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Home My WebLink About20240315Attachment 1 DSM 2023 Annual Report Supplement 1.pdf2023 ANNUAL REPORT MARCH 15, 2024 DEMAND-SIDE MANAGEMENT SUPPLEMENT 1: COST-EFFECTIVENESS Printed on recycled paper Demand-Side Management 2023 Annual Report Page i Supplement 1: Cost-Effectiveness d½ Ê¥ CÊÄãÄãÝ 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 Heating & Cooling Efficiency Program ................................................................................................20 Home Energy Report .........................................................................................................................23 Rebate Advantage ..............................................................................................................................24 Residential New Construction Program ..............................................................................................26 Shade Tree Project ..............................................................................................................................28 Weatherization Assistance for Qualified Customers ..........................................................................29 Weatherization Solutions for Eligible Customers ...............................................................................30 Commercial Energy-Saving Kits ..........................................................................................................31 Custom Projects..................................................................................................................................33 New Construction ...............................................................................................................................36 Retrofits .............................................................................................................................................41 Small Business Direct Install ...............................................................................................................50 Irrigation Efficiency Rewards ..............................................................................................................51 Demand-Side Management 2023 Annual Report Page ii Supplement 1: Cost-Effectiveness >®Ýã Ê¥ d½Ý Table 1. 2023 non-cost-effective measures ..............................................................................................10 Table 2. 2023 DSM detailed expenses by program (dollars) .....................................................................11 Table 3. 2023 Demand response program and portfolio $ per kW year .................................................13 Table 4. Cost-effectiveness of 2023 programs by benefit/cost test ..........................................................14 Demand-Side Management 2023 Annual Report Page 1 Supplement 1: Cost-Effectiveness SçÖÖ½ÃÄã 1: CÊÝã-E¥¥ã®òÄÝÝ 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 or is expected to become 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 or end the offering. This aligns with the expectations of the IPUC and OPUC. Demand-Side Management 2023 Annual Report Page 2 Supplement 1: Cost-Effectiveness /n KWhC KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͕ ŝssueĚ ŝn hD ϱϱ1͕ tŚe KWhC outlŝnes specŝĮc cost-effectiveness ŐuŝĚelŝnes Ĩoƌ eneƌŐǇ eĸcŝencǇ meĂsuƌes ĂnĚ pƌoŐƌĂms mĂnĂŐeĚ ďǇ pƌoŐƌĂm ĂĚmŝnŝstƌĂtoƌs͘ dŚe KWhC eǆpects tŚĂt meĂsuƌes ĂnĚ pƌoŐƌĂms offeƌeĚ ŝn KƌeŐon pĂss tŚe dZC test͘ /Ĩ /ĚĂŚo Woǁeƌ Ěeteƌmŝnes Ă pƌoŐƌĂm oƌ meĂsuƌe ŝs not cost-effective ďut meets one oƌ moƌe oĨ tŚe eǆceptions set ĨoƌtŚ ďǇ KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͕ tŚe compĂnǇ Įles Ăn eǆceptions ƌeƋuest ǁŝtŚ tŚe KWhC to continue offeƌŝnŐ tŚe meĂsuƌe oƌ pƌoŐƌĂm ǁŝtŚŝn ŝts KƌeŐon seƌvŝce ĂƌeĂ͘ Eon-cost-effective meĂsuƌes ĂnĚ pƌoŐƌĂms mĂǇ ďe offeƌeĚ ďǇ Ă utilŝtǇ ŝĨ tŚeǇ meet one oƌ moƌe oĨ tŚe ĨolloǁŝnŐ ĂĚĚŝtionĂl conĚŝtions specŝĮeĚ ďǇ Section 1ϯ oĨ KWhC KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ: A. dŚe meĂsuƌe pƌoĚuces sŝŐnŝĮcĂnt non-ƋuĂntiĮĂďle non-eneƌŐǇ ďeneĮts ;EEͿ B. /nclusŝon oĨ tŚe meĂsuƌe ǁŝll ŝncƌeĂse mĂƌŬet ĂcceptĂnce ĂnĚ ŝs eǆpecteĚ to leĂĚ to ƌeĚuceĚ cost oĨ tŚe meĂsuƌe C. dŚe meĂsuƌe ŝs ŝncluĚeĚ Ĩoƌ consŝstencǇ ǁŝtŚ otŚeƌ ĚemĂnĚ-sŝĚe mĂnĂŐement ;SDͿ programs in the region D. /nclusŝon oĨ tŚe meĂsuƌe Śelps ŝncƌeĂse pĂƌticŝpĂtion ŝn Ă cost-effective pƌoŐƌĂm E. dŚe pĂcŬĂŐe oĨ meĂsuƌes cĂnnot ďe cŚĂnŐeĚ ĨƌeƋuentlǇ͕ ĂnĚ tŚe meĂsuƌe ǁŝll ďe cost-effective ĚuƌŝnŐ tŚe peƌŝoĚ tŚe pƌoŐƌĂm ŝs offeƌeĚ F. dŚe meĂsuƌe oƌ pĂcŬĂŐe oĨ meĂsuƌes ŝs ŝncluĚeĚ ŝn Ă pŝlot oƌ ƌeseĂƌcŚ pƌoũect ŝntenĚeĚ to ďe offeƌeĚ to Ă lŝmŝteĚ numďeƌ oĨ customeƌs G. dŚe meĂsuƌe ŝs ƌeƋuŝƌeĚ ďǇ lĂǁ oƌ ŝs consŝstent ǁŝtŚ KWhC polŝcǇ ĂnĚͬoƌ Ěŝƌection &oƌ opeƌĂtionĂl ĂnĚ ĂĚmŝnŝstƌĂtive eĸcŝencǇ͕ /ĚĂŚo Woǁeƌ enĚeĂvoƌs to offeƌ ŝĚenticĂl pƌoŐƌĂms ŝn ďotŚ ŝts KƌeŐon ĂnĚ /ĚĂŚo ũuƌŝsĚŝctions͖ Śoǁeveƌ͕ Ěue to tŚe Ěŝffeƌent pƌŝmĂƌǇ cost-effectiveness tests ŝn eĂcŚ stĂte͕ meĂsuƌes mĂǇ not ďe offeƌeĚ ŝn ďotŚ stĂtes͘ Methodology &oƌ ŝts cost-effectiveness metŚoĚoloŐǇ͕ /ĚĂŚo Woǁeƌ ƌelŝes on tŚe Electƌŝc Woǁeƌ ZeseĂƌcŚ /nstitute ;EWZ/Ϳ EnĚ hse decŚnŝcĂl ssessment 'uŝĚe ;d'Ϳ͖ tŚe CĂlŝĨoƌnŝĂ StĂnĚĂƌĚ WƌĂctice DĂnuĂl ĂnĚ ŝts suďseƋuent ĂĚĚenĚum͖ tŚe EĂtionĂl ction WlĂn Ĩoƌ EneƌŐǇ EĸcŝencǇ͛s ;EWEEͿ hnĚeƌstĂnĚŝnŐ Cost Effectiveness oĨ EneƌŐǇ EĸcŝencǇ WƌoŐƌĂms: est WƌĂctices͕ decŚnŝcĂl DetŚoĚs͕ ĂnĚ EmeƌŐŝnŐ /ssues Ĩoƌ WolŝcǇ-DĂŬeƌs͘ &oƌ eneƌŐǇ eĸcŝencǇ pƌoŐƌĂms͕ eĂcŚ pƌoŐƌĂm͛s cost-effectiveness ŝs ƌevŝeǁeĚ ĂnnuĂllǇ Ĩƌom Ă oneͳyear peƌspective͘ dŚe ĂnnuĂl eneƌŐǇ-sĂvŝnŐs ďeneĮt vĂlue ŝs summeĚ oveƌ tŚe lŝĨe oĨ tŚe meĂsuƌe oƌ pƌoŐƌĂm ĂnĚ ŝs ĚŝscounteĚ to ƌeŇect ϮϬϮϯ ĚollĂƌs͘ dŚe ƌesult oĨ tŚe one-ǇeĂƌ peƌspective ŝs sŚoǁn ŝn dĂďle ϰ ĂnĚ tŚe Cost-Effectiveness dĂďles ďǇ WƌoŐƌĂm section ŝn tŚŝs supplement͘ dŚe ŐoĂl oĨ ĚemĂnĚ ƌesponse pƌoŐƌĂms ŝs to mŝnŝmŝǌe oƌ ĚelĂǇ tŚe neeĚ to ďuŝlĚ neǁ supplǇ-sŝĚe ƌesouƌces͘ hnlŝŬe eneƌŐǇ eĸcŝencǇ pƌoŐƌĂms oƌ supplǇ-sŝĚe ƌesouƌces͕ ĚemĂnĚ ƌesponse pƌoŐƌĂms Demand-Side Management 2023 Annual Report Page 3 Supplement 1: Cost-Effectiveness must ĂcƋuŝƌe ĂnĚ ƌetĂŝn pĂƌticŝpĂnts eĂcŚ ǇeĂƌ to mĂŝntĂŝn ĚeploǇĂďle ĚemĂnĚ-ƌeĚuction cĂpĂcŝtǇ Ĩoƌ tŚe compĂnǇ͘ /ĚĂŚo Woǁeƌ Ěeteƌmŝnes cost-effectiveness Ĩoƌ ŝts ĚemĂnĚ ƌesponse pƌoŐƌĂms usŝnŐ tŚe ĂppƌoveĚ metŚoĚ Ĩoƌ vĂluŝnŐ ĚemĂnĚ ƌesponse unĚeƌ /WhC cĂse /WC-E-Ϯ1-ϯϮ ;KƌĚeƌ Eo͘ ϯϱϯϯϲͿ ĂnĚ KWhC ocŬet Eo͘ s 1ϯϱϱ͘ dŚe ĂvoŝĚeĚ cost cĂlculĂtion Ĩoƌ ĚemĂnĚ ƌesponse pƌoŐƌĂms ŝs Ăs Ĩolloǁs: ;>evelŝǌeĚ &ŝǆeĚ Costs ʹ ĚĚŝtionĂl eneĮtsͿ ǆ Effective >oĂĚ CĂƌƌǇŝnŐ CĂpĂcŝtǇ ;E>CCͿ oĨ nnuĂl Z CĂpĂcŝtǇ CompĂƌeĚ to WƌoǆǇ Zesouƌce с Ψ peƌ Ŭt ǇeĂƌ Z voŝĚeĚ Costs EĂcŚ oĨ tŚe tŚƌee components ŚĂve ďeen upĚĂteĚ: ;EĂcŚ oĨ tŚe tŚƌee components ŚĂve ďeen upĚĂteĚ: 1. From the 2021 IRP͕ tŚe ϮϬϮϯ levelŝǌeĚ ĮǆeĚ cost vĂlue oĨ Ă Sŝmple CǇcle Comďustion duƌďŝne ;SCCdͿ ǁĂs ĚeteƌmŝneĚ to ďe Ψ1ϯϰ͘ϲϯ peƌ Ŭt peƌ ǇeĂƌ͘ 2. From the 2021 IRP͕ to Ěeteƌmŝne tŚe ĂĚĚŝtionĂl ĂncŝllĂƌǇ ďeneĮts pƌovŝĚeĚ ďǇ tŚe SCCd compĂƌeĚ to Z͕ Ăn ĂnĂlǇsŝs ǁĂs peƌĨoƌmeĚ ǁŚeƌe Z ǁĂs ƌeplĂceĚ ǁŝtŚ Ăn eƋuŝvĂlent SCCd ĂnĚ tŚe ĮǆeĚ costs oĨ tŚe SCCd ǁeƌe ƌemoveĚ Ĩƌom tŚe moĚel͘ dŚe ƌesult oĨ tŚŝs ĂnĂlǇsŝs sŚoǁeĚ tŚeƌe ǁeƌe no ĂĚĚŝtionĂl ďeneĮts ĂssocŝĂteĚ ǁŝtŚ tŚe SCCd ďecĂuse tŚe cost oĨ tŚe Ĩuel ĂnĚ SCCd plĂnt KΘD ƌeƋuŝƌeĚ to meet tŚe Z ĚemĂnĚ͘ 3. dŚe upĚĂteĚ E>CC oĨ ĂppƌoǆŝmĂtelǇ ϯ1ϲ Dt oĨ Z cĂpĂcŝtǇ compĂƌeĚ to Ă SCCd usŝnŐ 2021 IRP Ăssumptions ŝs ϲϮ͘ϴϮй͘ dŚŝs ƌesults ŝn Ă vĂlue oĨ Ψϴϰ͘ϱϳ peƌ Ŭt ǇeĂƌ Ăs tŚe ĂvoŝĚeĚ cost tŚƌesŚolĚ tŚĂt tŚe eǆŝstinŐ Z pƌoŐƌĂms neeĚ to ďe unĚeƌ to ďe consŝĚeƌeĚ cost effective͘ summĂƌǇ oĨ tŚe ĚollĂƌ peƌ Ŭt ǇeĂƌ Ĩoƌ eĂcŚ Z pƌoŐƌĂm cĂn ďe ĨounĚ ŝn dĂďle ϯ͘ Assumptions /ĚĂŚo Woǁeƌ ƌelŝes on tŚŝƌĚ-pĂƌtǇ ƌeseĂƌcŚ to oďtĂŝn sĂvŝnŐs ĂnĚ cost Ăssumptions Ĩoƌ vĂƌŝous meĂsuƌes͘ dŚese Ăssumptions Ăƌe ƌoutinelǇ ƌevŝeǁeĚ ŝnteƌnĂllǇ ĂnĚ ǁŝtŚ EE' ĂnĚ upĚĂteĚ Ăs neǁ ŝnĨoƌmĂtion ďecomes ĂvĂŝlĂďle͘ &oƌ mĂnǇ oĨ tŚe ƌesŝĚentiĂl ĂnĚ ŝƌƌŝŐĂtion meĂsuƌes ǁŝtŚŝn tŚŝs supplement͕ sĂvŝnŐs ĂnĚ costs ǁeƌe ĚeƌŝveĚ Ĩƌom eŝtŚeƌ tŚe ZeŐŝonĂl decŚnŝcĂl &oƌum ;Zd&Ϳ oƌ tŚe /ĚĂŚo Woǁeƌ EneƌŐǇ EĸcŝencǇ WotentiĂl StuĚǇ conĚucteĚ ďǇ pplŝeĚ EneƌŐǇ 'ƌoup ;E'Ϳ͘ dŚe Zd& ƌeŐulĂƌlǇ ƌevŝeǁs͕ evĂluĂtes͕ ĂnĚ ƌecommenĚs elŝŐŝďle eneƌŐǇ eĸcŝencǇ meĂsuƌes ĂnĚ pƌovŝĚes tŚe estimĂteĚ sĂvŝnŐs ĂnĚ costs ĂssocŝĂteĚ ǁŝtŚ tŚose meĂsuƌes͘ s tŚe Zd& upĚĂtes tŚese sĂvŝnŐs ĂnĚ cost Ăssumptions͕ /ĚĂŚo Woǁeƌ Ăpplŝes tŚem to cuƌƌent pƌoŐƌĂm offeƌŝnŐs ĂnĚ Ăssesses tŚe neeĚ to mĂŬe ĂnǇ pƌoŐƌĂm cŚĂnŐes͘ /ĚĂŚo Woǁeƌ stĂff pĂƌticŝpĂtes ŝn tŚe Zd& ďǇ ĂƩenĚŝnŐ montŚlǇ meetinŐs ĂnĚ contƌŝďutinŐ to vĂƌŝous suď-commŝƩees͘ epenĚŝnŐ on tŚe ǁoƌŬďooŬ ƌeĨeƌenceĚ͕ ĚĂtĂ Ĩƌom tŚe Zd& ŝs ŝn eŝtŚeƌ ϮϬ1Ϯ oƌ ϮϬ1ϲ ĚollĂƌs ĂnĚ must ďe escĂlĂteĚ to ϮϬϮϯ ĚollĂƌs͘ &oƌ costs ŝn ϮϬ1Ϯ ĚollĂƌs͕ tŚe cost Ăƌe escĂlĂteĚ ďǇ Ϯϳ͘ϳй͘ &oƌ costs ŝn ϮϬ1ϲ ĚollĂƌs͕ tŚe costs Ăƌe escĂlĂteĚ ďǇ 1ϵ͘ϳй͘ dŚese peƌcentĂŐes Ăƌe pƌovŝĚeĚ ďǇ tŚe Zd& ŝn ǁoƌŬďooŬ Zd&StĂnĚĂƌĚ/nĨoƌmĂtiontoƌŬďooŬͺvϰͺϴ͘ǆlsǆ. Demand-Side Management 2023 Annual Report Page 4 Supplement 1: Cost-Effectiveness /ĚĂŚo Woǁeƌ uses Ă tecŚnŝcĂl ƌeĨeƌence mĂnuĂl ;dZDͿ ĚevelopeĚ ďǇ D ssocŝĂtes͕ /nc͘ Ĩoƌ tŚe sĂvŝnŐs ĂnĚ cost Ăssumptions ŝn tŚe CommeƌcŝĂl ĂnĚ /nĚustƌŝĂl ;CΘ/Ϳ EneƌŐǇ EĸcŝencǇ WƌoŐƌĂm͛s Eeǁ Constƌuction ĂnĚ ZetƌoĮts options ĂnĚ tŚe DultiĨĂmŝlǇ EneƌŐǇ EĸcŝencǇ WƌoŐƌĂm͘ /n ϮϬϮϬ͕ tŚe compĂnǇ ďeŐĂn tŚe pƌocess to upĚĂte tŚe Ăssumptions ŝn tŚe CΘ/ dZD ďĂseĚ on tŚe ϮϬ1ϴ /nteƌnĂtionĂl EneƌŐǇ ConseƌvĂtion CoĚe ;/ECCͿ͘ dŚe upĚĂteĚ CΘ/ dZD ŝs tŚe souƌce Ĩoƌ most pƌescƌŝptive sĂvŝnŐs vĂlues Ĩoƌ tŚe Eeǁ Constƌuction ĂnĚ ZetƌoĮts options ŝn tŚe CΘ/ EneƌŐǇ EĸcŝencǇ pƌoŐƌĂm ĂnĚ ŚĂve ďeen ŝmplementeĚ Ăs oĨ mŝĚ-ϮϬϮ1͘ /n ϮϬϮϯ͕ /ĚĂŚo Woǁeƌ contƌĂcteĚ ǁŝtŚ D ssocŝĂtes to cƌeĂte Ă DultiĨĂmŝlǇ dZD͘ /ĚĂŚo Woǁeƌ Ălso ƌelŝes on otŚeƌ souƌces Ĩoƌ sĂvŝnŐs ĂnĚ cost Ăssumptions͕ sucŚ Ăs tŚe EoƌtŚǁest Woǁeƌ ĂnĚ ConseƌvĂtion Councŝl ;EtWCCͿ͕ EoƌtŚǁest EneƌŐǇ EĸcŝencǇ llŝĂnce ;EEEͿ͕ tŚe ĂtĂďĂse Ĩoƌ EneƌŐǇ EĸcŝencǇ Zesouƌces ;EEZͿ͕ tŚe EneƌŐǇ dƌust oĨ KƌeŐon ;EdKͿ͕ tŚe onnevŝlle Woǁeƌ ĚmŝnŝstƌĂtion ;WͿ͕ tŚŝƌĚ-pĂƌtǇ consultĂnts͕ ĂnĚ otŚeƌ ƌeŐŝonĂl utilŝties͘ KccĂsŝonĂllǇ͕ /ĚĂŚo Woǁeƌ ǁŝll Ălso use ŝnteƌnĂl enŐŝneeƌŝnŐ estimĂtes ĂnĚ cĂlculĂtions Ĩoƌ sĂvŝnŐs ĂnĚ costs ďĂseĚ on ŝnĨoƌmĂtion ŐĂtŚeƌeĚ Ĩƌom pƌevŝous pƌoũects͘ dŚe compĂnǇ Ĩƌeeǌes sĂvŝnŐs Ăssumptions ǁŚen tŚe ďuĚŐets ĂnĚ ŐoĂls Ăƌe estĂďlŝsŚeĚ Ĩoƌ tŚe neǆt cĂlenĚĂƌ ǇeĂƌ unless Ă coĚe cŚĂnŐes͕ Ă stĂnĚĂƌĚ cŚĂnŐes͕ oƌ pƌoŐƌĂm upĚĂtes necessŝtĂte Ă neeĚ to use upĚĂteĚ sĂvŝnŐs͘ dŚese Ăssumptions Ăƌe ĚŝscusseĚ ŝn moƌe ĚetĂŝl ŝn tŚe cost-effectiveness sections Ĩoƌ eĂcŚ pƌoŐƌĂm ŝn tŚe emĂnĚ-SŝĚe DĂnĂŐement ϮϬϮϯ nnuĂl Zepoƌt͘ 'eneƌĂllǇ͕ tŚe ϮϬϮϯ eneƌŐǇ sĂvŝnŐs ƌepoƌteĚ Ĩoƌ most pƌoŐƌĂms ǁŝll use tŚe Ăssumptions set Ăt tŚe ďeŐŝnnŝnŐ oĨ tŚe ǇeĂƌ͘ Kne eǆception ǁĂs ƌeŐĂƌĚŝnŐ tŚe lŝŐŚtinŐ sĂvŝnŐs Ăssumption͘ ecĂuse tŚe lŝŐŚtinŐ stĂnĚĂƌĚs Ĩƌom tŚe Energy Independence Act of 2007 ďecĂme ĨullǇ enĨoƌceĚ Ăs oĨ :ulǇ 1͕ ϮϬϮϯ͕ /ĚĂŚo Woǁeƌ ƌeĨeƌences tǁo Ěŝffeƌent lŝŐŚtinŐ ǁoƌŬďooŬs͕ one Ĩoƌ tŚe Įƌst ŚĂlĨ ĂnĚ ĂnotŚeƌ Ĩoƌ tŚe seconĚ ŚĂlĨ oĨ ϮϬϮϯ Ĩoƌ pƌoŐƌĂms tŚĂt clĂŝmeĚ sĂvŝnŐs Ĩƌom >E lŝŐŚtďulďs͘ dŚe ƌemĂŝnŝnŐ ŝnputs useĚ ŝn tŚe cost-effectiveness cĂlculĂtions Ăƌe oďtĂŝneĚ Ĩƌom tŚe /ZW pƌocess͘ /ĚĂŚo Woǁeƌ͛s 2021 IRP ǁĂs ĂcŬnoǁleĚŐeĚ ďǇ tŚe /WhC unĚeƌ cĂse /WC-E-Ϯ1-ϰϯ on Eovemďeƌ 1ϴ͕ ϮϬϮϮ͕ ĂnĚ ǁŝtŚ tŚe KWhC unĚeƌ cĂse >C ϳϴ on :ĂnuĂƌǇ 1ϯ͕ ϮϬϮϯ͘ dŚe 2021 IRP is tŚe souƌce Ĩoƌ Ăll ĮnĂncŝĂl ĂnĚ cost-effectives ĂnĂlǇsŝs Ĩoƌ tŚe ϮϬϮϯ eneƌŐǇ eĸcŝencǇ pƌoŐƌĂms͘ s noteĚ eĂƌlŝeƌ͕ tŚe 2021 IRP is Ălso useĚ to Ěeteƌmŝne tŚe cost-effectiveness tŚƌesŚolĚ Ĩoƌ tŚe Z pƌoŐƌĂms͘ Kn Septemďeƌ Ϯϵ͕ ϮϬϮϯ͕ /ĚĂŚo Woǁeƌ ĮleĚ ŝts ϮϬϮϯ /ZW ǁŝtŚ tŚe /WhC unĚeƌ cĂse /WC-E-Ϯϯ-Ϯϯ ĂnĚ ǁŝtŚ tŚe KWhC unĚeƌ cĂse >C ϴϰ͘ t tŚe EE' meetinŐ on uŐust 1ϳ͕ ϮϬϮϯ͕ /ĚĂŚo Woǁeƌ pƌesenteĚ ŝts pƌoposĂl to use ĂvoŝĚeĚ costs Ĩƌom tŚe most ƌecentlǇ ͞ĮleĚ͟ /ZW ƌĂtŚeƌ tŚĂn tŚe most ƌecentlǇ ͞ĂcŬnoǁleĚŐeĚ͟ /ZW Ĩoƌ SD pƌoŐƌĂm plĂnnŝnŐ͘ dŚe ŝntent oĨ tŚŝs sŚŝŌ ŝs to ƌeĚuce lĂŐ time ďetǁeen ǁŚen tŚe ĂvoŝĚeĚ costs Ăƌe upĚĂteĚ ĂnĚ useĚ Ĩoƌ pƌoŐƌĂm plĂnnŝnŐ ĂnĚ cost-effectiveness evĂluĂtions͘ s Ă ƌesult͕ ďeŐŝnnŝnŐ ǁŝtŚ tŚe ϮϬϮϰ pƌoŐƌĂm ǇeĂƌ͕ tŚe compĂnǇ ǁŝll noǁ use tŚe most cuƌƌent ŝnĨoƌmĂtion ĂvĂŝlĂďle Ĩoƌ ŝts SD plĂnnŝnŐ͕ evĂluĂtion͕ ĂnĚ ĂnĂlǇses͘ dŚeƌeĨoƌe͕ tŚe ϮϬϮϯ /ZW ǁŝll ďe tŚe souƌce oĨ tŚe cost-effectiveness ŝnputs Ĩoƌ tŚe ϮϬϮϰ pƌoŐƌĂm ǇeĂƌ͘ Appendix C—Technical Appendix oĨ Idaho Power’s 2021 IRP contĂŝns tŚe ĮnĂncŝĂl ĂssumptionsͶ sucŚ Ăs Ěŝscount ƌĂte͕ escĂlĂtion ƌĂte ĂnĚ lŝne losses--useĚ ŝn tŚe eneƌŐǇ eĸcŝencǇ cost-effectiveness Demand-Side Management 2023 Annual Report Page 5 Supplement 1: Cost-Effectiveness ĂnĂlǇsŝs͘ SD ĂvoŝĚeĚ costs vĂƌǇ ďǇ seĂson ĂnĚ time oĨ ĚĂǇ ĂnĚ Ăƌe ĂpplŝeĚ to Ăn enĚ-use loĂĚ sŚĂpe to oďtĂŝn tŚe vĂlue oĨ Ă pĂƌticulĂƌ meĂsuƌe oƌ pƌoŐƌĂm͘ SD ĂvoŝĚeĚ eneƌŐǇ costs Ăƌe ďĂseĚ on ďotŚ tŚe pƌoũecteĚ Ĩuel costs oĨ Ă peĂŬ-loĂĚ seƌvŝnŐ ƌesouƌce ĂnĚ ĨoƌǁĂƌĚ electƌŝcŝtǇ pƌŝces Ăs ĚeteƌmŝneĚ ďǇ /ĚĂŚo Woǁeƌ͛s poǁeƌ supplǇ moĚel͕ hZKZǆmpΠ Electƌŝc DĂƌŬet DoĚel͘ dŚe ĂvoŝĚeĚ cĂpŝtĂl cost oĨ cĂpĂcŝtǇ ŝs ďĂseĚ on Ă ŐĂs-ĮƌeĚ͕ sŝmple-cǇcle tuƌďŝne͘ dƌĂnsmŝssŝon ĂnĚ Ěŝstƌŝďution ;dΘͿ ďeneĮts Ăƌe Ălso ŝncluĚeĚ ŝn tŚe cost-effectiveness ĂnĂlǇses͘ s ƌecommenĚeĚ ďǇ tŚe EWEE͛s hnĚeƌstĂnĚŝnŐ Cost-Effectiveness oĨ EneƌŐǇ EĸcŝencǇ WƌoŐƌĂmsȪ /ĚĂŚo Woǁeƌ͛s ǁeŝŐŚteĚ ĂveƌĂŐe cost oĨ cĂpŝtĂl ;tCCͿ oĨ ϳ͘1Ϯй ŝs useĚ to Ěŝscount Ĩutuƌe ďeneĮts ĂnĚ costs to toĚĂǇ͛s ĚollĂƌs͘ Knce tŚe SD ĂvoŝĚeĚ costs ĂnĚ loĂĚ sŚĂpes Ăƌe ĂpplŝeĚ to tŚe ĂnnuĂl ŬtŚ sĂvŝnŐs oĨ Ă meĂsuƌe oƌ pƌoŐƌĂm͕ tŚe tCC ŝs useĚ to cĂlculĂte tŚe net pƌesent vĂlue ;EWsͿ oĨ tŚe ĂnnuĂl ďeneĮt Ĩoƌ tŚe hCd ĂnĚ dZC test ͬC ƌĂtios͘ ,oǁeveƌ͕ ĚeteƌmŝnŝnŐ tŚe ĂppƌopƌŝĂte Ěŝscount ƌĂte Ĩoƌ pĂƌticŝpĂnt cost ĂnĚ ďeneĮts ŝs Ěŝĸcult ďecĂuse oĨ tŚe vĂƌŝetǇ oĨ potentiĂl Ěŝscount ƌĂtes tŚĂt cĂn ďe useĚ ďǇ pĂƌticŝpĂnts͘ ecĂuse tŚe pĂƌticŝpĂnt ďeneĮt ŝs ďĂseĚ on tŚe ĂnticŝpĂteĚ ďŝll sĂvŝnŐs oĨ tŚe customeƌ͕ /ĚĂŚo Woǁeƌ ďelŝeves Ăn ĂlteƌnĂte Ěŝscount ƌĂte ŝn plĂce oĨ tŚe tCC ŝs ĂppƌopƌŝĂte͘ dŚe pĂƌticŝpĂnt ďŝll sĂvŝnŐs Ăƌe ďĂseĚ on /ĚĂŚo Woǁeƌ͛s ϮϬϮϯ ĂveƌĂŐe customeƌ seŐment ƌĂte ĂnĚ Ăƌe not escĂlĂteĚ͘ dŚe pĂƌticŝpĂnt ďŝll sĂvŝnŐs Ăƌe ĚŝscounteĚ usŝnŐ Ă ƌeĂl Ěŝscount ƌĂte oĨ ϰ͘ϳ1й͕ ǁŚŝcŚ ŝs ďĂseĚ on tŚe 2021 IRP’s tCC oĨ ϳ͘1Ϯй ĂnĚ Ăn escĂlĂtion ƌĂte oĨ Ϯ͘ϯй͘ dŚe ƌeĂl Ěŝscount ƌĂte ŝs useĚ to cĂlculĂte tŚe EWs oĨ ĂnǇ pĂƌticŝpĂnt ďeneĮts oƌ costs Ĩoƌ tŚe WCd oƌ ƌĂtepĂǇeƌ ŝmpĂct meĂsuƌe ;Z/DͿ ͬC ƌĂtios͘ dŚe ĨoƌmulĂ to cĂlculĂte tŚe ƌeĂl Ěŝscount ƌĂte ŝs Ăs Ĩolloǁs: ;;1 н tCCͿ р ;1 н EscĂlĂtionͿͿ ʹ 1 с ZeĂl >ŝne-loss peƌcentĂŐes Ăƌe ĂpplŝeĚ to tŚe meteƌeĚ-sŝte eneƌŐǇ sĂvŝnŐs to ĮnĚ tŚe eneƌŐǇ sĂvŝnŐs Ăt tŚe ŐeneƌĂtion level͘ dŚe Demand-Side Management 2023 Annual Report sŚoǁs tŚe estimĂteĚ electƌŝcĂl sĂvŝnŐs Ăt tŚe customeƌ meteƌ level͘ Cost-effectiveness ĂnĂlǇses Ăƌe ďĂseĚ on ŐeneƌĂtion-level eneƌŐǇ sĂvŝnŐs͘ dŚe ĚemĂnĚ ƌesponse pƌoŐƌĂm ƌeĚuctions Ăƌe ƌepoƌteĚ Ăt tŚe ŐeneƌĂtion level ǁŝtŚ tŚe lŝne losses͘ &oƌ tŚe cost-effectiveness cĂlculĂtions oĨ tŚe eneƌŐǇ eĸcŝencǇ pƌoŐƌĂms͕ tŚe sǇstem lŝne-loss ĨĂctoƌ oĨ ϵ͘ϲй ĂnĚ tŚe summeƌ peĂŬ lŝne-loss ĨĂctoƌ oĨ ϵ͘ϳй Ĩƌom tŚe 2021 IRP ǁeƌe utilŝǌeĚ͘ dŚe lŝne- loss peƌcentĂŐes ǁeƌe ƌe-evĂluĂteĚ ŝn pƌepĂƌĂtion Ĩoƌ tŚe 2023 IRP͘ dŚŝs stuĚǇ ĚeteƌmŝneĚ tŚĂt tŚe sǇstem ĂnĚ peĂŬ lŝne-loss ĨĂctoƌ ŝs noǁ ϳ͘ϲй͘ Sŝnce tŚese vĂlues ǁeƌe ĂvĂŝlĂďle pƌŝoƌ to tŚe summeƌ ĚemĂnĚ ƌesponse seĂson͕ /ĚĂŚo