20210415Application.pdf

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NATHAN F. GARDINER
Senior Counsel
[e-mail]
April 15,2021
VIA ELECTRONIG FILING
Jan Noriyuki, Secretary
ldaho Public Utilities Commission
11331 W. Chinden Blvd., Bldg 8,
Suite 2O1-A(83714)
PO Box 83720
Boise, ldaho 8372O-0OT 4
Case No. IPC-E-21-10
2021-2022 Power Cost Adjustment - ldaho Power Company's Application
and Testimony
Dear Ms. Noriyuki
Attached for electronic filing per Order No. 34781, is ldaho Power Company's
Application, as wel! as Direct Testimony of Nicole A. Blackwell, including Exhibit Nos. 1-3
(also attached in Excelformat). Also attached are ldaho Power Company's press release,
customer notice, and direct mail postcard.
Very truly yours,
r A--t'
Nathan F. Gardiner
NFG:slb
Attachments
Re
NATHAN F. GARDINER (lSB No. 4104)
ldaho Power Company
1221West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
Telephone: [phone]
Facsimile: [phone]
nqard iner@ idahopower.com
Attorney for ldaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
!N THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR
AUTHORIry TO IMPLEMENT POWER
cosT ADJUSTMENT ("PCA") RATES
FOR ELECTRIC SERVICE FROM JUNE
1,2021, THROUGH MAY 31,2022.
CASE NO. IPC-E-21-10
APPL!CATION
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ldaho Power Company ("ldaho Powef or'Company'), in accordance wilh ldaho
Code S 61-502 and RP 052, hereby respectfully requests the ldaho Public Utilities
Commission ('Commission") approve an update to Schedule 55 based on the
quantification of the 2021-2022 Power CostAdjustment ("PCA') to become effective June
1, 2021, for the period June 1 , 2021, through May 31 , 2022. lf the proposed rates and
charges for electric service in the strate of ldaho included as Attachment 1 to this
Application are approved, the 2021-2022 PCA will result in an overall revenue increase
of approximately $39.1 million, or a 3.36 percent increase from cunent billed revenue.
APPLICAT]ON - 1
ln support of this Application, ldaho Power has filed the Direct Testimony of Nicole
A. Blackwell, Regulatory Consultant. Ms. Blackwell's testimony details the 2021-2022
PCA amount, explains the factors that impact this year's PCA quantification, details the
calculation of the proposed 2021-2022 PCA rates, and discusses the additional PCA
component related to revenue sharing.
I. BACKGROUND
1. ldaho Power is an ldaho corporation whose principal place of business is
1221 West ldaho Street, Boise, ldaho 83702.
2. ldaho Power is a public utility supplying retail electric service to more than
580,000 customers in southern ldaho and eastern Oregon. ldaho Power is subject to the
jurisdiction of this Commission in ldaho and to the jurisdiction of the Public Utility
Commission of Oregon. ldaho Power is also subject to the jurisdiction of the Federal
Energy Regulatory Commission.
3. 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
ldaho Power customers. Neither ldaho Power or its shareholders receive any financia!
return on this filing - money collected from the surcharge can be used only to pay power
supply expenses.
4. On January 9, 2009, by Order No. 30715 issued in Case No. IPC-E-08-19,
the Commission approved certain changes to the PCA mechanism, including a 95
percenU5 percent sharing mechanism between customers and the Company. Order No.
APPLICATION - 2
30715 also approved changes to the Load Growth Adjustment Rate ("LGAR'), third-party
transmission expense, the PCA forecast, and power supply expense distribution.
5. On January 13,2010, the Commission issued Order No.30978 in Case No.
IPC-E-09-30, approving the settlement stipulation filed in lieu of a general rate case.
Through this stipulation, a revenue sharing mechanism was established to allow the
Company to accelerate the amortization of accumulated deferred investment tax credits
if the Company's actual ldaho jurisdictional year-end Return on Equity ("ROE') fell below
9.5 percent in any fiscal year from 2009 through 201 1. This mechanism also included a
provision for revenue sharing if the Company's actual ldaho jurisdictional year-end ROE
exceeded 10.5 percent in any year during the same three-year period. Per the terms of
the stipulation, 50 percent of the ldaho jurisdictional year-end ROE in excess of 10.5
percent was to be shared with customers in the form of a rate reduction.
6. On March 15,2011, the Commission issued Order No. 32206 in Case No.
GNR-E-10-03 adopting a revised LGAR methodology and changing the name of the
methodology to the Load Change Adjustment Rate CLCAR').
7. On December 27 , 2011, the Commission issued Order No. 32424 in Case
No. IPC-E-11-22 approving a settlement stipulation filed on December 12, 2011,
extending the revenue sharing mechanism through 2014 and modifying portions of the
previous accounting order. More specifically, Order No.32424 approved modifications
to the sharing portion of the mechanism, which allowed for greater customer benefits.
