20230315 2022 DSM Supplement 1.pdf

MARCH 15 2023
SUPPLEMENT 1: COST-EFFECTIVENESS
2022ANNUAL REPORTANNUAL REPORT
DEMAND-SIDE MANAGEMENT
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Page i Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Table of Contents
Supplement 1: Cost-Effectiveness ..............................................................................................................1
Cost-Effectiveness .................................................................................................................................1
Methodology ........................................................................................................................................2
Assumptions .........................................................................................................................................3
Conservation Adder ..............................................................................................................................5
Net-to-Gross .........................................................................................................................................6
Results ..................................................................................................................................................6
Cost-Effectiveness Tables by Program ......................................................................................................15
Educational Distributions ...................................................................................................................15
Energy Efficient Lighting .....................................................................................................................17
Energy House Calls .............................................................................................................................20
Heating & Cooling Efficiency Program ................................................................................................22
Home Energy Report ..........................................................................................................................25
Multifamily Energy Savings Program ..................................................................................................26
Rebate Advantage ..............................................................................................................................29
Residential New Construction Program ..............................................................................................31
Shade Tree Project ..............................................................................................................................33
Weatherization Assistance for Qualified Customers ..........................................................................34
Weatherization Solutions for Eligible Customers ...............................................................................35
Commercial Energy-Saving Kits ..........................................................................................................36
Custom Projects..................................................................................................................................38
New Construction ...............................................................................................................................41
Retrofits .............................................................................................................................................46
Small Business Direct Install ...............................................................................................................54
Irrigation Efficiency Rewards ..............................................................................................................55
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Supplement 1: Cost-Effectiveness
List of Tables
Table 1. 2022 non-cost-effective measures ................................................................................................8
Table 2. 2022 DSM detailed expenses by program (dollars) .....................................................................10
Table 3. 2022 Demand response program and portfolio $ per kW year .................................................13
Table 4. Cost-effectiveness of 2022 programs by benefit/cost test ..........................................................14
Page 1 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Supplement 1: Cost-Effectiveness
Cost-Effectiveness
Idaho Power considers cost-effectiveness of primary importance in the design, implementation,
and tracking of energy efficiency and demand response programs.
Prior to the actual implementation of energy efficiency or demand response programs, Idaho Power
performs a preliminary analysis to assess whether a potential program design or measure may be cost-
effective. Incorporated in the analysis are inputs from various sources that use the most current and
reliable information available. When possible, Idaho Power leverages the experiences of other utilities
in the region and/or throughout the country to help identify specific program parameters. This is
accomplished through discussions with other utilities’ program managers and researchers. Idaho Power
also uses electric industry research organizations, such as E Source, Northwest Energy Efficiency
Alliance (NEEA) Regional Emerging Technology Advisory Committee (RETAC), the Consortium for Energy
Efficiency (CEE), American Council for an Energy-Efficient Economy (ACEEE), and Advanced Load Control
Alliance (ALCA) to identify similar programs and their results. Additionally, Idaho Power relies on the
results of program impact evaluations and recommendations from consultants.
Idaho Power’s goal is for all programs to have benefit/cost (B/C) ratios greater than one for the utility
cost test (UCT) in Idaho, and the total resource cost (TRC) test in Oregon, at the program and measure
level. In addition, Idaho Power looks at both the UCT and TRC, as well as the participant cost test (PCT)
at the program and measure level, where appropriate. Each cost-effectiveness test provides a different
perspective, and Idaho Power believes each test provides value when evaluating program performance.
In 2020, Idaho Power transitioned to the UCT as the primary cost-effectiveness test in Idaho as directed
by the Idaho Public Utilities Commission (IPUC) in Order Nos. 34469 and 34503. The company will
continue calculating the TRC and PCT because each perspective can help inform the company and
stakeholders about the effectiveness of a particular program or measure. Additionally, programs and
measures offered in Oregon must still use the TRC as the primary cost-effectiveness test as directed by
the Public Utility Commission of Oregon (OPUC) in Order No. 94-590.
Idaho Power uses several assumptions when calculating the cost-effectiveness of a given program
or measure. For some measures within the programs, savings can vary based on factors, such as
participation levels or the participants’ locations. For instance, heat pumps installed in the Boise
area will have lower savings than those installed in the McCall area because of climate differences.
If program participation and savings increase, fixed costs (such as labor and marketing) are distributed
more broadly, and the program’s cost-effectiveness increases.
When an existing program or measure is not cost-effective from either the UCT perspective in Idaho or
the TRC perspective in Oregon, Idaho Power works with the Energy Efficiency Advisory Group (EEAG) to
get additional input about next steps. The company demonstrates why the non-cost-effective measures
or programs are implemented, or continued to be offered, and communicates the steps the company
plans to take to improve its cost-effectiveness. This aligns with the expectations of the IPUC and OPUC.
Page 2 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
In OPUC Order No. 94-590, issued in UM 551, the OPUC outlines specific cost-effectiveness guidelines
for energy efficiency measures and programs managed by program administrators. It is the expectation
of the OPUC that measures and programs offered in Oregon pass the TRC test. If Idaho Power
determines a program or measure is not cost-effective but meets one or more of the exceptions set
forth by Order No. 94-590, the company files an exceptions request with the OPUC to continue offering
the measure or program within its Oregon service area.
Non-cost-effective measures and programs may be offered by a utility if they meet one or more of the
following additional conditions specified by Section 13 of OPUC Order No. 94-590:
A. The measure produces significant non-quantifiable non-energy benefits (NEB)
B. Inclusion of the measure will increase market acceptance and is expected to lead to reduced
cost of the measure
C. The measure is included for consistency with other demand-side management (DSM)
programs in the region
D. Inclusion of the measure helps increase participation in a cost-effective program
E. The package of measures cannot be changed frequently, and the measure will be cost-
effective during the period the program is offered
F. The measure or package of measures is included in a pilot or research project intended to be
offered to a limited number of customers
G. The measure is required by law or is consistent with OPUC policy and/or direction
For operational and administrative efficiency, Idaho Power endeavors to offer identical programs in
both its Oregon and Idaho jurisdictions; however, due to the different primary cost-effectiveness tests
in each state, measures may not be offered in both states.
Methodology
For its cost-effectiveness methodology, Idaho Power relies on the Electric Power Research Institute
(EPRI) End Use Technical Assessment Guide (TAG); the California Standard Practice Manual and its
subsequent addendum; the National Action Plan for Energy Efficiency’s (NAPEE) Understanding Cost
Effectiveness of Energy Efficiency Programs: Best Practices, Technical Methods, and Emerging Issues for
Policy-Makers.
For energy efficiency programs, each program’s cost-effectiveness is reviewed annually from a one-
year perspective. The annual energy-savings benefit value is summed over the life of the measure or
program and is discounted to reflect 2022 dollars. The result of the one-year perspective is shown in
Table 4 and the Cost-Effectiveness Tables by Program section in this supplement.
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Supplement 1: Cost-Effectiveness
The goal of demand response programs is to minimize or delay the need to build new supply-side
resources. Unlike energy efficiency programs or supply-side resources, demand response programs
must acquire and retain participants each year to maintain deployable demand-reduction capacity for
the company.
Idaho Power determines cost-effectiveness for its demand response programs using the approved
method for valuing demand response under IPUC case IPC-E-21-32 (Order No. 35336) and OPUC Docket
No. ADV 1355. The avoided cost calculation for demand response programs is as follows:
(Levelized Fixed Costs – Additional Benefits) x Effective Load Carrying Capacity of Annual DR Capacity
Compared to Proxy Resource = $ per kW year DR Avoided Costs
Each of the three components have been updated:
1. From the 2021 IRP, the 2022 levelized fixed cost value of a Simple Cycle Combustion Turbine
(SCCT) was determined to be $131.60 per kW per year.
2. From the 2021 IRP, to determine the additional ancillary benefits provided by the SCCT
compared to DR, an analysis was performed where DR was replaced with an equivalent SCCT
and the fixed costs of the SCCT were removed from the model. The result of this analysis
showed there were no additional benefits associated with the SCCT because the cost of the fuel
and SCCT plant O&M required to meet the DR demand.
3. The updated ELCC of approximately 312 MW of DR capacity compared to a SCCT utilizing
2021 IRP assumptions is 63%.
This results in a value of $82.91 per kW year as the avoided cost threshold that the existing DR
programs need to be under to be considered cost effective. A summary of the dollar per kW year for
each DR program can be found in Table 3.
Assumptions
Idaho Power relies on third-party research to obtain savings and cost assumptions for various
measures. These assumptions are routinely reviewed internally and with EEAG and updated as
new information becomes available. For many of the residential and irrigation measures within this
supplement, savings and costs were derived from either the Regional Technical Forum (RTF) or the
Idaho Power Energy Efficiency Potential Study conducted by Applied Energy Group (AEG).
The RTF regularly reviews, evaluates, and recommends eligible energy efficiency measures and provides
the estimated savings and costs associated with those measures. As the RTF updates these savings and
cost assumptions, Idaho Power applies them to current program offerings and assesses the need to
make any program changes. Idaho Power staff participates in the RTF by attending monthly meetings
and contributing to various sub-committees. Because cost data from the RTF information is in 2012
dollars, measures with costs from the RTF are escalated to 2022 dollars. The costs are escalated by
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Supplement 1: Cost-Effectiveness
17.0%, which is the percentage provided by the RTF in workbook RTFStandardInformationWorkbook_
v4_7.xlsx.
Idaho Power uses a technical reference manual (TRM) developed by ADM Associates, Inc. for the
savings and cost assumptions in the Commercial and Industrial (C&I) Energy Efficiency Program’s New
Construction and Retrofits options. In 2020, the company began the process to update the assumptions
in the TRM based on the 2018 International Energy Conservation Code (IECC). The updated TRM is
the source for most prescriptive savings values for the New Construction and Retrofits options in the
C&I Energy Efficiency program and have been implemented as of mid-2021.
Idaho Power also relies on other sources for savings and cost assumptions, such as the Northwest
Power and Conservation Council (NWPCC), Northwest Energy Efficiency Alliance (NEEA), the Database
for Energy Efficiency Resources (DEER), the Energy Trust of Oregon (ETO), the Bonneville Power
Administration (BPA), third-party consultants, and other regional utilities. Occasionally, Idaho Power
will also use internal engineering estimates and calculations for savings and costs based on information
gathered from previous projects.
The company freezes savings assumptions when the budgets and goals are established for the next
calendar year unless a code changes, a standard changes, or program updates necessitate a need to
use updated savings. These assumptions are discussed in more detail in the cost-effectiveness sections
for each program in the Demand-Side Management 2022 Annual Report. Generally, the 2022 energy
savings reported for most programs will use the assumptions set at the beginning of the year.
The remaining inputs used in the cost-effectiveness calculations are obtained from the IRP process.
Idaho Power’s 2019 Second Amended IRP was acknowledged by the IPUC under case IPC-E-19-19 on
March 16, 2021 and with the OPUC under case LC 74 on June 4, 2021. The 2019 Second Amended
IRP is the source for all financial and cost-effectives analysis for the 2022 energy efficiency programs.
As noted earlier, the 2021 IRP is used to determine the cost-effectiveness threshold for the DR
programs. Because the 2021 IRP was not acknowledged at the time of the 2022 DSM energy efficiency
program planning, Idaho Power had shared with EEAG its intent to use 2019 Second Amended IRP for
the 2022 program year and the 2021 IRP for the 2023 program year.
Appendix C—Technical Appendix of Idaho Power’s 2019 Second Amended IRP contains the financial
assumptions, such as discount rate, escalation rate and line losses, used in the cost-effectiveness
analysis. DSM avoided costs vary by season and time of day and are applied to an end-use load shape
to obtain the value of a particular measure or program. DSM avoided energy costs are based on both
the projected fuel costs of a peak-load serving resource and forward electricity prices as determined by
Idaho Power’s power supply model, AURORAxmp® Electric Market Model. The avoided capital cost of
capacity is based on a gas-fired, simple-cycle turbine. In the 2019 IRP, the annual avoided capacity cost
is $121.19 per kilowatt (kW). Transmission and distribution (T&D) benefits are also included in the cost-
effectiveness analyses. In compliance with Order No. 33365, this value is escalated and added to the
2019 DSM avoided energy costs and included in the cost-effectiveness analysis for 2022.
Page 5 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
As recommended by the NAPEE’s Understanding Cost-Effectiveness of Energy Efficiency Programs¸
Idaho Power’s weighted average cost of capital (WACC) of 7.12% is used to discount future benefits
and costs to today’s dollars. Once the DSM avoided costs and load shapes are applied to the annual
kWh savings of a measure or program, the WACC is used to calculate the net present value (NPV) of the
annual benefit for the UCT and TRC test B/C ratios. However, determining the appropriate discount rate
for participant cost and benefits is difficult because of the variety of potential discount rates that can
be used by participants. Because the participant benefit is based on the anticipated bill savings of the
customer, Idaho Power believes an alternate discount rate in place of the WACC is appropriate.
The participant bill savings are based on Idaho Power’s 2022 average customer segment rate, and are
not escalated. The participant bill savings are discounted using a real discount rate of 4.81%. The 4.81%
is based on the 2019 Second Amended IRP’s WACC of 7.12% and an escalation rate of 2.2%. The real
discount rate is used to calculate the NPV of any participant benefits or costs for the PCT or ratepayer
impact measure (RIM) B/C ratios.
The formula to calculate the real discount rate is as follows:
((1 + WACC) ÷ (1 + Escalation)) – 1 = Real
Line-loss percentages are applied to the metered-site energy savings to find the energy savings at the
generation level. The Demand-Side Management 2022 Annual Report shows the estimated electrical
savings at the customer meter level. Cost-effectiveness analyses are based on generation-level energy
savings. The demand response program reductions are reported at the generation level with the line
losses. The system line-loss factor is 9.6% while the summer peak line-loss factor is 9.7%.
Conservation Adder
The Pacific Northwest Electric Power Planning and Conservation Act (Northwest Power Act) states the
following:
…any conservation or resource shall not be treated as greater than that of
any nonconservation measure or resource unless the incremental system
cost of such conservation or resource is in excess of 110 per centum of
the incremental system cost of the nonconservation measure or resource.
As a result of the Northwest Power Act, most utilities in the Pacific Northwest add a 10% conservation
adder in energy efficiency cost-effectiveness analyses. In OPUC Order No. 94-590, the OPUC states:
We support the staff’s position that the effect of conservation in reducing
uncertainty in meeting load growth is included in the ten percent cost
adder and that no separate adjustment is necessary.
Additionally, in IPUC Order No. 32788 in Case No. GNR-E-12-01, “Staff noted that Rocky Mountain
Page 6 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Power and Avista use a 10% conservation adder when calculating the cost-effectiveness of all their DSM
programs.” Staff recommended the utilities have the option to use a 10% adder, and the IPUC agreed
with the recommendation to allow utilities to use the 10% adder in the cost-effectiveness analyses for
low-income programs.
After reviewing the practices of other utilities in the Pacific Northwest, as well as the OPUC Order
No. 94-590 and IPUC Order 32788, Idaho Power applies the 10% conservation adder in all energy
efficiency measure and program cost-effectiveness analyses when calculating the TRC test.
Net-to-Gross
Net-to-gross (NTG), or net-of-free-ridership (NTFR), is defined by NAPEE’s Understanding
Cost-Effectiveness of Energy Efficiency Programs as a ratio that does the following:
Adjusts the impacts of the programs so that they only reflect those
energy efficiency gains that are the result of the energy efficiency
program. Therefore, the NTG deducts energy savings that would have
been achieved without the efficiency program (e.g., ‘free-riders’) and
increases savings for any ‘spillover’ effect that occurs as an indirect result
of the program. Since the NTG attempts to measure what the customers
would have done in the absence of the energy efficiency program, it can
be difficult to determine precisely.
Capturing the effects of Idaho Power’s energy efficiency efforts on free-ridership and spillover is
difficult. Due to the uncertainty surrounding NTG percentages, Idaho Power used an NTG of 100% for
nearly all measure and program cost-effectiveness analyses.
Sensitivity analyses are conducted to show what the minimum NTG percentage needs to be for a
program to remain (or become) cost-effective from either the TRC or UCT perspective. These NTG
percentages are shown in the program cost-effectiveness pages of this supplement.
Results
Idaho Power calculates cost-effectiveness on a program basis and, where relevant, a measure
basis. As part of Supplement 1: Cost-Effectiveness and where applicable, Idaho Power publishes the
cost-effectiveness by measure, the PCT and RIM test at the program level, the assumptions associated
with cost-effectiveness, and the sources and dates of metrics used in the cost-effectiveness calculation.
The B/C ratio from the participant cost perspective is not calculated for the Commercial Energy-Saving
Kits, Educational Distributions, Energy House Calls, Home Energy Report Program, Multifamily Energy
Savings Program, Small Business Direct Install, Weatherization Assistance for Qualified Customers
(WAQC), and Weatherization Solutions for Eligible Customers programs. These programs have few or
no participant-related costs. For energy efficiency programs, the cost-effectiveness analyses do not
assume ongoing participant costs. However, anticipated future costs are used to develop the life-cycle
cost-effectiveness analysis for the Home Energy Report Program.
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Supplement 1: Cost-Effectiveness
This supplement contains annual cost-effectiveness metrics for each program using actual information
from 2022 and includes results of the UCT, TRC, PCT, and RIM. Current customer energy rates are used
in the calculation of the B/C ratios from a PCT and RIM perspective. Rate increases are not forecasted
or escalated. A summary of the cost-effectiveness by program can be found in Table 4.
In 2022, most of Idaho Power’s energy efficiency programs were cost-effective from the UCT
perspective, except for Energy House Calls, Heating & Cooling Efficiency, Home Energy Report Program,
Multifamily Energy Savings Program, Commercial Energy-Savings Kits, Small Business Direct Install,
and the two weatherization programs for income-qualified customers.
For 2022, the Energy House Calls program had a UCT of 0.70 and a TRC of 0.77. The Multifamily Energy
Savings Program had a UCT of 0.49 and TRC of 0.68. In 2021 and 2022, Idaho Power shared with
EEAG the cost-effectiveness challenges facing the Energy House Calls and Multifamily Energy Savings
Program. For both programs, savings associated with the measures were either declining or deactivated
by the RTF. The company reviewed the programs internally using updated avoided costs assumption
from the IRP. Due to the declining savings as well as the increasing costs associated with offering a free
service for program participants, it was determined that the programs would continue to be not cost-
effective in its current format. With the support of EEAG, the Energy House Calls program closed on
June 30, 2022 and the Multifamily Energy Saving Program closed on December 31, 2022.
Heating & Cooling Efficiency Program had a UCT of 0.98 and TRC of 0.30. The cost-effectiveness ratios
include the costs associated with the 2021 process and impact evaluation which was completed
in 2022. If the evaluation costs are removed, the UCT and TRC ratios for the program are 1.00 and
0.30, respectively. Due to the changes to federal standards for air-source heat pumps, the program
will be modified in 2023 to incorporate the updated savings assumptions, updated measures, and
recommendations from the 2021 evaluation.