Woǁeƌ consŝĚeƌeĚ ŝt ĂppƌopƌŝĂte to ĂpplǇ tŚe upĚĂteĚ ϳ͘ϲй lŝne-loss ĨĂctoƌ ǁŚen ƌepoƌtinŐ tŚe ŐeneƌĂtion level cĂpĂcŝtǇ Ĩoƌ tŚe ĚemĂnĚ ƌesponse pƌoŐƌĂms ŝn ϮϬϮϯ͘ Conservation Adder dŚe Pacific Northwest Electric Power Planning and Conservation Act ;EoƌtŚǁest Woǁeƌ ctͿ stĂtes tŚe ĨolloǁŝnŐ: ͙ĂnǇ conseƌvĂtion oƌ ƌesouƌce sŚĂll not ďe tƌeĂteĚ Ăs ŐƌeĂteƌ tŚĂn tŚĂt oĨ ĂnǇ nonconseƌvĂtion meĂsuƌe oƌ ƌesouƌce unless tŚe ŝncƌementĂl sǇstem cost oĨ sucŚ conseƌvĂtion oƌ ƌesouƌce ŝs ŝn eǆcess oĨ 11Ϭ peƌ centum oĨ tŚe ŝncƌementĂl sǇstem cost oĨ tŚe nonconseƌvĂtion meĂsuƌe oƌ ƌesouƌce͘ Demand-Side Management 2023 Annual Report Page 6 Supplement 1: Cost-Effectiveness s Ă ƌesult oĨ tŚe EoƌtŚǁest Woǁeƌ ct͕ most utilŝties ŝn tŚe WĂcŝĮc EoƌtŚǁest ĂĚĚ Ă 1Ϭй conseƌvĂtion ĂĚĚeƌ ŝn eneƌŐǇ eĸcŝencǇ cost-effectiveness ĂnĂlǇses͘ /n KWhC KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͕ tŚe KWhC stĂtes: te suppoƌt tŚe stĂff͛s posŝtion tŚĂt tŚe effect oĨ conseƌvĂtion ŝn ƌeĚucŝnŐ unceƌtĂŝntǇ ŝn meetinŐ loĂĚ ŐƌoǁtŚ ŝs ŝncluĚeĚ ŝn tŚe ten peƌcent cost ĂĚĚeƌ ĂnĚ tŚĂt no sepĂƌĂte ĂĚũustment ŝs necessĂƌǇ͘ ĚĚŝtionĂllǇ͕ ŝn /WhC KƌĚeƌ Eo͘ ϯϮϳϴϴ ŝn CĂse Eo͘ 'EZ-E-1Ϯ-Ϭ1͕ ͞StĂff noteĚ tŚĂt ZocŬǇ DountĂŝn Woǁeƌ ĂnĚ vŝstĂ use Ă 1Ϭй conseƌvĂtion ĂĚĚeƌ ǁŚen cĂlculĂtinŐ tŚe cost-effectiveness oĨ Ăll tŚeŝƌ SD pƌoŐƌĂms͘͟ StĂff ƌecommenĚeĚ tŚe utilŝties ŚĂve tŚe option to use Ă 1Ϭй ĂĚĚeƌ͕ ĂnĚ tŚe /WhC ĂŐƌeeĚ ǁŝtŚ tŚe ƌecommenĚĂtion to Ălloǁ utilŝties to use tŚe 1Ϭй ĂĚĚeƌ ŝn tŚe cost-effectiveness ĂnĂlǇses Ĩoƌ loǁ-ŝncome pƌoŐƌĂms͘ Ōeƌ ƌevŝeǁŝnŐ tŚe pƌĂctices oĨ otŚeƌ utilŝties ŝn tŚe WĂcŝĮc EoƌtŚǁest͕ Ăs ǁell Ăs tŚe KWhC KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ ĂnĚ /WhC KƌĚeƌ ϯϮϳϴϴ͕ /ĚĂŚo Woǁeƌ Ăpplŝes tŚe 1Ϭй conseƌvĂtion ĂĚĚeƌ ŝn Ăll eneƌŐǇ eĸcŝencǇ meĂsuƌe ĂnĚ pƌoŐƌĂm cost-effectiveness ĂnĂlǇses ǁŚen cĂlculĂtinŐ tŚe dZC test͘ Net-to-Gross Eet-to-Őƌoss ;Ed'Ϳ͕ oƌ net-oĨ-Ĩƌee-ƌŝĚeƌsŚŝp ;Ed&ZͿ͕ ŝs ĚeĮneĚ ďǇ EWEE͛s Understanding Cost‑Effectiveness of Energy Efficiency Programs Ăs Ă ƌĂtio tŚĂt Ěoes tŚe ĨolloǁŝnŐ: Ěũusts tŚe ŝmpĂcts oĨ tŚe pƌoŐƌĂms so tŚĂt tŚeǇ onlǇ ƌeŇect tŚose eneƌŐǇ eĸcŝencǇ ŐĂŝns tŚĂt Ăƌe tŚe ƌesult oĨ tŚe eneƌŐǇ eĸcŝencǇ pƌoŐƌĂm͘ dŚeƌeĨoƌe͕ tŚe Ed' ĚeĚucts eneƌŐǇ sĂvŝnŐs tŚĂt ǁoulĚ ŚĂve ďeen ĂcŚŝeveĚ ǁŝtŚout tŚe eĸcŝencǇ pƌoŐƌĂm ;e͘Ő͕͘ ͚Ĩƌee-ƌŝĚeƌs͛Ϳ ĂnĚ ŝncƌeĂses sĂvŝnŐs Ĩoƌ ĂnǇ ͚spŝlloveƌ͛ effect tŚĂt occuƌs Ăs Ăn ŝnĚŝƌect ƌesult oĨ tŚe pƌoŐƌĂm͘ Sŝnce tŚe Ed' ĂƩempts to meĂsuƌe ǁŚĂt tŚe customeƌs ǁoulĚ ŚĂve Ěone ŝn tŚe Ăďsence oĨ tŚe eneƌŐǇ eĸcŝencǇ pƌoŐƌĂm͕ ŝt cĂn ďe Ěŝĸcult to Ěeteƌmŝne pƌecŝselǇ͘ CĂptuƌŝnŐ tŚe effects oĨ /ĚĂŚo Woǁeƌ͛s eneƌŐǇ eĸcŝencǇ effoƌts on Ĩƌee-ƌŝĚeƌsŚŝp ĂnĚ spŝlloveƌ ŝs Ěŝĸcult͘ ue to tŚe unceƌtĂŝntǇ suƌƌounĚŝnŐ Ed' peƌcentĂŐes͕ /ĚĂŚo Woǁeƌ useĚ Ăn Ed' oĨ 1ϬϬй Ĩoƌ neĂƌlǇ Ăll meĂsuƌe ĂnĚ pƌoŐƌĂm cost-effectiveness ĂnĂlǇses͘ SensŝtivŝtǇ ĂnĂlǇses Ăƌe conĚucteĚ to sŚoǁ ǁŚĂt tŚe mŝnŝmum Ed' peƌcentĂŐe neeĚs to ďe Ĩoƌ Ă pƌoŐƌĂm to ƌemĂŝn ;oƌ ďecomeͿ cost-effective Ĩƌom eŝtŚeƌ tŚe dZC oƌ hCd peƌspective͘ dŚese Ed' peƌcentĂŐes Ăƌe sŚoǁn ŝn tŚe pƌoŐƌĂm cost-effectiveness pĂŐes oĨ tŚŝs supplement͘ Results /ĚĂŚo Woǁeƌ cĂlculĂtes cost-effectiveness on Ă pƌoŐƌĂm ďĂsŝs ĂnĚ͕ ǁŚeƌe ƌelevĂnt͕ Ă meĂsuƌe ďĂsŝs͘ s pĂƌt oĨ Supplement 1: Cost‑Effectiveness ĂnĚ ǁŚeƌe ĂpplŝcĂďle͕ /ĚĂŚo Woǁeƌ puďlŝsŚes tŚe cost-effectiveness ďǇ meĂsuƌe͕ tŚe WCd ĂnĚ Z/D test Ăt tŚe pƌoŐƌĂm level͕ tŚe Ăssumptions ĂssocŝĂteĚ ǁŝtŚ cost-effectiveness͕ ĂnĚ tŚe souƌces ĂnĚ ĚĂtes oĨ metƌŝcs useĚ ŝn tŚe cost-effectiveness cĂlculĂtion͘ Demand-Side Management 2023 Annual Report Page 7 Supplement 1: Cost-Effectiveness dŚe ͬC ƌĂtio Ĩƌom tŚe pĂƌticŝpĂnt cost peƌspective ŝs not cĂlculĂteĚ Ĩoƌ tŚe CommeƌcŝĂl EneƌŐǇ- SĂvŝnŐ <ŝts͕ EĚucĂtionĂl ŝstƌŝďutions͕ ,ome EneƌŐǇ Zepoƌt WƌoŐƌĂm͕ SmĂll usŝness ŝƌect /nstĂll͕ teĂtŚeƌŝǌĂtion ssŝstĂnce Ĩoƌ YuĂlŝĮeĚ Customeƌs ;tYCͿ͕ ĂnĚ teĂtŚeƌŝǌĂtion Solutions Ĩoƌ ElŝŐŝďle Customeƌs pƌoŐƌĂms͘ dŚese pƌoŐƌĂms ŚĂve Ĩeǁ oƌ no pĂƌticŝpĂnt-ƌelĂteĚ costs͘ &oƌ eneƌŐǇ eĸcŝencǇ pƌoŐƌĂms͕ tŚe cost-effectiveness ĂnĂlǇses Ěo not Ăssume onŐoŝnŐ pĂƌticŝpĂnt costs͘ ,oǁeveƌ͕ ĂnticŝpĂteĚ Ĩutuƌe costs Ăƌe useĚ to Ěevelop tŚe lŝĨe-cǇcle cost-effectiveness ĂnĂlǇsŝs Ĩoƌ tŚe ,ome Energy Report Program. dŚŝs supplement contĂŝns ĂnnuĂl cost-effectiveness metƌŝcs Ĩoƌ eĂcŚ pƌoŐƌĂm usŝnŐ ĂctuĂl ŝnĨoƌmĂtion Ĩƌom ϮϬϮϯ ĂnĚ ŝncluĚes ƌesults oĨ tŚe hCd͕ dZC͕ WCd͕ ĂnĚ Z/D͘ Cuƌƌent customeƌ eneƌŐǇ ƌĂtes Ăƌe useĚ ŝn tŚe cĂlculĂtion oĨ tŚe ͬC ƌĂtios Ĩƌom Ă WCd ĂnĚ Z/D peƌspective͘ ZĂte ŝncƌeĂses Ăƌe not ĨoƌecĂsteĚ oƌ escĂlĂteĚ͘ summĂƌǇ oĨ tŚe cost-effectiveness ďǇ pƌoŐƌĂm cĂn ďe ĨounĚ ŝn dĂďle ϰ͘ /n ϮϬϮϯ͕ most oĨ /ĚĂŚo Woǁeƌ͛s eneƌŐǇ eĸcŝencǇ pƌoŐƌĂms ǁeƌe cost-effective Ĩƌom tŚe hCd peƌspective͕ eǆcept Ĩoƌ ,eĂtinŐ Θ CoolŝnŐ EĸcŝencǇ͕ ZeďĂte ĚvĂntĂŐe͕ SŚĂĚe dƌee͕ SmĂll usŝness ŝƌect /nstĂll͕ ĂnĚ tŚe tǁo ǁeĂtŚeƌŝǌĂtion pƌoŐƌĂms Ĩoƌ ŝncome-ƋuĂlŝĮeĚ customeƌs͘ dŚe ,eĂtinŐ Θ CoolŝnŐ EĸcŝencǇ WƌoŐƌĂm ŚĂĚ Ă hCd oĨ Ϭ͘ϵϰ ĂnĚ dZC oĨ Ϭ͘ϰϬ͘ dŚe pƌoŐƌĂm͛s oveƌĂll cost-effectiveness ǁĂs ŝmpĂcteĚ ďǇ tŚe Ěeclŝne ŝn oveƌĂll sĂvŝnŐs Ĩoƌ meĂsuƌes sucŚ Ăs smĂƌt tŚeƌmostĂts ĂnĚ Ăŝƌ-souƌce ŚeĂt pumps͘ /n Eovemďeƌ͕ tŚe compĂnǇ moĚŝĮeĚ tŚe pƌoŐƌĂm ďĂseĚ on tŚe upĚĂteĚ sĂvŝnŐs ĂnĚ ĂnĂlǇǌeĚ tŚe pƌoŐƌĂm ǁŝtŚ tŚe neǁest ĂvoŝĚeĚ costs Ĩƌom tŚe 2023 IRP. With tŚese cŚĂnŐes͕ tŚe pƌoŐƌĂm ŝs ĂnticŝpĂteĚ to ďe cost-effective ŐoŝnŐ ĨoƌǁĂƌĚ͘ ZeďĂte ĚvĂntĂŐe ŚĂĚ Ă hCd oĨ Ϭ͘ϵϴ ĂnĚ Ă dZC oĨ Ϭ͘ϵϯ͘ /ĚĂŚo Woǁeƌ useĚ tŚe sĂme sĂvŝnŐs ĂnĚ Ăssumptions ŝn ϮϬϮϯ Ăs ǁeƌe useĚ ŝn ϮϬϮϮ͘ dŚe Ěeclŝne ŝn hCd cost-effectiveness ǁĂs Ěue to tŚe ĂpplŝcĂtion oĨ tŚe ĂvoŝĚeĚ costs Ĩƌom tŚe 2021 IRP͘ Kn ĂveƌĂŐe tŚe ďeneĮt vĂlue ĚeclŝneĚ ϮϮй ďetǁeen tŚe pƌevŝous 2019 Seconded Amended IRP and the 2021 IRP͘ /Ĩ tŚe ĂvoŝĚeĚ costs Ĩƌom tŚe 2023 IRP are ĂpplŝeĚ͕ tŚe ďeneĮt vĂlue ŝncƌeĂses ďǇ ĂppƌoǆŝmĂtelǇ 1Ϯй͘ dŚeƌeĨoƌe͕ tŚe pƌoŐƌĂm ŝs ĂnticŝpĂteĚ to ďe cost-effective ŝn tŚe ϮϬϮϰ pƌoŐƌĂm ǇeĂƌ͘ ĚĚŝtionĂllǇ͕ ǁŚŝle ďotŚ ,eĂtinŐ Θ CoolŝnŐ EĸcŝencǇ ĂnĚ ZeďĂte ĚvĂntĂŐe sĂǁ Ă Ěeclŝne ŝn tŚe hCd cost-effectiveness ǇeĂƌ oveƌ ǇeĂƌ͕ tŚe dZC cost-effectiveness ŝmpƌoveĚ ǁŝtŚ tŚe ĂpplŝcĂtion oĨ tŚe tĂǆ cƌeĚŝts Ĩƌom tŚe Inflation Reduction Act of 2022. dŚe SŚĂĚe dƌee Wƌoũect ŚĂĚ Ă hCd oĨ Ϭ͘ϯ1 ĂnĚ dZC oĨ Ϭ͘ϰϮ͘ /n ϮϬϮϯ͕ /ĚĂŚo Woǁeƌ contƌĂcteĚ ǁŝtŚ Ă tŚŝƌĚ-pĂƌtǇ evĂluĂtoƌ to peƌĨoƌm Ăn ŝmpĂct evĂluĂtion ĂnĚ ĂuĚŝt oĨ tŚe tƌees tŚĂt ǁeƌe ĚŝstƌŝďuteĚ ŝn tŚe pĂst͘ dŚe evĂluĂtion ĨounĚ tŚĂt ǁŚŝle tŚe eǆŝstinŐ cĂlculĂtoƌ ǁĂs ĂcceptĂďle Ĩoƌ ĚeteƌmŝnŝnŐ eneƌŐǇ sĂvŝnŐs͕ tŚe moƌtĂlŝtǇ ƌĂte ǁĂs ŚŝŐŚeƌ tŚĂn pƌevŝouslǇ estimĂteĚ ĂnĚ tŚĂt tŚe sĂvŝnŐs neeĚeĚ to ďe ĂĚũusteĚ Ĩoƌ tŚe ŚeĂtinŐ ŝmpĂct sŚĂĚe tƌees ŚĂve on electƌŝcĂllǇ ŚeĂteĚ Śomes͘ /ĚĂŚo Woǁeƌ ǁoƌŬeĚ ǁŝtŚ tŚe evĂluĂtoƌ to Ěeteƌmŝne Śoǁ ďest to moĚel tŚe Ĩutuƌe sĂvŝnŐs oĨ tŚe tƌees͕ ĂnĚ tŚe evĂluĂtoƌ ƌevŝeǁeĚ /ĚĂŚo Woǁeƌ͛s upĚĂteĚ sĂvŝnŐs cĂlculĂtions Ĩoƌ tŚe tƌees ĚŝstƌŝďuteĚ ŝn ϮϬϮϯ to ensuƌe tŚe ĂĚũustments ǁeƌe ĂpplŝeĚ ŝn ĂccoƌĚĂnce ǁŝtŚ tŚe ƌecommenĚĂtions outlŝneĚ ŝn tŚe evĂluĂtion͘ dŚe ĂĚũusteĚ sĂvŝnŐs ǁeƌe tŚen ĂpplŝeĚ ŝn tŚe pƌoŐƌĂm͛s ϮϬϮϯ cost-effectiveness ĂnĂlǇsŝs͘ dŚe ŝncƌeĂseĚ eneƌŐǇ use Ĩƌom electƌŝcĂllǇ ŚeĂteĚ Śomes neŐĂteĚ mucŚ oĨ tŚe coolŝnŐ sĂvŝnŐs ďeneĮts Ĩƌom tŚe Demand-Side Management 2023 Annual Report Page 8 Supplement 1: Cost-Effectiveness sŚĂĚe tƌee͘ /n lŝŐŚt oĨ tŚe evĂluĂtion ƌesults͕ cŚĂnŐes ǁŝll neeĚ to ďe mĂĚe to ŝmpƌove tŚe offeƌŝnŐ͛s cost-effectiveness͘ /ĚĂŚo Woǁeƌ ǁŝll ǁoƌŬ ǁŝtŚ stĂŬeŚolĚeƌs to Ěevelop Ă plĂn Ĩoƌ necessĂƌǇ cŚĂnŐes to tŚe offeƌŝnŐ ŐoŝnŐ ĨoƌǁĂƌĚ͘ &ŝnĂllǇ͕ tŚe cost-effectiveness ƌĂtios ŝncluĚe tŚe costs ĂssocŝĂteĚ ǁŝtŚ tŚe ŝmpĂct evĂluĂtion͘ /Ĩ tŚe evĂluĂtion costs ǁeƌe ƌemoveĚ͕ tŚe hCd ĂnĚ dZC ƌĂtios Ĩoƌ tŚe pƌoŐƌĂm ǁoulĚ ďe Ϭ͘ϯϯ ĂnĚ Ϭ͘ϰϱ͕ ƌespectivelǇ͘ SmĂll usŝness ŝƌect /nstĂll ŚĂs Ă hCd oĨ Ϭ͘ϵϳ ĂnĚ dZC oĨ 1͘ϰϴ͘ dŚe cost-effectiveness ƌĂtios ŝncluĚe tŚe costs ĂssocŝĂteĚ ǁŝtŚ tŚe ŝmpĂct evĂluĂtion͘ /Ĩ tŚe evĂluĂtion costs ǁeƌe ƌemoveĚ͕ tŚe hCd ĂnĚ dZC ƌĂtios Ĩoƌ tŚe pƌoŐƌĂm ǁoulĚ ďe 1͘Ϭϴ ĂnĚ 1͘ϲϰ͕ ƌespectivelǇ͘ /n ϮϬϮϮ͕ /ĚĂŚo Woǁeƌ sŚĂƌeĚ tŚe cost-effectiveness cŚĂllenŐes Ĩoƌ tŚe pƌoŐƌĂm ǁŝtŚ EE'͘ dŚese cŚĂllenŐes ŝncluĚe tŚe ƌeĚuceĚ sĂvŝnŐs potentiĂl Ĩƌom scƌeǁ-ŝn lŝŐŚtďulďs ĂnĚ tŚe ŝncƌeĂseĚ costs ĂssocŝĂteĚ ǁŝtŚ mĂteƌŝĂls ĂnĚ lĂďoƌ͘ /Ĩ tŚe cost oĨ tŚŝs Ĩƌee seƌvŝce ǁeƌe to continue to ƌŝse͕ ŝt ǁoulĚ ďe ŝncƌeĂsŝnŐlǇ Ěŝĸcult Ĩoƌ tŚe pƌoŐƌĂm to ďe cost-effective Ĩƌom tŚe hCd peƌspective͘ s Ă ƌesult͕ tŚe offeƌŝnŐ closeĚ ŝn DĂƌcŚ ϮϬϮϯ͘ tYC ŚĂĚ Ă hCd ƌĂtio oĨ Ϭ͘1ϰ ĂnĚ Ă dZC oĨ Ϭ͘Ϯϯ͕ ĂnĚ teĂtŚeƌŝǌĂtion Solutions Ĩoƌ ElŝŐŝďle Customeƌs ŚĂĚ Ă hCd ƌĂtio oĨ Ϭ͘1ϯ ĂnĚ Ă dZC oĨ Ϭ͘1ϵ͘ dŚe tYC ƌĂtios ŝncluĚe tŚe sĂvŝnŐs ĂnĚ costs ĂssocŝĂteĚ ǁŝtŚ tŚe ƌe-ǁeĂtŚeƌŝǌĂtion effoƌts͘ dŚe hCd ĂnĚ dZC Ĩoƌ tŚe tYC-onlǇ poƌtion oĨ tŚe oveƌĂll pƌoŐƌĂm Ăƌe Ϭ͘1ϲ ĂnĚ Ϭ͘Ϯϱ͕ ƌespectivelǇ͘ dŚe hCd ĂnĚ dZC Ĩoƌ tŚe ƌe-ǁeĂtŚeƌŝǌĂtion effoƌts Ălone Ăƌe Ϭ͘Ϭϵ ĂnĚ Ϭ͘1Ϭ͕ ƌespectivelǇ͘ do cĂlculĂte tŚe cost-effectiveness Ĩoƌ tŚe ŝncome-ƋuĂlŝĮeĚ ǁeĂtŚeƌŝǌĂtion pƌoŐƌĂms͕ /ĚĂŚo Woǁeƌ ĂĚopteĚ tŚe ĨolloǁŝnŐ /WhC stĂff ƌecommenĚĂtions Ĩƌom CĂse Eo͘ 'EZ-E-1Ϯ-Ϭ1: • pplŝeĚ Ă 1ϬϬй Ed'͘ • ClĂŝmeĚ 1ϬϬй oĨ eneƌŐǇ sĂvŝnŐs Ĩoƌ eĂcŚ pƌoũect͘ • /ncluĚeĚ ŝnĚŝƌect ĂĚmŝnŝstƌĂtive oveƌŚeĂĚ costs͘ dŚe oveƌŚeĂĚ costs oĨ Ϯ͘ϰϴϴй ǁeƌe cĂlculĂteĚ Ĩƌom tŚe Ψ1͕Ϭϰϰ͕ϰϮϴ oĨ ŝnĚŝƌect pƌoŐƌĂm eǆpenses ĚŝvŝĚeĚ ďǇ tŚe totĂl SD eǆpenses oĨ Ψϰ1͕ϵϳϵ͕ϰϳϯ Ăs sŚoǁn ŝn ppenĚŝǆ ϯ oĨ tŚe Demand-Side Management 2022 Annual Report. • pplŝeĚ tŚe 1Ϭй conseƌvĂtion pƌeĨeƌence ĂĚĚeƌ͘ • moƌtiǌeĚ evĂluĂtion eǆpenses oveƌ Ă tŚƌee-ǇeĂƌ peƌŝoĚ͘ • ClĂŝmeĚ one ĚollĂƌ oĨ EEs Ĩoƌ eĂcŚ ĚollĂƌ oĨ utilŝtǇ ĂnĚ ĨeĚeƌĂl ĨunĚs ŝnvesteĚ ŝn ŚeĂltŚ͕ sĂĨetǇ͕ ĂnĚ ƌepĂŝƌ meĂsuƌes͘ tŚŝle tŚe tYC ĂnĚ teĂtŚeƌŝǌĂtion Solutions Ĩoƌ ElŝŐŝďle Customeƌs ƌemĂŝn not cost-effective͕ /ĚĂŚo Woǁeƌ ǁŝll continue to offeƌ tŚe pƌoŐƌĂms to tŚe compĂnǇ͛s lŝmŝteĚ-ŝncome customeƌs on Ăn onŐoŝnŐ ďĂsŝs͕ unless tŚe /ĚĂŚo ĂnĚ KƌeŐon commŝssŝons Ěŝƌect otŚeƌǁŝse͘ /ĚĂŚo Woǁeƌ ǁŝll Ălso continue to consult ǁŝtŚ EE' ĂnĚ tŚe ǁeĂtŚeƌŝǌĂtion mĂnĂŐeƌs Ăt tŚe CommunŝtǇ ction WĂƌtneƌsŚŝps to looŬ Ĩoƌ ǁĂǇs to ŝmpƌove tŚe pƌoŐƌĂms͛ cost-effectiveness͘ dŚe sectoƌ cost-effectiveness ƌĂtios ŝncluĚe Ăll tŚe ďeneĮts ĂnĚ costs ĂssocŝĂteĚ ǁŝtŚ pƌoŐƌĂms tŚĂt pƌoĚuce ƋuĂntiĮĂďle eneƌŐǇ sĂvŝnŐs͘ dŚe poƌƞolŝo cost-effectiveness ŝs tŚe sum oĨ Ăll eneƌŐǇ eĸcŝencǇ Demand-Side Management 2023 Annual Report Page 9 Supplement 1: Cost-Effectiveness Ăctivŝties͕ ŝncluĚŝnŐ tŚose tŚĂt Ěo not ŚĂve sĂvŝnŐs ĂssocŝĂteĚ͕ sucŚ Ăs oveƌŚeĂĚ eǆpenses͘ &oƌ ϮϬϮϯ͕ tŚe commeƌcŝĂl ĂnĚ ŝnĚustƌŝĂl sectoƌ ŚĂĚ Ă hCd oĨ Ϯ͘ϳϰ ĂnĚ dZC oĨ 1͘ϰϴ͕ ĂnĚ ŝƌƌŝŐĂtion sectoƌ ŚĂĚ Ă hCd oĨ Ϯ͘Ϭϲ ĂnĚ dZC oĨ Ϯ͘ϮϮ͘ dŚe ƌesŝĚentiĂl ĂnĚ poƌƞolŝo cost-effectiveness ǁĂs cĂlculĂteĚ ǁŝtŚ ĂnĚ ǁŝtŚout tŚe ďeneĮts ĂssocŝĂteĚ ǁŝtŚ tYC͕ ǁŚŝcŚ ŝs ĨunĚeĚ tŚƌouŐŚ ďĂse ƌĂtes ĂnĚ not tŚƌouŐŚ tŚe eneƌŐǇ eĸcŝencǇ ƌŝĚeƌ͘ tŚŝle tŚe pƌoŐƌĂm pƌovŝĚes ƌeĂl sĂvŝnŐs to customeƌs tŚĂt ǁoulĚ otŚeƌǁŝse ďe unĂďle to ĂffoƌĚ to ǁeĂtŚeƌŝǌe tŚeŝƌ Śome͕ ŝt ƌemĂŝns not cost-effective͘ WƌesentinŐ tŚe cost-effectiveness oĨ tŚe ƌesŝĚentiĂl sectoƌ ǁŝtŚ ĂnĚ ǁŝtŚout tYC ƌemĂŝns consŝstent ǁŝtŚ Śoǁ otŚeƌ /ĚĂŚo utilŝties pƌesent tŚeŝƌ sectoƌ ĂnĚ poƌƞolŝo cost-effectiveness ƌesults͘ tŝtŚout tYC͕ tŚe ƌesŝĚentiĂl sectoƌ ŚĂs Ă hCd oĨ 1͘1Ϯ ĂnĚ dZC oĨ Ϭ͘ϵϱ ĂnĚ tŚe poƌƞolŝo ŚĂs Ă hCd oĨ Ϯ͘Ϭϲ ĂnĚ dZC oĨ 1͘ϱ1͘ tŝtŚ tYC͕ tŚe ƌesŝĚentiĂl sectoƌ ŚĂs Ă hCd oĨ Ϭ͘ϴϳ ĂnĚ dZC oĨ Ϭ͘ϳϰ ĂnĚ tŚe poƌƞolŝo ŚĂs Ă hCd oĨ 1͘ϵϳ ĂnĚ dZC oĨ 1͘ϰϳ͘ totĂl oĨ ϴϮ out oĨ Ϯϵϱ ŝnĚŝvŝĚuĂl meĂsuƌes ŝn vĂƌŝous pƌoŐƌĂms Ăƌe not cost-effective Ĩƌom eŝtŚeƌ tŚe hCd oƌ dZC peƌspective͘ KĨ tŚe ϴϮ meĂsuƌes͕ 1Ϯ Ăƌe not cost-effective Ĩƌom tŚe hCd peƌspective͘ dǁo meĂsuƌes Ăƌe no lonŐeƌ ďeŝnŐ offeƌeĚ͕ ĂnĚ tŚƌee meĂsuƌes ǁeƌe moĚŝĮeĚ ĂnĚ ŝncentives ƌeĚuceĚ to ŝmpƌove cost-effectiveness͘ Seven meĂsuƌes ǁoulĚ ďe cost-effective ǁŝtŚout tŚe ŝnclusŝon oĨ ĂĚmŝnŝstƌĂtion eǆpenses͘ &oƌ most oĨ tŚe meĂsuƌes offeƌeĚ ŝn KƌeŐon tŚĂt ĨĂŝl tŚe dZC͕ /ĚĂŚo Woǁeƌ ĮleĚ cost-effectiveness eǆception ƌeƋuests ǁŝtŚ tŚe KWhC ŝn complŝĂnce ǁŝtŚ KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͘ DeĂsuƌes ĂnĚ pƌoŐƌĂms tŚĂt Ěo not pĂss tŚese tests mĂǇ ďe offeƌeĚ ďǇ tŚe utilŝtǇ ŝĨ tŚeǇ meet one oƌ moƌe oĨ tŚe ĂĚĚŝtionĂl conĚŝtions specŝĮeĚ ďǇ Section 1ϯ oĨ KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͘ dŚese eǆception ƌeƋuests ǁeƌe ĂppƌoveĚ unĚeƌ hD-1ϳ1Ϭ oƌ ǁŝtŚ tŚe specŝĮc pƌoŐƌĂm ĂĚvŝce ĮlŝnŐs͘ dŚe ĮlŝnŐs ĂnĚ eǆception ƌeƋuests Ăƌe noteĚ ŝn dĂďle 1͘ Table 1. 2023 non-cost-effective measures Program Number of Measures Number Fail UCT Notes EneƌŐǇ Eĸcŝent >ŝŐŚtinŐ 1 1 WƌoŐƌĂm closeĚ ŝn ϮϬϮϯ Ěue to tŚe ŝmplementĂtion oĨ ĨeĚeƌĂl lŝŐŚtinŐ stĂnĚĂƌĚs͘ ,eĂtinŐ Θ CoolŝnŐ EĸcŝencǇ 9 4 KĨ tŚe Ĩouƌ meĂsuƌes tŚĂt ĨĂŝl hCd͕ one meĂsuƌe ǁĂs ƌemoveĚ Ĩƌom tŚe pƌoŐƌĂm ĂnĚ tŚƌee meĂsuƌes ŚĂĚ ŝncentives ƌeĚuceĚ Ăs oĨ Eovemďeƌ 1͕ ϮϬϮϯ͘ ll meĂsuƌe ĨĂŝl dZC͘ WƌoŐƌĂm ƌeceŝveĚ Ă cost-effectiveness eǆception ǁŝtŚ Ěvŝce Eo͘ Ϯϯ-11 unĚeƌ KWhC KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͕ Section 1ϯ͘ ZeďĂte ĚvĂntĂŐe 6 2 dǁo meĂsuƌes ĨĂŝl hCd ďut ǁoulĚ ďe cost-effective ǁŝtŚ Ă hCd oĨ 1͘Ϯϵ ĂnĚ 1͘ϲϬ ǁŝtŚ- out tŚe ŝnclusŝon oĨ ĂĚmŝnŝstƌĂtion costs͘ &ouƌ meĂsuƌes ĨĂŝl dZC͘ Eǆception ƌeƋuest Ĩoƌ tŚe pƌoŐƌĂm ƌeƋuesteĚ ĂnĚ ĂppƌoveĚ ǁŝtŚ hD-1ϳ1Ϭ͕ KƌĚeƌ Eo͘ Ϯϯ-11Ϭ͘ ZesŝĚentiĂl Eeǁ Constƌuction 2 2 Kne meĂsuƌe ǁoulĚ ďe cost-effective ǁŝtŚ Ă hCd oĨ 1͘Ϯϵ ǁŝtŚout tŚe ŝnclusŝon oĨ ĂĚmŝnŝstƌĂtion costs͘ dŚe meĂsuƌe ŝs eǆpecteĚ to ďe cost-effective ŝn ϮϬϮϰ͘ /ĚĂŚo onlǇ program. Custom Wƌoũects-EneƌŐǇ Management 3 2 dǁo offeƌŝnŐs ĨĂŝl hCd ĂnĚ dZC ďut ǁoulĚ ďe cost-effective unĚeƌ ďotŚ tests ǁŝtŚout ĂĚmŝnŝstƌĂtion costs͘ Deets KWhC KƌĚeƌ Eo͘ ϵϰ-ϱϵϬ͕ Section 1Ϭ͘ Kne coŚoƌt offeƌŝnŐ pĂsses hCd ďut ĨĂŝls dZC ǁŝtŚout ĂĚmŝnŝstƌĂtion costs͖ Śoǁeveƌ͕ pĂƌticŝpĂtion ŝn tŚe coŚoƌt leĚ to cĂpŝtĂl pƌoũects totĂlŝnŐ ϴϮϲ͕Ϯϵϴ ŬtŚ pĂŝĚ ŝn ϮϬϮϯ ǁŝtŚŝn C/EE͘ Eeǁ Constƌuction ĂnĚ ZetƌoĮts 3 0 dŚƌee Ŭŝt conĮŐuƌĂtions cĂƌƌŝeĚ oveƌ Ĩƌom ϮϬϮ1 to ϮϬϮϮ Ĩƌom ŝnventoƌǇ͘ SŝnŐle Ŭŝt con- ĮŐuƌĂtion offeƌeĚ ŝn ϮϬϮϮ͘ tŝll monŝtoƌ ŝn-seƌvŝce ƌĂtes to upĚĂte sĂvŝnŐs͘ KffeƌŝnŐ to close ŝn ϮϬϮϯ Ěue to cost-effectiveness͘ Demand-Side Management 2023 Annual Report Page 10 Supplement 1: Cost-Effectiveness WƌoŐƌĂm Eumďeƌ oĨ DeĂsuƌes Eumďeƌ &Ăŝl hCd Eotes New Construction 16 1 All measures pass UCT. Offered in Idaho only. One measure would be cost-effective with a TRC of 1.00 without inclusion of administration costs. Retrofits 42 0 All measures offered in Idaho only. All measures pass UCT. dotĂl 82 1Ϯ 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, Shade Tree Project, 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. ϮϬϮϯ SD etĂŝleĚ Eǆpenses ďǇ WƌoŐƌĂm Included in this supplement is a detailed breakout of program expenses shown in Appendix 2 of the Demand-Side Management 2023 Annual Report. These expenses are broken out by funding source and major-expense type (labor/administration, materials, other expenses, purchased services, and incentives). dĂďle Ϯ͘ ϮϬϮϯ SD ĚetĂŝleĚ eǆpenses ďǇ pƌoŐƌĂm ;ĚollĂƌsͿ SectoƌͬWƌoŐƌĂm /ĚĂŚo ZŝĚeƌ KƌeŐon ZŝĚeƌ /ĚĂŚo Woǁeƌ dotĂl WƌoŐƌĂm EneƌŐǇ EĸcŝencǇ dotĂl $ Ϯ1͕ϴϬϵ͕ϱϲϵ $ ϱϳ1͕ϴϯϳ $ 1͕ϱϳϰ͕1ϴϵ $ Ϯϯ͕ϵϱϱ͕ϱϵϰ ZesŝĚentiĂl dotĂl ϯ͕ϱϲϬ͕ϵϲϱ ϴϰ͕Ϭϴϯ 1͕ϰϲϲ͕ϱϲϱ ϱ͕111͕ϲ1ϯ EĂsǇ SĂvŝnŐs: >oǁ-/ncome EneƌŐǇ EĸcŝencǇ EĚucĂtion ...––͕ 146,232 1ϰϲ͕ϮϯϮ Labor/Administrative Expense.....................................–– 21,227 Ϯ1͕ϮϮϳ Materials and Equipment ............................................–––– Other Expense .............................................................–– 5 ϱ Purchased Services ......................................................