HomeMy WebLinkAbout20250314Direct Nesbitt.pdf BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF IDAHO POWER COMPANY FOR A )
DETERMINATION OF 2024 DEMAND- ) CASE NO. IPC-E-25-12
SIDE MANAGEMENT EXPENSES AS )
PRUDENTLY INCURRED. )
IDAHO POWER COMPANY
DIRECT TESTIMONY
OF
QUENTIN NESBITT
1 Q. Please state your name, business address, and
2 present position with Idaho Power Company ("Idaho Power" or
3 "Company") .
4 A. My name is Quentin Nesbitt . My business
5 address is 1221 West Idaho Street, Boise, Idaho 83702 . I am
6 employed by Idaho Power as the Customer Relations and
7 Program Manager in the Customer Operations Department.
8 Q. Please describe your educational background.
9 A. I earned a Bachelor of Science degree in
10 Agricultural Engineering from the University of Idaho in
11 1989 and received my Professional Engineering license in
12 1992 .
13 Q. Please describe your work experience with
14 Idaho Power.
15 A. I began my employment with Idaho Power in
16 1991 as an Agricultural Representative in the Company' s
17 Energy Management Department where I was responsible for
18 providing customer service to irrigation and agricultural
19 customers . Later in 1991, I was promoted to an engineering
20 position where I provided technical support for Idaho Power
21 Agricultural Representatives . This involved Demand Side
22 Management ("DSM") program design and operation, pump
23 testing, new service requests, investigation of high bills,
24 and irrigation system evaluation and consultation. In 2002,
25 the Department was reorganized as the Customer Relations
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Idaho Power Company
1 Department, and I took on additional duties as the
2 Agricultural Customer Segment Advocate/Expert where I
3 coordinated Company activities that affected agricultural
4 customers . In October of 2014, I was promoted to Energy
5 Efficiency Program Leader and was responsible for
6 overseeing the Company' s Commercial and Industrial and
7 Irrigation DSM programs . In June of 2020, I became the
8 Customer Research and Analysis Leader and was responsible
9 for overseeing the Company' s analysis and reporting of all
10 DSM programs . In December of 2023, I was promoted to my
11 current position as Customer Relations and Program Manager.
12 Q. What is the purpose of your testimony in this
13 case?
14 A. The purpose of my testimony is to present the
15 Company' s request for a determination that $34, 873, 291 of
16 DSM expenses for the acquisition of demand-side resources
17 in 2024 was prudently incurred. This amount includes
18 $25, 922, 708 funded in 2024 by the Idaho Energy Efficiency
19 Rider ("Rider") and $8, 950, 583 of demand response program
20 incentive payments funded through base rates and tracked
21 annually through the Power Cost Adjustment ("PCA") .
22 My testimony will : (1) provide a review of 2024 DSM
23 program performance, (2) discuss 2024 DSM expenses and
24 adjustments, (3) provide an overview of the cost-
25 effectiveness results for 2024, (4) review program
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Idaho Power Company
1 evaluation efforts, and (5) describe the input stakeholders
2 provided during the year.
3 Q. Are you sponsoring any exhibits?
4 A. Yes . I am sponsoring the following exhibits :
Exhibit Description
Exhibit No. 1 2024 Idaho DSM Expenses and Adjustments
for Prudence Filing
Exhibit No. 2 2024 Cost-Effectiveness Summary by
Program Sector and Portfolio
Exhibit No. 3 2024 DSM Evaluation Plan
5
6 I . 2024 DSM PROGRAM PERFORMANCE
7 Q. What is Idaho Power' s focus when evaluating
8 program performance?
9 A. Idaho Power takes its responsibility of
10 prudently managing customer-funded DSM activities
11 seriously, and the Company believes it is important to
12 provide its customers with the maximum value from these
13 activities . The Company' s actions in 2024, and the content
14 of the Demand-Side Management 2024 Annual Report ("DSM 2024
15 Annual Report") , Attachment 1 to the Application filed in
16 this proceeding, provides evidence supporting the
17 conscientious work Idaho Power employees made toward using
18 customers' funds wisely to support DSM activities .
19 Q. Please provide an overview of Idaho Power' s
20 DSM activities in 2024 .
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Idaho Power Company
1 A. On a system-wide basis, Idaho Power offered a
2 broad portfolio of energy efficiency and demand response
3 programs available to all customer segments, and the
4 Company also participated in market transformation efforts
5 through the Northwest Energy Efficiency Alliance ("NEEA") .
6 Finally, the Company offered several educational and
7 behavioral initiatives including the Residential Energy
8 Efficiency Education Initiative, a seasonal contest, the
9 School and Campus Cohorts, and the Industrial Energy
10 Efficiency Cohort.
11 The Company leveraged its Energy Efficiency Advisory
12 Group ("EEAG") to solicit input and feedback on ways to
13 identify opportunities to increase program effectiveness,
14 delivery, and marketing. A summary of Idaho Power' s 2024
15 DSM programs is provided in Table 1 below.
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Idaho Power Company
1 Table 1
2 2024 DSM Programs by Sector, Operational Type, and Location
Program by Sector Operational Type State
Residential
A/C Cool Credit............................................................. Demand Response ID/OR
Easy Savings: Low-Income Energy Efficiency Education Energy Efficiency ID
Educational Distributions............................................... Energy Efficiency ID/OR
Heating&Cooling Efficiency Program.......................... Energy Efficiency ID/OR
Home Energy Audit....................................................... Energy Efficiency ID
Home Energy Report Program...................................... Energy Efficiency ID
Multifamily Energy Efficiency Program.......................... Energy Efficiency ID/OR
Oregon Residential Energy Conservation Program...... Energy Efficiency OR
Rebate Advantage........................................................ Energy Efficiency ID/OR
Residential New Construction Program........................ Energy Efficiency ID
Shade Tree Project....................................................... Energy Efficiency ID
Weatherization Assistance for Qualified Customers Energy Efficiency ID
(Idaho)
Weatherization Assistance for Qualified Customers Energy Efficiency OR
(Oregon)
Weatherization Solutions for Eligible Customers........... Energy Efficiency ID
Commercial/Industrial
Commercial and Industrial Energy Efficiency Program
Custom Projects....................................................... Energy Efficiency ID/OR
New Construction..................................................... Energy Efficiency ID/OR
Retrofits.................................................................... Energy Efficiency ID/OR
Flex Peak Program ....................................................... Demand Response ID/OR
Oregon Commercial Audit............................................. Energy Efficiency OR
Small Business Lighting Program ................................ Energy Efficiency ID/OR
Irrigation
Irrigation Efficiency Rewards......................................... Energy Efficiency ID/OR
Irrigation Peak Rewards................................................ Demand Response ID/OR
All Sectors
Northwest Energy Efficiency Alliance............................ Market Transformation ID/OR
3
4 Table 1 illustrates the broad availability of
5 programs offered by Idaho Power to its customers in energy
6 efficiency, demand response, and market transformation.