The Home Energy Report Program has a UCT and TRC of 0.71 and 0.79, respectively. The main drivers
contributing to the lower cost-effectiveness ratio for current year are the relatively short measure life
of the reports and the application of the avoided costs from the 2019 Second Amended IRP. Due to the
continuous nature of the HER program with costs and savings extending numerous years for the same
participants, a program life-cycle cost-effectiveness is utilized to understand the cost-effectiveness of
the offering. The program life cost-effectiveness is calculated to have a UCT of 1.17 and TRC of 1.29.
Commercial Energy-Saving Kits (CSK) program has a UCT of 0.78 and TRC of 0.87. Small Business Direct
Install has a UCT of 0.95 and TRC of 1.50. Idaho Power shared the cost-effectiveness challenges for the
program throughout 2021 and 2022. For CSKs, the 2022 evaluation indicated that the installation rates
for the kit items were less than previously estimated. Additionally, the implementation of the Energy
Independence and Security Act (EISA) lighting standards means the company will no longer be able
to claim savings for the screw-in LED lightbulbs after June 30, 2023. For SBDI, the defined time period
for the program offering was based on when the third-party vendor would be able to complete the
work throughout the service area. With all savings from the program coming from lighting measures,
the implementation of EISA will also impact program savings going forward. Due to declining savings
opportunities and cost-effectiveness issues, the programs will be discontinued in 2023.
Page 8 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
WAQC had a TRC of 0.32 and a UCT ratio of 0.17, and Weatherization Solutions for Eligible Customers
had a TRC of 0.23 and a UCT ratio of 0.15. To calculate the cost-effectiveness for the income-qualified
weatherization programs, Idaho Power adopted the following IPUC staff recommendations from
Case No. GNR-E-12-01:
• Applied a 100% NTG.
• Claimed 100% of energy savings for each project.
• Included indirect administrative overhead costs. The overhead costs of 3.508% were calculated
from the $1,507,146 of indirect program expenses divided by the total DSM expenses of
$42,963,579 as shown in Appendix 3 of the Demand-Side Management 2022 Annual Report.
• Applied the 10% conservation preference adder.
• Amortized evaluation expenses over a three-year period.
• Claimed one dollar of NEBs for each dollar of utility and federal funds invested in health,
safety, and repair measures.
While the WAQC and Weatherization Solutions for Eligible Customers remain not cost-effective, unless
the Idaho and Oregon commission directs otherwise, Idaho Power will continue to offer the programs
to the company’s limited-income customers on an ongoing basis. Idaho Power will also continue to
consult with EEAG and the weatherization managers at the Community Action Partnerships to look for
ways to improve the cost-effectiveness of the programs.
The sector cost-effectiveness ratios include all the benefits and costs associated with programs that
produce quantifiable energy savings. The portfolio cost-effectiveness is the sum of all energy efficiency
activities, including those that do not have savings associated, such as overhead expenses. For
2022, the commercial and industrial sector had a UCT of 2.71 and TRC of 1.34, and irrigation sector
had a UCT of 2.69 and TRC of 2.54. The residential and portfolio cost-effectiveness was calculated
with and without the benefits associated with WAQC, which is funded through base rates and not
through the energy efficiency rider. While the program provides real savings to customers that would
otherwise be unable to afford to weatherize their home, it remains not cost-effective. Presenting
the cost-effectiveness of the residential sector with and without WAQC remains consistent with how
other Idaho utilities present their sector and portfolio cost-effectiveness results. Without WAQC, the
residential sector has a UCT of 1.00 and TRC of 0.76 and the portfolio has a UCT of 2.02 and TRC of
1.43. With WAQC, the residential sector has a UCT of 0.84 and TRC of 0.67 and the portfolio has a UCT
of 1.94 and TRC of 1.40.
One hundred nineteen out of 300 individual measures in various programs are not cost-effective
from either the UCT or TRC perspective. Of the 119 measures, 42 are not cost-effective from the
UCT perspective. Seventeen of those measures are associated with the two direct-install programs
that closed in 2022 due to the programs no longer being cost-effective: Energy House Calls and the
Multifamily Energy Savings Program. Four measures that failed the UCT are associated with the
Commercial Energy-Savings Program that will close in 2023. Of the remaining 21 measures that failed
the UCT, 15 are expected to be cost-effective in 2023 with the application of the 2021 IRP avoided costs.
Page 9 Demand-Side Management 2022 Annual Report
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Of the remaining 6 non-cost-effective measures within the Heating & Cooling Efficiency and Retrofits
programs, they will be monitored and potentially modified in 2023.
For most of the measures offered in Oregon that fail the TRC, Idaho Power filed cost-effectiveness
exception requests with the OPUC in compliance with Order No. 94-590. Measures and programs
that do not pass these tests may be offered by the utility if they meet one or more of the additional
conditions specified by Section 13 of Order No. 94-590. These exception requests were approved under
UM-1710 or with the specific program advice filings. The filings and exception requests are noted in
Table 1.
Table 1. 2022 non-cost-effective measures
Program Number of Measures Number Fail UCT Notes
Energy House Calls 6 6 Offering closed in 2022 due to cost-effectiveness.
Heating & Cooling
Efficiency
11 5 Program to be modified in 2023 to incorporate updated savings assumptions due
to updated federal standards and recommendations from the 2021 evaluation.
Cost-effectiveness exception request for ductless heat pump and open-loop water
source heat pumps filed with the OPUC under UM-1710. OPUC Order No. 94-590, Section 13. Approved under Order No. 15-200. Exception request for the program and smart thermostats requested and approved with OPUC Advice No. 17-09.
Multifamily Energy
Savings Program
11 11 Offering closed in 2022 due to cost-effectiveness.
Rebate Advantage 10 0 All measures pass UCT. One measure would be cost-effective with a TRC 1.11 without the inclusion of administration costs. Meets OPUC Order No. 94-590, Section 10. Exception request for the program requested and approved with UM-1710, Order
No. 21-079.
Residential New
Construction
2 0 All measures pass UCT. Idaho only program.
Commercial Energy-Savings Kits 4 4 Three kit configurations carried over from 2021 to 2022 from inventory. Single kit configuration offered in 2022. Will monitor in-service rates to update savings.
Offering to close in 2023 due to cost-effectiveness.
Custom Projects 3 2 One measure passes UCT and fails TRC. Would be cost-effective with a TRC of 1.02 without the inclusion of administration costs. Meets OPUC Order No. 94-590,
Section 10. Two Cohort offering fail UCT and TRC but would be cost-effective without
administration costs. Measures expected to be cost-effective in 2023 with the
application of the 2021 IRP avoided costs.
New Construction and Retrofits 3 0 All measures pass UCT. Offered in Idaho only. One measure would be cost-effective with a TRC of 1.03 without inclusion of administration cost.
New Construction 20 6 Fourteen measures pass UCT and fail TRC. Offered in Idaho only. Six measures fail UCT with ratios of between 0.82 and 0.97. Measures expected to be cost-effective in 2023 with the application of the 2021 IRP avoided costs.
Retrofits 45 4 Forty-one measures pass UCT and fail TRC. Of those, thirty-six are offered in Idaho
only. Of the five measures that are offered in Idaho and Oregon, five measures
pass the TRC without the inclusion of admin costs. Meets OPUC Order No. 94-590, Section 10. Of the four measures that fail UCT, three measures expected to be cost-effective in 2023 with the application of the 2021 IRP avoided costs.
The remaining non-cost-effective measure that fails both UCT and TRC to be modified
or removed from the program in 2023.
Irrigation Efficiency Rewards 4 4 Four measures fail UCT but pass TRC. Measures expected to be cost-effective in 2023 with the application of the 2021 IRP avoided costs.
Total 119 42
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The following tables list the annual program cost-effectiveness results including measure-level
cost-effectiveness. Exceptions to the measure-level tables are programs that are analyzed at the project
level, such as the Custom Projects option of the C&I Energy Efficiency Program, the Custom Incentive
option of Irrigation Efficiency Rewards, Small Business Direct Install, WAQC, and Weatherization
Solutions for Eligible Customers.
The measure-level cost-effectiveness includes the following inputs: measure life, energy savings,
incremental cost, incentives, program administration cost, and non-energy impacts/benefits.
Program administration costs include all non-incentive costs such as: labor, marketing, training,
education, purchased services, and evaluation. Energy and expense data have been rounded to the
nearest whole unit.
2022 DSM Detailed Expenses by Program
Included in this supplement is a detailed breakout of program expenses shown in Appendix 2 of the
Demand-Side Management 2022 Annual Report. These expenses are broken out by funding source
and major-expense type (labor/administration, materials, other expenses, purchased services,
and incentives).
Table 2. 2022 DSM detailed expenses by program (dollars)
Sector/Program Idaho Rider Oregon Rider Idaho Power Total Program
Energy Efficiency Total $ 23,734,918 $ 473,587 $ 1,502,028 $ 25,710,533
Residential Total 4,144,232 103,384 1,443,223 5,690,839
Easy Savings: Low-Income Energy Efficiency Education ...––, 152,718 152,718
Labor/Administrative Expense.....................................–– 27,694 27,694
Materials and Equipment ............................................–– 125,000 125,000
Other Expense .............................................................–– 24 24
Educational Distributions ................................................. 1,061,898 24,866 49 1,086,813
Labor/Administrative Expense..................................... 14,681 786 49 15,516
Materials and Equipment ............................................ 885,521 19,746 – 905,268
Purchased Services ...................................................... 161,696 4,333 – 166,029
Energy Efficient Lighting ................................................... 505,430 29,475 76 534,982
Incentives .................................................................... 271,966 16,346 – 288,312
Labor/Administrative Expense..................................... 26,172 1,389 76 27,637
Other Expense ............................................................. 32 2 – 34
Purchased Services ...................................................... 207,260 11,740 – 218,999
Energy House Calls ............................................................ 36,734 1,378 51 38,163
Labor/Administrative Expense..................................... 15,328 815 51 16,193
Materials and Equipment ............................................ (2,209) (116)– (2,326)
Other Expense ............................................................. 598 31 – 629
Purchased Services ...................................................... 23,018 648 – 23,666
Heating & Cooling Efficiency Program .............................. 636,597 28,960 459 666,016
Incentives .................................................................... 351,586 17,425 – 369,011
Labor/Administrative Expense..................................... 138,470 7,312 459 146,241
Materials and Equipment ............................................– (3,150)– (3,150)
Page 11 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Sector/Program Idaho Rider Oregon Rider Idaho Power Total Program
Other Expense ............................................................. 42,620 2,243 – 44,863
Purchased Services ...................................................... 103,922 5,130 – 109,052
Home Energy Audit ........................................................... 184,650 – 208 184,858
Labor/Administrative Expense..................................... 62,825 – 208 63,034
Materials and Equipment ............................................ 9,141 –– 9,141
Other Expense ............................................................. 5,328 –– 5,328
Purchased Services ...................................................... 107,356 –– 107,356
Home Energy Report Program 964,709 –82 964,791
Incentives .................................................................... 911,702 –– 911,702
Labor/Administrative Expense..................................... 24,607 –82 24,688
Other Expense ............................................................. 28,400 –– 28,400
Multifamily Energy Savings Program ............................... 32,634 1,474 72 34,181
Labor/Administrative Expense..................................... 22,592 1,194 72 23,858
Materials and Equipment ............................................ 1,168 –– 1,168
Purchased Services ...................................................... 8,875 280 – 9,155
Oregon Residential Weatherization .................................– 8,825 – 8,825
Labor/Administrative Expense.....................................– 5,597 – 5,597
Other Expense .............................................................– 1,773 – 1,773
Purchased Services ......................................................– 1,456 – 1,456
Rebate Advantage ............................................................. 157,746 9,762 115 167,622
Incentives .................................................................... 91,000 6,000 – 97,000
Labor/Administrative Expense..................................... 34,792 1,838 115 36,745
Other Expense ............................................................. 13,754 724 – 14,478
Purchased Services ...................................................... 18,200 1,200 – 19,400
Residential New Construction Program ........................... 236,962 (1,356)126 235,732
Incentives .................................................................... 170,400 –– 170,400
Labor/Administrative Expense..................................... 43,724 –126 43,850
Other Expense ............................................................. 17,337 (1,356)– 15,982
Purchased Services ...................................................... 5,500 – 5,500
Shade Tree Project ............................................................ 128,673 – 183 128,856
Labor/Administrative Expense..................................... 56,955 – 183 57,138
Materials and Equipment ............................................ 24 – – 24
Other Expense ............................................................. 438 – – 438
Purchased Services ...................................................... 71,256 – – 71,256
Weatherization Assistance for Qualified Customers ............. – – 1,281,495 1,281,495
Labor/Administrative Expense..................................... – – 68,171 68,171
Other Expense ............................................................. – – 46 46
Purchased Services ...................................................... – – 1,213,278 1,213,278
Weatherization Solutions for Eligible Customers............. 198,198 – 7,590 205,788
Labor/Administrative Expense..................................... 102 – 7,590 7,691
Other Expense ............................................................. 4 – – 4
Purchased Services ...................................................... 198,092 – – 198,092
Commercial/Industrial Total 17,640,565 295,462 3,521 17,939,548
Commercial Energy-Saving Kits ........................................ 21,604 1,140 25 22,770
Labor/Administrative Expense..................................... 7,658 423 25 8,106
Materials and Equipment ............................................ 935 – – 935
Other Expense ............................................................. – – – –
Purchased Services ...................................................... 13,011 717 – 13,729
Custom Projects ................................................................ 8,753,084 164,248 2,595 8,919,927
Incentives .................................................................... 6,921,878 86,520 – 7,008,398
Labor/Administrative Expense..................................... 410,241 21,671 2,595 434,507
Page 12 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Sector/Program Idaho Rider Oregon Rider Idaho Power Total Program
Materials and Equipment ............................................ 88 5 – 93
Other Expense ............................................................. 349,938 15,492 – 365,430
Purchased Services ...................................................... 1,070,937 40,560 – 1,111,498
New Construction ............................................................. 2,762,412 17,582 513 2,780,507
Incentives .................................................................... 2,338,442 50 – 2,338,492
Labor/Administrative Expense..................................... 159,690 8,471 513 168,674
Other Expense ............................................................. 51,979 2,736 – 54,715
Purchased Services ...................................................... 212,301 6,325 – 218,626
Retrofits ............................................................................ 4,785,645 84,933 337 4,870,916
Incentives .................................................................... 4,067,431 46,763 – 4,114,194
Labor/Administrative Expense..................................... 102,223 5,432 337 107,992
Materials and Equipment ............................................ 1,000 – 1,000
Other Expense ............................................................. 56,099 2,953 – 59,052
Purchased Services ...................................................... 558,891 29,786 – 588,677
Small Business Direct Install ............................................. 1,317,820 27,558 51 1,345,429
Labor/Administrative Expense..................................... 15,649 853 51 16,552
Other Expense ............................................................. 4,322 228 – 4,550
Purchased Services ...................................................... 1,297,849 26,478 – 1,324,327
Irrigation Total 1,950,122 74,622 55,284 2,080,027
Irrigation Efficiency Rewards ............................................ 1,950,122 74,622 55,284 2,080,027
Incentives .................................................................... 1,612,826 56,718 – 1,669,543
Labor/Administrative Expense..................................... 303,517 16,150 55,284 374,951
Materials and Equipment ............................................ 1,824 96 – 1,920
Other Expense ............................................................. 30,685 1,610 – 32,295
Purchased Services ...................................................... 1,270 48 – 1,318
Market Transformation Total 2,650,440 139,497 – 2,789,937
NEAA ................................................................................. 2,650,440 139,497 – 2,789,937
Purchased Services ...................................................... 2,650,440 139,497 – 2,789,937
Other Program and Activities Total $ 2,939,309 $ 158,556 $ 5,689 $ 3,103,434
Commercial/Industrial Energy Efficiency Overhead ............. 826,911 44,184 2,383 873,477
Labor/Administrative Expense..................................... 702,043 37,612 2,256 741,911
Other Expense ............................................................. 96,907 5,100 127 102,134
Purchased Services ...................................................... 27,961 1,472 – 29,432
Energy Efficiency Direct Program Overhead .................... 296,204 15,653 895 312,752
Labor/Administrative Expense..................................... 280,253 14,813 895 295,961
Other Expense ............................................................. 15,951 839 – 16,791
Oregon Commercial Audit ................................................... – 7,493 – 7,493
Labor/Administrative Expense..................................... – 822 – 822
Other Expense ............................................................. – 171 – 171
Purchased Services ...................................................... – 6,500 – 6,500
Residential Energy Efficiency Education Initiative ................ 287,839 10,654 1,682 300,175
Labor/Administrative Expense..................................... 98,201 5,187 1,682 105,071
Materials and Equipment ............................................ 33,758 420 – 34,178
Other Expense ............................................................. 69,976 3,470 – 73,446
Purchased Services ...................................................... 85,904 1,576 – 87,481
Residential Energy Efficiency Overhead ........................... 1,528,355 80,573 728 1,609,656
Labor/Administrative Expense..................................... 243,680 12,889 728 257,298
Materials and Equipment ............................................–119 –119
Page 13 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Sector/Program Idaho Rider Oregon Rider Idaho Power Total Program
Other Expense ............................................................. 926,655 48,721 – 975,376
Purchased Services ...................................................... 358,020 18,843 – 376,863
Indirect Program Expenses Total $ 1,265,112 $ 66,148 $ 175,886 $ 1,507,146
Energy Efficiency Accounting and Analysis ...................... 1,236,470 64,628 175,865 1,476,963
Labor/Administrative Expense..................................... 455,807 24,135 167,947 647,888
Materials and Equipment ............................................––––
Other Expense ............................................................. 83,502 4,395 7,919 95,816
Purchased Services ...................................................... 697,161 36,098 – 733,259
Energy Efficiency Advisory Group ..................................... 15,575 826 20 16,421
Labor/Administrative Expense..................................... 6,151 330 20 6,501
Other Expense ............................................................. 9,424 496 – 9,920
Special Accounting Entries ............................................... 13,068 694 – 13,762
Special Accounting Entry ............................................. 13,068 694 – 13,762
Demand Response Total $ 1,083,772 $ 447,809 $ 8,320,948 $ 9,852,529
Residential Total 429,722 24,491 375,558 829,771
A/C Cool Credit ................................................................. 429,722 24,491 375,558 829,771
Incentives ....................................................................– 4,314 375,320 379,634
Labor/Administrative Expense..................................... 76,735 4,079 239 81,052
Materials and Equipment ............................................ (88,605) (4,663)– (93,268)
Other Expense ............................................................. 67,953 1,577 – 69,529
Purchased Services ...................................................... 373,640 19,185 – 392,825
Commercial/Industrial Total 84,582 151,148 283,888 519,618
Flex Peak Program ............................................................ 84,582 151,148 283,888 519,618
Incentives ....................................................................– 146,671 283,888 430,322
Labor/Administrative Expense..................................... 75,959 4,023 237 80,219
Other Expense ............................................................. 8,624 454 – 9,077
Irrigation Total 569,467 272,171 7,661,502 8,503,140
Irrigation Peak Rewards ................................................... 569,467 272,171 7,661,502 8,503,140
Incentives ....................................................................– 243,613 7,652,357 7,895,971
Labor/Administrative Expense..................................... 114,745 6,103 9,145 129,993
Materials and Equipment ............................................ 111,489 5,868 – 117,356
Other Expense ............................................................. 45,867 2,412 – 48,279
Purchased Services ...................................................... 297,367 14,175 – 311,542
Grand Total $ 31,673,550 $ 1,285,478 $ 10,004,551 $ 42,963,579
Note: Total does not sum due to rounding.