–– 125,000 1Ϯϱ͕ϬϬϬ EĚucĂtionĂl ŝstƌŝďutions ................................................. ϴϴϬ͕ϱϲϴ Ϯ1͕ϳϮϬ – ϵϬϮ͕Ϯϴϳ Labor/Administrative Expense..................................... 8,216 434 – ϴ͕ϲϱϬ Materials and Equipment ............................................ 711,365 16,659 – ϳϮϴ͕ϬϮϰ Other Expense ............................................................. 22,085 1,162 – Ϯϯ͕Ϯϰϳ Purchased Services ...................................................... 138,902 3,464 – 1ϰϮ͕ϯϲϲ EneƌŐǇ Eĸcŝent >ŝŐŚtinŐ ................................................... Ϯϳϴ͕ϲ1Ϭ 1ϱ͕ϱϴϲ ;ϬͿ Ϯϵϰ͕1ϵϳ Incentives .................................................................... 139,391 8,279 – 1ϰϳ͕ϲϳϬ Labor/Administrative Expense..................................... 6,761 357 (0) ϳ͕11ϴ Other Expense ............................................................. 13 1 – 1ϰ Purchased Services ...................................................... 132,445 6,950 – 1ϯϵ͕ϯϵϱ ,eĂtinŐ Θ CoolŝnŐ EĸcŝencǇ WƌoŐƌĂm .............................. ϱϵϯ͕ϰϬϳ ϯϬ͕ϲϰϬ – ϲϮϰ͕Ϭϰϳ Incentives .................................................................... 300,454 15,550 – ϯ1ϲ͕ϬϬϰ Labor/Administrative Expense..................................... 157,114 8,269 – 1ϲϱ͕ϯϴϯ Demand-Side Management 2023 Annual Report Page 11 Supplement 1: Cost-Effectiveness SectoƌͬWƌoŐƌĂm /ĚĂŚo ZŝĚeƌ KƌeŐon ZŝĚeƌ /ĚĂŚo Woǁeƌ dotĂl WƌoŐƌĂm Materials and Equipment ............................................ 40 2 – ϰϮ Other Expense ............................................................. 11,961 572 – 1Ϯ͕ϱϯϯ Purchased Services ...................................................... 123,839 6,247 – 1ϯϬ͕Ϭϴϱ ,ome EneƌŐǇ uĚŝt ........................................................... ϮϯϬ͕Ϭ11 –– ϮϯϬ͕Ϭ11 Labor/Administrative Expense..................................... 85,842 –– ϴϱ͕ϴϰϮ Materials and Equipment ............................................ 119 –– 11ϵ Other Expense ............................................................. 45,803 –– ϰϱ͕ϴϬϯ Purchased Services ...................................................... 98,246 –– ϵϴ͕Ϯϰϲ ,ome EneƌŐǇ Zepoƌt WƌoŐƌĂm ϴϴϯ͕ϱϬϱ –– ϴϴϯ͕ϱϬϱ Incentives .................................................................... 866,117 –– ϴϲϲ͕11ϳ Labor/Administrative Expense..................................... 17,388 –– 1ϳ͕ϯϴϴ Other Expense ............................................................. (0)–– ;ϬͿ DultiĨĂmŝlǇ EneƌŐǇ EĸcŝencǇ ........................................... ϮϮ͕ϳϱϴ 1͕Ϯ1ϲ – Ϯϯ͕ϵϳϰ Labor/Administrative Expense..................................... 18,958 1,016 – 1ϵ͕ϵϳϰ Other Expense ............................................................. 3,800 200 – ϰ͕ϬϬϬ KƌeŐon ZesŝĚentiĂl teĂtŚeƌŝǌĂtion .................................– ϳ͕ϴϲϬ – ϳ͕ϴϲϬ Labor/Administrative Expense.....................................– 5,029 – ϱ͕ϬϮϵ Other Expense .............................................................– 1,683 – 1͕ϲϴϯ Purchased Services ......................................................– 1,148 – 1͕1ϰϴ ZeďĂte ĚvĂntĂŐe ............................................................. 1ϯϬ͕Ϯϯϯ ϲ͕ϴϲϳ – 1ϯϳ͕1ϬϬ Incentives .................................................................... 75,000 4,000 – ϳϵ͕ϬϬϬ Labor/Administrative Expense..................................... 28,320 1,491 – Ϯϵ͕ϴ1Ϭ Other Expense ............................................................. 12,113 576 – 1Ϯ͕ϲϵϬ Purchased Services ...................................................... 14,800 800 – 1ϱ͕ϲϬϬ ZesŝĚentiĂl Eeǁ Constƌuction WƌoŐƌĂm ........................... 1ϵϱ͕1ϬϮ 1ϵϰ – 1ϵϱ͕Ϯϵϲ Incentives .................................................................... 109,500 –– 1Ϭϵ͕ϱϬϬ Labor/Administrative Expense..................................... 42,624 –– ϰϮ͕ϲϮϰ Other Expense ............................................................. 42,979 194 – ϰϯ͕1ϳϯ SŚĂĚe dƌee Wƌoũect ............................................................ ϮϲϮ͕ϯϰϰ – – ϮϲϮ͕ϯϰϰ Labor/Administrative Expense..................................... 45,791 – – ϰϱ͕ϳϵ1 Materials and Equipment ............................................ 164 – – 1ϲϰ Other Expense ............................................................. 18,784 – – 1ϴ͕ϳϴϰ Purchased Services ...................................................... 197,605 – – 1ϵϳ͕ϲϬϱ teĂtŚeƌŝǌĂtion ssŝstĂnce Ĩoƌ YuĂlŝĮeĚ Customeƌs ............. – – 1͕ϯ1ϳ͕Ϭϰ1 1͕ϯ1ϳ͕Ϭϰ1 Labor/Administrative Expense..................................... – – 73,212 ϳϯ͕Ϯ1Ϯ Other Expense ............................................................. – – 51 ϱ1 Purchased Services ...................................................... – – 1,243,779 1,243,779 teĂtŚeƌŝǌĂtion Solutions Ĩoƌ ElŝŐŝďle Customeƌs ............. ϴϰ͕ϰϮϴ – ϯ͕ϮϵϮ ϴϳ͕ϳ1ϵ Labor/Administrative Expense..................................... 277 – 3,292 ϯ͕ϱϲϵ Other Expense ............................................................. 1,098 – – 1͕Ϭϵϴ Purchased Services ...................................................... 83,052 – – ϴϯ͕ϬϱϮ CommeƌcŝĂlͬ/nĚustƌŝĂl dotĂl 1ϲ͕ϳϳϯ͕ϴϲϯ ϯϱϵ͕ϵϮϲ 1͕ϮϮϰ 1ϳ͕1ϯϱ͕Ϭ1ϯ CommeƌcŝĂl EneƌŐǇ-SĂvŝnŐ <ŝts ........................................ ϱϯ͕1ϲϳ Ϯ͕ϯϵϳ – ϱϱ͕ϱϲϯ Labor/Administrative Expense..................................... 5,219 291 – ϱ͕ϱϬϵ Other Expense ............................................................. 1,651 87 – 1,737 Purchased Services ...................................................... 46,297 2,019 – ϰϴ͕ϯ1ϳ Custom Wƌoũects ................................................................ 11͕ϮϮ1͕ϬϬϴ 1ϯϲ͕ϵϰϯ 1͕ϮϮϰ 11͕ϯϱϵ͕1ϳϲ Incentives .................................................................... 8,795,637 24,929 – ϴ͕ϴϮϬ͕ϱϲϱ Labor/Administrative Expense..................................... 471,661 24,850 1,224 ϰϵϳ͕ϳϯϱ Materials and Equipment ............................................ 100 5 – 1Ϭϲ Demand-Side Management 2023 Annual Report Page 12 Supplement 1: Cost-Effectiveness SectoƌͬWƌoŐƌĂm /ĚĂŚo ZŝĚeƌ KƌeŐon ZŝĚeƌ /ĚĂŚo Woǁeƌ dotĂl WƌoŐƌĂm Other Expense ............................................................. 315,308 28,747 – ϯϰϰ͕Ϭϱϱ Purchased Services ...................................................... 1,638,302 58,413 – 1͕ϲϵϲ͕ϳ1ϱ Eeǁ Constƌuction ............................................................. Ϯ͕1ϯϵ͕ϲϬϯ Ϯϵ͕Ϭϯϯ – Ϯ͕1ϲϴ͕ϲϯϲ Incentives .................................................................... 1,709,747 11,216 – 1͕ϳϮϬ͕ϵϲϯ Labor/Administrative Expense..................................... 175,549 9,289 – 1ϴϰ͕ϴϯϴ Other Expense ............................................................. 6,738 355 – ϳ͕ϬϵϮ Purchased Services ...................................................... 247,570 8,174 – Ϯϱϱ͕ϳϰϯ ZetƌoĮts ............................................................................ ϯ͕ϬϬϮ͕ϲϴ1 1ϴϮ͕Ϯϴϯ – ϯ͕1ϴϰ͕ϵϲϰ Incentives .................................................................... 2,223,999 141,325 – Ϯ͕ϯϲϱ͕ϯϮϰ Labor/Administrative Expense..................................... 136,777 7,224 – 1ϰϰ͕ϬϬϮ Materials and Equipment ............................................ 966 0 – ϵϲϲ Other Expense ............................................................. 9,001 474 – ϵ͕ϰϳϰ Purchased Services ...................................................... 631,938 33,260 – ϲϲϱ͕1ϵϴ SmĂll usŝness ŝƌect /nstĂll ............................................. ϯϱϳ͕ϰϬϰ ϵ͕ϮϳϬ – ϯϲϲ͕ϲϳϰ Labor/Administrative Expense..................................... 5,879 321 – ϲ͕ϮϬϬ Other Expense ............................................................. 34,388 1,810 – ϯϲ͕1ϵϴ Purchased Services ...................................................... 317,137 7,139 – ϯϮϰ͕Ϯϳϲ /ƌƌŝŐĂtion dotĂl 1͕ϰϳϰ͕ϳϰ1 1Ϯϳ͕ϴϮϳ 1Ϭϲ͕ϯϵϵ 1͕ϳϬϴ͕ϵϲϳ /ƌƌŝŐĂtion EĸcŝencǇ ZeǁĂƌĚs ............................................ 1͕ϰϳϰ͕ϳϰ1 1Ϯϳ͕ϴϮϳ 1Ϭϲ͕ϯϵϵ 1͕ϳϬϴ͕ϵϲϳ Incentives .................................................................... 1,103,512 108,230 – 1͕Ϯ11͕ϳϰϮ Labor/Administrative Expense..................................... 301,459 15,997 106,399 ϰϮϯ͕ϴϱϰ Materials and Equipment ............................................ 1,717 90 – 1͕ϴϬϳ Other Expense ............................................................. 67,099 3,467 – ϳϬ͕ϱϲϲ Purchased Services ...................................................... 954 44 – ϵϵϴ DĂƌŬet dƌĂnsĨoƌmĂtion dotĂl Ϯ͕ϱϴϵ͕ϵϴϳ 1ϯϲ͕ϯ1ϱ ʹ Ϯ͕ϳϮϲ͕ϯϬϮ EE ................................................................................. Ϯ͕ϱϴϵ͕ϵϴϳ 1ϯϲ͕ϯ1ϱ ʹ Ϯ͕ϳϮϲ͕ϯϬϮ Purchased Services ...................................................... 2,589,987 136,315 – Ϯ͕ϳϮϲ͕ϯϬϮ KtŚeƌ WƌoŐƌĂm ĂnĚ ctivŝties dotĂl $ Ϯ͕ϳϰϱ͕1ϰϰ $ 1ϰϱ͕ϳϲ1 $ ;1͕ϯϱϴͿ $ Ϯ͕ϴϴϵ͕ϱϰϳ CommeƌcŝĂlͬ/nĚustƌŝĂl EneƌŐǇ EĸcŝencǇ KveƌŚeĂĚ ............. ϴϵϬ͕ϯϬϬ ϰϳ͕Ϭϱϱ ;1Ϳ ϵϯϳ͕ϯϱϰ Labor/Administrative Expense..................................... 780,642 41,558 – ϴϮϮ͕ϮϬϬ Other Expense ............................................................. 83,299 4,110 (1) ϴϳ͕ϰϬϴ Purchased Services ...................................................... 26,359 1,387 – Ϯϳ͕ϳϰϲ EneƌŐǇ EĸcŝencǇ ŝƌect WƌoŐƌĂm KveƌŚeĂĚ .................... ϮϵϬ͕ϳϮϵ 1ϱ͕ϯ1ϳ – ϯϬϲ͕Ϭϰϲ Labor/Administrative Expense..................................... 278,971 14,698 – Ϯϵϯ͕ϲϲϵ Other Expense ............................................................. 11,758 619 – 1Ϯ͕ϯϳϲ KƌeŐon CommeƌcŝĂl uĚŝt ................................................... – ϲ͕ϰϬϮ – ϲ͕ϰϬϮ Labor/Administrative Expense..................................... – 1,053 – 1͕Ϭϱϯ Other Expense ............................................................. – 149 – 1ϰϵ Purchased Services ...................................................... – 5,200 – ϱ͕ϮϬϬ ZesŝĚentiĂl EneƌŐǇ EĸcŝencǇ EĚucĂtion /nŝtiĂtive ................ ϯϱϵ͕ϮϰϮ 1ϯ͕ϰϯϬ ;1͕ϯϱϳͿ ϯϳ1͕ϯ1ϲ Labor/Administrative Expense..................................... 122,565 6,426 (1,357) 1Ϯϳ͕ϲϯϰ Materials and Equipment ............................................ 75,626 1,475 – ϳϳ͕1Ϭ1 Other Expense ............................................................. 79,041 3,959 – ϴϯ͕ϬϬϬ Purchased Services ...................................................... 82,011 1,570 – ϴϯ͕ϱϴϬ ZesŝĚentiĂl EneƌŐǇ EĸcŝencǇ KveƌŚeĂĚ ........................... 1͕ϮϬϰ͕ϴϳϮ ϲϯ͕ϱϱϳ – 1͕Ϯϲϴ͕ϰϮϵ Labor/Administrative Expense..................................... 256,514 14,307 – ϮϳϬ͕ϴϮ1 Materials and Equipment ............................................– (119)– ;11ϵͿ Other Expense ............................................................. 935,606 48,979 – ϵϴϰ͕ϱϴϱ Purchased Services ...................................................... 12,752 390 – 1ϯ͕1ϰϮ Demand-Side Management 2023 Annual Report Page 13 Supplement 1: Cost-Effectiveness SectoƌͬWƌoŐƌĂm /ĚĂŚo ZŝĚeƌ KƌeŐon ZŝĚeƌ /ĚĂŚo Woǁeƌ dotĂl WƌoŐƌĂm /nĚŝƌect WƌoŐƌĂm Eǆpenses dotĂl $ ϳϵϱ͕ϰϬ1 $ ϰϵ͕ϰ1Ϭ $ 1ϵϵ͕ϲ1ϲ $ 1͕Ϭϰϰ͕ϰϮϴ EneƌŐǇ EĸcŝencǇ ccountinŐ ĂnĚ nĂlǇsŝs ...................... ϵϱϮ͕ϰϮϰ ϰϴ͕ϰϲ1 1ϵϵ͕ϲ1ϲ 1͕ϮϬϬ͕ϱϬ1 Labor/Administrative Expense..................................... 437,181 23,019 189,352 ϲϰϵ͕ϱϱϯ Other Expense ............................................................. 37,886 719 10,264 ϰϴ͕ϴϲϵ Purchased Services ...................................................... 477,357 24,722 – ϱϬϮ͕Ϭϳϵ EneƌŐǇ EĸcŝencǇ ĚvŝsoƌǇ 'ƌoup ..................................... 1ϰ͕ϰϮϮ ϳϲϵ – 1ϱ͕1ϵ1 Labor/Administrative Expense..................................... 11,674 624 – 1Ϯ͕Ϯϵϴ Other Expense ............................................................. 2,749 145 – Ϯ͕ϴϵϰ SpecŝĂl ccountinŐ Entƌŝes ............................................... ;1ϳ1͕ϰϰϱͿ 1ϴϬ – ;1ϳ1͕ϮϲϰͿ Labor/Administrative Expense..................................... (175,313)–– ;1ϳϱ͕ϯ1ϯͿ Special Accounting Entry ............................................. 3,869 180 – ϰ͕Ϭϰϵ emĂnĚ Zesponse dotĂl $ Ϯ͕Ϯϴϵ͕ϯϱϵ $ ϱϴϲ͕Ϭϳϴ $ ϴ͕ϰϴϴ͕1ϲϱ $ 11͕ϯϲϯ͕ϲϬϮ ZesŝĚentiĂl dotĂl 1͕ϱϯϲ͕ϴϳϯ ϴϱ͕ϬϲϬ ϯϲϱ͕ϲϵϬ 1͕ϵϴϳ͕ϲϮϯ ͬC Cool CƌeĚŝt ................................................................. 1͕ϱϯϲ͕ϴϳϯ ϴϱ͕ϬϲϬ ϯϲϱ͕ϲϵϬ 1͕ϵϴϳ͕ϲϮϯ Incentives ....................................................................– 4,115 365,690 ϯϲϵ͕ϴϬϱ Labor/Administrative Expense..................................... 97,273 5,128 – 1ϬϮ͕ϰϬ1 Materials and Equipment ............................................ 920,136 48,887 – ϵϲϵ͕ϬϮϯ Other Expense ............................................................. 78,971 3,777 – ϴϮ͕ϳϰϵ Purchased Services ...................................................... 440,494 23,152 – ϰϲϯ͕ϲϰϱ CommeƌcŝĂlͬ/nĚustƌŝĂl dotĂl 1ϯϱ͕ϳϯ1 ϮϰϮ͕1ϯϯ ϲϵϴ͕Ϯϴϱ 1͕Ϭϳϲ͕1ϰϵ &leǆ WeĂŬ WƌoŐƌĂm ............................................................ 1ϯϱ͕ϳϯ1 ϮϰϮ͕1ϯϯ ϲϵϴ͕Ϯϴϱ 1͕Ϭϳϲ͕1ϰϵ Incentives ....................................................................– 236,885 694,935 ϵϯ1͕ϴ1ϵ Labor/Administrative Expense..................................... 93,503 4,931 3,350 1Ϭ1͕ϳϴϰ Other Expense ............................................................. 5,628 296 – ϱ͕ϵϮϰ Purchased Services ...................................................... 36,600 21 – ϯϲ͕ϲϮ1 /ƌƌŝŐĂtion dotĂl ϲ1ϲ͕ϳϱϱ Ϯϱϴ͕ϴϴϰ ϳ͕ϰϮϰ͕1ϵϬ ϴ͕Ϯϵϵ͕ϴϯϬ /ƌƌŝŐĂtion WeĂŬ ZeǁĂƌĚs ................................................... ϲ1ϲ͕ϳϱϱ Ϯϱϴ͕ϴϴϰ ϳ͕ϰϮϰ͕1ϵϬ ϴ͕Ϯϵϵ͕ϴϯϬ Incentives .................................................................... – 231,527 7,394,482 ϳ͕ϲϮϲ͕ϬϬϴ Labor/Administrative Expense..................................... 161,748 8,568 29,708 ϮϬϬ͕ϬϮϰ Materials and Equipment ............................................ 39,949 2,103 – ϰϮ͕Ϭϱ1 Other Expense ............................................................. 52,794 3,242 – ϱϲ͕Ϭϯϲ Purchased Services ...................................................... 362,264 13,445 – ϯϳϱ͕ϳϬϵ 'ƌĂnĚ dotĂl $ ϯϬ͕ϮϮϵ͕ϰϲϬ $ 1͕ϰϴϵ͕ϰϬϬ $ 1Ϭ͕ϮϲϬ͕ϲ1ϯ $ ϰ1͕ϵϳϵ͕ϰϳϯ Note: Total does not sum due to rounding. dĂďle ϯ͘ ϮϬϮϯ emĂnĚ ƌesponse pƌoŐƌĂm ĂnĚ poƌƞolŝo Ψ peƌ Ŭt ǇeĂƌ WƌoŐƌĂm DĂǆ emĂnĚ CĂpĂcŝtǇ ;DtͿ DĂǆ emĂnĚ CĂpĂcŝtǇ ;ŬtͿ ϮϬϮϯ Eǆpenses ϮϬϮϯ EstimĂteĚ DĂǆ Eǆpenses ;ϲϬ ,ouƌsͿ 1 Ψ peƌ Ŭt ǇeĂƌ 2 A/C Cool Credit 25.3 25,324 $1,987,623 $1,617,818 $29.93 Flex Peak Programs 38.8 38,827 $1,076,149 $1,413,398 $36.40 Irrigation Peak Rewards 252.1 252,066 $8,299,830 $2,429,905 $42.57 dotĂl emĂnĚ Zesponse Woƌƞolŝo ϯ1ϲ͘Ϯ ϯ1ϲ͕Ϯ1ϳ Ψ11͕ϯϲϯ͕ϲϬϮ Ψϱ͕ϰϲ1͕1Ϯ1 ΨϰϬ͘ϴϬ 1 2023 expenses with estimated variable payments based on maximum 60 hours of operation. A/C Cool Credit Estimated Max Expenses adjusted for demand response units purchased in bulk in 2023 and transferred to overheads in 2024. Total does not sum due to rounding. 2 $ per kW year = 2023 Estimated Max Expenses 60 Hours/Max Demand Capacity kW. Demand-Side Management 2023 Annual Report Page 14 Supplement 1: Cost-Effectiveness dĂďle ϰ͘ Cost-effectiveness oĨ ϮϬϮϯ pƌoŐƌĂms ďǇ ďeneĮtͬcost test WƌoŐƌĂmͬSectoƌ hCd dZC RIM WCd Educational Distributions ..................................................................... 1.76 2.07 0.50 N/A Energy Efficient Lighting1 ...................................................................... 1.69 1.51 0.44 4.07 Heating & Cooling Efficiency Program .................................................. 0.94 0.40 0.36 0.88 Home Energy Report Program .............................................................. 