7 Idaho Power' s energy efficiency portfolio was cost-
8 effective, resulting in a 1 . 72 benefit/cost ratio when
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Idaho Power Company
1 evaluated from a Utility Cost Test ("UCT") perspective, a
2 1 . 64 benefit/cost ratio when evaluated from a Total
3 Resource Cost ("TRC") test perspective, and a 2 . 18
4 benefit/cost ratio when evaluated from a Participant Cost
5 Test ("PCT") perspective.
6 Attachment 1 to the Application, the DSM 2024 Annual
7 Report, provides details for each program, which include : a
8 program description, 2024 performance results, program
9 activities, cost-effectiveness ratios, marketing
10 activities, customer satisfaction, upcoming 2025 plans, and
11 evaluation results when applicable. Also included in
12 Attachment 1 are: Supplement 1 : Cost Effectiveness
13 ("Supplement 1") , which provides detailed cost-
14 effectiveness data by program and measure, and Supplement
15 2: Evaluation ("Supplement 2") , which provides copies of
16 the Company' s evaluations and reports conducted in 2024 .
17 Energy Efficiency
18 Q. What level of incremental annual energy
19 efficiency savings was achieved in 2024?
20 A. On a system-wide basis, Idaho Power achieved
21 143, 599 megawatt-hours ("MWh") of incremental annual energy
22 efficiency savings in 2024 . This value includes 119, 098 MWh
23 from Idaho Power' s energy efficiency programs and an
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Idaho Power Company
1 estimated 24, 501 MWhl of energy efficiency market
2 transformation savings through NEEA initiatives . Chart 1
3 below shows the incremental annual energy efficiency
4 savings in MWh from 2004 to the current year. Also shown in
5 this chart are the total energy efficiency expenses for
6 each year in millions of dollars .
7 Chart 1
8 Incremental Annual Energy Efficiency Savings (MWh) and
9 Energy Efficiency Expenses ($ millions) 2004-2024
250,000 $45
Market Transformation(NEEA)(MWh) $40
200,000 Idaho Power Program Savings(MWh)
$35
EE expenses(no DR) o
3 $30
150,000
m $25
a
s X
M W
'^ $20
100,000 r_
a w
w $15 .LJ
w
W
T
50,000 $10 °0
a
c
W
0 — , • , $0
2004 2006 2008 2010 2012 2014 2016 2018 2020 2022 2024
10
11 Note : 2024 NEEA market-transformation savings are
12 estimated.
1 Because Idaho Power will not receive final 2024 savings from NEEA
until the second quarter 2025, the NEEA-attributable savings is an
estimate provided to Idaho Power by NEEA.
NESBITT, DI 8
Idaho Power Company
1 Q. Did Idaho Power meet the energy efficiency
2 targets included in its most recently filed 2023 Integrated
3 Resource Plan ("IRP") ?
4 A. Yes . In 2024, Idaho Power achieved 16 . 4
5 average megawatts ("aMW") of incremental energy efficiency
6 savings, including NEEA estimated energy savings, which
7 exceeded the economic technical achievable potential
8 included in the 2023 IRP of 12 . 2 aMW. The 2024 savings
9 represent enough energy to power approximately 12, 596
10 average homes in Idaho Power' s service area for one year.
11 Q. How did the 2024 DSM program year compare to
12 2023?
13 A. In the 2024 program year, several of the
14 Company' s DSM programs outperformed their savings and
15 participation as compared to the 2023 program year.
16 Overall energy efficiency portfolio savings
17 increased by 5, 815 MWh year-over-year compared to 2023 . The
18 increase in savings can largely be attributed to the
19 Commercial and Industrial ("C&I") New Construction program
20 option. The C&I New Construction program increased its
21 total savings by 7, 519 MWh, with an increase in total
22 projects of 38 .
23 Additionally, the C&I Flex Peak and Irrigation Peak
24 Rewards demand response programs increased their combined
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Idaho Power Company
1 total participants by 116 and increased their demand
2 response capacity by 8 . 5 megawatts ("MW") .
3 Q. Does the Company engage in customer education
4 and outreach activities for which it cannot quantify or
5 report savings?
6 A. Yes . The Company engages in significant
7 educational awareness activities and marketing efforts that
8 are likely to result in energy savings experienced by
9 customers but are not quantified or claimed as part of
10 Idaho Power' s annual savings . These efforts are designed to
11 reach all customer segments and are more fully explained
12 throughout the DSM 2024 Annual Report. In 2024, this
13 included activities such as : holding virtual and in-person
14 technical trainings and workshops with customers, producing
15 the Energy@Work and Irrigation newsletters, participating
16 in several different types of agricultural shows, hosting
17 or participating in vendor workshops promoting irrigation
18 system efficiency, sharing residential energy efficiency
19 guides that showcased behavioral changes to save energy,
20 attending other outreach activities such as home shows to
21 discuss energy efficiency with customers one-on-one, and
22 supporting the Integrated Design Lab.
23 Demand Response
24 Q. What level of capacity was available from
25 Idaho Power' s demand response programs in 2024?
NESBITT, DI 10
Idaho Power Company
1 A. The total available capacity ("maximum
2 potential demand reduction") of Idaho Power' s three demand
3 response programs (Residential A/C Cool Credit, C&I Flex
4 Peak, and Irrigation Peak Rewards) was approximately 323
5 MW. This value represents the total enrolled MW from
6 participants adjusted for an expected maximum realization
7 rate . In 2024, as a result of Case No. IPC-E-23-24, the
8 Company implemented changes in its C&I Flex Peak program.
9 These changes helped increase the maximum potential demand
10 reduction of that program by 1 . 8 MW. The Company further
11 discusses the implementation and outcomes of these changes
12 starting on page 121 of the DSM 2024 Annual Report.
13 Q. What level of non-coincident demand reduction
14 was provided?
15 A. The Company' s demand response programs
16 provided actual non-coincident demand reduction of 257 MW
17 during the 2024 program season. The 257 MW of total maximum
18 actual demand reduction is less than the 323 MW of total
19 maximum potential demand reduction for a variety of reasons
20 including, but not limited to, the three demand response
21 programs are not always dispatched together during a single
22 event day, the four irrigation groups are also not always
23 dispatched coincidentally, and events are not always called
24 when the total program capacity is available . Chart 2 below
25 reflects the annual maximum potential demand reduction and
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Idaho Power Company
1 maximum actual demand reduction in MW since 2004 and the
2 associated annual expenses in millions of dollars .