Table 3. 2022 Demand response program and portfolio $ per kW year
Program Max Demand Capacity (MW)Max Demand Capacity (kW)2022 Expenses 2022 Estimated Max Expenses (60 Hours)1 $ per kW year2
A/C Cool Credit 26.8 26,778 $829,771 $829,771 $30.99
Flex Peak Programs 30.0 30,000 $519,618 $700,200 $23.34
Irrigation Peak Rewards 255.6 255,610 $8,503,140 $10,471,121 $40.97
Total Demand Response Portfolio 312.4 312,388 $9,852,529 $12,001,093 $38.42
1 2022 expenses with estimated variable payments based on maximum 60 hours of operation. Total does not sum due to rounding.2 $ per kW year = 2022 Estimated Max Expenses 60 Hours/Max Demand Capacity kW.
Page 14 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Table 4. Cost-effectiveness of 2022 programs by benefit/cost test
Program/Sector UCT TRC RIM PCT
Educational Distributions ..................................................................... 1.31 1.62 0.38 n/a
Energy Efficient Lighting ....................................................................... 1.68 1.52 0.41 4.35
Energy House Calls1 .............................................................................. 0.70 0.77 0.27 n/a
Heating & Cooling Efficiency Program .................................................. 0.98 0.30 0.34 0.76
Home Energy Report Program2 ............................................................ 0.71 0.79 0.25 n/a
Multifamily Energy Savings Program3 ................................................... 0.49 0.68 0.25 n/a
Rebate Advantage ................................................................................ 1.18 0.54 0.34 1.56
Residential New Construction Program ................................................ 1.45 0.84 0.41 1.70
Shade Tree Project ................................................................................ 1.02 1.21 0.47 n/a
Weatherization Assistance for Qualified Customers ............................ 0.17 0.32 0.13 n/a
Weatherization Solutions for Eligible Customers ................................. 0.15 0.23 0.11 n/a
Residential Energy Efficiency Sector4................................................... 1.00 0.76 0.34 2.89
Commercial and Industrial Energy Efficiency Program
Custom Projects .............................................................................2.88 1.12 0.88 1.17
New Construction ..........................................................................4.25 3.64 0.68 5.41
Retrofits .........................................................................................2.01 1.11 0.57 1.61
Commercial Energy-Saving Kits ............................................................0.78 0.87 0.39 n/a
Small Business Direct Install .................................................................0.95 1.50 0.43 n/a
Commercial/Industrial Energy Efficiency Sector5 ................................ 2.71 1.34 0.73 1.71
Irrigation Efficiency Rewards ................................................................ 2.69 2.54 0.79 2.66
Irrigation Energy Efficiency Sector6...................................................... 2.69 2.54 0.79 2.66
Energy Efficiency Portfolio7 .................................................................. 2.02 1.43 0.64 2.01
1 Program closed June 30, 2022.
2 Cost-effectiveness based on 2022 savings and expenses. Cost-effectiveness ratios also calculated for the program life-cycle. Program life-cycle UCT and TRC 1.17 and 1.29, respectively.
3 Program closed December 31, 2022.
4 Residential sector cost-effectiveness excludes WAQC benefits and costs. If included, the UCT, TRC, RIM, and PCT would be 0.84, 0.67, 0.32, and 2.56, respectively.
5 Commercial/Industrial Energy Efficiency Sector cost-effectiveness ratios include savings and participant costs from Green Motors Rewinds.
6 Irrigation Energy Efficiency Sector cost-effectiveness ratios include savings and participant costs from Green Motors Rewinds.
7 Portfolio cost-effectiveness excludes WAQC benefits and costs. If included, the UCT ,TRC, RIM, and PCT would be 1.94, 1.40, 0.63, and 2.00, respectively.
Page 15 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Cost-Effectiveness Tables by Program
Educational Distributions
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ....................................................$1,427,833 $1,086,813 1.31
TRC Test ..................................................1,761,503 1,086,813 1.62
RIM Test ..................................................1,427,833 $3,732,444 0.38
PCT ........................................................ N/A N/A N/A
Cost Inputs Ref
Program Administration ....................................................................................$ 1,086,813
Program Incentives ............................................................................................–I
Total UC .............................................................................................................$1,086,813 P
Measure Equipment and Installation (Incremental Participant Cost) ...............$–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ..................................3,741,954
NPV Cumulative Energy (kWh) ......................................31,617,824 $ 1,427,833 S
10% Credit (Northwest Power Act) ................................142,783
Total Electric Savings ...........................................................$ 1,570,616 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ........................$2,645,631 B
Other Benefits
Non-Utility Rebates/Incentives........................................$–NUI
NEBs ................................................................................$190,886 NEB
Benefits and Costs Included in Each Test
UC Test .......................................................= S * NTG = P
TRC Test .....................................................= (A + NUI + NEB) * NTG = P
RIM Test .....................................................= S * NTG = P + (B * NTG)
PCT ............................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................76%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Notes: Energy savings as reported by Tinker for the 2021–2022 student kits. NEBs for welcome kit lightbulb, and student kits include PV of periodic lightbulb replacement costs. NEBs for student kit include the NPV of therm savings.
No participant costs.
Page 16 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Student Energy Efficiency Kit
(SEEK) Program
2021–2022 kit offering. Kits include:
high-efficiency showerhead, showertimer, 3 LEDs, FilterTone alarm, digital thermometer, LED
nightlight.
No kit Kit IPC_Student Kits 10 186.53 $75.91 $14.87 –– $0.262 1.55 2.01 1
Welcome Kit (Lightbulb only
kit)
Four 1,050 to 1,489 lumen general purpose
lightbulbs; Two LED night lights
No kit Kit IPC_Welcome Kit 10 43.16 $15.06 $0.30 – – $0.348 1.00 1.12 2, 3
Nightlight
Give away
LED night light baseline
lightbulb
Lamp ResLightingExterior 8 12.00 $3.76 – – – $0.140 2.24 2.46 3
a Average measure life.b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended Integrated Resource Plan. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act
d No participant costs.e Average program administration and overhead costs to achieve each kWh of savings for each initiative. Calculated from 2022 actuals.f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 Tinker. Idaho Power Student Energy Efficiency Kit Program. School Year 2021–2022 Annual Report. 2022.
2 RTF. ResLighting_Lightbulbs_v9_4.xlsm. 2021.3 DNV GL. Idaho Power Educational Distributions Impact and Process Evaluation. 2020.
Year: 2022 Program: Educational Distributions Market Segment: Residential Program Type: Energy Efficiency
Page 17 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Energy Efficient Lighting
Segment: Residential2022 Program Results
Cost Inputs Ref
Program Administration ....................................................................................$246,670
Program Incentives ............................................................................................288,312 I
Total UC .............................................................................................................$534,982 P
Measure Equipment and Installation (Incremental Participant Cost)$467,775 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) .................................1,728,352
NPV Cumulative Energy (kWh) .....................................18,918,527 $896,324 S
10% Credit (Northwest Power Act) ...............................89,632
Total Electric Savings ..........................................................$985,956 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings .......................$1,648,451 B
Other Benefits
Non-Utility Rebates/Incentives......................................$–NUI
NEBs .............................................................................$98,589 NEB
Benefits and Costs Included in Each Test
UC Test .......................................................= S * NTG = P
TRC Test .....................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test .....................................................= S * NTG = P + (B * NTG)
PCT ............................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................60%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Note: NEBs include PV of periodic lightbulb replacement costs.
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ...........................................................$896,324 $534,982 1.68
TRC Test .........................................................1,084,546 714,445 1.52
RIM Test .........................................................896,324 2,183,433 0.41
PCT ................................................................2,035,352 467,775 4.35
Page 18 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
Unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Alternate
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e UCT Ratiof TRC Ratiog
Source/
Notes
Decorative and Mini-Base Retail_LED_Decorative and Mini-Base_250 to 1049 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 4.67 $2.42 $0.31 – $1.00 $0.143 1.45 1.78 1
Globe Retail_LED_Globe_250 to 1049 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 3.49 $1.81 $0.32 – $0.50 $0.143 1.81 2.31 1
General
Purpose, Dimmable, and Three-Way
Retail_LED_General Purpose,
Dimmable, and Three-Way_1050 to 1489 lumens
Baseline
lightbulb
Fixture Res Lighting Interior
and Exterior
13 7.17 $3.72 $0.27 – $1.00 $0.143 1.84 2.15 1
General Purpose, Dimmable, and Three-Way
Retail_LED_General Purpose, Dimmable, and Three-Way_1490 to 2600 lumens
Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 6.60 $3.42 $0.27 – $1.00 $0.143 1.76 2.08 1
General Purpose, Dimmable, and Three-Way
Retail_LED_General Purpose, Dimmable, and Three-Way_250 to 1049 lumens
Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 4.50 $2.33 $0.25 – $0.50 $0.143 2.04 2.46 1
Reflectors and Outdoor Retail_LED_Reflectors and Outdoor_1050 to 1489 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 4.14 $2.14 $0.26 – $1.00 $0.143 1.35 1.65 1
Reflectors and
Outdoor
Retail_LED_Reflectors and
Outdoor_1490 to 2600 lumens
Baseline
lightbulb
Fixture Res Lighting Interior
and Exterior
13 8.84 $4.59 $0.32 – $2.00 $0.143 1.40 1.64 1
Reflectors and Outdoor Retail_LED_Reflectors and Outdoor_250 to 1049 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 4.65 $2.41 $0.33 – $1.00 $0.143 1.45 1.79 1
LED Fixture Retailer Retail_Bathroom Vanity_1000 to 1999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 5.35 $3.89 $0.13 – $1.00 $0.143 2.20 2.50 2
LED Fixture Retailer Retail_Bathroom Vanity_2000 to 3999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 10.42 $7.57 $0.41 – $2.00 $0.143 2.17 2.50 2
LED Fixture Retailer Retail_Ceiling and Wall Flush Mount _500 to 999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 3.33 $2.42 $0.13 – $0.50 $0.143 2.48 2.86 2
LED Fixture Retailer Retail_Ceiling and Wall Flush Mount _1000 to 1999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 6.13 $4.45 $0.13 – $1.00 $0.143 2.37 2.68 2
LED Fixture Retailer Retail_Ceiling and Wall Flush Mount _2000 to 3999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 11.93 $8.67 $0.54 – $2.00 $0.143 2.34 2.72 2
LED Fixture Retailer Ceiling and Wall Flush Mount _4000 to 7999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 22.35 $16.24 $0.80 – $3.00 $0.143 2.62 3.01 2
LED Fixture Retailer Retail_Downlight Fixture_500 to 999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 2.13 $1.55 $0.13 – $1.00 $0.143 1.19 1.40 2
LED Fixture Retailer Retail_Downlight Fixture_1000 to 1999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 3.91 $2.84 $0.54 – $1.00 $0.143 1.82 2.35 2
LED Fixture Retailer Retail_Downlight Fixture_2000 to 3999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 7.62 $5.54 $0.80 – $1.00 $0.143 2.65 3.30 2
LED Fixture
Retailer
Retail_Exterior Porch_500 to
999 lumens
Baseline
fixture
Fixture Res Lighting Exterior 20 3.38 $2.41 $0.01 – $0.75 $0.143 1.95 2.16 2
LED Fixture Retailer Retail_Exterior Porch_1000 to 1999 lumens Baseline fixture Fixture Res Lighting Exterior 20 6.22 $4.43 $0.26 – $1.00 $0.143 2.35 2.72 2
Year: 2022 Program: Energy Efficient Lighting Market Segment: Residential Program Type: Energy Efficiency
Page 19 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Alternate Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
LED Fixture Retailer Retail_Exterior Porch_2000 to 3999 lumens Baseline fixture Fixture Res Lighting Exterior 20 12.11 $8.63 $0.39 – $3.00 $0.143 1.82 2.09 2
LED Fixture Retailer Exterior Porch_4000 to 7999 lumens Baseline fixture Fixture Res Lighting Exterior 20 22.68 $16.16 $0.78 – $4.00 $0.143 2.23 2.56 2
a Average measure life.b Estimated kWh savings measured at the customer’s meter, excluding line losses. c Sum of NPV of DSM alternate cost. Based on end-use load shape, measure life, savings including line losses, and alternate costs by pricing period as provided in the 2019 Second Amended IRP. TRC test benefit calculation includes 10% conservation adder from the Northwest Power Act.
d Incremental participant cost prior to customer incentives.
e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.f UCT Ratio = (NPV DSM Alternate Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)g TRC Ratio = ((NPV DSM Alternate Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 RTF. ResLighting_Lightbulbs_v9_3.xlsm. Modified baseline for grocery, dollar, mass-merchandise, and small hardware stores. 2021.
2 RTF. ResLighting_Lightbulbs_v9_3.xlsm. 2021.
Page 20 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Energy House Calls
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ...........................................................$26,561 $38,163 0.70
TRC Test .........................................................29,541 38,163 0.77
RIM Test .........................................................26,561 96,836 0.27
PCT ................................................................ N/A N/A N/A
Cost Inputs Ref
Program Administration ....................................................................................$38,163
Program Incentives ............................................................................................–I
Total UC .............................................................................................................$38,163 P
Measure Equipment and Installation (Incremental Participant Cost) ...............$–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ..............................................54,516
NPV Cumulative Energy (kWh) ..................................................658,526 $26,561 S
10% Credit (Northwest Power Act) ............................................2,656
Total Electric Savings .......................................................................$29,217 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ....................................$58,673 B
Other Benefits
Non-Utility Rebates/Incentives..................................................$–NUI
NEBs ..........................................................................................$325 NEB
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT .........................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................143%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Notes: NEBs include PV of periodic lightbulb replacement costs for direct-install LED lightbulbs. No participant costs.
Page 21 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof
TRC Ratiog
Source/Notes
PTCS Duct
Sealing
Manufactured Home Prescriptive
Duct Sealing - Electric FAF - Heating Zone 1
Pre-existing
duct leakage
Home R-All-HVAC-ER-All-All-E 18 972.81 $466.98 ––– $0.700 0.69 0.75 1, 2
PTCS Duct
Sealing
Manufactured Home Prescriptive
Duct Sealing - Electric FAF - Heating Zone 2 or 3
Pre-existing
duct leakage
Home R-All-HVAC-ER-All-All-E 18 1,248.19 $599.18 ––– $0.700 0.69 0.75 1, 2
PTCS Duct
Sealing
Manufactured Home Prescriptive
Duct Sealing - Heat Pump - Heating Zone 1
Pre-existing
duct leakage
Home R-All-HVAC-ASHP-All-
All-E
18 615.06 $343.61 ––– $0.700 0.80 0.88 1, 2
PTCS Duct Sealing Manufactured Home Prescriptive Duct Sealing - Heat Pump - Heating Zone 2 or 3
Pre-existing duct leakage Home R-All-HVAC-ASHP-All-All-E 18 875.72 $489.23 ––– $0.700 0.80 0.88 1, 2
General Purpose LED Direct Install
Direct install-LED_General Purpose, Dimmable, and Three-Way 250 to 1049 lumens (Average
High Use and Moderate Use)
Baseline lightbulb Lamp Res Lighting Interior 12 12.12 $5.89 $0.43 –– $0.700 0.69 0.81 2, 3
Water heater pipe covers Up to 6 feet.No existing coverage Pipe wrap R-All-WH-ERWH-All-All-R 10 74.81 $30.40 –– $0.700 0.58 0.64 2, 4
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 RTF. ResMH PerformanceDuctSeal_v3_0.xlsm. 2015.2 Measure not cost-effective. Offering closed in 2022.3 RTF. ResLighting_Lightbulbs_v9_4.xlsm. 2021.
4 AEG. Potential Study. 2020.
Year: 2022 Program: Energy House Calls Market Segment: Residential Program Type: Energy Efficiency
Page 22 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Heating & Cooling Efficiency Program
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ...........................................................$ 655,361 $666,016 0.98
TRC Test ......................................................... 720,898 2,414,026 0.30
RIM Test ......................................................... 655,361 1,915,703 0.34
PCT ................................................................1,618,698 2,117,021 0.76
Cost Inputs Ref
Program Administration .....................................................................................$297,005
Program Incentives .............................................................................................369,011 I
Total UC ..............................................................................................................$666,016 P
Measure Equipment and Installation (Incremental Participant Cost) ................$2,117,021 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ........................................1,310,260
NPV Cumulative Energy (kWh) ............................................14,341,985 $655,361 S
10% Credit (Northwest Power Act) ......................................65,536
Total Electric Savings .................................................................$720,898 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ..............................$1,249,687 B
Other Benefits
Non-Utility Rebates/Incentives..............................................$–NUI
NEBs ......................................................................................$–NEB
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT .........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................102%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Note: 2022 cost-effectiveness ratios include evaluation expenses. If evaluation expense were removed from the program’s cost-effectiveness, the UCT and TRC would be 1.00 and 0.30, respectively.
Page 23 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Heat Pump
Conversion
Existing Single Family and
Manufactured Home HVAC Conversion to Heat Pump with Commissioning and Sizing (Heating & Cooling Zone Weighted Average)
Conversion to
high efficiency heat pump
Unit R-All-HVAC-ASHP-All-
All-E
15 3,885.92 $1,884.75 – $5,831.72 $800.00 $0.227 1.12 0.31 1, 2, 3, 4
Heat Pump Upgrade Existing Single Family and Manufactured Home HVAC Heat Pump Upgrade (Heating
& Cooling Zone Weighted Average)
Heat pump to heat pump upgrade
Unit R-All-HVAC-ASHP-All-All-E 15 707.00 $342.91 – $518.70 $250.00 $0.227 0.84 0.56 1, 2, 3, 4, 5
Heat Pump
Upgrade
New Construction Single
Family and Manufactured Home HVAC Heat Pump
Upgrade (Heating & Cooling Zone Weighted Average)
Heat pump
to heat pump upgrade
Unit R-All-HVAC-ASHP-All-
All-E
15 662.92 $321.53 – $1,259.27 $250.00 $0.227 0.80 0.25 1, 2, 3, 4, 5
Open-Loop Heat
Pump
Open loop water source heat
pump for new construction - 14.00 EER 3.5 COP (Heating & Cooling Zone Weighted Average)
Electric
resistance/ Oil Propane
Unit R-All-HVAC-ASHP-All-
All-E
20 8,352.94 $5,029.71 – $16,286.84 $1,000.00 $0.227 1.74 0.30 4, 6
Ground-Source Heat Pump Ground source heat pump - 3.5 COP (Heating & Cooling Zone Weighted Average)
Electric resistance/Oil Propane
Unit R-All-HVAC-ASHP-All-All-E 20 9,483.57 $5,710.51 – $9,958.39 $3,000.00 $0.227 1.11 0.52 4, 6
Ductless Heat Pump Zonal to DHP. (Heating & Cooling Zone Weighted Average)
Zonal Electric Unit R-All-HVAC-ERconvertDHP-2022 weighted
15 1,389.42 $575.70 – $4,568.26 $750.00 $0.227 0.54 0.13 7, 14
Heat Pump
Water Heater
Weighted average of tier 2
and tier 3, heating and cooling zone, and indoor, basement, garage install location.