First, for actual year-end ldaho jurisdictional earnings greater than a 10 percent ROE, up
to and including 10.5 percent in any yearfrom 2012 through2014, the earningswould be
shared equally between ldaho customers and the Company. The customer revenue
APPLICATION - 3
sharing benefit would be in the form of a reduction to rates at the same time as the PCA
becomes effective. This modification provided customers an additional 25 basis points
of sharing potential. Second, ldaho eamings above a 10.5 percent ROE would also be
shared, with customers receiving 75 percent of the earnings applied as an offset to the
Company's pension balancing account.
8. On October 9,2014, the Commission issued Order No. 33149 in Case No.
IPC-E-14-14 approving the settlement stipulation filed on September 3,2014, extending
the revenue sharing mechanism through 2019 and modifying portions of the previous
accounting order. More specifically, Order No. 33149 approved modifications to the
sharing mechanism to reflect adjustments to the various sharing thresholds, as well as
the method by which shared amounts would be provided to customers. First, for actual
year-end Idaho jurisdictional eamings greater than 10 percent ROE, up to and including
10.5 percent in any year from 2015 through 2019, the eamings will be shared between
customers and the Company on a 75 percent and 25 percent basis, respectively. The
customer revenue sharing benefit will be in the form of a reduction to rates at the same
time as the PCA becomes effective. Second, ldaho earnings above a 10.5 percent ROE
will also be shared, with customers receiving 50 percent of the eamings in the form of a
reduction to rates at the same time as the PCA becomes effective, as well as 25 percent
of the earnings applied as an offset to the Company's pension balancing account, with
the Company retaining the remaining 25 percent.
9. On May 28,2015, the Commission issued Order No. 33307 in Case No.
IPC-E-15-15 converting the LCAR to a Sales Based Adjustment ("SBA') rate, as well as
modiffing the PCA deferral balance's monthly interest calculation. Per Order No. 33307,
APPLICATION .4
the SBA rate is calculated in the same manner as the LCAR, with the only modification
being the replacement of the load-based megawatt-hour ("MWh") denominator with the
conesponding sales-based MWh denominator. Second, the Order required the Company
to calculate monthly interest on the defenal balance by assigning annual base Net Power
Supply Expense ("NPSE") to each month according to expected base rate revenue
collection as set in the Company's last general rate case, Case No. IPC-E-11-08.
10. On May 31,2018, the Commission issued Order No.34071 in Case No.
GNR-U-18-01 approving the settlement stipulation filed on April 12, 2018, extending the
revenue sharing mechanism indefinitely and modiffing portions of the previous
accounting order. More specifically, Order No. 34071 approved modifications to the
sharing portion of the mechanism, which allowed for greater customer benefits. First, for
actual year-end ldaho jurisdictional eamings greater than 10 percent ROE, all amounts
up to and including 10.5 percent ROE wil! be shared between customers and the
Company on an 80 percent and 20 percent basis, respectively. The customer revenue
sharing benefit will be in the form of a reduction to rates at the time the subsequent year's
PCA becomes effective. Second, ldaho earnings above a 10.5 percent ROE will also be
shared, with customers receiving 55 percent of the eamings in the form of a reduction to
rates at the time the subsequent year's PCA becomes effective, as well as 25 percent of
the earnings applied as an offset to the Company's pension balancing account, with the
Company retaining the remaining 20 percent.
il. 2021-2022 PCA CALCULATTON
11. 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
APPLICATION - 5
Company's base rates for recovery or credit through an annual rate change on June 1.
The PCA is also the rate mechanism used by the Company to provide direct revenue
sharing benefits resulting from the revenue sharing mechanism approved in Order No.
34071.
12. The PCA mechanism utillzes a 12-month test period of Aprilthrough March
CPCA Yea/') and consists of a forecast component and a true-up component ("True-Up").
The PCA forecast component is based on the Company's March Operating Plan and
represents the difference between the NPSE forecast in the March Operating Plan and
the base level NPSE recovered in the Company's base rates. The True-Up compares
actual PCA account results to actual NPSE collections for the prior PCA year. The PCA
True-Up contains a second component that tracks the collection of the prior year's True-
Up amount, referred to as the "True-Up of the True-Up."
13. With the exception of Public Utility Regulatory Policies Act of 1978
("PURPA') expenses and demand response incentive costs, the PCA allows the
Company to pass through to ldaho customers 95 percent of the annual differences in
actua! NPSE as compared to the base level NPSE, whether positive or negative.
14. Forecast. The testimony of Ms. Blaclarell describes and computes the PCA
rate to be effective June 1, 2021, through May 31 , 2022. The system-level forecast of
NPSE for the 2021-2022 PCA Year is $442,357,407, which is $136,672,538 higher than
the currently approved base level NPSE of $305,684,869. The 2021-2022 PCA forecast
component to be collected from ldaho customers is $126,944,108. As described in the
testimony of Ms. Blackwell, the system-leve! forecast of NPSE for the 2021-2022 PCA
Year is $15,452,686 higher than last year's forecast amount of $426,904,721. This year,
APPLICATION - 6
due to an expected reduction in hydro generation, the Company expects to increase
thermal generation for load service. Additionally, the Company expects an increase in
PURPA generation and expense, a must-take resource. The Company anticipates that
market purchases of power will decrease due to higher market energy prices.