1.32 1.45 0.49 n/a Multifamily Energy Efficiency Program2................................................n/a n/a n/a n/a Rebate Advantage ................................................................................ 0.98 0.93 0.28 4.23 Residential New Construction Program ................................................ 1.05 1.25 0.34 3.85 Shade Tree Project ................................................................................ 0.31 0.42 0.27 n/a Weatherization Assistance for Qualified Customers ............................ 0.14 0.23 0.11 n/a Weatherization Solutions for Eligible Customers ................................. 0.13 0.19 0.10 n/a ZesŝĚentiĂl EneƌŐǇ EĸcŝencǇ Sectoƌ 3................................................... 1͘1Ϯ Ϭ͘ϵϱ Ϭ͘ϰ1 ϯ͘ϯϴ Commercial and Industrial Energy Efficiency Program Custom Projects ............................................................................. 2.91 1.44 0.95 1.41 New Construction .......................................................................... 2.78 2.74 0.70 3.81 Retrofits ......................................................................................... 2.35 1.17 0.68 1.53 Commercial Energy-Saving Kits1 ........................................................... 1.02 1.17 0.50 n/a Small Business Direct Install4 ................................................................ 0.97 1.48 0.47 n/a CommeƌcŝĂlͬ/nĚustƌŝĂl EneƌŐǇ EĸcŝencǇ Sectoƌ 5 ................................ Ϯ͘ϳϰ 1͘ϰϴ Ϭ͘ϴϱ 1͘ϲϯ Irrigation Efficiency Rewards ................................................................ 2.05 2.22 0.84 2.29 /ƌƌŝŐĂtion EneƌŐǇ EĸcŝencǇ Sectoƌ 6...................................................... Ϯ͘Ϭϲ Ϯ͘ϮϮ Ϭ͘ϴϰ Ϯ͘Ϯϵ EneƌŐǇ EĸcŝencǇ Woƌƞolŝo 7 .................................................................. Ϯ͘Ϭϲ 1͘ϱ1 Ϭ͘ϳϱ 1͘ϴϵ 1 Program closed June 30, 2023. 2 Program launched on November 1, 2023, and incurred costs, but no savings were realized in 2023. 3 Residential sector cost-effectiveness excludes WAQC benefits and costs. If included, the UCT, TRC, RIM, and PCT would be 0.87, 0.74, 0.37, and 2.73, respectively. 4 Program closed March 31, 2023. 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 1.97, 1.47, 0.73, and 1.88, respectively. Page 15 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness CÊÝã-E¥¥ã®òÄÝÝ d½Ý ù WÙÊ¦ÙÃ EĚucĂtionĂl ŝstƌŝďutions SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ....................................................$1,589,536 $902,287 1.76 TRC Test ..................................................1,865,167 902,287 2.07 RIM Test ..................................................1,589,536 3,201,680 0.50 PCT ........................................................ N/A N/A N/A Cost /nputs ZeĨ Program Administration ....................................................................................$902,287 Program Incentives ............................................................................................–I dotĂl hC .............................................................................................................$ϵϬϮ͕Ϯϴϳ P Measure Equipment and Installation (Incremental Participant Cost) ...............$–M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ..................................3,960,690 NPV Cumulative Energy (kWh) ......................................28,454,914 $1,589,536 S 10% Credit (Northwest Power Act) ................................158,954 dotĂl Electƌŝc SĂvŝnŐs ...........................................................$1͕ϳϰϴ͕ϰϴϵ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ........................$ 2,299,392 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives........................................$–NUI NEBs ................................................................................$ 116,677 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest UC Test .......................................................= S * NTG = P TRC Test .....................................................= (A + NUI + NEB) * NTG = P RIM Test .....................................................= S * NTG = P + (B * NTG) PCT ............................................................N/A N/A ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions Discount Rate Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................57% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eotes : Energy savings as reported by Tinker for the 2022–2023 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 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes Student Energy Efficiency Kit (SEEK) Program 2022–2023 kit offering. Kits include: high-efficiency showerhead, showertimer, 3 LEDs, FilterTone alarm, digital thermometer, LED nightlight. No kit Kit IPC_Student Kits 10 229.22 $115.19 $8.66 –– $0.178 2.83 3.32 1 Welcome Kit Q1-Q2 2023 Four 1,050 to 1,489 lumen general purpose lightbulbs; Two LED night lights No kit Kit IPC_Welcome Kit 10 43.16 $17.81 $0.33 – – $0.412 1.00 1.12 2, 3 Welcome Kit Q3-Q4 2023 Four 1,050 to 1,489 lumen general purpose lightbulbs (no savings); Two LED night lights No kit Kit IPC_Welcome Kit 8 24.00 $7.90 $0.329 1.00 1.10 3 Nightlight Give away LED night light baseline lightbulb Lamp ResLightingExterior 8 12.00 $3.95 – – – $0.129 2.56 2.82 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 2021 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 2023 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 2022–2023 Annual Report. 2023. 2 RTF. ResLighting_Lightbulbs_v9_4.xlsm. 2021. 3 DNV GL. Idaho Power Educational Distributions Impact and Process Evaluation. 2020. zeĂƌ : 2023 WƌoŐƌĂm : Educational Distributions DĂƌŬet SeŐment : Residential WƌoŐƌĂm dǇpe : Energy Efficiency Page 17 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness EneƌŐǇ Eĸcŝent >ŝŐŚtinŐ SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults Cost /nputs ZeĨ Program Administration ....................................................................................$146,527 Program Incentives ............................................................................................147,670 I dotĂl hC .............................................................................................................$Ϯϵϰ͕1ϵϳ P Measure Equipment and Installation (Incremental Participant Cost)$255,996 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) .................................883,491 NPV Cumulative Energy (kWh) .....................................9,670,680 $496,956 S 10% Credit (Northwest Power Act) ...............................49,696 dotĂl Electƌŝc SĂvŝnŐs ..........................................................$ϱϰϲ͕ϲϱϮ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings .......................$830,247 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives......................................$–NUI NEBs .............................................................................$63,150 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions Discount Rate Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................59% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eote: NEBs include PV of periodic lightbulb replacement costs. Program closed June 30, 2023. SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ...........................................................$496,956 $294,197 1.69 TRC Test .........................................................609,802 402,523 1.51 RIM Test .........................................................496,956 1,124,444 0.44 PCT ................................................................1,041,067 255,996 4.07 Page 18 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD lteƌnĂte Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $2.40 $0.32 $1.83 $1.00 $0.166 1.36 1.14 1 Globe Retail_LED_Globe_250 to 1049 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 3.49 $1.80 $0.33 $2.06 $0.50 $0.166 1.67 0.87 1,2 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 $3.69 $0.28 $1.66 $1.00 $0.166 1.69 1.52 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 $3.40 $0.28 $1.81 $1.00 $0.166 1.62 1.38 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 $2.32 $0.26 $1.61 $0.50 $0.166 1.86 1.19 1 Reflectors and Outdoor Retail_LED_Reflectors and Outdoor_1050 to 1489 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 4.14 $2.13 $0.27 $0.50 $1.00 $0.166 1.26 2.20 1 Reflectors and Outdoor Retail_LED_Reflectors and Outdoor_1490 to 2600 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 8.84 $4.55 $0.33 $0.01 $2.00 $0.166 1.31 3.62 1 Reflectors and Outdoor Retail_LED_Reflectors and Outdoor_250 to 1049 lumens Baseline lightbulb Fixture Res Lighting Interior and Exterior 13 4.65 $2.40 $0.34 $0.59 $1.00 $0.166 1.35 2.19 1 LED Fixture Retailer Retail_Bathroom Vanity_1000 to 1999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 5.35 $3.51 $0.13 $2.17 $1.00 $0.166 1.86 1.31 3 LED Fixture Retailer Retail_Bathroom Vanity_2000 to 3999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 10.42 $6.85 $0.43 $4.24 $2.00 $0.166 1.84 1.33 3 LED Fixture Retailer Retail_Ceiling and Wall Flush Mount _500 to 999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 3.33 $2.19 $0.13 $0.93 $0.50 $0.166 2.08 1.71 3 LED Fixture Retailer Retail_Ceiling and Wall Flush Mount _1000 to 1999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 6.13 $4.03 $0.13 $1.70 $1.00 $0.166 2.00 1.68 3 LED Fixture Retailer Retail_Ceiling and Wall Flush Mount _2000 to 3999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 11.93 $7.84 $0.56 $3.32 $2.00 $0.166 1.97 1.73 3 LED Fixture Retailer Ceiling and Wall Flush Mount _4000 to 7999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 22.35 $14.68 $0.82 $6.22 $3.00 $0.166 2.19 1.71 3 LED Fixture Retailer Retail_Downlight Fixture_500 to 999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 2.13 $1.40 $0.13 $0.10 $1.00 $0.166 1.03 3.68 3 LED Fixture Retailer Retail_Downlight Fixture_1000 to 1999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 3.91 $2.57 $0.56 $0.19 $1.00 $0.166 1.56 4.04 3 LED Fixture Retailer Retail_Downlight Fixture_2000 to 3999 lumens Baseline fixture Fixture Res Lighting Interior and Exterior 20 7.62 $5.01 $0.82 $0.38 $1.00 $0.166 2.21 3.85 3 LED Fixture Retailer Retail_Exterior Porch_500 to 999 lumens Baseline fixture Fixture Res Lighting Exterior 20 3.38 $2.02 $0.01 $0.40 $0.75 $0.166 1.54 2.33 3 LED Fixture Retailer Retail_Exterior Porch_1000 to 1999 lumens Baseline fixture Fixture Res Lighting Exterior 20 6.22 $3.72 $0.26 $0.74 $1.00 $0.166 1.83 2.46 3 zeĂƌ : 2023 WƌoŐƌĂm : Energy Efficient Lighting DĂƌŬet SeŐment : Residential WƌoŐƌĂm dǇpe : Energy Efficiency Page 19 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD lteƌnĂte Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes LED Fixture Retailer Retail_Exterior Porch_2000 to 3999 lumens Baseline fixture Fixture Res Lighting Exterior 20 12.11 $7.25 $0.39 $1.43 $3.00 $0.166 1.45 2.43 3 LED Fixture Retailer Exterior Porch_4000 to 7999 lumens Baseline fixture Fixture Res Lighting Exterior 20 22.68 $13.58 $0.78 $2.69 $4.00 $0.166 1.75 2.44 3 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 2021 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 2023 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 Measure cost-effective without inclusion of admin costs 3 RTF. ResLighting_Lightbulbs_v9_3.xlsm. 2021. Page 20 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness ,eĂtinŐ Θ CoolŝnŐ EĸcŝencǇ WƌoŐƌĂm SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ...........................................................$589,238 $624,047 0.94 TRC Test .........................................................787,470 1,987,191 0.40 RIM Test .........................................................589,238 1,645,641 0.36 PCT ................................................................1,476,905 1,679,147 0.88 Cost /nputs ZeĨ Program Administration .....................................................................................$308,044 Program Incentives .............................................................................................316,004 I dotĂl hC ..............................................................................................................$ϲϮϰ͕Ϭϰϳ P Measure Equipment and Installation (Incremental Participant Cost) ................$1,679,147 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ........................................1,040,069 NPV Cumulative Energy (kWh) ............................................11,805,033 $589,238 S 10% Credit (Northwest Power Act) ......................................58,924 dotĂl Electƌŝc SĂvŝnŐs .................................................................$ϲϰϴ͕1ϲϮ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ..............................$1,021,593 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives..............................................$–NUI NEBs ......................................................................................$139,308 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................106% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eote: Participant costs offset by tax credit available as part of the Inflation Reduction Act of 2022. Page 21 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes Heat Pump Conversion Existing and New 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 18 3,573.08 $2,036.45 – $6,016.22 $800.00 $0.296 1.10 0.32 1, 2 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 18 151.62 $86.41 – $2,111.29 $250.00 $0.296 0.29 0.04 1, 3 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 9,508.67 $5,724.27 – $9,138.43 $1,000.00 $0.296 1.50 0.53 2, 4 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 10,540.00 $6,345.13 – $7,282.09 $3,000.00 $0.296 1.04 0.67 2, 4 Ductless Heat Pump Zonal to DHP. (Heating & Cooling Zone Weighted Average) Zonal Electric Unit R-All-HVAC- ERconvertDHP-2023 weighted 15 1,164.07 $454.10 $814.67 $3,088.55 $750.00 $0.296 0.41 0.38 5, 6 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 1,705.70 $946.41 – $362.15 $300.00 $0.296 1.18 1.20 7 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 56.66 $95.44 – $110.50 $50.00 $0.296 1.43 0.82 2, 8 High-Efficiency Air Conditioner Minimum 17 SEER; minimum 13 EER Current practice baseline Unit R-All-HVAC-CAC-All-All-E 18 196.32 $330.70 – $565.29 $150.00 $0.296 1.59 0.58 2, 8 Evaporative Cooler Evaporative Cooler Central A/C Unit R-All-HVAC-CAC-All-All-E 12 653.12 $871.54 – $220.70 $150.00 $0.296 2.54 2.31 9 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 20 436.00 $196.89 – $526.68 $350.00 $0.296 0.41 0.33 6, 10 Electronically Commutated Motor (ECM) Blower Motor ECM Blower Motor permanent split capacitor (PSC) motor Unit R-All-Bld-Bldg-All-All-R 18 2,318.83 $1,451.31 – $300.00 $50.00 $0.296 1.97 1.62 11 Whole-House Fan Whole-House Fan Displaced forced air dx cooling Unit R-All-HVAC-CAC-All-All-E 18 456.60 $769.15 – $700.00 $200.00 $0.296 2.29 1.01 11 zeĂƌ : 2023 WƌoŐƌĂm : Heating & Cooling Efficiency Program DĂƌŬet SeŐment : Residential WƌoŐƌĂm dǇpe : Energy Efficiency Page 22 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes Smart Thermostat Smart Thermostat Non wi-fi enabled thermostat/no thermostat Unit R-All-HVAC-ER-All-All-E 7 301.85 $67.90 – $210.24 $75.00 $0.296 0.41 0.25 6, 12 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 2021 IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. d Incremental participant cost prior to customer incentives. Participant costs include tax credit from the Inflation Reduction Act of 2022. e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2023 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. ResSF&MHExistingHVAC_v6_1.xlsx. 2022. Weighted average of 2023 participants in heating and cooling zones 1-3. 