Electric water
heater
Unit R-All-WH-WHConvert-
All-All-N
13 1,705.79 $891.57 – $880.68 $300.00 $0.227 1.30 0.77 4, 8
High Efficiency Air Conditioner Minimum 15 SEER but <17 SEER; minimum 12 EER Current practice baseline
Unit R-All-HVAC-CAC-All-All-E 18 91.81 $113.29 – $126.70 $50.00 $0.227 1.60 0.84 4, 9
Evaporative Cooler Evaporative Cooler Central A/C Unit R-All-HVAC-CAC-All-All-E 12 653.12 $572.78 – $258.22 $150.00 $0.227 1.92 1.55 10
Prescriptive
Duct Sealing Single Family
Duct Tightness - PTCS Duct
Sealing - Average Heating System. Weighted average of Heating Zones 1-3.
Pre-existing
duct leakage
Unit R-All-HVAC-ER-All-All-E 20 847.72 $438.66 – $738.95 $350.00 $0.227 0.81 0.52 4, 5, 11
Electronically Commutated
Motor (ECM) Blower Motor
ECM Blower Motor permanent split capacitor
(PSC) motor
Unit R-All-Bld-Bldg-All-All-R 18 3,168.75 $1,896.56 – $300.00 $50.00 $0.227 2.47 2.05 12
Year: 2022 Program: Heating & Cooling Efficiency Program Market Segment: Residential Program Type: Energy Efficiency
Page 24 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Whole-House Fan Whole-House Fan Displaced forced air dx cooling
Unit R-All-HVAC-CAC-All-All-E 18 445.60 $549.86 – $700.00 $200.00 $0.227 1.83 0.75 4, 12
Smart Thermostat Smart Thermostat Non wi-fi enabled
thermostat/no thermostat
Unit R-All-HVAC-ER-All-All-E 5 474.20 $71.62 – $140.86 $75.00 $0.227 0.39 0.32 13, 14
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.d Incremental participant cost prior to customer incentives.e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1RTF. ResSF&MHExistingHVAC_v5_1.xlsx. Weighted average of 2022 participants in heating and cooling zones 1-3.2 RTF. ResHeatingCoolingCommissioningControlsSizingSF_v3_6.xlsm. Weighted average of 2022 participants in heating and cooling zones 1-3.3 RTF. ResMHHeatingCoolingCommissioningControlsSizing_v3_4.xlsx. Weighted average of 2022 participants in heating and cooling zones 1-3.
4 Measure not cost-effective from TRC perspective.
5 Measure cost-effective without inclusion of admin costs.
6 RTF. ResGSHP_v2_7. 2016. Weighted average of 2021 participants in heating and cooling zones 1-3.7 RTF. ResDHPforZonal_v5_1.xlsm. Weighted average of 2021 participants in heating and cooling zones 1-3.8 RTF. ResHPfor WH_v5_3.xlsm. 2021. Measure cost-effective without inclusion of admin costs.
9 RTF.ResEfficientCentralAC_v1_1.xlsm. 2020. Idaho only measure.
10 New Mexico Technical Resource Manual for the Calculation of Energy Efficiency Savings. Evaporative Cooling. Santa Fe. Savings discounted by 44.4% for proportion evaporative coolers replacing refrigerated air. 2019.
11 RTF. ResSFDuctSealing_v5_1.xlsm. 2019. 12 Idaho Power engineering calculations based on Integrated Design Lab inputs. 2015.13 RTF. ResConnectedTstats_v1.3.xlsm. 2018
14 Measure not cost-effective. Offering will be modified in 2023.
Page 25 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Home Energy Report
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results Program Year 2022
Test Benefit Cost Ratio
UC Test ...........................................................$689,660 $964,791 0.71
TRC Test .........................................................758,626 964,791 0.79
RIM Test .........................................................689,660 2,794,394 0.25
PCT ................................................................ N/A N/A N/A
Program Year 2022 Cost Inputs Ref
Program Administration .....................................................................................$964,791
Program Incentives .............................................................................................–I2022
Total UC ..............................................................................................................$964,791 P2022
Measure Equipment and Installation (Incremental Participant Cost) ................$–M2022
Net Benefit Inputs (2020–2026)Ref
Resource Savings
NPV Cumulative Energy (kWh) 2020–2026 .......................84,190,742 $3,932,816 Sall
10% Credit (Northwest Power Act) ......................................393,282
Total Electric Savings .................................................................$4,326,098 Aall
Participant Bill Savings
NPV Cumulative Participant Bill Savings ..............................$7,172,271 Ball
Other Benefits
Non-Utility Rebates/Incentives..............................................$–NUIall
NEBs ......................................................................................$–NEBall
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT ......................................................... N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity (2022).....................................................................................140%
Minimum NTG Sensitivity (2020–2026)...........................................................................86%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Note: 2022 savings as reported by Aclara is 20,734,611 kWh. Idaho Power discounting savings by 0.44% for reporting and analysis as recommended by evaluators to account for potential double-counting of savings. Percentage reviewed in 2022 evaluation.
Program Life Cost Inputs (2020–2026)Ref
NPV Program Administration .............................................................................$3,362,234
NPV Program Incentives .....................................................................................–Iall
NPV Total UC ......................................................................................................$3,362,234 Pall
Measure Equipment and Installation (Incremental Participant Cost) ................$–Mall
Program Year 2022 Benefit Inputs Ref
Resource Savings
2022 Annual Gross Energy (kWh) ........................................20,643,379 $689,660 S2022
10% Credit (Northwest Power Act) ......................................68,966
Total Electric Savings .................................................................$758,626 A2022
Participant Bill Savings
NPV Cumulative Participant Bill Savings ..............................$ 1,829,603 B2022
Other Benefits
Non-Utility Rebates/Incentives..............................................$–NUI2022
NEBs ......................................................................................$–NEB2022
Summary of Cost-Effectiveness Results Program Life (2020–2026)
Test Benefit Cost Ratio
UC Test ...........................................................$3,932,816 $3,362,234 1.17
TRC Test .........................................................4,326,098 3,362,234 1.29
RIM Test .........................................................3,932,816 10,534,505 0.37
PCT ................................................................ N/A N/A N/A
Page 26 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Multifamily Energy Savings Program
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ............................................................$ 16,629 $ 34,181 0.49
TRC Test ..........................................................23,413 34,181 0.68
RIM Test ..........................................................16,629 66,116 0.25
PCT .................................................................N/A N/A N/A
Cost Inputs Ref
Program Administration .....................................................................................$34,181
Program Incentives .............................................................................................–I
Total UC ..............................................................................................................$34,181 P
Measure Equipment and Installation (Incremental Participant Cost) ................$–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ..............................................41,959
NPV Cumulative Energy (kWh) ..................................................378,457 $16,629 S
10% Credit (Northwest Power Act) ............................................1,663
Total Electric Savings .......................................................................$18,292 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ....................................$ 31,936 B
Other Benefits
Non-Utility Rebates/Incentives..................................................$–NUI
NEBs ..........................................................................................$5,122 NEB
Benefits and Costs Included in Each Test
UC Test .....................................................= S * NTG = P
TRC Test ...................................................= (A + NUI + NEB) * NTG = P
RIM Test ...................................................= S * NTG = P + (B * NTG)
PCT ..........................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................205%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Notes: NEBs include PV of periodic lightbulb replacement costs for direct-install LED lightbulb. No participant costs. Program closed December 31, 2022.
Page 27 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Year: 2022 Program: Multifamily Energy Savings Program Market Segment: Residential Program Type: Energy Efficiency
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
Unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Alternate
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e UCT Ratiof
TRC
Ratiog
Source/
Notes
General Purpose LED
Direct Install
Efficient Technology: LED Lamp Type: General Purpose
and Dimmable Lumen Category: 250 to 1049 lumens Space Type: High-Use Interior
Baseline lightbulb Lamp ResLighting Interior 12 13.98 $6.79 $0.72 –– $0.815 0.60 0.72 1, 2
Reflector LED Direct Install Efficient Technology: LED Lamp Type: Reflectors and
Outdoor Lumen Category: 250 to 1049 lumens Space Type: High-Use Interior
Baseline lightbulb Lamp ResLighting Interior 12 9.44 $4.59 $0.66 –– $0.815 0.60 0.74 1, 2
General Purpose LED Direct Install
Efficient Technology: LED Lamp Type: General Purpose and Dimmable Lumen Category: 250 to 1049 lumens Space Type: Moderate-Use Interior
Baseline lightbulb Lamp ResLightingInterior 12 10.26 $4.98 $0.54 –– $0.815 0.60 0.72 1, 2
Reflector LED Direct Install Efficient Technology: LED Lamp Type: Reflectors and Outdoor Lumen Category: 250 to 1049
lumens Space Type: Moderate-Use Interior
Baseline lightbulb Lamp ResLightingInterior 12 6.02 $2.92 $0.57 –– $0.815 0.60 0.77 1, 2
Globe LED
Direct Install
Efficient Technology: LED Lamp
Type: Globe Lumen Category: 250 to 1049 lumens Space Type: Moderate-Use Interior
Baseline
lightbulb
Lamp ResLighting
Interior
12 4.73 $2.30 $0.50 –– $0.815 0.60 0.79 1, 2
General Purpose LED
Direct Install
Efficient Technology: LED Lamp Type: General Purpose and
Dimmable Lumen Category: 250 to 1049 lumens Space Type: Exterior
Baseline lightbulb Lamp ResLightingExterior 12 15.40 $7.27 $0.81 –– $0.815 0.58 0.70 1, 2
Reflector LED
Direct Install
Efficient Technology: LED Lamp
Type: Reflectors and Outdoor Lumen Category: 250 to 1049 lumens Space Type: Exterior
Baseline
lightbulb
Lamp ResLighting
Exterior
12 7.88 $3.72 $0.54 –– $0.815 0.58 0.72 1, 2
General Purpose LED Direct Install
Efficient Technology: LED Lamp Type: General Purpose and Dimmable Lumen Category: 1490 to 2600 lumens Space Type: Exterior
Baseline lightbulb Lamp ResLighting Exterior 12 35.36 $16.70 $0.91 –– $0.815 0.58 0.67 1, 2
General Purpose LED Direct Install
Efficient Technology: LED Lamp Type: Reflectors and Outdoor Lumen Category: 250 to 1049 lumens Space Type: Common areas - Calculated
Baseline lightbulb Lamp ResLighting Interior 1 251.83 $8.53 $0.47 –– $0.815 0.04 0.05 2, 3
Page 28 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Alternate Costsc NEB
Gross Incremental Participant Costd Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog Source/Notes
Low-flow
showerheads and thermostatic shower valve combination
unit
Residential_Direct install_Valve
and 1.75 gpm showerhead_Electric resistance DHW
Any
showerhead 2.2 gpm or higher
Showerhead R-All-WH-
ERWH-All-All-R
10 49.94 $20.29 $49.56 –– $0.815 0.50 1.77 2, 4
Water heater pipe covers Up to 6 feet No existing coverage Pipe wrap R-All-WH- ERWH-All-All-R 10 75.93 $30.85 ––– $0.815 0.50 0.55 2, 5
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c Sum of NPV of DSM alternate cost. Based on end-use load shape, measure life, savings including line losses, and alternate costs by pricing period as provided in the 2019 Second Amended IRP. TRC test benefit calculation includes 10% conservation adder from the Northwest Power Act.d No participant costs.
e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Alternate Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Alternate Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))1 RTF. ResLighting_Lightbulbs_v9_4.xlsm. 2021.2 Measure not cost-effective. Offering closed in 2022.
3 Savings calculated based on wattage difference between the existing and replacement lightbulb and average hours of use for common areas.
4 RTF. ResThermostaicShowerRestrictionValve_v3_1.xlsm. 2019.
5 AEG. Potential Study. 2020.
Page 29 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Rebate Advantage
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ............................................................$197,702 $167,622 1.18
TRC Test ..........................................................217,472 402,649 0.54
RIM Test ..........................................................197,702 588,422 0.34
PCT ................................................................. 517,800 332,027 1.56
Cost Inputs Ref
Program Administration .....................................................................................$70,622
Program Incentives .............................................................................................97,000 I
Total UC ..............................................................................................................$167,622 P
Measure Equipment and Installation (Incremental Participant Cost) ................$332,027 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ..............................................255,541
NPV Cumulative Energy (kWh) ..................................................4,139,829 $197,702 S
10% Credit (Northwest Power Act) ............................................19,770
Total Electric Savings .......................................................................$217,472 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ....................................$ 420,800 B
Other Benefits
Non-Utility Rebates/Incentives..................................................$–NUI
NEBs ..........................................................................................$–NEB
Benefits and Costs Included in Each Test
UC Test ......................................................= S * NTG = P
TRC Test ....................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ....................................................= S * NTG = P + (B * NTG)
PCT ...........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................85%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Page 30 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Year: 2022 Program: Rebate Advantage Market Segment: Residential Program Type: Energy Efficiency
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e
UCT Ratiof
TRC Ratiog
Source/Notes
ENERGY STAR®
manufactured home
Estar_electric_Heating Zone (HZ) 1_Cooling Zone
(CZ) 3
Manufactured home built to Housing and Urban Development
(HUD) code.
Home R-All-HVAC-ER-All-All-E 45 2,070.80 $1,613.73 – $2,941.47 $1,000.00 $0.276 1.03 0.51 1,2
ENERGY STAR manufactured
home
Estar_electric_HZ2_CZ1 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 45 3,020.26 $2,353.62 – $2,941.47 $1,000.00 $0.276 1.28 0.69 1,2
ENERGY STAR manufactured
home
Estar_electric_HZ2_CZ2 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 45 3,022.11 $2,355.06 – $2,941.47 $1,000.00 $0.276 1.28 0.69 1,2
ENERGY STAR manufactured home
Estar_electric_HZ2_CZ3 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 45 3,024.85 $2,357.20 – $2,941.47 $1,000.00 $0.276 1.28 0.69 1,2
ENERGY STAR manufactured home
Estar_electric_HZ3_CZ1 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 45 3,819.13 $2,976.16 – $2,941.47 $1,000.00 $0.276 1.45 0.82 1,2
Northwest Energy Efficient Manufactured (NEEM) home
NEEM_electric_HZ1_CZ3 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 43 2,612.39 $2,005.73 – $4,809.64 $1,000.00 $0.276 1.17 0.40 1,2
NEEM home NEEM_electric_HZ2_CZ1 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 43 3,733.25 $2,866.30 – $4,809.64 $1,000.00 $0.276 1.41 0.54 1,2
NEEM home NEEM_electric_
HZ2_CZ2
Manufactured home
built to HUD code.
Home R-All-HVAC-ER-All-
All-E
43 3,735.67 $2,868.16 – $4,809.64 $1,000.00 $0.276 1.41 0.54 1,2
NEEM home NEEM_electric_HZ2_CZ3 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 43 3,739.15 $2,870.83 – $4,809.64 $1,000.00 $0.276 1.41 0.54 1,2
NEEM home NEEM_electric_HZ3_CZ1 Manufactured home built to HUD code.Home R-All-HVAC-ER-All-All-E 44 4,679.39 $3,620.26 – $4,809.64 $1,000.00 $0.276 1.58 0.65 1,2
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.d Incremental participant cost prior to customer incentives.e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 RTF. NewMHNewHomesandHVAC_v4_2.xlsm. 2021.2 Measure not cost-effective from TRC perspective.
Page 31 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Residential New Construction Program
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test .........................................................$342,237 $235,732 1.45
TRC Test ....................................................... 484,397 578,922 0.84
RIM Test .......................................................342,237 830,360 0.41
PCT .............................................................. 872,965 513,591 1.70
Cost Inputs Ref
Program Administration ....................................................................................$65,332
Program Incentives ............................................................................................170,400 I
Total UC .............................................................................................................$235,732 P
Measure Equipment and Installation (Incremental Participant Cost) ...............$513,591 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) .........................................337,562
NPV Cumulative Energy (kWh) .............................................5,641,587 $342,237 S
10% Credit (Northwest Power Act) .......................................34,224
Total Electric Savings ..................................................................$376,460 A
Participant Bill Savings
NPV Cumulative Participant Savings .....................................$ 594,628 B
Other Benefits
Non-Utility Rebates/Incentives.............................................$–NUI
NEBs .....................................................................................$107,937 NEB
Benefits and Costs Included in Each Test
UC Test .....................................................= S * NTG = P
TRC Test ...................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ...................................................= S * NTG = P + (B * NTG)
PCT ..........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................69%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Notes: 2018 International Energy Conservation Code (IECC) with amendments adopted in Idaho in 2021.
Page 32 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual
Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog Source/Notes
Next Step Home - 10% to 14.99% above code
Next Step Home - average per home savings.Home built to International Energy Conservation Code 2018
Code. Adopted 2021.
Home Prog_ResNewConst 56 1,489.81 $1,500.02 $879.18 $4,050.31 $1,200.00 $0.194 1.01 0.58 1
Next Step Home - 15% to 19.99%
above code
Next Step Home - average per home savings.Home built to International Energy
Conservation Code 2018 Code. Adopted 2021.
Home Prog_ResNewConst 56 2,181.19 $2,196.14 $976.17 $5,117.07 $1,500.00 $0.194 1.14 0.61 1
Next Step Home
- 20% or more above code'
Next Step Home - average
per home savings.
Home built to
International Energy Conservation Code 2018 Code. Adopted 2021.
Home Prog_
ResNewConst
59 5,876.23 $5,976.73 $1,105.33 $4,813.03 $2,000.00 $0.194 1.90 1.29 1
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.
d Incremental participant cost prior to customer incentives.
e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))1 NEEA circuit rider code enforcement initiative. 2022 average per home savings. Costs and NEBs from RTF. RESNCMTHouse_ID_v3_1_.xlsm. 2019.