15. True-Up. ln addition to the NPSE incurred during the Apri! 2020 through
March 2021 penod, ldaho Power included its actual cost of Westem Energy lmbalance
Market ('ElM") participation for April 2020 through March 2021 in the True-Up as
approved by Commission Order No. 34100. Benefits associated with EIM participation
are embedded in actual NPSE experienced over that same period.
16. The True-Up defenal balance at the end of March 2021, with interest
applied, was approximately negative $22.1 million. This credit to customers was largely
driven by an increase in market energy prices, which resulted in increased dispatch of
thermal generation for economic surplus sales.
17. True-Up of the True-Up. ln the True-Up of the True-Up, the Company under
collected Iast year's PCA True-Up balance by approximately $4.5 million. The 2020-2021
combined PCATTe-Up credit balance of $17.6 million is approximately $25.3 million less
than the credit customers are currently receiving through lhe 2019-2020 combined PCA
True-Up.
18. Combined Uniform PCA Rate. The Company's uniform PCA rate for the
2021-2022 PCA Year is comprised of (1) the 0.8793 cents per kilowatt-hour ('k\ /h")
adjustment for the 2021-2022 projected power cost of serving firm loads under the current
PCA methodology and 95 percent sharing, (2) the negative 0.1535 cents per kWh for the
2020-2021 True-Up portion of the PCA, and (3) the 0.0313 cents per kWh for the True-
APPLICATION - 7
Up of the True-Up. The sum of these three components results in an approximate 0.7571
cents per kWh charge for all rate classes.
III. ADDITIONAL RATE ADJUSTMENTS
19. Revenue Sharino. The Company's earnings in each year from 2011
through 2015, as well as 2018, resulted in revenue sharing with ldaho customers totaling
$126.2 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
and 2019 were below the revenue sharing threshold. As described in greater detai! in the
direct testimony of Ms. Blackwell, the Company's 2020 ldaho jurisdictionalyear-end ROE
was 9.98 percent. ln accordance with the terms of the modified revenue sharing
mechanism approved by Order No. 34071, the Company's ldaho jurisdictional year-end
ROE was below the 10.0 percent ROE threshold for revenue sharing. Therefore, the
2021-2022 PCA will not include a revenue sharing component.
IV. CUMULATIVE PROPOSED JUNE 1. 2021. RATE CHANGES
20. The 2021-2022 total PCA amount, as measured from the currently
approved base level NPSE, including the revenue sharing provision, is $109.3 million.
This represents an increase in total billed revenue of $39.1 million, an increase of 3.36
percent, for ldaho customers, effective June 2021 through May 2022.
21. On March 15, 202'1, ldaho Power filed its annua! Fixed Cost Adjustment
("FCA") in Case No. IPC-E-21-03. The Company's 2020FCA filing proposes a $2.1
million increase in current billed revenue, or a 0.38 percent increase, for ldaho Residential
and Small General Service customers, effective June 2021through May 2022.
APPLICATION - 8
22. Combined Effect of the PCA and FCA Filinqs. lf the proposed PCA and
FCA rate changes are approved as filed, the combined impact is an overall increase in
cunent billed revenue of $41.2 million, or 3.55 percent, for June 2021 through May 2022.
23. Aftachment 1 to this Application is ldaho Powe/s proposed IPUC No. 29,
Tariff No. 101, in both clean and legislative formats, which contiains the tariff sheets
speciffing the proposed Schedule 55 rates for providing retail electric service to its
customers in the state of ldaho for June 1,2021, through May 31 ,2022.
24. 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 $39.1 million more, from June 2021 through May 2022, than the PCA
rates cunently in effect.
V. MODIFIED PROCEDURE
25. ldaho 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 wriften submissions rather than by hearing. RP 201,
ef seg. !f, however, the Commission determines that a technical hearing is required, the
Company stands ready to present its testimony and support the Application in such
hearing.
VI. COMMUNICATIONS AND SERVICE OF PLEADINGS
26. !n conformance with RP 125, this Application will be brought to the attention
of ldaho 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. To ensure that all customers are notified in a timely manner and
APPLICATION - 9
have sufficient time to submit comments, ldaho 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 15,2021.
27. The Company has also prominently displayed its intent to file the PCA on
its website since March 15,2021. Upon filing of this Application, this web graphic will link
directly to the PCA press release and bil! insert. ldaho Power will also keep its
Application, testimony, and exhibits open for public inspection at its offices throughoutthe
state of ldaho. ldaho Power asserts that this notice procedure satisfies the Rules of
Procedure of this Commission; however, the Company will, in the altemative, bring the
Application to the aftention of its affected customers through any other means directed by
this Commission.