2 Measure not cost-effective from TRC perspective. 3 Measure removed from the offering as of November 1, 2023 4 RTF. ResGSHP_v2_7. 2016. Weighted average of 2023 participants in heating and cooling zones 1-3. 5 RTF. ResDHPforZonal_v6_1.xlsm. 2023. Weighted average of 2023 participants in heating and cooling zones 1-3. 6 Measure not cost-effective. Offering modified in as of November 1, 2023. 7 RTF. ResHPWH_v6_3.xlsm. 2023. Measure cost-effective without inclusion of admin costs. 8 RTF. ResEfficientCentralAC_v2_2.xlsm. 2023. 9 New Mexico Technical Resource Manual for the Calculation of Energy Efficiency Savings. Evaporative Cooling. Sante Fe. Discounted by 44.4% for proportion evaporative coolers replacing refrigerated air. 2019. 10 RTF. ResSFDuctSealing_v7_3.xlsm. 2023. 11 Idaho Power engineering calculations based on Integrated Design Lab inputs. 2015. 12 RTF. ResConnectedTstats_v3.1.xlsm. 2023. Page 23 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness ,ome EneƌŐǇ Zepoƌt SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest UC Test ....................................................= S * NTG = P TRC Test ..................................................= (A + NUI + NEB) * NTG = P RIM Test ..................................................= S * NTG = P + (B * NTG) PCT ......................................................... N/A N/A ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................76% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ...........................................................$1,161,909 $883,505 1.32 TRC Test .........................................................1,278,100 883,505 1.45 RIM Test .........................................................1,161,909 2,380,737 0.49 PCT ................................................................ N/A N/A N/A Eote : 2023 savings as reported by Harris Utility Consumer Analytics is 17,737,130 Wh. Idaho Power discounting savings by 0.44% for reporting and analysis as recommended by evaluators to account for potential double-counting of savings. Percentage will be reviewed in future evaluations. Cost /nputs ZeĨ Program Administration .....................................................................................$ 883,505 Program Incentives .............................................................................................–I dotĂl hC ..............................................................................................................$ϴϴϯ͕ϱϬϱ P Measure Equipment and Installation (Incremental Participant Cost) ................$–M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ........................................17,659,087 NPV Cumulative Energy (kWh) ............................................19,355,910 $1,161,909 S 10% Credit (Northwest Power Act) ......................................116,191 dotĂl Electƌŝc SĂvŝnŐs .................................................................$1͕Ϯϳϴ͕1ϬϬ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ..............................$ 1,497,232 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives..............................................$–NUI NEBs ......................................................................................$–NEB Page 24 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness ZeďĂte ĚvĂntĂŐe SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ............................................................$134,342 $137,100 0.98 TRC Test ..........................................................147,776 159,600 0.93 RIM Test ..........................................................134,342 487,536 0.28 PCT .................................................................429,437 101,500 4.23 Cost /nputs ZeĨ Program Administration .....................................................................................$ 58,100 Program Incentives .............................................................................................79,000 I dotĂl hC ..............................................................................................................$1ϯϳ͕1ϬϬ P Measure Equipment and Installation (Incremental Participant Cost) ................$101,500 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ..............................................214,236 NPV Cumulative Energy (kWh) ..................................................3,470,681 $ 134,342 S 10% Credit (Northwest Power Act) ............................................13,434 dotĂl Electƌŝc SĂvŝnŐs .......................................................................$1ϰϳ͕ϳϳϲ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ....................................$350,437 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives..................................................$–NUI NEBs ..........................................................................................$–NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................102% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eote: Participant costs offset by $2,500 tax credit available to the home builder as part of the Inflation Reduction Act of 2022, Section 45L Tax Credit for Energy Efficient New Homes. Page 25 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness zeĂƌ : 2023 WƌoŐƌĂm : Rebate Advantage DĂƌŬet SeŐment : Residential WƌoŐƌĂm dǇpe : Energy Efficiency eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $1,287.28 – $703.09 $1,000.00 $0.271 0.82 1.12 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 $1,877.50 – $703.09 $1,000.00 $0.271 1.03 1.36 1 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 $1,878.65 – $703.09 $1,000.00 $0.271 1.03 1.36 1 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 $1,880.35 – $703.09 $1,000.00 $0.271 1.03 1.36 1 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 $2,374.10 – $703.09 $1,000.00 $0.271 1.17 1.50 1 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 $1,604.21 – $2,800.82 $1,000.00 $0.271 0.94 0.50 1, 2, 3 NEEM home NEEM_electric_ HZ2_CZ1 Manufactured home built to HUD code. Home R-All-HVAC-ER-All- All-E 43 3,733.25 $2,292.50 – $2,800.82 $1,000.00 $0.271 1.14 0.66 1, 3 NEEM home NEEM_electric_ HZ2_CZ2 Manufactured home built to HUD code. Home R-All-HVAC-ER-All- All-E 43 3,735.67 $2,293.99 – $2,800.82 $1,000.00 $0.271 1.14 0.66 1, 3 NEEM home NEEM_electric_ HZ2_CZ3 Manufactured home built to HUD code. Home R-All-HVAC-ER-All- All-E 43 3,739.15 $2,296.13 – $2,800.82 $1,000.00 $0.271 1.14 0.66 1, 3 NEEM home NEEM_electric_ HZ3_CZ1 Manufactured home built to HUD code. Home R-All-HVAC-ER-All- All-E 44 4,679.39 $2,891.60 – $2,800.82 $1,000.00 $0.271 1.27 0.78 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 2021 IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. d Incremental participant cost prior to customer incentives. Participant costs include tax credit from the Inflation Reduction Act of 2022. e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2023 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_v5_1.xlsm. 2023. 2 Measure cost-effective from UCT perspective without the inclusion of admin expenses. ³ Measure not cost-effective from TRC perspective. Page 26 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness ZesŝĚentiĂl Eeǁ Constƌuction WƌoŐƌĂm SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test .........................................................$204,177 $195,296 1.05 TRC Test .......................................................302,149 241,468 1.25 RIM Test .......................................................204,177 607,349 0.34 PCT ..............................................................599,106 155,672 3.85 Cost /nputs ZeĨ Program Administration ....................................................................................$85,796 Program Incentives ............................................................................................109,500 I dotĂl hC .............................................................................................................$1ϵϱ͕Ϯϵϲ P Measure Equipment and Installation (Incremental Participant Cost) ...............$155,672 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) .........................................234,945 NPV Cumulative Energy (kWh) .............................................3,926,534 $204,177 S 10% Credit (Northwest Power Act) .......................................20,418 dotĂl Electƌŝc SĂvŝnŐs ..................................................................$ϮϮϰ͕ϱϵϱ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Savings .....................................$412,053 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives.............................................$–NUI NEBs .....................................................................................$77,553 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................95% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eotes : 2018 International Energy Conservation Code (IECC) with amendments adopted in Idaho in 2021. 2023 cost-effectiveness ratios include evaluation expenses. If evaluation expense were removed from the program’s cost-effectiveness, the UCT and TRC would be 1.23 and 1.42, respectively. Participant costs offset by $2,500 tax credit available to the home builder as part of the Inflation Reduction Act of 2022, Section 45L Tax Credit for Energy Efficient New Homes. Page 27 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 1,186.28 $1,025.14 $1,068.51 $2,886.70 $1,200.00 $0.365 0.63 0.66 1, 2 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 59 2,218.83 $1,933.29 $1,178.81 $1,504.36 $1,500.00 $0.365 0.84 1.43 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 58 5,171.12 $4,493.93 $1,286.06 $2,318.36 $2,000.00 $0.365 1.16 1.48 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 2021 IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. d Incremental participant cost prior to customer incentives. Participant costs include tax credit from the Inflation Reduction Act of 2022. e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2023 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. 2023 average per home savings. Costs and NEBs from RTF. RESNCMTHouse_ID_v3_1_.xlsm. 2019. 2 Measure not cost-effective. Will be monitored in 2024. zeĂƌ : 2023 WƌoŐƌĂm : Residential New Construction Program DĂƌŬet SeŐment : Residential WƌoŐƌĂm dǇpe : Energy Efficiency Page 28 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness SŚĂĚe dƌee Wƌoũect SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ............................................................$81,739 $262,344 0.31 TRC Test ..........................................................109,957 262,344 0.42 RIM Test ..........................................................81,739 302,649 0.27 PCT .................................................................N/A N/A N/A Cost /nputs ZeĨ Program Administration .....................................................................................$262,344 Program Incentives .............................................................................................–I dotĂl hC ..............................................................................................................$ϮϲϮ͕ϯϰϰ P Measure Equipment and Installation (Incremental Participant Cost) ................$–M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) from 2019 plantings .............11,199 Cumulative Energy (kWh) from 2023 plantings .........................820,035 NPV Cumulative Energy (kWh) ..................................................164,533 $65,919 S 10% Credit (Northwest Power Act) ............................................6,592 dotĂl Electƌŝc SĂvŝnŐs .......................................................................$ϳϮ͕ϱ1Ϭ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ....................................$32,504 B KtŚeƌ eneĮts Non-Energy Impacts (Therms) ...................................................$(11,466)NEI NEBs ..........................................................................................$34,262 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest UC Test .....................................................= S * NTG = P TRC Test ...................................................= ((A + NEI) * NTG)+NEB = P RIM Test ...................................................= S * NTG = P + (B * NTG) PCT ..........................................................N/A N/A ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................124% Minimum NTG Sensitivity ................................................................................................396% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eote: Annual Report shows incremental savings from the 2019 planting year. Cost-effectiveness based on the trees distributed in 2023 to coincide with the 2023 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. Non-energy impacts include costs associated with increased home heating energy. Other non-energy benefits associated with air quality, stormwater runoff, and carbon dioxide. 2023 cost-effectiveness ratios include evaluation expenses. If evaluation expense were removed from the program’s cost-effectiveness, the UCT and TRC would be 0.33 and 0.45, respectively. Page 29 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness teĂtŚeƌŝǌĂtion ssŝstĂnce Ĩoƌ YuĂlŝĮeĚ Customeƌs SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio Total UC Test .....................$194,716 $1,361,613 0.14 TRC Test ...................489,805 2,159,840 0.23 RIM Test ...................194,716 1,804,971 0.11 PCT ..........................N/A N/A N/A WAQC Only UC Test .....................$162,992 $994,392 0.16 TRC Test ...................454,910 1,792,619 0.25 RIM Test ...................162,992 1,365,518 0.12 PCT ..........................N/A N/A N/A Re-weatherization Only UC Test .....................$31,724 $367,220 0.09 TRC Test ...................34,896 367,220 0.10 RIM Test ...................31,724 439,453 0.07 PCT ..........................N/A N/A N/A Cost /nputs tYC KnlǇ Ze- teĂtŚeƌŝǌĂtion dotĂl ZeĨ Program Administration ..................................................................$ $156,955 32,573 189,528 Community Action Partnership (CAP) Agency Payments ................ $813,298 325,732 1,139,030 dotĂl hC ...........................................................................................