Year: 2022 Program: Residential New Construction Program Market Segment: Residential Program Type: Energy Efficiency
Page 33 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Shade Tree Project
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ............................................................$131,637 $128,856 1.02
TRC Test ..........................................................156,458 128,856 1.21
RIM Test ..........................................................131,637 279,439 0.47
PCT .................................................................N/A N/A N/A
Cost Inputs Ref
Program Administration .....................................................................................$128,856
Program Incentives .............................................................................................–I
Total UC ..............................................................................................................$128,856 P
Measure Equipment and Installation (Incremental Participant Cost) ................$–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) from 2013–2018 plantings ...39,595
Cumulative Energy (kWh) from 2022 plantings .........................3,040,832
NPV Cumulative Energy (kWh) ..................................................714,268 $106,159 S
10% Credit (Northwest Power Act) ............................................10,616
Total Electric Savings .......................................................................$116,774 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ....................................$121,438 B
Other Benefits
Non-Energy Impacts (Therms) ...................................................$ (22,289)NEI
NEBs ..........................................................................................$39,296 NEB
Benefits and Costs Included in Each Test
UC Test .....................................................= S * NTG = P
TRC Test ...................................................= ((A + NEI) * NTG)+NEB = P
RIM Test ...................................................= S * NTG = P + (B * NTG)
PCT ..........................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................124%
Minimum NTG Sensitivity ................................................................................................121%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Note: Annual report shows incremental savings from the 2013 - 2018 planting years. Cost-effectiveness based on the trees distributed in 2022 to coincide with the 2022 financials. Net-to-gross factor of 124% applied to energy savings and therm impacts to account for trees shading neighboring homes per evaluator’s recommendation. Trees distributed in 2022 via the mail are approximately 1 year younger than trees distributed at in person events. Expected savings impact shifted out one year to account for the smaller trees. NEIs include costs associated with increased home heating energy. Other NEBs associated with air quality, stormwater runoff, and carbon dioxide.
Page 34 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Weatherization Assistance for Qualified Customers
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ............................................................$179,852 $1,038,781 0.17
TRC Test ..........................................................570,391 1,785,799 0.32
RIM Test ..........................................................179,852 1,427,279 0.13
PCT .................................................................N/A N/A N/A
Cost Inputs Ref
Program Administration .....................................................................................$153,926
Community Action Partnership (CAP) Agency Payments ...................................849,650
Total UC ..............................................................................................................$1,003,576 P
Accruals/Reversal of Carryover Dollars ..............................................................277,919
Total Program Expenses .....................................................................................1,281,495
Idaho Power Indirect Overhead Expense Allocation—3.508% ...........................$35,205 OH
Additional State Funding .................................................................................... 747,018 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) .........................................272,647
NPV Cumulative Energy (kWh) .............................................4,051,556 $179,852 S
10% Credit (Northwest Power Act) .......................................17,985
Total Electric Savings ..................................................................$197,837 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ...............................$ 388,497 B
Other Benefits
Non-Utility Rebates/Incentives............................................$–NUI
NEBs ....................................................................................
Health and Safety ..........................................................$344,408
Repair ............................................................................9,125
Other .............................................................................19,022
NEBs Total .............................................................................$372,554 NEB
Benefits and Costs Included in Each Test
UC Test .................................................= S * NTG = P + OH
TRC Test ...............................................= (A + NUI + NEB) * NTG = P + OH + M
RIM Test ...............................................= S * NTG = P + OH + (B * NTG)
PCT .......................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................575%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Notes: Savings based on a billing analysis of the 2016–2018 weatherization projects.
Program cost-effectiveness incorporated IPUC staff recommendations from case GNR-E-12-01. Recommendations include: Claimed 100% of savings; increased NTG to 100%; added a 10% conservation preference adder; health, safety, and repair NEBs; and allocation of indirect overhead expenses. No customer participant costs. Costs shown are from the DOE state weatherization assistance program.
Page 35 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Weatherization Solutions for Eligible Customers
Segment: Residential2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ............................................................$31,817 $213,007 0.15
TRC Test ..........................................................48,539 213,007 0.23
RIM Test ..........................................................31,817 281,735 0.11
PCT .................................................................N/A N/A N/A
Cost Inputs Ref
Program Administration .....................................................................................$26,932
Weatherization LLC Payments ............................................................................178,856
Total Program Expenses .....................................................................................$205,788
Total UC ..............................................................................................................$205,788 P
Idaho Power Indirect Overhead Expense Allocation—3.508% ...........................7,219 OH
Additional State Funding ....................................................................................–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ..............................................48,233
NPV Cumulative Energy (kWh) ..................................................716,746 $31,817 S
10% Credit (Northwest Power Act) ............................................3,182
Total Electric Savings .......................................................................$34,999 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ....................................$68,728 B
Other Benefits
Non-Utility Rebates/Incentives..................................................$–NUI
NEBs ..........................................................................................
Health and Safety ................................................................8,480
Repair ..................................................................................3,115
Other ...................................................................................1,946
NEBs Total ..................................................................................$13,541 NEB
Benefits and Costs Included in Each Test
UC Test .................................................= S * NTG = P +OH
TRC Test ...............................................= (A + NUI + NEB) * NTG = P + OH + M
RIM Test ...............................................= S * NTG = P + OH + (B * NTG)
PCT .....................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................667%
Average Customer Segment Rate/kWh ...........................................................................$0.089
Line Losses .......................................................................................................................9.60%
Notes: Savings based on a billing analysis of the 2016–2018 weatherization projects. Program cost-effectiveness incorporated IPUC staff recommendations from case GNR-E-12-01. Recommendations include: Claimed 100% of savings; increased NTG to 100%; added a 10% conservation preference adder; health, safety, and repair NEBs; and allocation of indirect overhead expenses. No customer participant costs.
Page 36 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Commercial Energy-Saving Kits
Segment: Commercial2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ........................................................$17,649 $22,770 0.78
TRC Test ...................................................... 19,728 22,770 0.87
RIM Test ......................................................17,649 45,367 0.39
PCT .............................................................N/A N/A N/A
Cost Inputs Ref
Program Administration ....................................................................................$22,770
Program Incentives ............................................................................................–I
Total UC .............................................................................................................$22,770 P
Measure Equipment and Installation (Incremental Participant Cost) ...............$–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ....................................48,758
NPV Cumulative Energy (kWh) ........................................411,974 $17,649 S
10% Credit (Northwest Power Act) ..................................1,765
Total Electric Savings .............................................................$19,414 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ..........................$22,597 B
Other Benefits
Non-Utility Rebates/Incentives........................................$–NUI
NEBs ................................................................................$314 NEB
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT ..........................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................129%
Average Customer Segment Rate/kWh ...........................................................................$0.058
Line Losses .......................................................................................................................9.60%
Notes: NEBs include PV of periodic lightbulb replacement costs for direct-install LED lightbulbs and water, waste water, and therm savings from water-saving devices.
Page 37 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Restaurant Commercial Kit
3-9W LEDs, 2-bathroom aerators, 2-kitchen aerators, 2-exit sign retrofit, 1-pre-
rinse spray valve.
No kit Kit IPC_Commercial Kit Restaurant 10 191.68 $71.10 $73.85 – – $0.467 0.79 1.70 1, 2
Retail Commercial
Kit
2-9W LEDs, 2-8W LED BR30s, 1-bathroom aerator, 2-exit
sign retrofit
No kit Kit IPC_Commercial Kit Retail 5 208.42 $36.19 $0.33 – – $0.467 0.37 0.41 1, 2
Office Commercial
Kit
2-9W LEDs, 2-bathroom aerators, 1-kitchen
aerator, 2-exit sign retrofit, 1-advance power strip
No kit Kit IPC_Commercial Kit Office 9 56.17 $17.94 $5.39 – – $0.467 0.68 0.96 1, 2
Commercial ESK 2-9W LEDs, 2-8W LED BR30s, 1-bathroom aerator, 1-kitchen aerator, 1-exit sign retrofit
No kit Kit IPC_CSK_All 10 147.78 $53.41 $(1.60)–– $0.467 0.77 0.83 1, 3
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.d Incremental participant cost prior to customer incentives.
e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))1 ADM evaluation. Estimated savings average hours of use by building type and varying electric water heat saturations. Hours of use from TRM. Electric water heat saturation from 2022 evaluation survey results.2 Measure not cost-effective. Business specific kit removed from offering in 2022. Kits remaining in inventory distributed in 2022.
3 Measure not cost-effective. Offering to close in 2023.
Year: 2022 Program: Commercial Energy-Saving Kits Market Segment: Commercial Program Type: Energy Efficiency
Page 38 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Custom Projects
Segment: Industrial2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ........................................................$25,695,351 $8,919,927 2.88
TRC Test ......................................................28,784,302 25,715,468 1.12
RIM Test ......................................................25,695,351 29,301,006 0.88
PCT .............................................................27,908,894 23,803,939 1.17
Cost Inputs Ref
Program Administration ....................................................................................$1,911,528
Program Incentives ............................................................................................7,008,398 I
Total UC .............................................................................................................$8,919,927 P
Measure Equipment and Installation (Incremental Participant Cost) ...............$ 23,803,939 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ....................................56,157,060
NPV Cumulative Energy (kWh) ........................................564,320,823 $25,695,351 S
10% Credit (Northwest Power Act) ..................................2,569,535
Total Electric Savings .............................................................$28,264,886 A
Participant Bill Savings
NPV Cumulative Participant Savings ................................$20,381,079 B
Other Benefits
Non-Utility Rebates/Incentives........................................$–NUI
NEBs ................................................................................$519,417 NEB
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT ..........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................35%
Average Customer Segment Rate/kWh ...........................................................................$0.037
Line Losses .......................................................................................................................9.60%
Notes: Energy savings are unique by project and are reviewed by Idaho Power engineering staff or third-party consultants. Each project must complete a certification inspection. Green Rewind initiative is available to agricultural, commercial, and industrial customers. Commercial and industrial motor rewinds are paid under Custom Projects, but the savings are not included in the program cost-effectiveness. Green Rewind savings are included in the sector cost-effectiveness. NEB/impacts on a $/kWh for each end-use. Based on 2019 impact evaluation of other C&I programs.
Page 39 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Green Motors Program Rewind:
Motor size 15 HP
Green Motors Program Rewind:
Motor size 15 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 7 525.20 $135.50 – $146.33 $15.00 $0.029 4.48 0.92 1, 2
Green Motors Program Rewind:
Motor size 20 HP
Green Motors Program Rewind:
Motor size 20 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 7 702.77 $181.32 – $163.26 $20.00 $0.029 4.49 1.09 1
Green Motors Program Rewind:
Motor size 25 HP
Green Motors Program Rewind:
Motor size 25 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 893.48 $267.25 – $186.53 $25.00 $0.029 5.25 1.38 1
Green Motors Program Rewind: Motor size 30 HP
Green Motors Program Rewind: Motor size 30 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 962.42 $287.87 – $204.87 $30.00 $0.029 4.97 1.36 1
Green Motors Program Rewind: Motor size 40 HP
Green Motors Program Rewind: Motor size 40 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 1,120.77 $335.23 – $250.36 $40.00 $0.029 4.62 1.30 1
Green Motors Program Rewind: Motor size 50 HP
Green Motors Program Rewind: Motor size 50 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 1,206.18 $360.78 – $277.15 $50.00 $0.029 4.25 1.27 1
Green Motors
Program Rewind: Motor size 60 HP
Green Motors
Program Rewind: Motor size 60 HP
Standard rewind
practice
Motor I-All-Other-Shift2-
All-All-S
8 1,268.50 $379.42 – $326.87 $60.00 $0.029 3.92 1.15 1
Green Motors
Program Rewind: Motor size 75 HP
Green Motors
Program Rewind: Motor size 75 HP
Standard rewind
practice
Motor I-All-Other-Shift2-
All-All-S
8 1,305.49 $390.48 – $353.32 $75.00 $0.029 3.46 1.10 1
Green Motors
Program Rewind: Motor size 100 HP
Green Motors
Program Rewind: Motor size 100 HP
Standard rewind
practice
Motor I-All-Other-Shift2-
All-All-S
8 1,723.08 $515.38 – $438.29 $100.00 $0.029 3.44 1.16 1
Green Motors
Program Rewind: Motor size 125 HP
Green Motors
Program Rewind: Motor size 125 HP
Standard rewind
practice
Motor I-All-Other-Shift2-
All-All-S
8 1,990.39 $595.34 – $436.88 $125.00 $0.029 3.26 1.32 1
Green Motors
Program Rewind: Motor size 150 HP
Green Motors
Program Rewind: Motor size 150 HP
Standard rewind
practice
Motor I-All-Other-Shift2-
All-All-S
8 2,366.02 $707.69 – $486.64 $150.00 $0.029 3.24 1.40 1
Green Motors Program Rewind: Motor size 200 HP
Green Motors Program Rewind: Motor size 200 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 3,138.34 $938.70 – $585.84 $200.00 $0.029 3.23 1.53 1
Green Motors Program Rewind: Motor size 250 HP
Green Motors Program Rewind: Motor size 250 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 3,798.53 $1,136.16 – $752.95 $250.00 $0.029 3.15 1.45 1
Green Motors Program Rewind: Motor size 300 HP
Green Motors Program Rewind: Motor size 300 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 4,534.67 $1,356.35 – $761.09 $300.00 $0.029 3.14 1.67 1
Green Motors Program Rewind: Motor size 350 HP
Green Motors Program Rewind: Motor size 350 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 5,286.56 $1,581.24 – $797.71 $350.00 $0.029 3.14 1.83 1
Year: 2022 Program: Custom Projects Market Segment: Industrial Program Type: Energy Efficiency
Page 40 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog Source/Notes
Green Motors Program Rewind:
Motor size 400 HP
Green Motors Program Rewind:
Motor size 400 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 5,994.15 $1,792.89 – $890.97 $400.00 $0.029 3.12 1.85 1
Green Motors Program Rewind:
Motor size 450 HP
Green Motors Program Rewind:
Motor size 450 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 6,732.12 $2,013.62 – $973.90 $450.00 $0.029 3.12 1.89 1
Green Motors Program Rewind:
Motor size 500 HP
Green Motors Program Rewind:
Motor size 500 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 7,490.56 $2,240.47 – $1,052.13 $500.00 $0.029 3.12 1.94 1
Green Motors Program Rewind:
Motor size 600 HP
Green Motors Program Rewind:
Motor size 600 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 10,137.37 $3,032.15 – $1,583.37 $600.00 $0.029 3.39 1.78 1
Green Motors Program Rewind: Motor size 700 HP
Green Motors Program Rewind: Motor size 700 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 11,776.73 $3,522.49 – $1,727.45 $700.00 $0.029 3.38 1.87 1
Green Motors Program Rewind: Motor size 800 HP
Green Motors Program Rewind: Motor size 800 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 13,430.58 $4,017.17 – $1,916.66 $800.00 $0.029 3.38 1.92 1
Green Motors Program Rewind: Motor size 900 HP
Green Motors Program Rewind: Motor size 900 HP
Standard rewind practice Motor I-All-Other-Shift2-All-All-S 8 15,077.39 $4,509.74 – $2,113.02 $900.00 $0.029 3.37 1.95 1
Green Motors
Program Rewind: Motor size 1,000 HP
Green Motors
Program Rewind: Motor size 1,000 HP
Standard rewind
practice
Motor I-All-Other-Shift2-
All-All-S
8 16,681.86 $4,989.64 – $2,277.19 $1,000.00 $0.029 2.32 1.60 1
Continuous Energy
Improvement Cohort for Schools
Cohort workshop
training
No change Offering Commercial-
School-Misc
1 7,380,223.00 $237,393.79 – $150,127.15 $129,397.90 $0.029 0.69 0.72 3, 4
Water Supply
Optimization Cohort
Cohort workshop
training
No change Offering I-WaterSupply-
Mot-All-All-All-U
1 727,247.00 $23,452.69 – $8,064.84 $5,645.38 $0.029 0.88 0.88 3, 4
a Average measure life.b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.
d Incremental participant cost prior to customer incentives.e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 RTF. Ind_and_Ag_GreenMotorRewind_v3_1.xlsm. 2017.
2 Offering cost-effective without inclusion of admin costs.3 2023 total cohort savings.4 Offering cost-effective without inclusion of admin costs.
Page 41 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
New Construction
Segment: Commercial2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test .......................................................$11,821,165 $2,780,507 4.25
TRC Test ..................................................... 13,269,329 3,641,930 3.64
RIM Test .....................................................11,821,165 17,492,798 0.68
PCT ............................................................ 17,316,829 3,199,915 5.41
Cost Inputs Ref
Program Administration .....................................................................................$442,015
Program Incentives .............................................................................................2,338,492 I
Total UC ..............................................................................................................$2,780,507 P
Measure Equipment and Installation (Incremental Participant Cost) ................$3,199,915 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ....................................27,615,777
NPV Cumulative Energy (kWh) ........................................263,785,420 $11,821,165 S
10% Credit (Northwest Power Act) ..................................1,182,117
Total Electric Savings .............................................................$13,003,282 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ..........................$14,712,291 B
Other Benefits
Non-Utility Rebates/Incentives........................................$–NUI
NEBs ................................................................................$266,047 NEB
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT .........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................24%
Average Customer Segment Rate/kWh ...........................................................................$0.058
Line Losses .......................................................................................................................9.60%
Notes: Non-energy benefits/impacts on a $/kWh for each end-use. Based on 2019 impact evaluation. 2022 cost-effectiveness ratios include evaluation expenses. IF evaulation expense were removed from the program’s cost-effectiveness, the UCT and TRC would be 4.34 and 3.70, respectively.
Page 42 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e
UCT Ratiof TRC Ratiog
Source/Notes
Lighting Interior Light Load Reduction. Part A: 10-19.9% below code.Code standards ft2 C-All-Lgt-LPD Int-All-All-E 14 0.43 $0.21 – $0.13 $0.10 $0.029 1.91 1.66 1
Lighting Interior Light Load Reduction. Part
B: 20-29.9% below code.
Code standards ft2 C-All-Lgt-LPD Int-
All-All-E
14 0.86 $0.43 – $0.25 $0.20 $0.029 1.91 1.72 1
Lighting Interior Light Load Reduction. Part C: Equal to or greater than 30%
below code.
Code standards ft2 C-All-Lgt-LPD Int-All-All-E 14 1.95 $0.97 – $0.58 $0.30 $0.029 2.73 1.68 1
Lighting Exterior Light Load Reduction. Minimum of 15% below code.Code standards kW Commercial-Misc. Com-ExtLight 15 4,059.00 $2,268.08 – $287.00 $200.00 $0.029 7.14 6.16 1
Lighting Networked Lighting Controls - Interior Code standards kWh C-All-Lgt-LPD Int-All-All-E 12 1.00 $0.44 – $0.33 $0.26 $0.029 1.51 1.33 1
Lighting Networked Lighting Controls -
Exterior
Code standards kWh Commercial-Misc.