28. Communications and service of pleadings with reference to this Application
should be sent to the following:
Nathan Gardiner
ldaho Power Company
1221 West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
nqard iner@ idahopower.com
[e-mail]
VII. REQUEST FOR RELIEF
29. As discussed in greater detail above, ldaho Power respectfully requests that
the Commission issue an order approving an update to Schedule 55 based on the
quantification of the 2021-2022 PCA, resulting in an overall increase to cunent billed
revenue of approximately $39.1 million to become effective June 1 ,2021.
Matthew T. Larkin
Timothy E. Tatum
ldaho Power Company
1221West ldaho Street (83702)
P.O. Box 70
Boise, ldaho 83707
m larkin @ ida hooower.com
[e-mail]
APPLICATION - 10
DATED at Boise, ldaho, this 15h day of April 2021.
F
NATHAN F. GARDINER
Aftorney for ldaho Power Company
1*
APPLICATION - 11
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-10
IDAHO POWER COMPANY
ATTACHMENT 1
PROPOSED TARIFF
(Clean and Legislative Formats)
ldaho Power Company Fifteenth Revised Sheet No. 55-1
Cancels
LP.U.C. No. 29. Tariff No. 101 Fourteenth Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPLICABILITY
This schedule is applicable to the electric energy delivered to all ldaho 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
The Base Power Cost of the Company's rates is computed by dividing the sum of the Company's
power cost components by firm k\ffh sales. The power cost components are segmented into three
categories: 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 smal! 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 smal!
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.
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 k\Mr.
TRUE-UP AND TRUE.UP OF THE TRUE-UP
The True-up is based upon the difference 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 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
Residential Service
Master Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Residential Service On-Site Generation
Small General Service
d per kWh
0.0000
0.0000
0.0000
0.0000
0.0000
1
3
5
6
7
IDAHO
lssued per Order No.
Effective-June 1,2021
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Tenth Revised Sheet No. 55-2
Cancels
|.P.U.C. No. 29. Tariff No. 101 Ninth Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHARING (Continued)
I
9S
9P
9T
15
19S
19P
197
24
40
41
42
Small General Service On-Site Generation
Large General Service - Secondary
Large General Service - Primary
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
Agricultura! !rrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Earninqs sharinq
Monthlv creditMicron $ (0.00)Simplot $ (0.00)DOE $ (0.00)
Description
Residential Service
Mastered Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Residential Service On-Site Generation
Small General Service
Small General Service On-Site Generation
Large General Service - Secondary
Large General Service - Primary
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
Tax Reform
d per k\&h
0.0000
0.0000
0.0000
26
29
30
POWER COST ADJUSTMENT
The Power Cost Adjustment 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) 1OO percent of the difference
between the Projected Power Costs in Category 2and 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-ups; and 5) Earnings Sharing.
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 kWr rates
shown below.
Schedule d per k\A/h
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
0.7571
1
3
5
6
7I
9S
9P
9T
15
195
19P
197
IDAHO
lssued per Order No.
Effective - June 1,2021
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Ninth Revised Sheet No. 55-3
Cancels
!.P.U.C. No. 29. Tariff No. 101 Eiohth Revised Sheet No. 5$3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT (Continued)
24
40
41
42
Agricultural lrrigation Service
Unmetered Genera! Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
0.7571
0.7571
0.7571
o.7571
0.7571
0.7571
0.7571
26
29
30
EXPIRAT!ON
The Power Cost Adjustment included on this schedule will expire May 31 ,2022
!DAHO
lssued per Order No
Effective - June t, ZOZ|
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company Fewifteenth Revised Sheet No. 55-1
Cancels
|.P.U.C. No. 29. Tariff No. 101 ThirFourteenth Revised Sheet No. 55-1
SCHEDULE 55
POWER COST ADJUSTMENT
APPL!CABILITY
This schedule is applicable to the electric energy delivered to all ldaho 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
The Base Power Cost of the Company's rates 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: 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 2.0#+2-37_ cents per kWh, which is comprised of Category 1 power costs of 1.067712
cents per kWh, Category 2 power costs of 0.890e82[6 cents per kWh and Category 3 power costs of
O.07%rucents 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.%Ag@.cents per kWh,
which is comprised of Category 1 power costs of 'l .4gg+517 4 cents per kWh, Category 2 power costs of
1.2889a557 cents per kWh and Category 3 power costs of 0.053e!Z cents per kWh.
TRUE.UP AND TRUE.UP OF THE TRUE-UP
The True-up is based upon the difference 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 is (0.*l+1222) cents per
kwh.
EARNINGS SHARING
Order Nos. 30978,32424, an433149, 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 20!P.4 earnings were below the prescribed threshold resulting in a credit of 0.0000 cents
per kWh.