$ ΨϵϳϬ͕Ϯϱϯ ϯϱϴ͕ϯϬϲ Ψ1͕ϯϮϴ͕ϱϱϴ P Accruals/Reversal of Carryover Dollars ...........................................(11,517)– (11,517) dotĂl WƌoŐƌĂm Eǆpenses ..................................................................ϵϱϴ͕ϳϯϲ ϯϱϴ͕ϯϬϲ 1͕ϯ1ϳ͕Ϭϰ1 Idaho Power Indirect Overhead Expense Allocation—2.488% ........$24,140 8,915 33,055 OH Additional State Funding .................................................................798,227 –798,227 M Eet eneĮt /nputs ;EWsͿ tYC KnlǇ Ze- teĂtŚeƌŝǌĂtion dotĂl ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) .........................................263,060 51,200 314,260 NPV Cumulative Energy (kWh) .............................................$3,909,144 760,846 4,669,990 Avoided Costs .......................................................................$162,992 31,724 194,716 S 10% Credit (Northwest Power Act) .......................................$16,299 3,172 19,472 dotĂl Electƌŝc SĂvŝnŐs ..................................................................$1ϳϵ͕ϮϵϮ ϯϰ͕ϴϵϲ Ϯ1ϰ͕1ϴϳ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ...............................$371,125 72,233 443,358 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives............................................$–––NUI NEBs .................................................................................... Health and Safety ..........................................................$271,167 –271,167 Repair ............................................................................4,451 –4,451 Other .............................................................................––– NEBs Total .............................................................................$Ϯϳϱ͕ϲ1ϴ –Ϯϳϱ͕ϲ1ϴ NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) .................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 ..............................4.71% Escalation Rate .........................................................................2.30% Net-to-Gross (NTG) ...................................................................100% Minimum NTG Sensitivity .........................................................699% Average Customer Segment Rate/kWh ....................................$0.087 Line Losses ................................................................................9.60% Eotes: Savings updated in 2020 and 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 30 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness teĂtŚeƌŝǌĂtion Solutions Ĩoƌ ElŝŐŝďle Customeƌs SeŐment : Residential ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ............................................................$11,267 $89,902 0.13 TRC Test ..........................................................17,093 89,902 0.19 RIM Test ..........................................................11,267 115,556 0.10 PCT .................................................................N/A N/A N/A Cost /nputs ZeĨ Program Administration .....................................................................................$12,644 Weatherization LLC Payments ............................................................................75,075 dotĂl WƌoŐƌĂm Eǆpenses .....................................................................................$ϴϳ͕ϳ1ϵ dotĂl hC ..............................................................................................................$ϴϳ͕ϳ1ϵ P Idaho Power Indirect Overhead Expense Allocation—2.488% ...........................2,182 OH Additional State Funding ....................................................................................–M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ..............................................18,184 NPV Cumulative Energy (kWh) ..................................................270,219 $11,267 S 10% Credit (Northwest Power Act) ............................................1,127 dotĂl Electƌŝc SĂvŝnŐs .......................................................................$1Ϯ͕ϯϵϰ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ....................................$25,654 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives..................................................$–NUI NEBs .......................................................................................... Health and Safety ................................................................1,695 Repair ..................................................................................2,195 Other ...................................................................................809 NEBs Total ..................................................................................$ϰ͕ϲϵϵ NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................798% Average Customer Segment Rate/kWh ...........................................................................$0.087 Line Losses .......................................................................................................................9.60% Eotes: Savings updated in 2020 and 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 31 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness CommeƌcŝĂl EneƌŐǇ-SĂvŝnŐ <ŝts SeŐment : Commercial ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ........................................................$56,567 $55,563 1.02 TRC Test ......................................................65,280 55,563 1.17 RIM Test ......................................................56,567 113,982 0.50 PCT .............................................................N/A N/A N/A Cost /nputs ZeĨ Program Administration ....................................................................................$55,563 Program Incentives ............................................................................................–I dotĂl hC .............................................................................................................$ϱϱ͕ϱϲϯ P Measure Equipment and Installation (Incremental Participant Cost) ...............$–M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ....................................190,827 NPV Cumulative Energy (kWh) ........................................1,093,906 $56,567 S 10% Credit (Northwest Power Act) ..................................5,657 dotĂl Electƌŝc SĂvŝnŐs .............................................................$ϲϮ͕ϮϮϰ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ..........................$58,418 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives........................................$–NUI NEBs ................................................................................$3,055 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest UC Test ....................................................= S * NTG = P TRC Test ..................................................= (A + NUI + NEB) * NTG = P RIM Test ..................................................= S * NTG = P + (B * NTG) PCT ..........................................................N/A N/A ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................98% Average Customer Segment Rate/kWh ...........................................................................$0.058 Line Losses .......................................................................................................................9.60% Eotes: NEBs include PV of periodic lightbulb replacement costs for direct-install LED lightbulbs and water, waste water, and therm savings from water-saving devices. Program closed June 30, 2023. Page 32 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 6 170.84 $50.64 $2.74 –– $0.291 1.02 1.17 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 2021 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 2023 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 Estimated savings based on average hours of use by building type and self reported electric water heat saturations. Hours of use from TRM. Installations rates from 2022 evaluation. zeĂƌ : 2023 WƌoŐƌĂm : Commercial Energy-Saving Kits DĂƌŬet SeŐment : Commercial WƌoŐƌĂm dǇpe : Energy Efficiency Page 33 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness Custom Wƌoũects SeŐment : Industrial ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ........................................................$33,011,082 $11,359,176 2.91 TRC Test ......................................................37,706,076 26,228,419 1.44 RIM Test ......................................................33,011,082 34,567,071 0.95 PCT ............................................................. $33,422,345 23,689,808 1.41 Cost /nputs ZeĨ Program Administration ....................................................................................$2,538,611 Program Incentives ............................................................................................8,820,565 I dotĂl hC .............................................................................................................$11͕ϯϱϵ͕1ϳϲ P Measure Equipment and Installation (Incremental Participant Cost) ...............$23,689,808 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ....................................60,667,088 NPV Cumulative Energy (kWh) ........................................637,787,255 $33,011,082 S 10% Credit (Northwest Power Act) ..................................3,301,108 dotĂl Electƌŝc SĂvŝnŐs .............................................................$ϯϲ͕ϯ1Ϯ͕1ϵ1 A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Savings ................................$23,207,895 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives........................................$–NUI NEBs ................................................................................$ 1,393,885 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................34% Average Customer Segment Rate/kWh ...........................................................................$0.037 Line Losses .......................................................................................................................9.60% Eotes: 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 34 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $183.39 – $164.20 $15.00 $0.044 4.79 1.08 1 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 $245.40 – $183.19 $20.00 $0.044 4.80 1.26 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 $344.26 – $209.31 $25.00 $0.044 5.33 1.52 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 $370.82 – $229.88 $30.00 $0.044 5.10 1.50 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 $431.83 – $280.92 $40.00 $0.044 4.81 1.44 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 $464.74 – $310.99 $50.00 $0.044 4.49 1.40 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 $488.75 – $366.78 $60.00 $0.044 4.20 1.27 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 $503.01 – $396.46 $75.00 $0.044 3.79 1.22 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 $663.90 – $491.81 $100.00 $0.044 3.76 1.29 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 $766.90 – $490.22 $125.00 $0.044 3.60 1.46 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 $911.63 – $546.05 $150.00 $0.044 3.58 1.54 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 $1,209.20 – $657.37 $200.00 $0.044 3.57 1.67 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 $1,463.58 – $844.89 $250.00 $0.044 3.50 1.59 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 $1,747.21 – $854.01 $300.00 $0.044 3.49 1.82 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 $2,036.92 – $895.10 $350.00 $0.044 3.49 1.98 1 zeĂƌ : 2023 WƌoŐƌĂm : Custom Projects DĂƌŬet SeŐment : Industrial WƌoŐƌĂm dǇpe : Energy Efficiency Page 35 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $2,309.55 – $999.75 $400.00 $0.044 3.47 2.01 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 $2,593.89 – $1,092.80 $450.00 $0.044 3.47 2.05 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 $2,886.12 – $1,180.59 $500.00 $0.044 3.47 2.10 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 $3,905.94 – $1,776.70 $600.00 $0.044 3.72 1.93 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 $4,537.58 – $1,938.36 $700.00 $0.044 3.71 2.03 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 $5,174.81 – $2,150.67 $800.00 $0.044 3.71 2.07 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 $5,809.33 – $2,371.02 $900.00 $0.044 3.70 2.10 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 $6,427.53 – $2,555.22 $1,000.00 $0.044 2.55 1.73 1 Continuous Energy Improvement Cohort for Schools Strategic energy management offering No change Participant Commercial- School-Misc 1 75,405.00 $3,556.40 – $48,889.00 $1,885.13 $0.044 0.68 0.07 2, 3 Water Supply Optimization Cohort Strategic energy management offering No change Participant I-WaterSupply- Mot-All-All-All-U 1 553,108.00 $31,472.45 – $2,489.75 $1,742.82 $0.044 1.20 1.28 2, 4 Find & Fix Energy management offering No change Participant I-All-SecTotal-All- All-All-E 1 591,263.00 $33,956.64 – $12,375.00 $11,766.83 $0.044 0.89 0.97 2, 4 Compressed Air Leak Repairs Energy management offering No change Participant I-All-SecTotal-All- All-All-E 1 5,190,646.00 $298,102.36 – $114,415.49 $98,464.44 $0.044 0.91 0.95 2, 4 Facility Tune up Energy management offering No change Participant I-All-SecTotal-All- All-All-E 1 1,150,703.00 $66,085.66 – $9,000.00 $9,000.00 $0.044 1.10 1.21 2, 4 a Average measure life. b Estimated kWh savings measured at the customer’s meter, excluding line losses. c NPV of DSM avoided costs. Based on end-use load shape, measure life, savings including line losses, and avoided costs by pricing period as acknowledged in the 2021 IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. d Incremental participant cost prior to customer incentives. e Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2023 actuals. f UCT Ratio = (NPV DSM Avoided Costs) / ((Admin Cost/kWh * kWh Savings) + Incentives) g TRC Ratio = ((NPV DSM Avoided Costs * 110%) + NEB) / ((Admin Cost/kWh * kWh Savings) + Incentives + (Incremental Participant Cost - Incentives)) 1 RTF. Ind_and_Ag_GreenMotorRewind_v4_0.xlsm. 2022. 2 2023 total cohort savings. 3 Offering cost-effective from UCT perspective without inclusion of admin costs. Participation in the cohort lead to capital projects totaling 826,298 kWh paid in 2023 within CIEE. 4 Offering cost-effective from UCT and TRC perspective without inclusion of admin costs. Page 36 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness Eeǁ Constƌuction SeŐment : Commercial ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test .......................................................$ 6,033,395 $2,168,636 2.78 TRC Test .....................................................8,190,196 2,990,934 2.74 RIM Test .....................................................6,033,395 8,581,653 0.70 PCT ............................................................9,687,440 2,543,260 3.81 Cost /nputs ZeĨ Program Administration .....................................................................................