Com-ExtLight
12 1.00 $0.46 – $0.33 $0.20 $0.029 2.01 1.40 1
Lighting Occupancy Sensors Code standards Sensor C-All-Lgt-LPD Int-All-All-E 8 329.00 $96.76 – $134.00 $25.00 $0.029 2.80 0.74 1, 2
Lighting High-Efficiency Exit Signs Code standards Sign IPC_8760 16 28.00 $15.18 – $10.83 $7.50 $0.029 1.83 1.43 1
A/C Unitary Commercial Air Conditioners, Air Cooled (Cooling Mode). Split system & single package. Part A: Base to CEE Tier 1
IECC 2018 Code Standard Tons C-All-HVAC-CAC-All-All-E 15 47.00 $31.25 – $79.00 $25.00 $0.029 1.19 0.43 1, 2
A/C Unitary Commercial Air
Conditioners, Air Cooled (Cooling Mode). Split system & single package. Part B: Base to CEE Tier 2
IECC 2018 Code
Standard
Tons C-All-HVAC-CAC-
All-All-E
15 88.00 $58.50 – $123.00 $50.00 $0.029 1.11 0.51 1, 2
Heat Pump Heat Pumps, Air Cooled (Cooling Mode). Split system & single package. Part A: Base to CEE Tier 1
IECC 2018 Code Standard Tons C-All-HVAC-CAC-All-All-E 15 72.00 $47.87 – $36.00 $50.00 $0.029 0.92 1.38 1, 6, 7
Heat Pump Heat Pumps, Air Cooled (Cooling Mode). <= 5 tons. Split system & single package. Part B: Base to CEE Tier 2
IECC 2018 Code Standard Tons C-All-HVAC-CAC-All-All-E 15 104.00 $69.14 – $67.00 $70.00 $0.029 0.95 1.09 1
VRF AC Variable Refrigerant Flow Units. Air Conditioner. Part B: Base to CEE Tier 1
IECC 2018 Air Cooled AC Code Standard
Tons C-All-HVAC-CAC-All-All-E 15 87.00 $57.84 – $93.00 $35.00 $0.029 1.54 0.67 1, 2
VRF AC Variable Refrigerant Flow Units.
<= 5 tons. A/C. Part C: Base to CEE Tier 2
IECC 2018 Air
Cooled AC Code Standard
Tons C-All-HVAC-CAC-
All-All-E
15 119.00 $79.11 – $108.00 $55.00 $0.029 1.35 0.78 1, 2
VRF Heat Pump Variable Refrigerant Flow Units.
Heat Pump. Part B: Base to CEE Tier 1
IECC 2018 Air
Cooled AC Code Standard
Tons C-All-HVAC-CAC-
All-All-E
15 97.00 $64.49 – $36.00 $50.00 $0.029 1.22 1.83 1
VRF Heat Pump Variable Refrigerant Flow Units.
<= 5 tons. Heat Pump. Part C: Base to CEE Tier 2
IECC 2018 Air
Cooled AC Code Standard
Tons C-All-HVAC-CAC-
All-All-E
15 129.00 $85.76 – $71.00 $85.00 $0.029 0.97 1.26 1, 7
Year: 2022 Program: New Construction Market Segment: Commercial Program Type: Energy Efficiency
Page 43 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e
UCT Ratiof TRC Ratiog
Source/Notes
A/C Air Conditioners, Water Cooled Any Size IECC 2018 Air Cooled AC Code Standard
Ton C-All-HVAC-CAC-All-All-E 15 67.00 $44.54 – $225.00 $40.00 $0.029 1.06 0.22 1, 2
HP Heat Pumps, Water Cooled Any Size IECC 2018 Air Cooled AC Code
Standard
Ton C-All-HVAC-CAC-All-All-E 15 133.00 $88.42 – $370.00 $100.00 $0.029 0.85 0.26 1, 2, 6
VRF HP Variable Refrigerant Flow, Water Cooled Heat Pump <= 64 Tons
Base to CEE Tier 1
IECC 2018 Air Cooled AC Code
Standard
Ton C-All-HVAC-CAC-All-All-E 15 128.00 $85.10 – $145.00 $100.00 $0.029 0.82 0.63 1, 2, 6
A/C Air-cooled chiller condenser, IPLV 14.0 EER or higher IECC 2018 Code standards Tons C-All-HVAC-CAC-All-All-E 20 102.00 $84.12 – $209.00 $80.00 $0.029 1.01 0.44 2, 3
A/C Water-cooled chiller electronically operated, reciprocating and positive displacement
IECC 2018 Code standards Tons C-All-HVAC-CAC-All-All-E 20 61.00 $50.31 – $103.00 $40.00 $0.029 1.20 0.53 2, 4
A/C Airside economizer IECC 2018 Code standards Ton of cooling C-All-HVAC-CAC-All-All-E 15 197.00 $130.97 – $81.36 $75.00 $0.029 1.62 1.65 1
A/C Water-side Economizer IECC 2018 Code
Standard
Combined
chiller tonnage
C-All-HVAC-CAC-
All-All-E
10 153.00 $70.07 – $725.82 $50.00 $0.029 1.29 0.11 1, 2
A/C Direct evaporative cooler IECC 2018 Code standards Tons C-All-HVAC-CAC-All-All-E 15 315.00 $209.41 – $364.00 $200.00 $0.029 1.00 0.62 1, 2
A/C Indirect evaporative cooler IECC 2018 Code Standard Tons C-All-HVAC-CAC-All-All-E 15 225.00 $149.58 – $1,553.00 $130.00 $0.029 1.10 0.11 1, 2
A/C Evaporative Pre-Cooler on Air-
Cooled Chillers
air-cooled
condenser coil
Tons C-All-HVAC-CAC-
All-All-E
15 63.00 $41.88 – $173.00 $30.00 $0.029 1.32 0.26 1, 2
A/C Evaporative Pre-Cooler on Air-Cooled Refrigeration Systems air-cooled condenser coil Tons C-All-HVAC-CAC-All-All-E 15 110.00 $73.13 – $173.00 $30.00 $0.029 2.20 0.46 1, 2
Building Shell Reflective roof treatment IECC 2018 Code Standard ft2 roof area C-All-HVAC-CAC-All-All-E 15 0.12 $0.08 – $0.05 $0.05 $0.029 1.45 1.59 1
Controls Energy Management System (EMS) controls. Part A: 1 strategy IECC 2018 Code standards Tons of cooling C-All-HVAC-Vent-All-All-E 15 227.00 $120.22 $34.09 $162.00 $60.00 $0.029 1.81 0.99 1, 2
Controls Energy Management System (EMS) controls. Part B: 2 strategies IECC 2018 Code standards Tons of cooling C-All-HVAC-Vent-All-All-E 15 409.00 $216.60 $34.09 $198.00 $80.00 $0.029 2.36 1.30 1
Controls EMS controls. Part C: 3 strategies IECC 2018 Code standards Tons of cooling C-All-HVAC-Vent-All-All-E 15 473.00 $250.49 $56.82 $233.00 $100.00 $0.029 2.20 1.35 1
Controls EMS controls. Part D: 4 strategies IECC 2018 Code Standard Tons of cooling C-All-HVAC-Vent-All-All-E 15 567.00 $300.27 $119.32 $269.00 $120.00 $0.029 2.20 1.58 1
Controls EMS controls. Part E: 5 strategies IECC 2018 Code standards Tons of cooling C-All-HVAC-Vent-All-All-E 15 617.00 $326.75 $119.32 $304.00 $140.00 $0.029 2.07 1.49 1
Controls Guest room energy management
system
IECC 2018 Code
standards
Ton C-Lod-fan-SGS-All-
All-S
11 550.00 $237.82 – $57.50 $50.00 $0.029 3.61 3.56 1
Controls Variable speed drive on HVAC system applications IECC 2018 Code standards HP C-All-HVAC-Vent-All-All-E 15 582.00 $308.22 – $153.91 $125.00 $0.029 2.17 1.99 1
Controls Part C: Variable speed drive on Potato/Onion Storage Shed Ventilation
No VFD HP C-All-HVAC-Vent-All-All-E 10 1,193.00 $439.92 – $264.00 $250.00 $0.029 1.55 1.62 1
Page 44 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e
UCT Ratiof TRC Ratiog
Source/Notes
Controls Demand Controlled Kitchen Ventilation Exhaust Hood Kitchen hood with constant speed ventilation motor
HP C-All-Food-Cook-All-All-C 15 4,590.00 $2,427.68 – $248.00 $250.00 $0.029 6.34 7.01 1
Appliances with Electric Dryer Efficient Laundry Machines (electric dryer)IECC 2018 Code standards Unit Commercial-Misc. Com-Misc 9 814.50 $265.32 $1,179.74 $400.00 $200.00 $0.029 1.19 3.47 5
Refrigeration Efficient Refrigeration Condenser Code standards Ton C-Gro-Ref-All-All-All-E 15 114.00 $59.98 – $192.00 $40.00 $0.029 1.39 0.34 1, 2
Automatic High-Speed Doo Refrigerator to Dock Code standards ft2 Commercial-Ref.warehouse-Misc 16 360.00 $197.91 – $167.00 $80.00 $0.029 2.19 1.23 1
Automatic High-Speed Door Freezer to Refrigerator Code standards ft2 Commercial-Ref.warehouse-Misc 16 1,829.00 $1,005.51 – $167.00 $160.00 $0.029 4.72 5.03 1
Automatic High-
Speed Door
Freezer to Dock Code standards ft2 Commercial-Ref.
warehouse-Misc
16 2,531.00 $1,391.44 – $167.00 $320.00 $0.029 3.54 6.37 1
High-Volume, Low-Speed Fan High-Volume, Low-Speed Fan Standard high-speedfan Fan I-All-Other-Shift2-All-All-S 15 16,733.00 $9,019.95 – $3,185.00 $2,000.00 $0.029 3.63 2.70 1
Compressed Air Air compressor VFD No existing VFD HP Commercial-Misc. Com-Misc 13 949.00 $435.97 – $223.00 $200.00 $0.029 1.92 1.91 1
Compressed Air No-Loss Condensate Drain Open tube with ball valve HP Commercial-Misc. Com-Misc 10 1,970.00 $711.54 – $194.00 $200.00 $0.029 2.77 3.12 1
Compressed Air Low Pressure Drop Filter Standard filter HP Commercial-Misc. Com-Misc 10 44.00 $15.89 – $10.00 $10.00 $0.029 1.41 1.55 1
Compressed Air Refrigerated Compressed Air Dryer Standard air dryer CFM Commercial-Misc. Com-Misc 13 10.62 $4.88 – $6.00 $3.00 $0.029 1.47 0.85 1, 2
Compressed Air Efficient Compress Air Nozzle Code standards unit Commercial-Misc. Com-Misc 15 2,223.00 $1,152.08 – $85.00 $80.00 $0.029 7.97 8.48 1
Engine Block
Heater Control
Wall-mounted engine block heater Standard engine
block heater without controls
Unit C-All-HVAC-ER-All-
All-E
15 2,738.00 $1,172.96 – $70.00 $100.00 $0.029 6.54 8.64 1
Engine Block Heater Controls Engine-mounted engine block heater Standard engine block heater without controls
Unit C-All-HVAC-ER-All-All-E 15 2,352.00 $1,007.59 – $120.00 $150.00 $0.029 4.62 5.89 1
Dairy VFD VFD on milking vacuum pump No existing VFD VFD A-Da-Proc-MilkingSchedule-All-All-S
10 548.00 $215.76 – $273.00 $170.00 $0.029 1.16 0.82 1, 2
Dairy VFD VFD on milking transfer pump No existing VFD VFD A-Da-Proc-MilkingSchedule-All-All-S
10 7,687.00 $3,026.53 – $1,469.00 $1,500.00 $0.029 1.76 1.97 1
Engine block heater Stationary pump-driven circulating block heater Circulating Block Heater on a Backup Generator <200 kW
per unit C-All-HVAC-ER-All-All-E 15 1,106.00 $473.81 – $239.00 $200.00 $0.029 2.04 1.92 1
Page 45 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e
UCT Ratiof TRC Ratiog
Source/Notes
Engine block heater Stationary pump-driven circulating block heater Circulating Block Heater on a Backup Generator 201-500 kW
per unit C-All-HVAC-ER-All-All-E 15 2,493.00 $1,068.00 – $573.00 $350.00 $0.029 2.53 1.82 1
Engine block
heater
Stationary pump-driven circulating
block heater
Circulating Block
Heater on a Backup Generator 501-1000 kW
per unit C-All-HVAC-ER-All-
All-E
15 4,385.00 $1,878.53 – $573.00 $500.00 $0.029 3.00 2.95 1
Ice Machines ENERY STAR Ice Machine <200 lbs per day non ENERGY STAR ice machine unit Commercial-Misc. Com-Misc 9 285.00 $92.84 – $311.00 $100.00 $0.029 0.86 0.32 1, 2, 6
Ice Machines ENERY STAR Ice Machine >= 200
lbs per day
non ENERGY STAR
ice machine
unit Commercial-Misc.
Com-Misc
9 2,608.00 $849.54 – $311.00 $300.00 $0.029 2.26 2.42 1
High-Efficiency Battery Chargers High-Efficiency Battery Chargers - Single or Three Phase Code standards unit Commercial-Fleet_EV_Charger 15 3,337.00 $1,625.69 – $400.00 $200.00 $0.029 5.48 3.60 1
a Average measure life.b Estimated kWh savings measured at the customer’s meter, excluding line losses. c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.
d Incremental participant cost prior to customer incentives.
e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 Idaho Power TRM prepared by ADM Associates, Inc. 2022.
2 Idaho only measure.
3 Idaho Power TRM prepared by ADM Associates, Inc. 2022. Averaged air-cooled chillers.4 Idaho Power TRM prepared by ADM Associates, Inc. 2022. Averaged water-cooled chillers.5 Idaho Power TRM prepared by ADM Associates, Inc. 2022. NEBs from water savings from RTF. ComClothesWashers_v5_1.xlsm. Simple average. 2018.
6 Measure not cost-effective from UCT perspective. Will continue to monitor in 2023.
7 Measure not cost-effective. Measure cost-effective without inclusion of admin costs.
Page 46 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Retrofits
Segment: Commercial2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ..........................................................$9,798,547 $4,870,916 2.01
TRC Test ........................................................14,820,782 13,402,016 1.11
RIM Test ........................................................9,798,547 17,065,912 0.57
PCT ............................................................... 20,351,571 12,645,295 1.61
Cost Inputs Ref
Program Administration .....................................................................................$756,722
Program Incentives .............................................................................................4,114,194 I
Total UC ..............................................................................................................$4,870,916 P
Measure Equipment and Installation (Incremental Participant Cost) ................$12,645,295 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) .......................................22,890,678
NPV Cumulative Energy (kWh) ...........................................218,651,361 $9,798,547 S
10% Credit (Northwest Power Act) .....................................979,855
Total Electric Savings ................................................................$10,778,402 A
Participant Bill Savings
NPV Cumulative Participant Savings ...................................$12,194,997 B
Other Benefits
Non-Utility Rebates/Incentives...........................................$–NUI
NEBs ...................................................................................$4,042,380 NEB
Benefits and Costs Included in Each Test
UC Test ....................................................= S * NTG = P
TRC Test ..................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ..................................................= S * NTG = P + (B * NTG)
PCT .........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................50%
Average Customer Segment Rate/kWh ...........................................................................$0.058
Line Losses .......................................................................................................................9.60%
Note: Measure inputs from Evergreen Consulting Group or the TRM prepared by ADM Associates, Inc., unless otherwise noted. NEB/impacts on a $/kWh for each end-use. Based on 2019 impact evaluation. 2022 cost-effectiveness ratios include evaluation expenses. If evaluation expense were removed from the program’s cost-effectiveness, the UTC and TRC would be 2.03 and 1.11, respectively
Page 47 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure unit End Use Measure Life (yrs)a
Annual Gross
Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross
Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e
UCT Ratiof
TRC Ratiog
Source/Notes
Permanent Fixture Removal Permanent Fixture Removal fixture C-All-Lgt-LPD Int-All-All-E 6 873.61 $186.78 – $29.08 $22.69 $0.029 3.89 3.78 1
LEDs Screw-in or pin-based LED Screw-in or pin-base lamp using higher wattage fixture C-All-Lgt-LPD Int-All-All-E 1 138.06 $4.56 – $22.80 $4.73 $0.029 0.52 0.19 1, 15
LEDs HID LED screw-in replacement lamp Existing HID lamp using > input watts fixture C-All-Lgt-LPD Int-All-All-E 12 662.71 $289.50 – $107.70 $49.23 $0.029 4.23 2.51 1
LEDs LED Tubes (type A, B & DM)fixture using higher wattage fixture C-All-Lgt-LPD Int-All-All-E 12 203.00 $88.68 – $42.86 $12.47 $0.029 4.83 2.00 1
LEDs LED Tubes (type C) or LED Level 1
Retrofit Kit
fixture using higher
wattage
fixture C-All-Lgt-LPD Int-
All-All-E
12 309.96 $135.40 – $85.80 $33.55 $0.029 3.18 1.57 1
LEDs LED Level 1 retrofit kit with single control strategy fixture using higher wattage fixture C-All-Lgt-LPD Int-All-All-E 12 289.43 $126.43 – $127.38 $40.52 $0.029 2.58 1.02 1
LEDs LED Level 1 retrofit kit with multiple control strategy
fixture using higher
wattage fixture C-All-Lgt-LPD Int-All-All-E 12 410.70 $179.41 – $140.40 $65.71 $0.029 2.31 1.30 1
LEDs LED Level 1 retrofit kit with
networked control strategy
fixture using higher wattage fixture C-All-Lgt-LPD Int-
All-All-E
12 455.35 $198.91 – $142.98 $81.96 $0.029 2.09 1.40 1
LEDs LED fixture or LED Level 2 retrofit kit fixture using higher wattage fixture C-All-Lgt-LPD Int-All-All-E 12 440.45 $192.41 – $178.93 $83.69 $0.029 1.99 1.10 1
LEDs LED fixture or LED Level 2 retrofit kit with single control strategy fixture using higher wattage fixture C-All-Lgt-LPD Int-All-All-E 12 518.33 $226.43 – $203.25 $108.85 $0.029 1.83 1.14 1
LEDs LED fixture or LED Level 2 retrofit kit
with multiple control strategy
fixture using higher
wattage
fixture C-All-Lgt-LPD Int-
All-All-E
12 599.94 $262.08 – $282.13 $143.99 $0.029 1.62 0.96 1, 2
LEDs LED fixture or LED Level 2 retrofit kit with networked control strategy fixture using higher wattage fixture C-All-Lgt-LPD Int-All-All-E 12 722.45 $315.59 – $348.50 $187.84 $0.029 1.51 0.94 1, 2
LED Exit Sign LED Exit Sign fixture using higher wattage sign IPC_8760 12 230.68 $98.04 – $61.89 $40.00 $0.029 2.10 1.57 1
LED sign lighting
retrofit kit
LED sign lighting retrofit kit fixture using higher
wattage
fixture C-All-Lgt-LPD Int-
All-All-E
12 427.11 $186.58 – $161.34 $76.68 $0.029 2.09 1.18 1
Lighting Controls (Idaho)Lighting Controls Manual controls controls C-All-Lgt-LPD Int-All-All-E 10 159.70 $58.82 – $85.47 $27.31 $0.029 1.84 0.72 1, 3
Lighting Controls (Oregon)
Lighting Controls Manual controls controls C-All-Lgt-LPD Int-All-All-E 10 139.18 $51.27 –$75.47 $25.00 $0.029 1.77 0.71 1, 15
Refrigeration Case Lighting Refrigeration Case Lighting fixture using higher wattage lamp C-All-Lgt-LPD Int-All-All-E 7 365.73 $92.88 – $107.23 $52.26 $0.029 1.48 0.87 1, 3
Permanent
Fixture Removal
Permanent Fixture Removal fixture Commercial-Misc.