3 Chart 2 .
4 Maximum Potential Demand Reduction (MW) and Demand Response
5 Expenses ($ millions) 2004-2024
500 �Maximum actual demand reduction $25
Available demand reduction
3 450
—Demand response expenses
c 400 $20 c
■ 2
v
350
300 $15
m
w
a
a 250 w
m c
200 $10 °o
a '^
w
0. 150
v
E m
E 100 $5 E
'x O
m
50 _ oil , $0
2004 2006 2008 2010 2012 2014 2016 2018 2020 2022 2024
6
7 II . 2024 DSM EXPENSES AND ADJUSTMENTS
8 Q. What amount of DSM expenses is the Company
9 requesting the Idaho Public Utilities Commission
10 ("Commission") find were prudently incurred?
11 A. In the delivery of energy efficiency, demand
12 response, and market transformation programs, Idaho Power
13 expended $25, 922, 708 of Rider funds and paid $8, 950, 583 in
14 demand response program incentives, for a total of
15 $34, 873, 291 spent on demand-side resource acquisition in
16 2024 . Idaho Power requests that the 2024 Rider-funded DSM
17 expenses, and the 2024 demand response program incentives
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Idaho Power Company
1 recovered through base rates and tracked through the PCA,
2 be reviewed together for a prudence determination. Exhibit
3 No . 1 to my testimony, 2024 Idaho DSM Expenses and
4 Adjustments for Prudence Filing, shows a breakout of these
5 expenses by program, customer sector, and funding source .
6 Q. Please compare the dollar amounts in Exhibit
7 No . 1 to your testimony with Appendix 2, 2024 DSM expenses
8 by funding source (dollars) , of the DSM 2024 Annual Report.
9 A. For clarity and ease of understanding, Exhibit
10 No . 1 ties to Appendix 2, which is found on page 176 of the
11 DSM 2024 Annual Report. The first column of Appendix 2
12 labeled "Idaho Rider" and the first column of Exhibit No. 1
13 labeled "Idaho Rider" match at the row labeled "Total DSM
14 Expense" in Exhibit No. 1 and "Grand Total" in Appendix 2
15 in the amount of $25, 912, 503 . All values in Exhibit No. 1
16 represent DSM expenses for the Idaho service area only. Two
17 prior year-end accounting adjustments and three current
18 year-end accounting adjustments were necessary to
19 accurately arrive at the total 2024 expenses for purposes
20 of the prudence determination. These five adjustments are
21 listed in Exhibit No . 1 under the "Adjustments" section as
22 2023 Irrigation Peak Rewards, Residential New Construction
23 Program, Home Energy Audit, Rebate Advantage, and
24 Irrigation Peak Rewards .
NESBITT, DI 13
Idaho Power Company
1 Q. Please describe the prior year-end accounting
2 adjustments included in Exhibit No. 1 .
3 A. The first adjustment of $1, 771 was related to
4 expenses associated with the Irrigation Peak Rewards
5 program that should have been charged to Operations and
6 Maintenance ("O&M") , rather than the Idaho Rider in 2023 .
7 The correction to reduce Idaho Rider expenses was made in
8 2024, and therefore $1, 771 needs to be added back to avoid
9 understating the 2024 prudence request.
10 The second adjustment of $194 is associated with the
11 Residential New Construction program where the expense was
12 initially charged to the Oregon Rider instead of the Idaho
13 Rider in 2023 . The correction adding the expense to the
14 Idaho Rider was made in 2024, and therefore $194 needs to
15 be subtracted from the 2024 prudence request because it was
16 already deemed prudent by the Commission in the 2023
17 request.
18 Q. Please describe the current year-end
19 accounting adjustments included in Exhibit No. 1 .
20 A. Three accounting adjustments for 2024 were
21 identified through Idaho Power' s year-end review of
22 expenses and the corrections were made after the 2024 year-
23 end financial books were closed.
24 The first adjustment results in an addition of
25 $5, 383 associated with the Home Energy Audit program where
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Idaho Power Company
1 the expenses were initially charged to O&M instead of the
2 Idaho Rider.
3 The second adjustment results in an addition of
4 $5, 523 associated with the Rebate Advantage program where
5 the expenses were initially charged to 0&M instead of the
6 Idaho Rider.
7 The third adjustment results in a reduction of
8 $2, 278 associated with the Irrigation Peak Rewards program
9 where the expenses were initially charged to the Idaho
10 Rider instead of 0&M.
11 Q. What was the year-end 2024 balance of the
12 Rider?
13 A. The Rider account balance on December 31,
14 2024, had a positive, or over-collected, balance of
15 $7, 570, 508 . Table 2 below shows the January 2024 beginning
16 balance, funding plus accrued interest, expenses, and the
17 ending balance as of December 31, 2024 .
18 Table 2
19 Idaho Energy Efficiency Rider (January-December 2024)
Idaho Energy Efficiency Rider � 1
2024 Beginning Balance $ 700,361
2024 Funding plus Accrued Interest as of 12/31/24 32,782,650
Total 2024 Funds 33,483,011
2024 Expenses as of 12/31/24 (25,912,503)
Ending Balance as of 12/31/24 $ 7,570,508
20
NESBITT, DI 15
Idaho Power Company
1 III . 2024 COST-EFFECTIVENESS OVERVIEW
2 Q. What is Idaho Power' s overall goal when it
3 comes to DSM cost-effectiveness tests?
4 A. Idaho Power strives to ensure that DSM funds
5 collected from customers are utilized to support the
6 pursuit of cost-effective energy efficiency and demand
7 response programs, with the limited exception of certain
8 policy considerations . This goal is achieved by applying a
9 multi-step process . Prior to the actual implementation of
10 energy efficiency or demand response programs, Idaho Power
11 performs a preliminary cost-effectiveness analysis to
12 assess whether a potential program design or measure will
13 be cost-effective from the perspective of customers as well
14 as the Company. Idaho Power measures cost-effectiveness
15 under three tests : the UCT, the TRC test, and the PCT. A
16 review of each test allows for an economic assessment of
17 the life—cycle costs and benefits of a DSM investment from
18 the perspective of DSM program participants, Idaho Power,
19 and non-participating customers .
20 Idaho Power also reviews the cost-effectiveness
21 results for each program and measure on an annual basis to
22 determine whether a program should continue or be modified
23 so it remains cost-effective on an ongoing basis . If a
24 measure or program is identified as non-cost-effective,
25 Idaho Power seeks EEAG input before making its
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Idaho Power Company
1 determination on modifying, continuing, or discontinuing an
2 offering.
3 The cost-effectiveness test methodologies and
4 assumptions are described in more detail in the first pages
5 of Supplement 1, included in Attachment 1 to the
6 Application in this proceeding.
7 Q. Does Idaho Power believe its application of
8 the standard economic tests is consistent with Commission
9 directives?
