUBLIC UTILITIES COMMISSION

CASE NO. IPC-E-21-38

IDAHO POWER COMPANY

ATTACHMENT 3

PROPOSED SCHEDULE 55
(LEGISLATIVE)
Idaho Power Company FifteenthSixteenth Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 FourteenthFifteenth Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35054 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2021 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. 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: Category 1, Category
2 and Category 3. Category 1 power costs include 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. Category 2 power costs
include purchased power expense from cogeneration and small power producers. Category 3 power
costs include demand response incentive payments. The Base Power Cost is 2.0237 cents per kWh,
which is comprised of Category 1 power costs of 1.0612 cents per kWh, Category 2 power costs of 0.8846
cents per kWh and Category 3 power costs of 0.0779 cents per kWh.

PROJECTED POWER COST

The Projected Power Cost is the Company estimate, expressed in cents per kWh, of the Category
1, Category 2 and Category 3 power cost components for the forecasted time period beginning April 1
each year and ending the following March 31. The Projected Power Cost is 2.9258 cents per kWh, which
is comprised of Category 1 power costs of 1.5174 cents per kWh, Category 2 power costs of 1.3557
cents per kWh and Category 3 power costs of 0.0527 cents per kWh.

TRUE-UP AND TRUE-UP OF THE TRUE-UPBALANCING ADJUSTMENT

The Balancing AdjustmentTrue-up is based upon the differences between the previous Projected
Power Cost and the power costs actually incurred. The True-up of the True-up is the difference between
the previous year’s approved True-Up revenues and actual revenues collected. The total True-up
Balancing Adjustment is (0.1222) cents per kWh.

EARNINGS SHARING

Order Nos. 30978, 32424, 33149, and 34071 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 2020 earnings were below the prescribed threshold resulting in a credit of 0.0000 cents per
kWh.

Schedule Description ¢ per kWh
1 Residential Service 0.0000
3 Master Metered Mobile Home Park 0.0000
5 Residential – Time-of-Day Pilot Plan 0.0000
6 Residential Service On-Site Generation 0.0000
7 Small General Service 0.0000

Idaho Power Company FifteenthSixteenth Revised Sheet No. 55-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 FourteenthFifteenth Revised Sheet No. 55-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35054 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2021 1221 West Idaho Street, Boise, Idaho

Idaho Power Company TenthEleventh Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 NinthTenth Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35054 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2021 1221 West Idaho Street, Boise, Idaho

SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)

EARNINGS SHARING (Continued)

8 Small General Service On-Site Generation 0.0000
9S Large General Service – Secondary 0.0000
9P Large General Service – Primary 0.0000
9T Large General Service – Transmission 0.0000
15 Dusk to Dawn Lighting 0.0000
19S Large Power Service – Secondary 0.0000
19P Large Power Service – Primary 0.0000
19T Large Power Service – Transmission 0.0000
24 Agricultural Irrigation Service 0.0000
40 Unmetered General Service 0.0000
41 Street Lighting 0.0000
42 Traffic Control Lighting 0.0000

Earnings sharing Tax Reform
Monthly credit ¢ per kWh
26 Micron $ (0.00) 0.0000
29 Simplot $ (0.00) 0.0000
30 DOE $ (0.00) 0.0000

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) the True-upsBalancing Adjustment; and 5) Earnings Sharing. The following table
calculates the rates for Categories 1, 2 and 3.

The following table shows the determination of PCA rates for Categories 1, 2, and 3:

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.
1.0612 1.5174 0.4562 95% 0.4334
Idaho Power Company TenthEleventh Revised Sheet No. 55-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 NinthTenth Revised Sheet No. 55-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35054 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2021 1221 West Idaho Street, Boise, Idaho
2
Purchased power expense from
cogeneration and small power
producers.
0.8846 1.3557 0.4711 100% 0.4711
3 Demand response incentive
payments. 0.0779 0.0527 -0.0252 100% -0.0252
Total 2.0237 2.9258 0.9021 0.8793

Idaho Power Company NinthTenth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 EighthNinth Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35054 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2021 1221 West Idaho Street, Boise, Idaho

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.

Schedule Description ¢ per kWh
1 Residential Service 0.7571
3 Mastered Metered Mobile Home Park 0.7571
5 Residential – Time-of-Day Pilot Plan 0.7571
6 Residential Service On-Site Generation 0.7571
7 Small General Service 0.7571
8 Small General Service On-Site Generation 0.7571
9S Large General Service – Secondary 0.7571
9P Large General Service – Primary 0.7571
9T Large General Service – Transmission 0.7571
15 Dusk to Dawn Lighting 0.7571
19S Large Power Service – Secondary 0.7571
19P Large Power Service – Primary 0.7571
19T Large Power Service – Transmission 0.7571

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.

Schedule Category
Balancing
Adjustment
Earnings
Sharing
Total PCA
1 2 3
1 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
3 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
5 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
6 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
7 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
8 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
9S 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
9P 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
9T 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
15 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
19S 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
19P 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
19T 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
24 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
40 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
41 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
42 0.4334 0.4711 (0.0252) (0.1222) - 0.7571
26 0.4334 0.4711 (0.0252) (0.1222) * 0.7571
29 0.4334 0.4711 (0.0252) (0.1222) * 0.7571
30 0.4334 0.4711 (0.0252) (0.1222) * 0.7571
Idaho Power Company NinthTenth Revised Sheet No. 55-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 EighthNinth Revised Sheet No. 55-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 35054 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2021 1221 West Idaho Street, Boise, Idaho

* Earnings Sharing Credits are applied as monthly amounts, and are currently $0.00 per month.

POWER COST ADJUSTMENT (Continued)

24 Agricultural Irrigation Service 0.7571
40 Unmetered General Service 0.7571
41 Street Lighting 0.7571
42 Traffic Control Lighting 0.7571

26 Micron 0.7571
29 Simplot 0.7571
30 DOE 0.7571

EXPIRATION

The Power Cost Adjustment included on this schedule will expire May 31, 2022.