Com-ExtLight
6 1,013.14 $221.25 – $39.44 $17.69 $0.029 4.70 3.54 1
LEDs Screw-in or pin-based LED Screw-in or pin-base lamp using higher wattage fixture Commercial-Misc. Com-ExtLight 1 156.95 $5.08 – $36.02 $3.09 $0.029 0.66 0.14 1, 15
LEDs HID LED screw-in replacement lamp Existing HID lamp using > input watts fixture Commercial-Misc. Com-ExtLight 12 743.75 $341.91 – $106.32 $43.98 $0.029 5.22 2.94 1
Year: 2022 Program: Retrofits Market Segment: Commercial Program Type: Energy Efficiency
Page 48 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Avoided
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e
UCT
Ratiof
TRC
Ratiog
Source/
Notes
LEDs LED Tubes (type A, B & DM)fixture using higher
wattage
fixture Commercial-Misc.
Com-ExtLight
12 287.20 $132.03 – $63.89 $12.24 $0.029 6.42 2.01 1
LEDs LED Tubes (type C) or LED Level 1 Retrofit Kit fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 526.92 $242.23 – $125.38 $37.74 $0.029 4.57 1.89 1
LEDs LED Level 1 retrofit kit with single control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 646.59 $297.24 – $167.32 $77.59 $0.029 3.09 1.76 1
LEDs LED Level 1 retrofit kit with multiple
control strategy
fixture using higher
wattage
fixture Commercial-Misc.
Com-ExtLight
12 850.79 $391.11 – $202.36 $119.11 $0.029 2.72 1.89 1
LEDs LED Level 1 retrofit kit with networked control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 933.44 $429.11 – $218.51 $149.35 $0.029 2.43 1.92 1
LEDs LED fixture or LED Level 2 retrofit kit fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 912.48 $419.47 – $279.77 $127.75 $0.029 2.72 1.51 1
LEDs LED fixture or LED Level 2 retrofit kit with single control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 951.89 $437.59 – $341.84 $152.30 $0.029 2.43 1.30 1
LEDs LED fixture or LED Level 2 retrofit kit with multiple control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 753.43 $346.36 – $269.49 $135.62 $0.029 2.20 1.31 1
LEDs LED fixture or LED Level 2 retrofit kit with networked control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 1,636.51 $752.31 – $556.48 $327.30 $0.029 2.01 1.37 1
LED sign lighting retrofit kit
LED sign lighting retrofit kit fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 487.27 $224.00 – $172.05 $68.22 $0.029 2.72 1.32 1
Lighting Controls (Idaho)Lighting Controls Manual controls controls Commercial-Misc. Com-ExtLight 10 295.20 $113.89 – $103.41 $19.82 $0.029 4.01 1.12 1
Lighting Controls
(Oregon)
Lighting Controls Manual controls controls Commercial-Misc. Com-ExtLight 10 366.20 $141.28 – $110.26 $20.12 $0.029 4.60 1.29 1
Air Conditioning (AC) Units Base to CEE Tier 1 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 152.00 $101.05 – $940.00 $85.00 $0.029 1.13 0.12 3, 4
AC Units Base to CEE Tier 2 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 193.00 $128.31 – $984.00 $110.00 $0.029 1.11 0.14 3, 4
AC Units <= 5 ton VRF. Base to CEE Tier 2 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 161.00 $107.03 – $1,093.00 $100.00 $0.029 1.02 0.11 3, 4
AC Units VRF.
Base to CEE Tier 1
working pre-existing
system
tons C-All-HVAC-CAC-
All-All-E
15 129.00 $85.76 – $1,078.00 $75.00 $0.029 1.09 0.09 3, 4
AC Units Water-cooled AC that meets CEE Tier 1 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 130.00 $86.42 – $1,237.00 $75.00 $0.029 1.10 0.08 3, 4
AC Units Air-conditioning Tune Up ton C-All-HVAC-CAC-All-All-E 10 99.50 $45.57 – $35.00 $25.00 $0.029 1.63 1.32 4
Heat Pump (HP) Units Air Cooled HP Base to CEE Tier 1 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 187.00 $124.32 – $888.00 $110.00 $0.029 1.08 0.15 3, 4
HP Units <= 5 ton HP Unit. Base to CEE Tier 2 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 219.00 $145.59 – $919.00 $130.00 $0.029 1.07 0.17 3, 4
Page 49 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Avoided
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e
UCT
Ratiof
TRC
Ratiog
Source/
Notes
HP Units Water-cooled HP that
meets CEE Tier 1
working pre-existing
system
tons C-All-HVAC-CAC-
All-All-E
15 129.00 $85.76 – $971.00 $75.00 $0.029 1.09 0.10 3, 4
HP Units <= 5 ton Air-cooled VRF. Base to CEE Tier 2 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 175.00 $116.34 – $1,034.00 $110.00 $0.029 1.01 0.12 3, 4
HP Units Air-cooled VRF. Base to CEE Tier 1 working pre-existing system tons C-All-HVAC-CAC-All-All-E 15 143.00 $95.07 – $999.00 $90.00 $0.029 1.01 0.10 3, 4
HP Units Water-cooled VRF that
meets CEE Tier 1
working pre-existing
system
tons C-All-HVAC-CAC-
All-All-E
15 75.00 $49.86 – $1,187.00 $45.00 $0.029 1.06 0.05 3, 4
Chiller Units Air-cooled chiller, IPLV 14.0 EER or higher working pre-existing system tons C-All-HVAC-CAC-All-All-E 20 154.00 $127.00 – $784.00 $110.00 $0.029 1.11 0.18 3, 5
Chiller Units Water-cooled chiller electronically operated, reciprocating and positive displacement
working pre-existing system tons C-All-HVAC-CAC-All-All-E 20 91.00 $75.05 – $596.00 $60.00 $0.029 1.20 0.14 3, 6
Economizers Air-side economizer control addition No prior control Ton of cooling C-All-HVAC-CAC-All-All-E 15 279.00 $185.48 – $155.01 $100.00 $0.029 1.72 1.25 4
Economizers Air-side economizer
control repair
Non-functional
economizer
Ton of
cooling
C-All-HVAC-CAC-
All-All-E
15 279.00 $185.48 – $73.65 $50.00 $0.029 3.19 2.50 4
Economizers Water-side economizer control addition No prior control Combined chiller
tonnage
C-All-HVAC-CAC-All-All-E 10 153.00 $70.07 – $725.82 $50.00 $0.029 1.29 0.11 3, 4
Evaporative Coolers Direct evaporative cooler Replacing standard AC unit Ton C-All-HVAC-CAC-All-All-E 15 350.00 $232.68 – $1,178.00 $200.00 $0.029 1.11 0.22 3, 4
Evaporative Coolers Indirect evaporative cooler Replacing standard AC unit ton C-All-HVAC-CAC-All-All-E 15 250.00 $166.20 – $2,367.00 $130.00 $0.029 1.21 0.08 3, 4
Evaporative Pre-Cooler on Air-Cooled
Chillers
Evaporative Pre-Cooler on Air-Cooled Chillers existing air-cooled condenser coil ton C-All-HVAC-CAC-All-All-E 15 63.00 $41.88 – $173.00 $30.00 $0.029 1.32 0.26 3, 4
Automated Control Systems Energy Management System (EMS) controls with 1 strategy Proposed strategy not existing (retrofit system)tons of cooling C-All-HVAC-Vent-All-All-E 15 372.00 $197.00 $45.46 $198.00 $100.00 $0.029 1.78 1.26 4
Automated Control Systems EMS controls with 2 strategies Proposed strategy not existing (retrofit system)tons of cooling C-All-HVAC-Vent-All-All-E 15 622.00 $329.40 $34.09 $233.00 $150.00 $0.029 1.96 1.58 4
Automated
Control Systems
EMS controls with 3 strategies Proposed strategy not
existing (retrofit system)
tons of
cooling
C-All-HVAC-Vent-
All-All-E
15 811.00 $429.49 $102.28 $269.00 $175.00 $0.029 2.16 1.96 4
Automated Control Systems EMS controls with 4 strategies Proposed strategy not existing (retrofit system)tons of cooling C-All-HVAC-Vent-All-All-E 15 1,728.00 $915.12 $545.47 $304.00 $200.00 $0.029 3.66 4.38 4
Automated Control Systems EMS controls with 5 strategies Proposed strategy not existing (retrofit system)tons of cooling C-All-HVAC-Vent-All-All-E 15 1,796.00 $951.13 $551.15 $340.00 $225.00 $0.029 3.43 4.07 4
Automated
Control Systems
EMS controls with 1 strategy Proposed strategy not
existing (new system)
tons of
cooling
C-All-HVAC-Vent-
All-All-E
15 227.00 $120.22 $34.09 $162.00 $60.00 $0.029 1.81 0.99 3, 4
Automated
Control Systems
EMS controls with 2 strategies Proposed strategy not
existing (new system)
tons of
cooling
C-All-HVAC-Vent-
All-All-E
15 409.00 $216.60 $34.09 $198.00 $80.00 $0.029 2.36 1.30 4
Page 50 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Avoided
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e
UCT
Ratiof
TRC
Ratiog
Source/
Notes
Automated
Control Systems
EMS controls with 3 strategies Proposed strategy not
existing (new system)
tons of
cooling
C-All-HVAC-Vent-
All-All-E
15 473.00 $250.49 $56.82 $233.00 $100.00 $0.029 2.20 1.35 4
Automated
Control Systems
EMS controls with 4 strategies Proposed strategy not
existing (new system)
tons of
cooling
C-All-HVAC-Vent-
All-All-E
15 567.00 $300.27 $119.32 $269.00 $120.00 $0.029 2.20 1.58 4
Automated
Control Systems
EMS controls with 5 strategies Proposed strategy not
existing (new system)
tons of
cooling
C-All-HVAC-Vent-
All-All-E
15 617.00 $326.75 $119.32 $304.00 $140.00 $0.029 2.07 1.49 4
Automated
Control Systems
Lodging room occupancy controls Manual controls Unit C-Lod-fan-SGS-All-
All-S
11 643.00 $278.03 – $150.61 $75.00 $0.029 2.97 1.81 4
Electronically Commutated Motor (ECM)
ECM/PMSM motor in HVAC applications.Shaded pole or permanent split capacitor motor
HP C-All-HVAC-Vent-All-All-E 15 8,815.25 $4,668.40 – $239.50 $200.00 $0.029 10.25 10.37 4
Premium Windows Low U-value, U-factor of .30 or less Standard window sq ft window area
C-All-HVAC-ER-All-All-C 25 9.00 $5.91 – $22.08 $2.50 $0.029 2.14 0.29 3, 4
Reflective roofing Adding reflective roof treatment non-reflective low pitch roof ft2 roof area C-All-HVAC-CAC-All-All-E 15 0.12 $0.08 – $0.05 $0.05 $0.029 1.45 1.59 4
Ceiling Insulation Increase to R38 min. insulation.Insulation level, R11 or less sq ft C-All-HVAC-ER-All-All-C 25 0.38 $0.25 – $1.45 $0.20 $0.029 1.19 0.19 3, 4
Wall Insulation Increase to R11 min. insulation.Insulation level, R2.5 or less sq ft wall area C-All-HVAC-ER-All-All-C 25 2.82 $1.85 – $0.64 $0.40 $0.029 3.84 2.82 4
Wall Insulation Increase to R19 min. insulation.Insulation level, R2.5 or less sq ft wall area C-All-HVAC-ER-All-All-C 25 3.16 $2.07 – $0.85 $0.55 $0.029 3.23 2.42 4
Laundry Machines High efficiency washer Standard washer, electric dryer Machine Commercial-Misc. Com-Misc 9 814.50 $265.32 $1,179.74 $400.00 $200.00 $0.029 1.19 3.47 4, 7
HVAC Fan
Motor Belts
Type AX notched V-belt
Type BX notched V-belt
Type A solid V-belt
Type B solid V-belt
HP C-All-HVAC-Vent-
All-All-E
4 83.00 $10.90 – $4.40 $5.00 $0.029 1.47 1.76 4
HVAC Fan Motor Belts Synchronous belt Standard fan belt HP C-All-HVAC-Vent-All-All-E 4 213.00 $27.97 – $67.00 $25.00 $0.029 0.90 0.42 3, 8
Engine block heater Stationary pump-driven circulating block heater Circulating Block Heater on a Backup Generator <200 kW
unit C-All-HVAC-ER-All-All-E 15 1,106.00 $473.81 – $1,268.00 $200.00 $0.029 2.04 0.40 3, 4
Engine block heater Stationary pump-driven circulating block heater Circulating Block Heater on a Backup Generator 201-500 kW
unit C-All-HVAC-ER-All-All-E 15 2,493.00 $1,068.00 – $2,152.00 $350.00 $0.029 2.53 0.53 3, 4
Engine block heater Stationary pump-driven circulating block heater Circulating Block Heater on a Backup Generator
501-1000 kW
unit C-All-HVAC-ER-All-All-E 15 4,385.00 $1,878.53 – $2,645.00 $500.00 $0.029 3.00 0.75 3, 4
Engine block heater Wall mounted engine block heater standard engine block heater without controls Unit C-All-HVAC-ER-All-All-E 15 2,738.00 $1,172.96 – $120.00 $100.00 $0.029 6.54 6.47 4
Engine block heater Engine-mounted engine block heater standard engine block heater without controls Unit C-All-HVAC-ER-All-All-E 15 2,352.00 $1,007.59 – $170.00 $150.00 $0.029 4.62 4.65 4
Page 51 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Avoided
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e
UCT
Ratiof
TRC
Ratiog
Source/
Notes
High Efficiency
Battery Chargers
High Efficiency Battery Chargers Standard battery charger unit Commercial-Fleet_
EV_Charger
15 3,337.00 $1,625.69 – $400.00 $200.00 $0.029 5.48 3.60 4
High Volume
Low Speed Fan
High Volume Low Speed Fan Standard high-speed fan Fan I-All-Other-Shift2-
All-All-S
15 16,733.00 $9,019.95 – $4,185.00 $2,000.00 $0.029 3.63 2.12 4
Compressed Air VFD on air compressor No existing VFD HP Commercial-Misc. Com-Misc 13 949.00 $435.97 – $223.00 $200.00 $0.029 1.92 1.91 4
Compressed Air Low Pressure Filter Standard filter HP Commercial-Misc. Com-Misc 10 44.00 $15.89 – $10.00 $10.00 $0.029 1.41 1.55 4
Compressed Air No-Loss Condensate Drain Open tube with ball valve Unit Commercial-Misc.
Com-Misc
10 1,970.00 $711.54 – $244.00 $200.00 $0.029 2.77 2.60 4
Compressed Air Efficient Compress Air Nozzle Standard air nozzle Unit Commercial-Misc. Com-Misc 15 2,223.00 $1,152.08 – $85.00 $80.00 $0.029 7.97 8.48 4
Compressed Air Efficient Refrigerated Compressed Air Dryer Standard air dryer CFM Commercial-Misc. Com-Misc 13 10.62 $4.88 – $6.00 $3.00 $0.029 1.47 0.85 3, 4
Refrigeration Install auto-closer - walk-in no/damaged auto-closer,
low temp
Door C-Gro-Ref-All-All-
All-E
8 2,509.00 $730.64 – $736.00 $400.00 $0.029 1.55 0.99 2, 4
Refrigeration Install auto-closer - reach-in Damaged auto-closer, low temp Door C-Gro-Ref-All-All-All-E 8 326.00 $94.93 – $736.00 $75.00 $0.029 1.12 0.14 3, 4
Refrigeration Install auto-closer - walk-in No/damaged auto-closer, med. Temp Door C-Gro-Ref-All-All-All-E 8 562.00 $163.66 – $736.00 $135.00 $0.029 1.08 0.24 3, 4
Refrigeration Install auto-closer - reach-in Damaged auto-closer, med. Temp Door C-Gro-Ref-All-All-All-E 8 243.00 $70.76 – $736.00 $55.00 $0.029 1.14 0.10 3, 4
Refrigeration Anti-sweat heat controls Low/med.temp case without controls Linear ft C-Gro-Ref-All-All-All-E 8 256.00 $74.55 – $77.26 $50.00 $0.029 1.30 0.97 3, 4
Evaporative Pre-Cooler on Air-Cooled
Refrigeration Systems
Evaporative Pre-Cooler on Air-Cooled Refrigeration Systems existing air-cooled condenser coil ton C-All-Ref-Refrig-All-All-C 15 110.00 $57.65 – $173.00 $30.00 $0.029 1.74 0.36 3, 4
Refrigeration No-heat glass door commercial glass door door C-Gro-Ref-All-All-
All-E
12 779.00 $338.03 – $664.00 $200.00 $0.029 1.52 0.54 3, 4
Defrost Coil Control Defrost Coil Control - Cooler or Freezer no evaporative coil defrost control per fan C-Gro-Ref-All-All-All-E 10 195.50 $71.44 – $500.00 $50.00 $0.029 1.28 0.16 3, 4
Automatic high speed doors Freezer to Dock manual or electric warehouse door sq ft Commercial-Ref.warehouse-Misc 16 2,812.00 $1,545.92 – $188.00 $320.00 $0.029 3.85 6.31 4
Automatic high
speed doors
Freezer to Refrigerator manual or electric
warehouse door
sq ft Commercial-Ref.