10 A. Yes . Idaho Power believes its application of
11 the three economic tests is consistent with prior
12 Commission directives, as described in Order No. 33365 :2
13 We thus find it reasonable for the Company to
14 continue screening potential programs using
15 each test as a guideline, and to advise us on
16 how the Company' s programs fare under each
17 test . When the Company ultimately seeks to
18 recover its prudent investment in such
19 programs, however, we believe the Company may
20 (but need not exclusively) emphasize the UCT-
21 and that test ' s focus on Company-controlled
22 benefits and costs—to argue whether the
23 programs were cost-effective . As always, the
24 Company ultimately must persuade us that its
25 program investments were prudent under the
26 totality of the circumstances .
27
28 Because Idaho Power must ultimately demonstrate to
29 the Commission that its program investments were prudent
2 In the Matter of the Application of Idaho Power Company for a
Determination of 2014 Demand-Side Management Expenditures as Prudently
Incurred, Case No. IPC-E-15-06, Order No. 33365, p. 9-10 (Aug. 28,
2015) .
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Idaho Power Company
1 under "the totality of the circumstances", the Company
2 continues to evaluate performance from the three
3 perspectives .
4 A. 2024 Cost-Effectiveness Results
5 Q. What were the results of the 2024 cost-
6 effectiveness analyses?
7 A. Exhibit No. 2 to my testimony, 2024 Cost-
8 Effectiveness Summary by Program, Sector, and Portfolio,
9 shows the results of the UCT, TRC test, and PCT for every
10 energy efficiency program aggregated by sector and for the
11 overall portfolio. As shown in Table 3 below, the overall
12 DSM Portfolio achieved benefit/cost ratios greater than 1 . 0
13 for each of the three cost-effectiveness tests . All three
14 of the program sectors achieved benefit/cost ratios greater
15 than or equal to 1 . 0 from the UCT and PCT perspectives with
16 the Residential Sector having a TRC less than 1 . 0 .
17 Table 3
18 2024 Benefit/Cost by Sector & Portfolio
Utility Cost Total Participant
Sector Test (UCT) Resource Cost Cost Test
(TRC) Test (PCT)
Residential* 1 . 25 0 . 95 3 . 37
Commercial/Industrial 2 . 22 1 . 12 1 . 44
Irrigation 1 . 65 3 . 86 4 . 04
Portfolio* 1 . 72 1 . 64 2 . 18
*Does not include Weatherization Assistance for Qualified Customers Program
19
20 Q. Did the Company quantify the Residential
21 Sector and DSM Portfolio cost-effectiveness, including the
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Idaho Power Company
1 costs and benefits of the Weatherization Assistance for
2 Qualified Customers ("WAQC") program?
3 A. Yes . Table 4 below shows the cost-
4 effectiveness of the Residential Sector and the Overall DSM
5 Portfolio with and without the WAQC program included.
6 Table 4
7 Residential and Portfolio Cost-Effectiveness with and
8 without WAQC
WAQC Not Included WAQC Included
Sector UCT TRC PCT UCT TRC PCT
Residential 1 . 25 0 . 95 3 . 37 0 . 88 0 . 71 2 . 73
Portfolio 1 . 72 1 . 64 2 . 18 1 . 63 1 . 59 2 . 16
9
10 While the WAQC program remains non-cost-effective
11 from an economic perspective, it provides real savings to
12 customers that would otherwise likely be unable to afford
13 to weatherize their homes and offers health and safety
14 benefits to customers in need that are not quantified
15 through the economic tests .
16 Q. What assumptions were utilized to calculate
17 the sector and portfolio cost-effectiveness for 2024?
18 A. Idaho Power relies on research conducted by
19 third parties to obtain savings and cost assumptions for
20 various measures . The Company fixes savings assumptions
21 when budgets and goals are established for the next
22 calendar year unless codes and standards change, or program
23 updates necessitate a need to use updated savings . The
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Idaho Power Company
I remaining inputs are obtained from the Company' s IRP
2 planning process . Because the 2023 IRP was the most
3 recently acknowledged IRP at the time 2024 DSM program
4 planning occurred, Idaho Power used the avoided costs from
5 the 2023 IRP in its cost-effectiveness analysis .
6 To calculate the sector cost-effectiveness, Idaho
7 Power includes the benefits and costs associated with
8 programs that produce quantifiable energy savings . The
9 portfolio cost-effectiveness is the sum of all energy
10 efficiency activities, including those that do not have
11 savings associated with them, such as overhead expenses .
12 Q. What are the cost-effectiveness results for
13 each of the Company' s DSM programs?
14 A. As reflected in Exhibit No. 2 to my testimony,
15 on an individual program basis, 9 of the 14 energy
16 efficiency programs offered in Idaho for which the Company
17 calculates cost-effectiveness had benefit/cost ratios
18 greater than 1 . 0 under the UCT.
19 It should be noted that the PCT ratios cannot be
20 calculated for programs that do not have a direct customer
21 cost, and the PCT is shown as "N/A" in Exhibit No. 2 for
22 those programs . The details of the other calculations are
23 found in Supplement 1 of the DSM 2024 Annual Report.
NESBITT, DI 20
Idaho Power Company
1 Q. How many measures did Idaho Power calculate
2 cost-effectiveness for within each energy efficiency
3 program it offers?
4 A. In 2024, Idaho Power evaluated the benefits
5 and costs of 324 measures . The results of these
6 calculations, along with measure assumption details and
7 source documentation, can be found in Supplement 1 to the
8 DSM 2024 Annual Report.
9 Q. How does Idaho Power address any individual
10 measures that are not cost-effective based on one or more
11 tests?
12 A. The cost and benefit values used in the
13 various analyses are based on markets, technologies,
14 economic inputs, savings estimates, and cost estimates,
15 which can change over time. When a measure is identified as
16 non-cost-effective at a specific point in time, Idaho Power
17 first evaluates whether the inputs used in the calculations
18 are still applicable. Then the Company determines if the
19 measure parameters should be modified or if the measure
20 should be eliminated altogether . For additional detail on
21 measure analysis, please refer to Supplement 1 to the DSM
22 2024 Annual Report.
23 B. Non-Cost-Effective Programs
24 1 . Income Qualified Weatherization
NESBITT, DI 21
Idaho Power Company
1 Q. Please explain what drivers influence the
2 cost-effectiveness results for the WAQC and Weatherization
3 Solutions for Eligible Customers ("Solutions") programs?
4 A. The WAQC and Solutions programs provide real
5 and substantial per home savings, but due to the costs of
6 comprehensive whole-house weatherization, it is difficult
7 for the value of the savings to outweigh the costs . The
8 weatherization services provided through the WAQC program
9 are consistent with the Idaho State Weatherization
10 Assistance Program guidelines, and both the WAQC and
11 Solutions programs are offered at no charge to the
12 participant . Please refer to pages 75 and 90 in the DSM
13 2024 Annual Report for the savings, costs, and the number
14 of homes weatherized in 2024 .