Schedule Descriotion d oer kWh1 ResidentialService 0.00003 Master Metered Mobile Home Park 0.00005 Residential- Time-of-Day Pilot Plan 0.00006 ResidentialService On-Site Generation 0.00007 SmallGeneralService 0.0000
IDAHO
lssued per Order No. 34682
Effective - June 1,20297
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company NinTenth Revised Sheet No. 55-2
Cancels
|.P.U.C. No. 29. Tariff No. 101 EiehNinth Revised Sheet No. 55-2
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
EARNINGS SHARING (Continued)
26
29
30
I
9S
9P
9T
15
19S
19P
197
24
40
41
42
1
3
5
o
7I
9S
9P
9T
15
19S
19P
197
Small General Service On-Site Generation
Large General Service - Secondary
Large General Service - Primary
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
Agricultural lrrigation Service
Unmetered General Service
Street Lighting
Traffic Gontrol Lighting
Eaminos sharino
Monthlv creditMicron $ (0.00)
Simplot $ (0.00)DOE $ (0.00)
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
Tax Reform
d oer kWh
0.0000
0.0000
0.0000
POWER COST ADJUSTMENT
The Power Cost Adjustment 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 PowerCosts in Category 2and the Base PowerCosts in Category2; 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-ups; and 5) Earnings Sharing.
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 Descriotion
Residential Service
Mastered Metered Mobile Home Park
Residential - Time-of-Day Pilot Plan
Residential Service On-Site Generation
Small GeneralService
Small General Service On-Site Generation
Large General Service - Secondary
Large General Service - Primary
Large General Service - Transmission
Dusk to Dawn Lighting
Large Power Service - Secondary
Large Power Service - Primary
Large Power Service - Transmission
d per kWhO.Mru0.ffizruO.MEI1O.Mru0.MzruO.WHIJ0.w
0.w2,571O,WO,MUI10.MEllO.MEI1O.MEII
IDAHO
lssued per Order No. 34682
Effective - June 1,2O2O!
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
ldaho Power Company EighNinth Revised Sheet No. 55-3
Cancels
|.P.U.C. No. 29. Tariff No. l0l S,evenEiohth Revised Sheet No. 55-3
SCHEDULE 55
POWER COST ADJUSTMENT
(Continued)
POWER COST ADJUSTMENT (Continued)
24
40
41
42
Agricultural lrrigation Service
Unmetered General Service
Street Lighting
Traffic Control Lighting
Micron
Simplot
DOE
0.wEIlO.MEI10.ME!10.eE!1
o.ME!7o.ME!1O.MEII
26
29
30
EXPIRATION
The Power Cost Adjustment included on this schedule will expire May 31 ,202+2.
IDAHO
lssued per Order No. 34693
Effective - June 1,2029L
lssued by IDAHO POWER COMPANY
Timothy E. Tatum, Vice President, Regulatory Affairs
1221 West ldaho Street, Boise, ldaho
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
GASE NO. IPC-E-21-10
IDAHO POWER COMPANY
ATTACHMENT 2
2021 PCA REVENUE IMPACT SUMMARY
RafrB
Sch.
Ne.
AwEge
Nmberofccbrm(r)
ldaho Pomr Conp.ny
Calculltlon ol R.rrn$ lnE ct 202!-m2l
&rb otld.ho
PosrCoatAdr$hnt
Flhd Aprll t5, 2Ol1
Cumnt BllLd R.[n[ to P]o9cd BllLd R.mD
NmdEed
Mitb
Pskwh
Mill3Emrgy(kwhl(r)Llm
NO
1
2
3
1
5
6
7II
10
11
12
13
14
15
Tarifi Dsqlptbn
ljnltum Tartfi Raha:
R6ldental S€rvice
Mabr Motffid i,loula H,ome Ps*
R€aldsntd Sfllce Ere€y Wsbh
Red&n0d Sm,lce TlrFof-Day
Raldontd Sffne orHSII€ G6mra0on
Strdl Gelml Seilice OFSIE @nordon
LargoG6ffid56rl€
Dlltb DamLEhlng
LaO€ Pow Smr6
UnmoB€d GemEl Servlcs
St€ot Llghtry
Trafiic Contol Lightng
Tohl Unlfom Tartlb
I
3
1
5
6
7
8
9
15
19
24
40
41
12
473,W.
21
0
1,031
9,6S)
N,751
@
37,035
0
117
14,41
1,585
2,87
124
5218,521,0O2.
4,323,473
0
17fi8,975
53,601.Sb
r36,618,c,6
197,24
3.850.260.546
6,042,348
2,2*,962,A8
1.855,297.472
12,559,188
25,881,98'
2,166,7fi
Cumnt
Bllled
Rmnue
$531,36,1,631
i4m,n8
t0
$1,741,U7
S5,78,t,379
N17,1N,852
u6,9:16
s276,707,983
$1.295205
8129,456,fl9
$116,112,723
$1,075,124
$3,567,488
$171,455
014,136,973
811,712
$0
$48,028
t145,48
t370,r01
$531
310,454.737
916.369
16,206,217
$5,026,001
$31,024
$70,114
$7,492
1(x.53
100.03
0.00
1m.96
fi0.62
r30.26
139..27
71.11
217.6
59.2
81.,16
88.31
140.55
64.70
101.82
97.p.