warehouse-Misc
16 2,032.00 $1,117.11 – $188.00 $160.00 $0.029 5.10 4.98 4
Automatic high speed doors Refrigerator to Dock manual or electric warehouse door sq ft Commercial-Ref.warehouse-Misc 16 400.00 $219.90 – $188.00 $80.00 $0.029 2.40 1.21 4
Strip Curtain For walk-in freezers no protective barrier sq ft C-Gro-Ref-All-All-All-E 4 210.00 $27.13 – $9.00 $5.00 $0.029 2.45 1.98 4
Page 52 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Avoided
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e
UCT
Ratiof
TRC
Ratiog
Source/
Notes
Strip Curtain For walk-in refrigerators no protective barrier sq ft C-Gro-Ref-All-All-
All-E
4 78.00 $10.08 – $9.00 $5.00 $0.029 1.39 0.98 2, 4
Compressor Head Fan Motor
to ECM
Compressor Head Fan Motor to ECM SP or PSC with motors less than or equal to
existing motor size
unit C-Gro-Ref-All-All-All-E 15 345.61 $181.84 – $228.08 $100.00 $0.029 1.65 0.84 3, 4
Floating Head/Suction
Pressures
Head pressure controller Standard head pressure control HP C-Gro-Ref-All-All-All-E 16 440.00 $243.77 – $311.90 $160.00 $0.029 1.41 0.83 3, 4
Floating Head/Suction
Pressures
Suction pressure controller Standard suction pressure control HP C-Gro-Ref-All-All-All-E 16 104.00 $57.62 – $86.91 $40.00 $0.029 1.34 0.70 3, 4
Demand Controlled Kitchen Ventilation
Exhaust Hood
VFD installed on kitchen exhaust and/or makeup air fan Kitchen hood with constant speed ventilation motor
HP C-All-Food-Cook-All-All-C 15 4,590.00 $2,427.68 – $469.00 $250.00 $0.029 6.34 4.44 4
Ice Machines Ice Machines (<200 lbs/day)code per unit C-All-Ref-Refrig-All-All-C 9 285.00 $93.49 – $311.00 $100.00 $0.029 0.86 0.32 3, 4, 8
Ice Machines Ice Machines (>200 lbs/day)code per unit C-All-Ref-Refrig-All-All-C 9 2,608.00 $855.47 – $311.00 $300.00 $0.029 2.28 2.43 4
Commercial
Kitchen Equipment
Efficient Hot Food Holding Cabinet
(Half Size)
per unit C-All-Food-Cook-
All-All-C
10 1,605.05 $591.38 – $315.94 $200.00 $0.029 2.40 1.79 9
Commercial
Kitchen Equipment
Efficient Hot Food Holding Cabinet
(Full Size)
per unit C-All-Food-Cook-
All-All-C
10 2,839.99 $1,046.38 – $672.68 $400.00 $0.029 2.17 1.52 9
Commercial
Kitchen Equipment
Efficient Hot Food Holding Cabinet
(Double Size)
per unit C-All-Food-Cook-
All-All-C
10 5,238.05 $1,929.94 – $2,838.36 $800.00 $0.029 2.03 0.71 3, 9
New On-
Demand Overwrapper
New On-Demand Overwrapper per unit Commercial-
Grocery-Process
10 1,583.68 $600.88 – $345.19 $100.00 $0.029 4.12 1.69 10
Commercial
Kitchen Equipment
ENERGY STAR listed electric
combination oven (5-15 pans)
Standard electric oven oven C-All-Food-Cook-
All-All-C
7 5,106.65 $1,298.43 – $989.08 $800.00 $0.029 1.37 1.26 11
Commercial Kitchen Equipment
ENERGY STAR listed electric combination oven (16-20 pans)Standard electric oven oven C-All-Food-Cook-All-All-C 7 5,528.10 $1,405.59 – $555.21 $300.00 $0.029 3.05 2.16 11
Commercial Kitchen Equipment
ENERGY STAR listed electric convection oven Standard electric oven oven C-All-Food-Cook-All-All-C 8 736.40 $216.77 – $439.97 $180.00 $0.029 1.08 0.52 3, 12
Commercial Kitchen Equipment
ENERGY STAR listed electric fryer Standard fryer fryer C-All-Food-Cook-All-All-C 6 883.76 $189.28 – $1,296.18 $150.00 $0.029 1.08 0.16 3, 13
Page 53 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing
Measure
unit End Use
Measure
Life (yrs)a
Annual Gross Energy Savings
(kWh/yr)b
NPV DSM Avoided
Costsc NEB
Gross Incremental Participant
Costd
Incentive/
Unit
Admin Cost
($/kWh)e
UCT
Ratiof
TRC
Ratiog
Source/
Notes
Commercial
Kitchen Equipment
ENERGY STAR listed electric steamer
-Any Size
Standard steamer pan C-All-Food-Cook-
All-All-C
7 2,995.49 $761.64 $883.21 $73.15 $30.00 $0.029 6.52 10.76 14
Variable Speed
Controls
Variable speed drive on HVAC system
application
single speed HVAC system
fan/ump
HP C-All-HVAC-Vent-
All-All-E
15 622.00 $329.40 – $184.55 $125.00 $0.029 2.30 1.79 4
Variable Speed Controls Variable speed drive on potato and onion storage shed ventilation no existing VFD HP A-SpudOnionVFD 10 1,193.00 $361.35 – $264.00 $250.00 $0.029 1.27 1.33 4
Variable Speed Controls VFD on milking vacuum pump no existing VFD HP A-Da-Proc-MilkingSchedule-All-All-S
10 3,084.00 $1,214.24 – $356.00 $250.00 $0.029 3.58 3.00 4
Variable Speed Controls VFD on milking transfer pump no existing VFD HP A-Da-Proc-MilkingSchedule-All-All-S
10 11,777.00 $4,636.85 – $2,052.00 $1,500.00 $0.029 2.52 2.13 4
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. Total Resource Cost Test Benefit calculation includes 10% conservation adder from the Northwest Power Act.d Incremental participant cost prior to customer incentives.e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 Evergreen Consulting Group, LLC. Idaho Power Lighting Tool. 2022.2 Measure not cost-effective from TRC perspective. Measure cost-effective without inclusion of admin costs.3 Idaho only measure.
4 Idaho Power TRM prepared by ADM Associates, Inc. 2022.
5 Idaho Power TRM prepared by ADM Associates, Inc. 2022. Averaged air-cooled chillers.
6 Idaho Power TRM prepared by ADM Associates, Inc. 2022. Averaged water-cooled chillers.7 Idaho Power TRM prepared by ADM Associates, Inc. 2022. NEBs from water savings from RTF. ComClothesWashers_v5_1.xlsm. Simple average. 2018.8 Measure not cost-effective from UCT perspective. Will continue to monitor in 2023.
9 RTF. ComCookingHotFoodCabinet_v3_2. 2020.
10 RTF. ComOnDemandOverwrappers_v1_1. 2018.
11 RTF. ComCookingCombinationOven_v3_1. 2019.12 RTF. ComCookingConvectionOven_v3_1. Simple average of Half Size Oven savings. 2018.13 RTF. ComCookingFryer_v3_3. 2020.
14 RTF. ComCookingSteamer_v3_1. Calculated per pan savings using Any size savings divided by average steamer size of 6 pans. 2019.
15 Measure not cost-effective. Will be modified in 2023.
Page 54 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Notes: NEB/impacts on a $/kWh for each end-use. Based on 2019 impact evaluation of other C&I programs
Small Business Direct Install
Segment: Commercial2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ........................................................$1,280,686 $1,345,429 0.95
TRC Test ......................................................2,017,935 1,345,429 1.50
RIM Test ......................................................1,280,686 2,956,117 0.43
PCT ..............................................................N/A N/A N/A
Cost Inputs Ref
Program Administration .....................................................................................$1,345,429
Program Incentives .............................................................................................–I
Total UC ..............................................................................................................$1,345,429 P
Measure Equipment and Installation (Incremental Participant Cost) ................$–M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ......................................3,228,365
NPV Cumulative Energy (kWh) ..........................................29,118,685 $1,280,686 S
10% Credit (Northwest Power Act) ....................................128,069
Total Electric Savings ...............................................................$1,408,755 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ............................$ 1,610,688 B
Other Benefits
Non-Utility Rebates/Incentives...........................................$–NUI
NEBs ...................................................................................$ 609,181 NEB
Benefits and Costs Included in Each Test
UC Test .....................................................= S * NTG = P
TRC Test ...................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ...................................................= S * NTG = P + (B * NTG)
PCT ..........................................................N/A N/A
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................105%
Average Customer Segment Rate/kWh ...........................................................................$0.058
Line Losses .......................................................................................................................9.60%
Page 55 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Irrigation Efficiency Rewards
Segment: Irrigation2022 Program Results
Summary of Cost-Effectiveness Results
Test Benefit Cost Ratio
UC Test ........................................................$5,585,689 $2,080,027 2.69
TRC Test ...................................................... 35,804,000 14,083,686 2.54
RIM Test ......................................................5,585,689 7,059,015 0.79
PCT ..............................................................36,308,273 13,666,743 2.66
Cost Inputs Ref
Program Administration .....................................................................................$410,484
Program Incentives .............................................................................................1,669,543 I
Total UC ..............................................................................................................$2,080,027 P
Measure Equipment and Installation (Incremental Participant Cost) ................$13,666,743 M
Net Benefit Inputs (NPV)Ref
Resource Savings
2022 Annual Gross Energy (kWh) ......................................6,937,855
NPV Cumulative Energy (kWh) ..........................................83,817,664 $5,585,689 S
10% Credit (Northwest Power Act) ....................................558,569
Total Electric Savings ...............................................................$6,144,257 A
Participant Bill Savings
NPV Cumulative Participant Bill Savings ............................$ 4,978,988 B
Other Benefits
Non-Utility Rebates/Incentives...........................................$–NUI
NEBs ...................................................................................$29,659,742 NEB
Benefits and Costs Included in Each Test
UC Test .....................................................= S * NTG = P
TRC Test ...................................................= (A + NUI + NEB) * NTG = P + ((M-I) * NTG)
RIM Test ...................................................= S * NTG = P + (B * NTG)
PCT ..........................................................= B + I + NUI + NEB = M
Assumptions for Levelized Calculations
Discount Rate
Nominal (WACC) ........................................................................................................7.12%
Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.81%
Escalation Rate ................................................................................................................2.20%
Net-to-Gross (NTG) ..........................................................................................................100%
Minimum NTG Sensitivity ................................................................................................38%
Average Customer Segment Rate/kWh ...........................................................................$0.059
Line Losses .......................................................................................................................9.60%
Notes: Energy savings are combined for projects under the Custom and Menu program. Savings under each Custom project is unique and individually calculated and assessed. For Custom option, NEBs including yield, labor, and other benefits reported by the customer. For Menu option, NEBs from RTF. Green Rewind initiative is available to agricultural, commercial, and industrial customers. Agricultural motor rewinds are paid under Irrigation Efficiency Rewards, but the savings are not included in the program cost-effectiveness. Green Rewind savings are included in the sector cost-effectiveness.
Page 56 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Namea Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)b
Annual Gross Energy Savings (kWh/yr)c
NPV DSM Avoided Costsd NEB
Gross Incremental Participant Coste
Incentive/ Unit
Admin Cost ($/kWh)f UCT Ratiog
TRC Ratioh
Sources/Notes
Nozzle
Replacement
New flow-control-type nozzles
replacing existing brass nozzles or worn out flow control nozzles of same flow rate or less
Brass nozzles or
worn out flow control nozzles of same flow rate or less
Unit A-Irr-Irr-
Irrigation-All-All-E
6 21.46 $5.62 $3.06 $7.04 $2.50 $0.060 1.48 1.11 1
Nozzle Replacement New nozzles replacing existing worn nozzles of same flow rate or less
Worn nozzle of same flow rate or less
Unit A-Irr-Irr-Irrigation-All-All-E
6 21.46 $5.62 $3.06 $0.70 $0.35 $0.060 3.43 4.65 1
Sprinklers Rebuilt or new brass
impact sprinklers
Worn sprinkler Unit A-Irr-Irr-
Irrigation-All-All-E
6 1.90 $0.50 $14.50 $11.85 $0.50 $0.060 0.81 1.26 1, 2
Levelers Rebuilt or new wheel line levelers Worn wheel line
leveler
Unit A-Irr-Irr-
Irrigation-All-All-E
7 3.62 $1.16 $7.82 $4.70 $1.00 $0.060 0.95 1.85 1, 2
Sprinklers Center pivot/linear move: Install
new sprinkler package on an existing system
Worn sprinkler
system
Unit A-Irr-Irr-
Irrigation-All-All-E
6 26.04 $6.82 $23.42 $27.83 $8.00 $0.060 0.71 1.05 1, 3
Gasket
Replacement
New gaskets for hand lines,
wheel lines, or portable mainline
Worn gasket Unit A-Irr-Irr-
Irrigation-All-All-E
6 13.33 $3.49 $4.16 $2.24 $1.00 $0.060 1.94 2.63 1
Drain
Replacement
New drains, hand lines, wheel
lines, or portable mainline
Worn drain Unit A-Irr-Irr-
Irrigation-All-All-E
6 9.79 $2.56 $5.87 $5.94 $3.00 $0.060 0.71 1.33 1, 3
a Available measures in the Irrigation Efficiency Rewards Menu Incentive Option. For the Custom Incentive Option, projects are thoroughly reviewed by Idaho Power staff.b Average measure life.
c Estimated peak demand reduction measured at the customer’s meter, excluding line losses.
d NPV of DSM avoided costs. Based on end use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. e Incremental participant cost prior to customer incentives.f Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
g UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
h TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))
1 RTF. AgIrrigationHardware_v5_2.xlsm. 2021. Weighted average of Western Idaho (11.62%), Eastern Washington & Oregon (2.73%), and Eastern & Southern Idaho (85.65%).2 Measure not cost-effective. Measure cost-effective without inclusion of admin costs.3 Measure not cost-effective from UCT perspective. Will continue to monitor in 2023.
Year: 2022 Program: Irrigation Efficiency Rewards Market Segment: Irrigation Program Type: Energy Efficiency
Page 57 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Green Motors Program
Rewind: Motor size 15 HP
Green Motors Program
Rewind: Motor size 15 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
18 222.19 $178.89 – $134.57 $15.00 $0.060 6.31 1.33 1
Green Motors Program Rewind: Motor size 20 HP Green Motors Program Rewind: Motor size 20 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 18 297.32 $239.37 – $150.13 $20.00 $0.060 6.33 1.57 1
Green Motors Program Rewind: Motor size 25 HP Green Motors Program Rewind: Motor size 25 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 17 447.57 $345.30 – $171.53 $25.00 $0.060 6.66 1.91 1
Green Motors Program
Rewind: Motor size 30 HP
Green Motors Program
Rewind: Motor size 30 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
17 482.11 $371.95 – $188.39 $30.00 $0.060 6.31 1.88 1
Green Motors Program Rewind: Motor size 40 HP Green Motors Program Rewind: Motor size 40 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 17 561.43 $433.14 – $230.22 $40.00 $0.060 5.88 1.81 1
Green Motors Program Rewind: Motor size 50 HP Green Motors Program Rewind: Motor size 50 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 17 604.21 $466.15 – $254.87 $50.00 $0.060 5.40 1.76 1
Green Motors Program
Rewind: Motor size 60 HP
Green Motors Program
Rewind: Motor size 60 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
21 553.16 $495.58 – $300.58 $60.00 $0.060 5.32 1.63 1
Green Motors Program Rewind: Motor size 75 HP Green Motors Program Rewind: Motor size 75 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 21 569.29 $510.03 – $324.91 $75.00 $0.060 4.67 1.56 1
Green Motors Program Rewind: Motor size 100 HP Green Motors Program Rewind: Motor size 100 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 21 751.39 $673.17 – $403.05 $100.00 $0.060 4.64 1.65 1
Green Motors Program Rewind: Motor size 125 HP Green Motors Program Rewind: Motor size 125 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 23 555.70 $527.02 – $291.81 $125.00 $0.060 3.33 1.78 1
Green Motors Program Rewind: Motor size 150 HP Green Motors Program Rewind: Motor size 150 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 23 660.58 $626.49 – $325.04 $150.00 $0.060 3.30 1.89 1
Green Motors Program Rewind: Motor size 200 HP Green Motors Program Rewind: Motor size 200 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 23 876.20 $830.98 – $391.31 $200.00 $0.060 3.29 2.06 1
Green Motors Program Rewind: Motor size 250 HP Green Motors Program Rewind: Motor size 250 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 19 1,357.04 $1,135.74 – $502.92 $250.00 $0.060 3.43 2.14 1
Green Motors Program Rewind: Motor size 300 HP Green Motors Program Rewind: Motor size 300 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 19 1,620.02 $1,355.83 – $508.37 $300.00 $0.060 3.41 2.46 1
Green Motors Program
Rewind: Motor size 350 HP
Green Motors Program
Rewind: Motor size 350 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
19 1,888.64 $1,580.64 – $532.82 $350.00 $0.060 3.41 2.69 1
Green Motors Program Rewind: Motor size 400 HP Green Motors Program Rewind: Motor size 400 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 19 2,141.43 $1,792.21 – $595.11 $400.00 $0.060 3.39 2.72 1
Green Motors Program Rewind: Motor size 450 HP Green Motors Program Rewind: Motor size 450 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 19 2,405.07 $2,012.86 – $650.51 $450.00 $0.060 3.39 2.79 1
Green Motors Program
Rewind: Motor size 500 HP
Green Motors Program
Rewind: Motor size 500 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
19 2,676.03 $2,239.63 – $702.76 $500.00 $0.060 3.39 2.85 1
Green Motors Program Rewind: Motor size 600 HP Green Motors Program Rewind: Motor size 600 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 24 4,113.93 $4,001.37 – $1,388.11 $600.00 $0.060 4.73 2.69 1
Green Motors Program Rewind: Motor size 700 HP Green Motors Program Rewind: Motor size 700 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 24 4,779.22 $4,648.46 – $1,514.42 $700.00 $0.060 4.71 2.84 1
Green Motors Program
Rewind: Motor size 800 HP
Green Motors Program
Rewind: Motor size 800 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
24 5,450.38 $5,301.25 – $1,680.30 $800.00 $0.060 4.70 2.91 1
Year: 2022 Program: Irrigation Efficiency Rewards—Green Motors Market Segment: Irrigation Program Type: Energy Efficiency
Page 58 Demand-Side Management 2022 Annual Report
Supplement 1: Cost-Effectiveness
Benefit Cost B/C Tests
Measure Name Measure Descriptions Replacing Measure Unit End Use Measure Life (yrs)a
Annual Gross Energy Savings (kWh/yr)b
NPV DSM Avoided Costsc NEB
Gross Incremental Participant Costd
Incentive/ Unit
Admin Cost ($/kWh)e UCT Ratiof TRC Ratiog
Source/Notes
Green Motors Program Rewind: Motor size 900 HP Green Motors Program Rewind: Motor size 900 HP Standard rewind practice Motor A-Irr-Irr-Irrigation-All-All-E 24 6,118.68 $5,951.27 – $1,852.45 $900.00 $0.060 4.70 2.95 1
Green Motors Program
Rewind: Motor size 2000 HP
Green Motors Program
Rewind: Motor size 2000 HP
Standard rewind
practice
Motor A-Irr-Irr-
Irrigation-All-All-E
24 11,137.11 $10,832.39 $- $3,497.64 $2,000.00 $0.060 3.25 2.47 1
a Average measure life.
b Estimated kWh savings measured at the customer’s meter, excluding line losses.
c NPV of DSM avoided costs. Based on end use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2019 Second Amended IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act d Incremental participant cost prior to customer incentives.
e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2022 actuals.
f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives)
g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives))1 RTF. Ind_and_Ag_GreenMotorRewind_v3_1.xlsm. 2017.