$447,674 Program Incentives .............................................................................................1,720,963 I dotĂl hC ..............................................................................................................$Ϯ͕1ϲϴ͕ϲϯϲ P Measure Equipment and Installation (Incremental Participant Cost) ................$2,543,260 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ....................................10,642,465 NPV Cumulative Energy (kWh) ........................................111,884,031 $6,033,395 S 10% Credit (Northwest Power Act) ..................................603,340 dotĂl Electƌŝc SĂvŝnŐs .............................................................$ϲ͕ϲϯϲ͕ϳϯϱ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ..........................$6,413,017 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives........................................$–NUI NEBs ................................................................................$1,553,461 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................36% Average Customer Segment Rate/kWh ...........................................................................$0.058 Line Losses .......................................................................................................................9.60% Eotes : Non-energy benefits/impacts on a $/kWh for each end-use. Based on 2019 impact evaluation. Page 37 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $0.24 – $0.13 $0.10 $0.044 1.99 1.75 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 $0.47 – $0.25 $0.20 $0.044 1.99 1.81 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 $1.07 – $0.58 $0.30 $0.044 2.78 1.77 1 Lighting Exterior Light Load Reduction. Minimum of 15% below code. Code standards kW Commercial-Misc. Com-ExtLight 15 4,059.00 $2,687.55 – $287.00 $200.00 $0.044 7.07 6.33 1 Lighting Networked Lighting Controls - Interior Code standards kWh C-All-Lgt-LPD Int- All-All-E 12 1.00 $0.50 – $0.33 $0.26 $0.044 1.64 1.45 1 Lighting Networked Lighting Controls - Exterior Code standards kWh Commercial-Misc. Com-ExtLight 12 1.00 $0.57 – $0.33 $0.20 $0.044 2.35 1.67 1 Lighting Occupancy Sensors Code standards Sensor C-All-Lgt-LPD Int- All-All-E 8 329.00 $123.23 – $134.00 $25.00 $0.044 3.11 0.91 1, 2 Lighting High-Efficiency Exit Signs Code standards Sign IPC_8760 16 28.00 $16.32 – $10.83 $7.50 $0.044 1.87 1.49 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 $38.41 – $79.00 $25.00 $0.044 1.42 0.52 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 $71.92 – $123.00 $50.00 $0.044 1.33 0.62 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 $58.84 – $36.00 $50.00 $0.044 1.11 1.65 1 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 $84.99 – $67.00 $70.00 $0.044 1.14 1.31 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 $71.10 – $93.00 $35.00 $0.044 1.83 0.81 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 $97.25 – $108.00 $55.00 $0.044 1.61 0.94 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 $79.27 – $36.00 $50.00 $0.044 1.46 2.16 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 $105.43 – $71.00 $85.00 $0.044 1.16 1.51 1 zeĂƌ : 2023 WƌoŐƌĂm : New Construction DĂƌŬet SeŐment : Commercial WƌoŐƌĂm dǇpe : Energy Efficiency Page 38 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $54.76 – $225.00 $40.00 $0.044 1.27 0.26 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 $108.70 – $370.00 $100.00 $0.044 1.03 0.32 1, 2 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 $104.61 – $145.00 $100.00 $0.044 0.99 0.76 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 $97.27 – $209.00 $80.00 $0.044 1.15 0.50 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 $58.17 – $103.00 $40.00 $0.044 1.36 0.61 2, 4 A/C Airside economizer IECC 2018 Code standards Ton of cooling C-All-HVAC-CAC- All-All-E 15 197.00 $161.00 – $81.36 $75.00 $0.044 1.92 1.97 1 A/C Water-side Economizer IECC 2018 Code Standard Combined chiller tonnage C-All-HVAC-CAC- All-All-E 10 153.00 $96.46 – $725.82 $50.00 $0.044 1.70 0.14 1, 2 A/C Direct evaporative cooler IECC 2018 Code standards Tons C-All-HVAC-CAC- All-All-E 15 315.00 $257.44 – $364.00 $200.00 $0.044 1.20 0.75 1, 2 A/C Indirect evaporative cooler IECC 2018 Code Standard Tons C-All-HVAC-CAC- All-All-E 15 225.00 $183.88 – $1,553.00 $130.00 $0.044 1.31 0.13 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 $51.49 – $173.00 $30.00 $0.044 1.57 0.32 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 $89.90 – $173.00 $30.00 $0.044 2.58 0.56 1, 2 Building Shell Reflective roof treatment IECC 2018 Code Standard ft2 roof area C-All-HVAC-CAC- All-All-E 15 0.12 $0.09 – $0.05 $0.05 $0.044 1.72 1.89 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 $129.91 $19.79 $162.00 $60.00 $0.044 1.85 0.95 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 $234.07 $19.79 $198.00 $80.00 $0.044 2.39 1.28 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 $270.70 $32.99 $233.00 $100.00 $0.044 2.24 1.30 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 $324.49 $69.27 $269.00 $120.00 $0.044 2.24 1.45 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 $353.11 $69.27 $304.00 $140.00 $0.044 2.11 1.38 1 Controls Guest room energy management system IECC 2018 Code standards Ton C-Lod-fan-SGS-All- All-S 11 550.00 $293.76 – $57.50 $50.00 $0.044 3.95 3.95 1 Controls Variable speed drive on HVAC system applications IECC 2018 Code standards HP C-All-HVAC-Vent- All-All-E 15 582.00 $333.08 – $153.91 $125.00 $0.044 2.21 2.04 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 $524.94 – $264.00 $250.00 $0.044 1.73 1.82 1 Page 39 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $2,609.98 – $248.00 $250.00 $0.044 5.75 6.36 1 Appliances with Electric Dryer Efficient Laundry Machines (electric dryer) IECC 2018 Code standards Unit Commercial-Misc. Com-Misc 9 814.50 $320.97 $2,183.52 $400.00 $200.00 $0.044 1.36 5.82 5 Refrigeration Efficient Refrigeration Condenser Code standards Ton C-Gro-Ref-All-All- All-E 15 114.00 $66.47 – $192.00 $40.00 $0.044 1.48 0.37 1, 2 Automatic High- Speed Doo Refrigerator to Dock Code standards ft2 Commercial-Ref. warehouse-Misc 16 360.00 $211.79 – $167.00 $80.00 $0.044 2.21 1.27 1 Automatic High- Speed Door Freezer to Refrigerator Code standards ft2 Commercial-Ref. warehouse-Misc 16 1,829.00 $1,076.03 – $167.00 $160.00 $0.044 4.46 4.77 1 Automatic High- Speed Door Freezer to Dock Code standards ft2 Commercial-Ref. warehouse-Misc 16 2,531.00 $1,489.02 – $167.00 $320.00 $0.044 3.44 5.87 1 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 $9,855.11 – $3,185.00 $2,000.00 $0.044 3.59 2.76 1 Compressed Air Air compressor VFD No existing VFD HP Commercial-Misc. Com-Misc 13 949.00 $480.89 – $223.00 $200.00 $0.044 1.99 2.00 1 Compressed Air No-Loss Condensate Drain Open tube with ball valve HP Commercial-Misc. Com-Misc 10 1,970.00 $837.42 – $194.00 $200.00 $0.044 2.91 3.27 1 Compressed Air Low Pressure Drop Filter Standard filter HP Commercial-Misc. Com-Misc 10 44.00 $18.70 – $10.00 $10.00 $0.044 1.57 1.72 1 Compressed Air Refrigerated Compressed Air Dryer Standard air dryer CFM Commercial-Misc. Com-Misc 13 10.62 $5.38 – $6.00 $3.00 $0.044 1.55 0.91 1, 2 Compressed Air Efficient Compress Air Nozzle Code standards unit Commercial-Misc. Com-Misc 15 2,223.00 $1,229.33 – $85.00 $80.00 $0.044 6.88 7.37 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 $1,048.49 – $70.00 $100.00 $0.044 4.74 6.03 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 $900.67 – $120.00 $150.00 $0.044 3.54 4.42 1 Dairy VFD VFD on milking vacuum pump No existing VFD VFD A-Da-Proc- MilkingSchedule- All-All-S 10 548.00 $274.58 – $273.00 $170.00 $0.044 1.41 1.02 1, 2 Dairy VFD VFD on milking transfer pump No existing VFD VFD A-Da-Proc- MilkingSchedule- All-All-S 10 7,687.00 $3,851.67 – $1,469.00 $1,500.00 $0.044 2.09 2.34 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 $423.53 – $239.00 $200.00 $0.044 1.70 1.62 1 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 $954.67 – $573.00 $350.00 $0.044 2.07 1.54 1 Page 40 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $1,679.19 – $573.00 $500.00 $0.044 2.42 2.41 1 Ice Machines ENERY STAR Ice Machine <200 lbs per day non ENERGY STAR ice machine unit C-All-Ref-Refrig-All- All-C 9 285.00 $116.90 – $311.00 $100.00 $0.044 1.04 0.40 1, 2 Ice Machines ENERY STAR Ice Machine >= 200 lbs per day non ENERGY STAR ice machine unit C-All-Ref-Refrig-All- All-C 9 2,608.00 $1,069.78 – $311.00 $300.00 $0.044 2.57 2.76 1 High-Efficiency Battery Chargers High-Efficiency Battery Chargers - Single or Three Phase Code standards unit Commercial-Fleet_ EV_Charger 15 3,337.00 $1,778.68 – $400.00 $200.00 $0.044 5.11 3.57 1 Indoor Pool Cover No pool cover Code standards per sq ft Residential-Spa Heater 10 23.50 $12.64 – $4.99 $2.00 $0.044 4.15 2.30 7 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 2021 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 2023 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. 2021. 2 Idaho only measure. 3 Idaho Power TRM prepared by ADM Associates, Inc. 2021. Averaged air-cooled chillers. 4 Idaho Power TRM prepared by ADM Associates, Inc. 2021. Averaged water-cooled chillers. 5 Idaho Power TRM prepared by ADM Associates, Inc. 2021. NEBs from water savings from RTF. ComClothesWashers_v7_1.xlsm. Simple average. 2023. 6 Measure not cost-effective. Measure cost-effective without inclusion of admin costs. 7 Idaho Power Multifamily TRM prepared by ADM Associates, Inc. 2023. Page 41 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness ZetƌoĮts SeŐment : Commercial ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ..........................................................$7,478,245 $3,184,964 2.35 TRC Test ........................................................10,579,531 9,012,722 1.17 RIM Test ........................................................7,478,245 10,968,361 0.68 PCT ...............................................................12,502,182 8,193,082 1.53 Cost /nputs ZeĨ Program Administration .....................................................................................$819,640 Program Incentives .............................................................................................2,365,324 I dotĂl hC ..............................................................................................................$ϯ͕1ϴϰ͕ϵϲϰ P Measure Equipment and Installation (Incremental Participant Cost) ................$8,193,082 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) .......................................14,457,180 NPV Cumulative Energy (kWh) ...........................................138,096,375 $7,478,245 S 10% Credit (Northwest Power Act) .....................................747,825 dotĂl Electƌŝc SĂvŝnŐs ................................................................$ϴ͕ϮϮϲ͕ϬϳϬ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Savings ...................................$ 7,783,397 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives...........................................$–NUI NEBs ...................................................................................$2,353,461 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................43% Average Customer Segment Rate/kWh ...........................................................................$0.058 Line Losses .......................................................................................................................9.60% Eote: 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. Page 42 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes Permanent Fixture Removal Permanent Fixture Removal fixture C-All-Lgt-LPD Int- All-All-E 2 873.61 $99.04 – $29.08 $22.69 $0.044 1.61 1.61 1 LEDs Pin-based LED Pin-base lamp using higher wattage fixture C-All-Lgt-LPD Int- All-All-E 5 125.30 $31.69 – $23.02 $4.30 $0.044 3.22 1.22 1 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 $321.59 – $104.82 $49.23 $0.044 4.09 2.64 1 LEDs LED Tubes (type A, B & DM)fixture using higher wattage fixture C-All-Lgt-LPD Int- All-All-E 12 203.00 $98.51 – $41.20 $18.29 $0.044 3.61 2.16 1 LEDs LED Tubes (type C)fixture using higher wattage fixture C-All-Lgt-LPD Int- All-All-E 12 310.10 $150.48 – $99.04 $31.01 $0.044 3.36 1.47 1 LEDs LED Level 1 Retrofit Kit fixture using higher wattage fixture Commercial-All Com-IntLight 12 309.75 $150.31 – $75.17 $43.37 $0.044 2.63 1.86 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 $140.45 – $127.38 $49.20 $0.044 2.26 1.10 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 $199.30 – $140.40 $78.03 $0.044 2.07 1.38 1 LEDs LED Level 1 retrofit kit with networked/luminaire level lighting control strategy fixture using higher wattage fixture C-All-Lgt-LPD Int- All-All-E 12 455.35 $220.97 – $142.98 $100.42 $0.044 1.83 1.49 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 $213.74 – $178.93 $96.90 $0.044 1.84 1.18 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 $251.53 – $203.25 $129.58 $0.044 1.65 1.22 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 12 631.13 $306.27 – $282.13 $170.40 $0.044 1.54 1.09 1 LEDs LED fixture or LED Level 2 retrofit kit with networked/luminaire level lighting control strategy fixture using higher wattage fixture C-All-Lgt-LPD Int- All-All-E 12 733.88 $356.13 – $347.57 $223.34 $0.044 1.39 1.03 1 LED Exit Sign LED Exit Sign fixture using higher wattage sign IPC_8760 12 230.68 $112.41 – $63.77 $40.00 $0.044 2.24 1.67 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 $207.26 – $161.34 $85.42 $0.044 1.99 1.26 1 Lighting Controls (Idaho) Lighting Controls Manual controls controls C-All-Lgt-LPD Int- All-All-E 10 163.59 $70.19 – $71.73 $27.31 $0.044 2.03 0.98 1, 3 Refrigeration Case Lighting Refrigeration Case Lighting fixture using higher wattage lamp C-All-Lgt-LPD Int- All-All-E 7 365.73 $124.14 – $107.23 $52.26 $0.044 1.81 1.11 1, 3 Permanent Fixture Removal Permanent Fixture Removal fixture Commercial-Misc. Com-ExtLight 2 1,013.14 $126.89 – $28.00 $22.69 $0.044 1.88 1.91 1 LEDs Pin-based LED Pin-base lamp using higher wattage fixture Commercial-Misc. Com-ExtLight 5 141.25 $39.77 – $25.74 $4.18 $0.044 3.81 1.37 1 zeĂƌ : 2023 WƌoŐƌĂm : Retrofits DĂƌŬet SeŐment : Commercial WƌoŐƌĂm dǇpe : Energy Efficiency Page 43 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes LEDs HID LED screw-in replacement lamp Existing HID lamp using > input watts fixture Commercial-Misc. Com-ExtLight 12 743.75 $410.71 – $110.38 $47.64 $0.044 5.09 3.15 1 LEDs LED Tubes (type A, B & DM)fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 287.20 $158.59 – $63.89 $18.12 $0.044 5.14 2.28 1 LEDs LED Tubes (type C) fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 297.93 $164.52 – $113.66 $29.79 $0.044 3.83 1.43 1 LEDs LED Level 1 Retrofit Kit fixture using higher wattage fixture Commercial-All Com-ExtLight 12 661.62 $365.35 $132.28 $92.63 $0.044 3.00 2.49 1 LEDs LED Level 1 retrofit kit with single control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 646.59 $357.05 – $167.32 $109.92 $0.044 2.58 2.00 1 LEDs LED Level 1 retrofit kit with multiple control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 850.79 $469.81 – $202.36 $161.55 $0.044 2.36 2.15 1 LEDs LED Level 1 retrofit kit with networked