0.00
98.25
107.91
'127.5
136.56
71.70
211.35
56.51
78.75
85.60
137.84
61.99
Total
Adj6tn€nb
b 8i[6dRma
Pmpcd
Total Billod
RgvW€
9545,501,605
$432,491
t0
$'1,789,875
$5,929,586
i17,795,9Si
w,170
$2a7,162,7N
$1,3r 1,574
$135.662,266
$15r,138,724
t1,r09,r47
03,637,602
$178,947
Ptr kwh
Prcst
ClEng6
Billod b Bilbd (4
Rmre
2.ffiX
2.favo
N/A
2.7ffi
2.51%
2.1*
r.9896
3.7896
12616
1.79*
3.4496
3.r616
1.97%
1.57%
16 TotalSpeciatCotacts
574,939 13,48(i761,426 $r,115,150,450 &.70 $36,527,5't0
19.74 $2.582,190
t0.5il lte,i0e,7!0
85.41
52.41
l,,24
3.2896
5.45%
3.36'ta
3 953,189,313
raI3ao50,7t0
t47,107,703
trJo,558,rs3
$r,r51,67r,959
$49,989,8S3
trr0r,$715217il19,p
(l ) Juno 01 , 202'l - May 31 , 2022 FoMtod Tost Y@r
(2) Percmtage lmpact doB mt lnclude @mpononb wttlch are appll€d I psrrnbgB, Rldffi and FErchlsa FG.
Opportunities for Public Review
ldaho Power's proposal is subject to public review
and approval by the IPUC. Copies of the application
are available to the public at the IPUC offices (1'1331
W. Chinden Blvd. Building 8, Suite 201-A, Boise, lD
83714),ldaho Power offices, or at idahopower.com
or puc.idaho.gov. Customers also may subscribe to
the IPUC's RSS feed to receive periodic updates via
email about the case. Written comments regarding
ldaho Power's proposal may be filed with the IPUC.
ldaho Power Files Annual
Power Cost Adjustment
ldaho Power has filed the final piece of its annual
spring cost adjustments with the ldaho Public Utilities
Commission (PUC). This year's Power Cost Adjustment
(PCA) calls for a price increase of $39.1 million across all
customer classes. Overall, ldaho Power's prices remain
about 20% lower than the national average for residential
customers and 30% lower for business customers.
ldaho Power understands some customers are still
facing hardship from the pandemic and remains
committed to helping those struggling with their bills.
Expanded payment arrangement options are available
to help customers with past-due balances. Customers
can call the Customer Care team at 208-388-2323 or
1-800-488-6151 to help set up payment arrangements or
learn more about bill assistance.
Thank you for reading this notice.
We value your husiness.
sllmloP0,I,ER.(D Printed on recychd paper.
An IDACORP Company
@2021 ldaho Power
31'!80-l-0130
Neither ldaho Power nor its shareholders receive any
financial return from this filing - money collected is
used to either recover costs or credit benefits associated
with annual fluctuations in power costs. These typically
represent approximately one-fourth to one-third of the
company's annual cost of serving customers.
The overall impact to customer bills for residential and
small general service customers is dependent on the
outcome of the following two filings:
. The annual PCA, filed April 15, is a cost-recovery tool
that passes on both the benefits and costs of supplying
energy to ldaho Power customers. lf the PCA proposal
is approved by the IPUC as filed. the typical ldaho
residential customer using 950 kilowatt-hours (kWh) of
energy per month will see a $2.57 increase on their bill
related to this request, beginning June 1.
. The annual Fixed Cost Adjustment (FCA), filed in March
and applicable to only residential and small commercial
customers, adjusts prices based on changes in energy
use per customer during the previous year. lf the FCA
proposal is approved as filed, a typical residential
customer will see an increase of $0.37, beginning June 1
The impact of these two filings is shown in the
table. A typical ldaho residential customer will see an
overall monthly increase of $2.94. The actual percentage
of change will depend on a customer's class and the rate
they pay.
Reven!eChang€ Reridcntial(millions)l.rigation
$2.1 0^38% 0.38% N/A N/A N/A
$39.1 2.660/o 2.12% 3.74o/o 4.97o/o 3.44%
$41.2 3.O4o/o 2.50o/o
r lncludes lighting s(hedules;: lncludes special contracts
The PCA has two main components: the forecast and the
true-up. The forecast reflects ldaho Power's anticipated
fuel costs, purchased power costs and customer benefits
from sales of surplus energy for the coming April through
March. The true-up brings last year's forecasted costs
in balance with costs actually incurred by the company
by looking back at what happened the previous April
through March.