15 Q. Did the Company make changes to the programs
16 during 2024?
17 A. Yes . In compliance with Order No . 36042 issued
18 in Case No. IPC-E-23-11, the Company filed Tariff Advice
19 No . IPC-TAE-24-03 to update administrative details and
20 funding levels for its WAQC program. The advice was
21 converted into Case No. IPC-E-24-39 and the Commission
22 issued Order No. 36406 approving the following changes :
23 elimination of the requirement to track and carryover
24 unspent funds, allowing for services rendered in the
25 current year to be invoiced within 60 days of the following
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Idaho Power Company
1 year, removal of the dollar limit that can be transferred
2 between Community Action Partnership ("CAP") agencies, a
3 one-time increase in the maximum annual average cost per
4 home weatherized to $8, 495, and the addition of other
5 electric equipment upgrades in addition to HVAC for the re-
6 weatherization offering. Holistically, these changes are
7 intended to help CAP agencies spend more of the Idaho Power
8 funds that are available to them for the WAQC program.
9 Q. Does Idaho Power have plans for further
10 modifications to the WAQC and Solutions programs?
11 A. Not at this time . While the Company has
12 identified that the programs are not cost-effective under
13 the UCT, unless the Commission directs otherwise, Idaho
14 Power intends to continue to offer them to the Company' s
15 limited-income customers on an ongoing basis . The Company
16 will also continue to consult the EEAG and the
17 weatherization managers who oversee the weatherization work
18 to look for ways to improve outreach and the cost-
19 effectiveness of these programs as opportunities are
20 available .
21 2 . Shade Tree Project
22 Q. What is the Shade Tree Project?
23 A. The Shade Tree Project was initially offered
24 in 2013 and provided no-cost shade trees to Idaho
25 residential customers . Participants enrolled in the program
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Idaho Power Company
1 online and picked up their trees at specific events .
2 Unclaimed trees were donated to cities, schools, and other
3 non-profit organizations .
4 In 2023, it was determined that based on the results
5 of an impact evaluation, the program was no longer expected
6 to be cost-effective going forward. Accordingly, and with
7 the support of EEAG, the Company ultimately decided to end
8 the offering after the existing tree supply contract
9 expired. The Company held its last event in May 2024 .
10 Q. Did the Company calculate cost-effectiveness
11 results for the Shade Tree Project?
12 A. No. Because the trees are not large enough to
13 produce recognizable savings until the fifth year after
14 planting, Idaho Power has not claimed incremental savings
15 associated with the trees until that fifth year.
16 Accordingly, 2024 would be the year to report incremental
17 savings for trees planted in 2020, however in 2020 there
18 were no Shade Tree events held due to COVID-19 limitations .
19 While there are quantifiable savings accruing to the system
20 associated with trees planted during and before 2019, it
21 has not been the Company' s practice to claim those
22 incremental savings in future years beyond the fifth year.
23 3 . Heating and Cooling Efficiency Program
24 Q. What were the cost-effectiveness results for
25 the Heating and Cooling Efficiency program?
NESBITT, DI 24
Idaho Power Company
1 A. As shown in Exhibit No . 2, the Heating and
2 Cooling Efficiency program achieved a UCT of 0 . 95 and a TRC
3 of 0 . 39 .
4 Q. What was the primary contributor to the
5 program not being cost-effective?
6 A. Lower than anticipated program participation
7 and accordingly, program savings during the year was the
8 primary contributor. However, despite the lower
9 participation and savings, the UCT ratio increased from
10 0 . 94 in 2023 to 0 . 95 in 2024, driven by a general increase
11 in DSM avoided costs as well as the modifications made to
12 program incentives at the end of 2023 . While the Company
13 anticipated the changes to the program would result in the
14 program being cost-effective in 2024, the lower savings
15 benefits resulting from the lower-than-anticipated
16 participation were not enough to outweigh the program
17 costs .
18 In 2024, smart thermostats made up 32 percent of the
19 total program participation and 8 percent of total savings .
20 This is a notable drop from 2023 when smart thermostats
21 made up 45 percent of participation and 14 percent of
22 savings . The program reduced the smart thermostat incentive
23 from $75 to $50 at the end of 2023, which noticeably
24 contributed to the participation decline.
NESBITT, DI 25
Idaho Power Company
1 Air-source heat pumps made up 17 percent of the
2 total program participation and 51 percent of the total
3 savings . In 2024, the program removed the incentive option
4 for upgrading an existing air-source heat pump to a more
5 efficient air-source heat pump. Prior to its removal this
6 was a popular option; in the 2023 program year it had 55
7 participants . The option was removed due to a change in the
8 eligibility requirements outlined in the Regional Technical
9 Forum workbook used to claim savings . Idaho Power plans to
10 assess possibilities for this incentive to return, likely
11 with different eligibility requirements .
12 Ductless heat pumps made up 23 percent of the
13 program participation and 22 percent of the total savings .
14 While the savings assumptions did not change year over
15 year, the average savings per unit, which are dependent on
16 location, declined by approximately 8 percent.
17 Q. Does Idaho Power expect the program to be
18 cost-effective going forward?
19 A. In November 2023, Idaho Power modified the
20 program based on the updated savings and analyzed with the
21 newest DSM avoided costs from the 2023 IRP. These changes
22 improved program cost-effectiveness in 2024, but Idaho
23 Power has plans to review additional modifications and
24 offerings to further improve the program cost-
25 effectiveness . The program will be incurring evaluation
NESBITT, DI 26
Idaho Power Company
1 expenses in 2025 and still may not be cost effective for
2 2025 because of these expenses .
3 4 . Small Business Lighting
4 Q. What were the cost-effectiveness results for
5 the Small Business Lighting program?
6 A. As shown in Exhibit No. 2, the Small Business
7 Lighting program achieved a UCT of 0 .25 and a TRC of 0.35.
8 Q. What was the primary contributor to the
9 program not being cost-effective?
10 A. The program was not expected to be cost-
11 effective in program year 2024, due primarily to its launch
12 being late in the year, leaving it with only a short window
13 to build awareness and produce savings .
14 Of the 22, 967 kilowatt hours ("kWh") of savings
15 claimed in 2024, approximately 82 percent came from
16 interior lighting measures and 18 percent from exterior
17 lighting. Exterior lighting tends to have a higher avoided
18 cost benefit value due to the savings occurring during
19 higher-risk hours thus providing greater system reliability
20 benefits . Initial cost-effectiveness modeling anticipated a
21 more even interior-exterior split with 65 percent of
22 savings from interior lighting and 35 percent from exterior
23 lighting. Additionally, the initial program modeling
24 assumed an average project size of 3, 458 kWh, which is
NESBITT, DI 27
Idaho Power Company
1 higher than the 2024 actual average of 2, 552 kWh. With only
2 nine projects completed in 2024, the data is still limited.