The increase in this year's PCA is primarily attributed
to a smaller credit to customers through the true-up
component. ln addition, this year's PCA forecast reflects
expected increases to power costs primarily due to weaker
forecast water conditions, which would result in less
low-cost hydro generation available to serve customers,
as well as higher costs associated with power purchase
agreements under the Public Utilities Regulatory Poliq Act
of 1978 (PURPA).
-
l-arge
Geoeral
Se.vi(.r
Snall
Grneral
5€rvi.e
large
Powerr
FtxED COST ADTUSMENT (FCA)
POWER COST ADTUSMENT (PCA)
COMBINED IMPACT
3.74o/o 4.970h 3.44o/o
ldaho Povrer has filed the {inal pie(e of its annual spring cost adjustrnents
with the ldaho hJblic tftilities Commision (ltuC). This year's Power Cost
Adjustmenl (rc$ calb for a price increase of i3.1 million aoocs all
cwtomer dasses. Overall, ldaho Porver's prices remain about 20% lo^/er
than the national a\Erage for ruidentid customers and 30o/o knarer for
business customers,
ldaho Porter understands some customers are still facing hardship from the
pandemic and remains committed to helping those struggling with their bills.
Expanded payment anangement options are availabh to help ortomers
with past-due balances. Customers can call the Customer Care team at
208-388-2323 or 1-800-488-6151 to help set up payment arangements or
leam more about bill assistance.
Neither ldaho Pcniver nor its shareholders receive any financial retum from
this filing - money collected is used to either recover costs or credh benefits
associated with annual flwtuations in po,ver costs. These typicalry represent
appoxinutely one.fourth to one-third of the company's annual cost of
serving customers.
The olterall impact to customer bills lor residential and small general servke
cr.stomers is dependent on the outaome of the follorving two lilings:
. The annual PCA, filed April 15, is a co6t-recorery tool that pases on both
the benefits and costs of supplying energy to ldaho Po/ver customers. lf the
PCA proposal is apprwed by the IRJC as fihd, the typical ldaho residential
customer using 950 kilo,vatt-hours (kWh) of energy per month will see a
$2.57 increase on their bill related to this request, beginning June 1.
. The annual Fb(ed Cost Adjustment (KA), filed in March and applicabh
to only residenfnl and small commercial cutomers, adjusts prices based
on changes in energy use per customer during the
previotrs par. lf the FCA proposal is approred as fled,
a typical residential customer will see an irrcrease of
$0.37, beginning June 1.
The imp&ct of these two filings is shown in the
tabh. A typical ldaho residential customer will see an
werall monthly irrrease of $2.94. The actual percentage
of dung will depend on a cwtomer's dass and the rate
thery pay.
32.1 0.38% 0.38% N/A N/A N/A
J39.1 2.660lo 7.12o/o 3.74% 4.979o 3.44%
Cdtinudq,ffeside
lat.2 | 3.0a%, f.SO* , 3.r1% | a.gt% trA{l%
kr(lLdes lightir'9 5:hEdul!!,I hrclLd€s rpicr.l (0illra(!5
lESilr)isl&rtd H Ia!.
rROM CURRENT BITLTD NTV[NUE
fIXED COST ADJUSMENI (fCA)
PERCENIAGE
2021 RATE FILINGS
<SITN}() PO'I'ER
t, DI: tri .i:
Adiustment
ldaho Power
Files Annual
Power Cost
ldaho Power Files Annual Power Cost Adjustment
Condnued fom reverte tide
The PCA has two main components: the
forecast and the true-up. The forxast
reflects ldaho Power's anticipated fuel
costs, purchased pourer costs and customer
benefits from sales of surplus energy for the
coming Aprilthrough March. The true-up
brings hst year's forecasted costs in balance
with costs actually incurred by the company
by looking back at what happened the
prwious April through March.
The increase in this year's PCA is primarily
attributed to a smaller credit to customers
through the true-up component.
ln addition, this year's PCA forecast reflects
expected increases to porer costs primarily
due to weaker forecast water conditions,
which would resuh in less lolrrr-cost hydro
generation available to serve customers,
as well as higher costs associated with
power purchase agreements under the
Public Wiles Regulatory Policy Act of
7978 (ruRPA).
Opportunities for
Public Review
ldaho Poiler's proposal is subject to
public rwiew and approval by the IPUC.
Copies of the application are available
to the public at the lPUc offices
(11331 W. Chinden Bfud. Building 8, Suite
201-A, Boise, lD 83714), ldaho Power
offices, or at idahopower.com or
puc.idaho.gov. Customers also may
subscribe to the IPUC's RSS feed to
receive periodic updates via email about
the case. Written comments regarding
ldaho Poweas proposal may be filed with
the IPUC.
lhank you for reading this notice.
We value your business.
P.O. 8ox 70 (8370 /)
122I W. ldaho St.
8orse, lD 83702
!moortantlnformation:
i3iIM}OPO'I'ER.
PRI,5ORIED
9TANDARD
U,S, POSTA6T
PAID
BOt5t. tDIt RM|T NO. 579
Pleise Notc: We want to ensure all of our customers
ha/e sufficient time to submit cornments to the lruC.
Because your bill is processed to,vard the end of the
IPUC's reviarv of our requesl you will receive this
rotification twice: first in this postcard and then in
an insert in your bill later this month.
An IDACORP Company
SrorypFtmrER.
An IDACORP Company
NEWS RELEASE
Idaho Power Files Annual Power Cost Adjustment
April 15,2021
BOISE, ldaho - ldaho Power has filed the final piece of its annual spring cost adjustments with the
ldaho Public Utilities Commission (IPUC). This year's Power Cost Adjustment (PCA) calls for a price
increase of S39.1 million across all customer classes. Overall, ldaho Powe/s prices remain aboul20%
lower than the national average for residential customers and 30% lower for business customers.
ldaho Power understands some customers are still facing hardship from the pandemic and remains
committed to helping those struggling with their bills. Expanded payment arrangement options are
available to help customers with past-due balances. Customers can callthe Customer Care team at
208-388-2323 or 1-800-488-5151to help set up payment arrangements or learn more about bill
assistance.
Neither ldaho Power nor its shareholders receive any financial return from this filing - money collected
is used to either recover costs or credit benefits associated with annual fluctuations in power costs.
These typically represent approximately one-fourth to one-third of the company's annual cost of
serving customers.
The overall impact to customer bills for residential and small general service customers is dependent on
the outcome of the following two filings:
The annual PCA, filed today, is a cost-recovery tool that passes on both the benefits and costs of
supplying energy to ldaho Power customers. lf the PCA proposal is approved by the IPUC as
filed, the typical ldaho residential customer using 950 kilowatt-hours (kwh) of energy per month
will see a 5Z.Sl increase on their bill related to this request, beginning June 1.
The annual Fixed Cost Adjustment (FCA), filed in March and applicable to only residential and
small commercial customers, adjusts prices based on changes in energy use per customer during
the previous year. lf the FCA proposal is approved as filed, a typical residential customer will see
an increase of 50.37, beginning June 1.
The impact of these two filings is shown in the table. A typical ldaho residential customer will see an
overall monthly increase of 52.94. The actual percentage of change will depend on a custome/s class
and the rate they pay.
P.O. Bor 70 O3707)
t22t W. H.ho tt.
8oiic, lD &1702
a
a
2021RATE FIUNGS
Percentoge Change from Current Billed Revenue
Filing Revenue
Change
(millions)
Residential Small
General
Service
Large
General
Service r
Large
Power z
lrrigation
FCA Sz.r o.38%o38%N/A N/A N/A
PCA Sgg.r 2.6604 2.12%3.74%4.97%3.44%
Combined
lmpact 3
s4t.2 3.0404 2.50%3.74%4.97%3.44%
r lncludes lighting schedules; z Includes special contracts
The PCA has two main components: the forecast and the true-up. The forecast reflects ldaho Powe/s
anticipated fuel costs, purchased power costs and customer benefits from sales of surplus energy for the
coming Aprilthrough March. The true-up brings last yea/s forecasted costs in balance with costs
actually incurred by the company by looking back at what happened the previous Aprilthrough March.
The increase in this year's PCA is primarily attributed to a smaller credit to customers through the true-
up component. ln addition, this yea/s PCA forecast reflects expected increases to power costs primarily
due to weaker forecast water conditions, which would result in less low-cost hydro generation available
to serve customers, as well as higher costs associated with power purchase agreements under the Public
Utilities Regulatory Policy Act of t978 (PURPA).
Opportunities for Public Review
ldaho Power/s proposal is subject to public review and approval by the IPUC. Copies of the application
are available to the public at the IPUC offices (11331 W. Chinden Blvd. Building 8, Suite 201-A, Boise, lD
837L4l,,ldaho Power offices, or at !d-a.hg@gl! or puc.idaho.sov. Customers also may subscribe to
the IPUC's RSS feed to receive periodic updates via email about the case. Written comments regarding
ldaho Power's proposal may be filed with the IPUC.
About ldaho Power
ldaho Power, headquartered in vibrant and fast-growing Boise, ldaho, has been a locally operated
energy company since 1915. Today, it serves a 24,000-square-mile area in ldaho and Oregon. The
company's goalto provide 100% clean energy by 2045 builds on its long history as a clean-energy leader
that provides reliable service at affordable prices. With 17 low-cost hydroelectric projects at the core of
its diverse energy mix, ldaho Power's residential, business and agricultural customers pay among the
nation's lowest prices for electricity. lts 2,000 employees proudly serve more than 580,000 customers
with a culture of safety first, integrity always and respect for all.
IDACORP lnc. (NYSE: IDA), ldaho Powe/s independent publicly traded parent company, is also
headquartered in Boise, ldaho. To learn more, visit idahopower.com or idacoroinc.com.
Jordan Rodriguez
Com munications Specialist
i rod riguez@ idahopower.com
208-388-2450