3 Q. Does Idaho Power expect the program to be
4 cost-effective going forward?
5 A. Yes . Idaho Power expects the program to be
6 cost-effective as it will be offered for the entire year in
7 2025 .
8 C. Demand Response Cost-Effectiveness
9 Q. Does Idaho Power evaluate cost-effectiveness
10 for its three demand response programs?
11 A. Yes . The methodology approved in Order No .
12 353363 is used to determine the cost-effectiveness of the
13 demand response programs and sets the maximum avoided cost
14 value . In accordance with the approved methodology, the
15 2024 cost-effectiveness threshold for demand response is
16 $62 . 39 per kilowatt ("kW") year.
17 Q. How was the $62 . 39 determined?
18 A. Using the approved method, the avoided cost
19 calculation for the demand response programs is as follows :
20
21 (Levelized Fixed Costs - Additional Benefits)
22 x Effective Load Carrying Capacity ("ELCC") of Annual
3In the Matter of Idaho Power Company's Application for Approval to
Modify its Demand Response Programs, Case No. IPC-E-21-32, Order No.
35336, p. 9-10 (Mar. 4, 2022) .
NESBITT, DI 28
Idaho Power Company
I Demand Response Capacity Compared to Proxy Resource
2 = $ per kW year Demand Response Avoided Costs
3
4 Each of the three components have been updated and
5 are :
6 1 . From the 2023 IRP, the 2024 levelized fixed
7 cost value of a Simple-Cycle Combustion Turbine ("SCCT")
8 was determined to be $145 . 94 per kW per year.
9 2 . From the 2023 IRP, to determine the
10 additional ancillary benefits provided by the SCCT compared
11 to demand response, an analysis was performed where demand
12 response was replaced with an equivalent SCCT and the fixed
13 costs of the SCCT were removed from the model . The result
14 of this analysis showed there were $1 . 66 in benefits
15 associated with the SCCT, this value is mainly driven by
16 market prices .
17 3 . The updated ELCC of approximately 323 MW of
18 demand response capacity compared to a SCCT utilizing 2023
19 IRP assumptions is 43 . 24 percent.
20
21 ($145. 94 - $1 . 66) * 43.24 0 =
22 $62. 39 per kW year Demand Response Avoided Cost
23
24 Additional details of the methodology are included
25 in Supplement 1 .
NESBITT, DI 29
Idaho Power Company
1 Q. What were the total and per kW costs of the
2 Company' s demand response programs?
3 A. In 2024, the system-wide cost of operating the
4 three demand response programs was approximately $9 . 7
5 million ($9 . 2 million of incentives and $ . 5 of other
6 costs) . The amounts attributable to the Idaho-only
7 jurisdiction were $9 . 4 million ($9 million of incentives
8 and $ . 4 million of other costs) . Table 5 below shows the
9 2024 dollar per kW year costs for each program and the
10 overall demand response portfolio assuming the programs
11 were dispatched for the maximum 60 hours . Idaho Power
12 estimates that if the three programs were dispatched for
13 the full 60 hours allowed, the total costs would have been
14 approximately $14 million on a system-wide basis .
15 Table 5
16 Demand Response Program 2024 $ per kW year
Program $ per kW year
Residential A/C Cool Credit $47 .25
C&I Flex Peak $27 .54
Irrigation Peak Rewards $45.43
Total Demand Response Portfolio $43.31
17
18 Q. Were the demand response programs cost-
19 effective?
20 A. Yes . All three of the Company' s demand
21 response programs, as well as the demand response
22 portfolio, had a cost per kW less than the 2024 threshold
NESBITT, DI 30
Idaho Power Company
1 of $62 . 39, meaning the programs and the portfolio were
2 cost-effective.
3 Q. Did Idaho Power consider updates to its demand
4 response cost-effectiveness methodology as a result of Case
5 No . IPC-E-24-11?
6 A. Yes . In Order No. 36331 issued in Case No .
7 IPC-E-24-11, the Commission directed the Company to work
8 with Staff to consider alternative cost-effectiveness
9 calculations for its demand response programs . Based on the
10 outcome of discussions with Staff in 2024, the Company
11 determined that the current method for valuing the maximum
12 avoided cost threshold was still appropriate and is not
13 currently pursuing changes to that method.
14 IV. EVALUATION ACTIVITY OVERVIEW
15 Q. What is the Company' s approach to DSM program
16 evaluation?
17 A. To ensure the ongoing cost-effectiveness of
18 programs through validation of energy savings and demand
19 reduction, and to guide the efficient management of its
20 programs, the Company utilizes evaluations conducted by
21 third-party contractors chosen through a competitive
22 bidding process . Idaho Power uses industry-standard
23 protocols, internal analyses, and regional and national
24 studies to inform its internal and external evaluation
25 efforts . The Company has generally conducted impact
NESBITT, DI 31
Idaho Power Company
1 evaluations every three years, and process evaluations for
2 relatively new programs, or when a program has significant
3 changes . Supplement 2 to the DSM 2024 Annual Report
4 provides additional information regarding how Idaho Power
5 evaluates its programs .
6 Q. How does Idaho Power utilize the evaluations
7 described above?
8 A. Idaho Power uses the results of its
9 evaluations to inform decisions related to program
10 improvement, to compare processes to industry best
11 practices, and to benchmark and validate reported program
12 savings .
13 Q. What evaluation activities took place in 2024?
14 A. In addition to the annual cost-effectiveness
15 analyses that the Company conducts for each program, Idaho
16 Power contracted with several third-party evaluators to
17 conduct impact and process evaluations in 2024 . Evaluations
18 conducted by these evaluators were on the following
19 programs :
20 • Impact evaluation on the Education Distributions
21 program.
22 • Impact and process evaluations on the Rebate
23 Advantage and C&I Custom Projects programs .
24 • Internal evaluations on the A/C Cool Credit, C&I
25 Flex Peak, and Irrigation Peak Rewards programs .
NESBITT, DI 32
Idaho Power Company
1 The impact evaluations that were conducted in 2024
2 analyzed reported savings from the 2023 program year.
3 Realization rates were as follows :
4 • Educational Distributions Welcome Kits : 178 . 7
5 percent .
6 • Educational Distributions Student/Teacher Kits :
7 126 . 9 percent.
8 • Rebate Advantage: 99 . 77 percent.
9 • C&I Custom Projects 100 . 3 percent.
10 The final reports for these evaluations, and the
11 market effects evaluations conducted by NEEA, are included
12 in Supplement 2 to the DSM 2024 Annual Report.
13 Q. Does Idaho Power have a DSM program evaluation
14 plan for 2025-2026?
15 A. Yes . The evaluation plan is included as
16 Exhibit No . 3 to my testimony and is also included in
17 Supplement 2 to the DSM 2024 Annual Report. In 2025, Idaho
18 Power' s evaluation plan includes the following third-party
19 evaluations : impact and process evaluations on the Heating
20 and Cooling Efficiency, New Construction, Retrofits, A/C
21 Cool Credits, and Irrigation Peak Rewards programs .
22 Consistent with the directive from Order No. 36331,
23 issued in Case No. IPC-E-24-11, the Heating and Cooling
24 Efficiency evaluation will include an analysis of the
25 savings of self-installed versus contractor-installed smart
NESBITT, DI 33
Idaho Power Company
1 thermostats . Additionally, a Residential New Construction
2 program evaluation will be conducted using billing data.
3 The Company anticipates filing the Residential New
4 Construction evaluation as a supplement to this Application
5 once it is completed.
6 V. STAKEHOLDER INPUT
7 Q. What is the EEAG?
8 A. In 2002, Idaho Power formed the EEAG to
9 provide input on enhancing existing DSM programs,
10 recommending new energy efficiency measures, and
11 implementing energy efficiency programs . Members include
12 customer representatives from residential, irrigation,
13 commercial, and industrial sectors as well as technical
14 experts, representatives for limited-income individuals,
15 environmental organizations, state agencies, county and
16 city governments, the Commission, and Idaho Power.
17 Q. What is the structure of EEAG meetings?
18 A. The EEAG generally meets quarterly, and when
19 necessary additional meetings are held to address special
20 topics . The agenda during EEAG meetings is varied, but
21 typically includes program and project updates, new energy
22 efficiency program or measure proposals, marketing methods,
23 specific measure details including cost-effectiveness, the
24 status of energy efficiency expenses, and general
25 information on DSM issues . When appropriate, the Company
NESBITT, DI 34
Idaho Power Company
1 invites experts to speak on evaluations, research, and
2 other topics of interest to enhance EEAG' s understanding.
3 Q. How did Idaho Power solicit guidance from the
4 EEAG during the 2024 program year?
5 A. In 2024, the Company held four EEAG meetings,
6 two in person with a virtual option and two virtually.
7 During these meetings, Idaho Power discussed and requested
8 recommendations on a broad range of DSM issues . While a
9 comprehensive list of the topics Idaho Power worked with
10 the EEAG on for development, design, promotion, or input
11 are included in the DSM 2024 Annual Report, a few of the
12 items are highlighted as follows :
13 • C&I Flex Peak and Irrigation Peak Rewards
14 Updates : Based on feedback from customers and
15 the company' s pursuit of additional cost-
16 effective demand response capacity, the Company
17 requested feedback from EEAG on potential
18 updates to its C&I Flex Peak and Irrigation
19 Peak Rewards programs . EEAG members were
20 generally supportive of the changes and the
21 Company ultimately received approval of the
22 modifications in Order No. 36449, issued in
23 Case No. IPC-E-24-37 . Program changes will be
24 implemented for the 2025 program season.
NESBITT, DI 35
Idaho Power Company
1 • Small Business Lighting: Since the closure of
2 the Company' s previous small business offering,
3 Small Business Direct Install, the Company has
4 been committed to continue to look at ways to
5 meet the needs of its small business customers .
6 Based on feedback and support received from
7 EEAG, the Company launched its Small Business
8 Lighting program in September 2024 .
9 • Residential Home Energy Reports : As a result of
10 Order No. 36331 issued in Case No IPC-E-24-11,
11 the Company presented to EEAG alternative ways
12 to validate savings for the Home Energy Reports
13 program that would allow all customers to
14 participate in the program. The Company is
15 continuing to evaluate alternative methods and
16 will continue to bring the information to EEAG
17 for feedback.
18 • A Bring Your Own Thermostat option being added
19 to Residential A/C Cool Credit program: Based
20 on continued decline in A/C Cool Credit
21 participation and Idaho Power' s continued
22 pursuit of additional cost-effective demand
23 response capacity, the Company consulted with
24 the EEAG on adding a new option, Bring Your Own
25 Thermostat, to A/C Cool Credit. EEAG has
NESBITT, DI 36
Idaho Power Company
1 expressed general support for the option and
2 the Company has submitted a filing to the
3 Commission seeking approval of the program
4 option.
5 VI . CONCLUSION
6 Q. Do you believe that the information contained
7 in this testimony and attached exhibits supports a prudence
8 determination for 2024 DSM expenses?
9 A. Yes . Based on the DSM 2024 Annual Report, the
10 testimony set forth above, and the attached exhibits, Idaho
11 Power respectfully requests the Commission determine that
12 $34, 873, 291 was prudently incurred for the acquisition of
13 demand-side resources in 2024 .
14 Q. Does this conclude your testimony?
15 A. Yes, it does .
NESBITT, DI 37
Idaho Power Company
1 ATTESTATION OF TESTIMONY
2
3 STATE OF IDAHO )
4 ) ss .
5 County of Ada )
6
7 I, Quentin Nesbitt, having been duly sworn to
8 testify truthfully, and based upon my personal knowledge,
9 state the following:
10 I am employed by Idaho Power Company as the Customer
11 Relations and Program Manager in the Customer Operations
12 Department and am competent to be a witness in this
13 proceeding.
14 I declare under penalty of perjury of the laws of
15 the state of Idaho that the foregoing pre-filed testimony
16 and exhibits are true and correct to the best of my
17 information and belief.
18 DATED this 14th day of March 2025 .
19
20
21 Quentin Nesbitt
22
23 SUBSCRIBED AND SWORN to before me this 14th day of
24 March 2025 .
25
26
27 ;• FIn. NO• 0y0 'A Notary Public for Idaho
28 ? ; 140TAR : •. Residing at Ada County Idaho
29 �.� r ; My commission expires : 11/02/2024
30 pUB LtC�ti.;
,'�'•9�•OF�IDP`,r•••• NESBIIdaho PowerCompany38
�n��u�•
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-12
IDAHO POWER COMPANY
NESBITT, DI
TESTIMONY
EXHIBIT NO. 1
Exhibit 1
2024 Idaho DSM Expenses and Adjustments for Prudence Filing
Demand Response
Sector/Program Idaho Rider Program Incentives Total
Recorded in PCA
Energy Efficiency
Residential
A/C Cool Credit (242,227) 345,788 103,561
Easy Savings:Low-Income Energy Efficiency Education 125,050 - 125,050
Educational Distributions 737,775 737,775
Heating&Cooling Efficiency Program 331,068 331,068
Home Energy Audit 72,571 72,571
Home Energy Reports 783,117 783,117
Multi-Family Energy Efficiency 30,985 30,985
Rebate Advantage 128,849 128,849
Residential New Construction Program 209,809 209,809
Shade Tree Project 59,627 59,627
Weatherization Assistance for Qualified Customers(Idaho) 638,289 638,289
Weatherization Solutions for Eligible Customers 111,940 111,940
Commercial/Industrial
Commercial and Industrial Energy Efficiency Program
Custom Projects 8,595,184 8,595,184
New Construction 3,696,504 3,696,504
Retrofits 3,117,026 - 3,117,026
Flex Peak Program 7,783 504,883 512,666
Small Business Lighting(SBL)Program 13,050 - 13,050
Irrigation
Irrigation Efficiency Rewards 1,229,784 - 1,229,784
Irrigation Peak Rewards 413,658 8,099,912 8,513,570
Energy Efficiency/Demand Response Total 20,059,843 8,950,583 299010,426
Market Transformation
Northwest Energy Efficiency Alliance 3,203,890 - 3,203,890
Market Transformation Total 3,203,890 3,203,890
Other Programs and Activities
Commercial/Industrial Energy Efficiency Overhead 152,095 152,095
Energy Efficiency Direct Program Overhead 54,880 54,880
Residential Energy Efficiency Education Initiative 246,737 246,737
Residential Energy Efficiency Overhead 919,691 919,691
Other Programs and Activities Total 1,373,403 1,373,403
Indirect Program Expenses
Energy Efficiency Accounting&Analysis 1,274,151 1,274,151
Energy Efficiency Advisory Group 1,263 1,263
Special Accounting Entries
Special Accounting Entries (45) (45)
Indirect Program Expenses Total 1,275,369 - 1,275,369
Total DSM Expense 25,912,503 8,950,583 34,863,087
Adjustments
Prior year-end accounting adjustments:
2023 Irrigation Peak Rewards(a) 1,771 1,771
Residential New Construction Program(b) (194) (194)
Current year-end accounting adjustments:
Home Energy Audit(c) 5,383 5,383
Rebate Advantage(c) 5,523 5,523
Irrigation Peak Rewards(d) (2,278) (2,278)
2024 Prudence Filing Total $ 25,922,708 $ 8,950,583 $ 34,873,291
(a)2023 O&M expense initially charged to the Idaho Rider.The correction was made in 2024.
(b)2023 Idaho Rider expenses initially charged to the Oregon Rider. The correction was made in 2024.
(c)2024 Idaho Rider expense initially charged to O&M.The correction was made in 2025.
(d)2024 O&M expense initially charged to the Idaho Rider The correction was made in 2025.
Exhibit No.1
Case No.IPC-E-25-12
Q.Nesbitt,IPC
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-12
IDAHO POWER COMPANY
NESBITT, DI
TESTIMONY
EXHIBIT NO. 2
2024 Cost-Effectiveness Summary by Program, Sector, and Portfolio
2024 Benefit/Cost Tests
Utility Cost Test Total Resource Cost Participant Cost
Program/Sector (UCT) (TRC) (PCT)
Educational Distributions 2.31 2.69 N/A
Heating & Cooling Efficiency Program 0.95 0.39 0.93
Home Energy Reports 1.31 1.44 N/A
Multifamily Energy Efficiency Program 1.16 0.75 2.14
Rebate Advantage 1.16 0.47 1.64
Residential New Construction 1.04 1.09 3.20
Shade Tree Project - - -
Weatherization Assistance for Qualified Customers (Idaho) 0.16 0.22 N/A
Weatherization Assistance for Qualified Customers (Oregon) 0.06 0.20 N/A
Weatherization Solutions for Eligible Customers 0.14 0.21 N/A
Residential Energy Efficiency Sectorz 1.25 0.95 3.37
Commercial and Industrial Energy Efficiency Program
Custom Projects 2.21 0.91 1.18
New Construction 2.46 2.32 3.06
Retrofits 1.96 0.96 1.20
Small Business Lighting 0.25 0.35 1.89
Commercial/Industrial Energy Efficiency Sector 2.22 1.12 1.44
Irrigation Efficiency 1.65 3.86 4.04
Irrigation Energy Efficiency Sector 1.65 3.86 4.04
Energy Efficiency Portfolio 1.72 1.64 2.18
1 Program closed after Spring 2024 event.
2 Residential sector cost-effectiveness excludes WAQC benefits and costs. If included, the UCT, TRC, and PCT would be 0.88, 0.71, and 2.73, respectively.
3 Program launched September,2024.
4 Commercial/Industrial Energy Efficiency Sector cost-effectiveness ratios include savings and participant costs from Green Motors Rewinds.
5 Irrigation Energy Efficiency Sector cost-effectiveness ratios include savings and participant costs from Green Motors Rewinds.
6 Portfolio cost-effectiveness excludes WAQC benefits and costs. If included, the UCT, TRC, and PCT would be 1.63, 1.59, and 2.16 respectively.
Exhibit No. 2
Case No. IPC-E-25-12
Q. Nesbitt, IPC
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-25-12
IDAHO POWER COMPANY
NESBITT, DI
TESTIMONY
EXHIBIT NO. 3
Customer Relations and Energy Efficiency 2025-2026 Program Evaluation Plan
2026 2025 2024 2023 2022 2021 2020 2019 2018 2017 2016 2015� 2014 2013 2012 2011 2010
Residential Energy Efficiency Programs
Educational Distributions I I/P
Energy House Calls I/P I P
Heating&Cooling Efficiency Program I/P I/P UP P I P
Home Energy Audit I/P I P
Home Energy Reports UP I P
Multifamily Direct Install Program I/P
Multifamily Energy Savings Program UP
Rebate Advantage I/P I I/P I
Residential New Construction Program O 1 UP
Shade Tree Project 1 O P
Weatherization Assistance for Qualified Customers O O O P I
Weatherization Solutions for Eligible Customers O O O P I
Commercial/Industrial Energy Efficiency Programs
Commercial Energy-Saving Kits UP
Custom Projects I/P I/P I P I/P I P
New Construction I/P I/P I P I I P
Retrofits I/P I/P I P I P I P
Small Business Direct-Install I P
Small Business Lighting
Irrigation Energy Efficiency Programs
Irrigation Efficiency Rewards I/P I I/P I/P P/O I/P P
Demand-Response Programs
A/C Cool Credit O I/P O O O I O I O o I I I O P O
Flex Peak Program I/P O O 1 O O 1 1/0 O O o O 1/0 1/0 P/O O
Irrigation Peak Rewards O I/P O 1 O O 1 1/0 O O O O O 1/0 O O O
Energv efFciencv programs evaluated in 2015 have since been eliminated or combined into another program.
Evaluation Type: I=Impact,P=Process,O=Other
Program not yet inexistence
Exhibit No. 3
Case No. IPC-E-25-12
Q. Nesbitt, IPC
Page 1 of 1