control strategy fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 933.44 $515.45 – $218.51 $205.68 $0.044 2.09 2.18 1 LEDs LED fixture or LED Level 2 retrofit kit fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 912.48 $503.88 – $279.77 $200.74 $0.044 2.09 1.73 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 $525.64 – $310.73 $237.97 $0.044 1.88 1.64 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 $416.05 – $248.13 $170.40 $0.044 2.04 1.63 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 $903.69 – $524.84 $491.91 $0.044 1.60 1.66 1 LED sign lighting retrofit kit LED sign lighting retrofit kit fixture using higher wattage fixture Commercial-Misc. Com-ExtLight 12 487.27 $269.07 – $172.05 $97.45 $0.044 2.26 1.53 1 Lighting Controls Lighting Controls Manual controls controls Commercial-Misc. Com-ExtLight 10 366.19 $177.84 – $109.09 $30.12 $0.044 3.84 1.56 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 $124.22 – $940.00 $85.00 $0.044 1.35 0.14 3, 4 AC Units Base to CEE Tier 2 working pre-existing system tons C-All-HVAC-CAC- All-All-E 15 193.00 $157.73 – $984.00 $110.00 $0.044 1.33 0.17 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 $131.58 – $1,093.00 $100.00 $0.044 1.23 0.13 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 $105.43 – $1,078.00 $75.00 $0.044 1.31 0.11 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 $106.24 – $1,237.00 $75.00 $0.044 1.32 0.09 3, 4 AC Units Air-conditioning Tune Up ton C-All-HVAC-CAC- All-All-E 10 99.50 $62.73 – $35.00 $25.00 $0.044 2.13 1.75 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 $152.83 – $888.00 $110.00 $0.044 1.29 0.19 3, 4 Page 44 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $178.98 – $919.00 $130.00 $0.044 1.28 0.21 3, 4 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 $105.43 – $971.00 $75.00 $0.044 1.31 0.12 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 $143.02 – $1,034.00 $110.00 $0.044 1.21 0.15 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 $116.87 – $999.00 $90.00 $0.044 1.21 0.13 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 $61.29 – $1,187.00 $45.00 $0.044 1.27 0.06 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 $146.86 – $784.00 $110.00 $0.044 1.26 0.20 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 $86.78 – $596.00 $60.00 $0.044 1.36 0.16 3, 6 Economizers Air-side economizer control addition No prior control Ton of cooling C-All-HVAC-CAC- All-All-E 15 279.00 $228.02 – $155.01 $100.00 $0.044 2.03 1.50 4 Economizers Air-side economizer control repair Non-functional economizer Ton of cooling C-All-HVAC-CAC- All-All-E 15 279.00 $228.02 – $73.65 $50.00 $0.044 3.66 2.92 4 Economizers Water-side economizer control addition No prior control Combined chiller tonnage C-All-HVAC-CAC- All-All-E 10 153.00 $96.46 – $725.82 $50.00 $0.044 1.70 0.14 3, 4 Evaporative Coolers Direct evaporative cooler Replacing standard AC unit Ton C-All-HVAC-CAC- All-All-E 15 350.00 $286.04 – $1,178.00 $200.00 $0.044 1.33 0.26 3, 4 Evaporative Coolers Indirect evaporative cooler Replacing standard AC unit ton C-All-HVAC-CAC- All-All-E 15 250.00 $204.31 – $2,367.00 $130.00 $0.044 1.45 0.09 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 $51.49 – $173.00 $30.00 $0.044 1.57 0.32 3, 4 Package Terminal Air Conditioner (PTAC) PTAC 13.2-14.3 EER existing ptac ton C-All-HVAC-CAC- All-All-E 15 231.30 $189.03 – $1,571.18 $50.00 $0.044 3.14 0.13 3, 4 PTAC PTAC >=14.4 EER existing ptac ton C-All-HVAC-CAC- All-All-E 15 279.49 $228.42 – $1,735.62 $75.00 $0.044 2.61 0.14 3, 4 Package Terminal Heat Pump (PTHP) PTHP 13.2-14.3 EER existing pthp ton C-All-HVAC-Vent- All-All-E 15 436.45 $249.78 – $918.00 $50.00 $0.044 3.60 0.29 3, 4 PTHP PTHP >=14.4 EER existing pthp ton C-All-HVAC-Vent- All-All-E 15 560.12 $320.56 – $999.00 $75.00 $0.044 3.21 0.34 3, 4 Connected Thermostat No existing connected (web- enabled) thermostat No existing connected (web-enabled) thermostat unit C-All-HVAC-Vent- All-All-E 5 1,588.35 $411.72 – $300.00 $150.00 $0.044 1.87 1.22 3, 15 Page 45 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $212.90 $26.39 $198.00 $100.00 $0.044 1.83 1.21 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 $355.97 $19.79 $233.00 $150.00 $0.044 2.00 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 $464.14 $59.38 $269.00 $175.00 $0.044 2.20 1.87 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 $988.93 $316.68 $304.00 $200.00 $0.044 3.58 3.69 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 $1,027.85 $319.98 $340.00 $225.00 $0.044 3.37 3.46 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 $129.91 $19.79 $162.00 $60.00 $0.044 1.85 0.95 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 $234.07 $19.79 $198.00 $80.00 $0.044 2.39 1.28 4 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 $270.70 $32.99 $233.00 $100.00 $0.044 2.24 1.30 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 $324.49 $69.27 $269.00 $120.00 $0.044 2.24 1.45 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 $353.11 $69.27 $304.00 $140.00 $0.044 2.11 1.38 4 Automated Control Systems Lodging room occupancy controls Manual controls Unit C-Lod-fan-SGS-All- All-S 11 643.00 $343.43 – $150.61 $75.00 $0.044 3.32 2.11 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 $5,044.97 – $239.50 $200.00 $0.044 8.54 8.80 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 $5.45 – $22.08 $2.50 $0.044 1.88 0.27 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 $0.09 – $0.05 $0.05 $0.044 1.72 1.89 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 $0.23 – $1.45 $0.20 $0.044 1.07 0.17 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 $1.71 – $0.64 $0.40 $0.044 3.25 2.46 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 $1.91 – $0.85 $0.55 $0.044 2.77 2.13 4 Laundry Machines High efficiency washer Standard washer, electric dryer Machine Commercial-Misc. Com-Misc 9 814.50 $320.97 $2,183.52 $400.00 $200.00 $0.044 1.36 5.82 4, 7 Page 46 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $17.99 – $4.40 $5.00 $0.044 2.07 2.45 4 HVAC Fan Motor Belts Synchronous belt Standard fan belt HP C-All-HVAC-Vent- All-All-E 4 213.00 $46.18 – $67.00 $25.00 $0.044 1.34 0.66 3, 4 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 $423.53 – $1,268.00 $200.00 $0.044 1.70 0.35 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 $954.67 – $2,152.00 $350.00 $0.044 2.07 0.46 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 $1,679.19 – $2,645.00 $500.00 $0.044 2.42 0.65 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 $1,048.49 – $120.00 $100.00 $0.044 4.74 4.78 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 $900.67 – $170.00 $150.00 $0.044 3.54 3.61 4 High Efficiency Battery Chargers High Efficiency Battery Chargers Standard battery charger unit Commercial-Fleet_ EV_Charger 15 3,337.00 $1,778.68 – $400.00 $200.00 $0.044 5.11 3.57 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 $9,855.11 – $4,185.00 $2,000.00 $0.044 3.59 2.20 4 Compressed Air VFD on air compressor No existing VFD HP Commercial-Misc. Com-Misc 13 949.00 $480.89 – $223.00 $200.00 $0.044 1.99 2.00 4 Compressed Air Low Pressure Filter Standard filter HP Commercial-Misc. Com-Misc 10 44.00 $18.70 – $10.00 $10.00 $0.044 1.57 1.72 4 Compressed Air No-Loss Condensate Drain Open tube with ball valve Unit Commercial-Misc. Com-Misc 10 1,970.00 $837.42 – $244.00 $200.00 $0.044 2.91 2.78 4 Compressed Air Efficient Compress Air Nozzle Standard air nozzle Unit Commercial-Misc. Com-Misc 15 2,223.00 $1,229.33 – $85.00 $80.00 $0.044 6.88 7.37 4 Compressed Air Efficient Refrigerated Compressed Air Dryer Standard air dryer CFM Commercial-Misc. Com-Misc 13 10.62 $5.38 – $6.00 $3.00 $0.044 1.55 0.91 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 $950.95 – $736.00 $400.00 $0.044 1.86 1.23 4 Refrigeration Install auto-closer - reach-in Damaged auto-closer, low temp Door C-Gro-Ref-All-All- All-E 8 326.00 $123.56 – $736.00 $75.00 $0.044 1.38 0.18 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 $213.01 – $736.00 $135.00 $0.044 1.33 0.31 3, 4 Refrigeration Install auto-closer - reach-in Damaged auto-closer, med. Temp Door C-Gro-Ref-All-All- All-E 8 243.00 $92.10 – $736.00 $55.00 $0.044 1.40 0.14 3, 4 Refrigeration Anti-sweat heat controls Low temp case without controls Linear ft C-Gro-Ref-All-All- All-E 8 292.00 $110.67 – $77.26 $50.00 $0.044 1.76 1.35 3, 4 Page 47 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes Refrigeration Anti-sweat heat controls Med.temp case without controls Linear ft C-Gro-Ref-All-All- All-E 8 220.00 $83.38 $77.26 $50.00 $0.044 1.40 1.05 3, 4 Refrigeration Refrigerated case doors - med temp No existing case door or barrier Linear ft C-Gro-Ref-All-All- All-E 15 700.00 $408.14 $342.73 $130.00 $0.044 2.53 1.20 2 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 $63.59 – $173.00 $30.00 $0.044 1.82 0.39 3, 4 Refrigeration No-heat glass door commercial glass door door C-Gro-Ref-All-All- All-E 12 779.00 $394.25 – $664.00 $200.00 $0.044 1.68 0.62 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 $87.29 – $500.00 $50.00 $0.044 1.49 0.19 3, 4 Automatic high speed doors Freezer to Dock manual or electric warehouse door sq ft Commercial-Ref. warehouse-Misc 16 2,812.00 $1,654.34 – $188.00 $320.00 $0.044 3.72 5.82 4 Automatic high speed doors Freezer to Refrigerator manual or electric warehouse door sq ft Commercial-Ref. warehouse-Misc 16 2,032.00 $1,195.46 – $188.00 $160.00 $0.044 4.78 4.73 4 Automatic high speed doors Refrigerator to Dock manual or electric warehouse door sq ft Commercial-Ref. warehouse-Misc 16 400.00 $235.33 – $188.00 $80.00 $0.044 2.41 1.26 4 Strip Curtain For walk-in freezers no protective barrier sq ft C-Gro-Ref-All-All- All-E 4 210.00 $45.87 – $9.00 $5.00 $0.044 3.20 2.76 4 Strip Curtain For walk-in refrigerators no protective barrier sq ft C-Gro-Ref-All-All- All-E 4 78.00 $17.04 – $9.00 $5.00 $0.044 2.01 1.50 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 $201.51 – $228.08 $100.00 $0.044 1.75 0.91 3, 4 Floating Head/Suction Pressures Head pressure controller Standard head pressure control HP C-Gro-Ref-All-All- All-E 16 440.00 $266.27 – $311.90 $160.00 $0.044 1.48 0.88 3, 4 Floating Head/Suction Pressures Suction pressure controller Standard suction pressure control HP C-Gro-Ref-All-All- All-E 16 104.00 $62.94 – $86.91 $40.00 $0.044 1.41 0.76 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 $2,609.98 – $469.00 $250.00 $0.044 5.75 4.27 4 Ice Machines Ice Machines (<200 lbs/day)code per unit C-All-Ref-Refrig-All- All-C 9 285.00 $116.90 – $311.00 $100.00 $0.044 1.04 0.40 3, 4 Ice Machines Ice Machines (>200 lbs/day)code per unit C-All-Ref-Refrig-All- All-C 9 2,608.00 $1,069.78 – $311.00 $300.00 $0.044 2.57 2.76 4 Commercial Kitchen Equipment Efficient Hot Food Holding Cabinet (Half Size) Standard hot food holding cabinet per unit C-All-Food-Cook- All-All-C 7 1,373.07 $463.48 – $883.13 $200.00 $0.044 1.78 0.54 3, 8 Page 48 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe unŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes Commercial Kitchen Equipment Efficient Hot Food Holding Cabinet (Full Size) Standard hot food holding cabinet per unit C-All-Food-Cook- All-All-C 7 2,602.55 $878.48 – $3,184.56 $400.00 $0.044 1.70 0.29 3, 8 Commercial Kitchen Equipment Efficient Hot Food Holding Cabinet (Double Size) Standard hot food holding cabinet per unit C-All-Food-Cook- All-All-C 7 4,473.47 $1,510.01 – $3,587.61 $800.00 $0.044 1.51 0.44 3, 8 New On- Demand Overwrapper New On-Demand Overwrapper Standard overwrapper per unit Commercial- Grocery-Process 10 1,270.77 $585.73 – $294.33 $100.00 $0.044 3.75 1.84 9 Commercial Kitchen Equipment ENERGY STAR listed electric combination oven (3-4 pans) Standard electric oven oven C-All-Food-Cook- All-All-C 10 1,306.90 $571.80 – $1,027.82 $300.00 $0.044 1.60 0.58 3, 10 Commercial Kitchen Equipment ENERGY STAR listed electric combination oven (5-14 pans) Standard electric oven oven C-All-Food-Cook- All-All-C 10 6,428.11 $2,812.46 – $1,027.82 $800.00 $0.044 2.59 2.36 10 Commercial Kitchen Equipment ENERGY STAR listed electric combination oven (15-28 pans) Standard electric oven oven C-All-Food-Cook- All-All-C 10 5,640.26 $2,467.75 – $1,027.82 $800.00 $0.044 2.35 2.12 10 Commercial Kitchen Equipment ENERGY STAR listed electric combination oven (29-40 pans) Standard electric oven oven C-All-Food-Cook- All-All-C 10 11,633.69 $5,090.03 – $1,027.82 $800.00 $0.044 3.87 3.63 10 Commercial Kitchen Equipment ENERGY STAR listed electric convection oven Standard electric oven oven C-All-Food-Cook- All-All-C 12 1,206.40 $596.79 – $553.07 $180.00 $0.044 2.56 1.08 3, 11 Commercial Kitchen Equipment ENERGY STAR listed electric fryer Standard fryer fryer C-All-Food-Cook- All-All-C 9 953.15 $386.68 – $1,439.43 $150.00 $0.044 2.01 0.29 3, 12 Commercial Kitchen Equipment ENERGY STAR listed electric steamer -Any Size Standard steamer pan C-All-Food-Cook- All-All-C 8 1,689.45 $628.98 – $- $30.00 $0.044 6.00 6.59 13 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 $355.97 – $184.55 $125.00 $0.044 2.33 1.85 4 Variable Speed Controls Variable speed drive on potato and onion storage shed ventilation no existing VFD HP A-SpudOnionVFD 10 1,193.00 $372.74 – $264.00 $250.00 $0.044 1.23 1.29 4 Variable Speed Controls VFD on milking vacuum pump no existing VFD HP A-Da-Proc- MilkingSchedule- All-All-S 10 3,084.00 $1,545.28 – $356.00 $250.00 $0.044 4.00 3.45 4 Variable Speed Controls VFD on milking transfer pump no existing VFD HP A-Da-Proc- MilkingSchedule- All-All-S 10 11,777.00 $5,901.02 – $2,052.00 $1,500.00 $0.044 2.92 2.52 4 Indoor/Outdoor pool cover No pool cover No pool cover per sq ft Residential-Spa Heater 10 34.75 $18.69 – $4.99 $2.00 $0.044 5.28 3.15 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 2021 IRP. Total Resource Cost Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. Page 49 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness d /ncƌementĂl pĂƌticŝpĂnt cost pƌŝoƌ to customeƌ ŝncentives͘ e veƌĂŐe pƌoŐƌĂm ĂĚmŝnŝstƌĂtion ĂnĚ oveƌŚeĂĚ costs to ĂcŚŝeve eĂcŚ ŬtŚ oĨ sĂvŝnŐs͘ CĂlculĂteĚ Ĩƌom ϮϬϮϯ ĂctuĂls͘ Ĩ hCd ZĂtio с ;EWs SD voŝĚeĚ CostsͿ ͬ ;;Ěmŝn CostͬŬtŚ Ύ ŬtŚ SĂvŝnŐsͿ н /ncentivesͿ g dZC ZĂtio с ;;EWs SD voŝĚeĚ Costs Ύ 11ϬйͿ н EEͿ ͬ ;;Ěmŝn CostͬŬtŚ Ύ ŬtŚ SĂvŝnŐsͿ н /ncentives н ;/ncƌementĂl WĂƌticŝpĂnt Cost - /ncentivesͿͿ 1 EveƌŐƌeen ConsultinŐ 'ƌoup͕ >>C͘ /ĚĂŚo Woǁeƌ >ŝŐŚtinŐ dool͘ ϮϬϮϯ͘ 2 /ĚĂŚo Woǁeƌ enŐŝneeƌŝnŐ cĂlculĂtions͘͘ 3 /ĚĂŚo onlǇ meĂsuƌe͘ 4 /ĚĂŚo Woǁeƌ dZD pƌepĂƌeĚ ďǇ D ssocŝĂtes͕ /nc͘ ϮϬϮ1͘ 5 /ĚĂŚo Woǁeƌ dZD pƌepĂƌeĚ ďǇ D ssocŝĂtes͕ /nc͘ ϮϬϮ1͘ veƌĂŐeĚ Ăŝƌ-cooleĚ cŚŝlleƌs͘ 6 /ĚĂŚo Woǁeƌ dZD pƌepĂƌeĚ ďǇ D ssocŝĂtes͕ /nc͘ ϮϬϮ1͘ veƌĂŐeĚ ǁĂteƌ-cooleĚ cŚŝlleƌs͘ 7 /ĚĂŚo Woǁeƌ dZD pƌepĂƌeĚ ďǇ D ssocŝĂtes͕ /nc͘ ϮϬϮ1͘ EEs Ĩƌom ǁĂteƌ sĂvŝnŐs Ĩƌom Zd&͘ ComClotŚestĂsŚeƌsͺvϳͺ1͘ǆlsm͘ Sŝmple ĂveƌĂŐe͘ ϮϬϮϯ͘ Ц Zd&͘ ComCooŬŝnŐ,ot&ooĚCĂďŝnetͺvϱͺ1͘ ϮϬϮϯ͘ Ч Zd&͘ ComKnemĂnĚKveƌǁƌĂppeƌsͺvϯͺϮ͘ ϮϬϮϯ͘ 10 Zd&͘ ComCooŬŝnŐComďŝnĂtionKvenͺvϱͺϬ͘ ϮϬϮϯ 11 Zd&͘ ComCooŬŝnŐConventionKvenͺvϱͺ1͘ ϮϬϮϯ 12 Zd&͘ ComCooŬŝnŐ&ƌǇeƌͺvϱͺ1͘ ϮϬϮϯ 13 Zd&͘ ComCooŬŝnŐSteĂmeƌͺvϱͺ1͘ CĂlculĂteĚ peƌ pĂn sĂvŝnŐs͘ ϮϬϮϯ͘ 14 /ĚĂŚo Woǁeƌ DultiĨĂmŝlǇ dZD pƌepĂƌeĚ ďǇ D ssocŝĂtes͕ /nc͘ ϮϬϮϯ͘ 15 Zd&͘ ComConnecteĚdŚeƌmostĂtͺϮͺ1͘ǆlsm͘ ϮϬϮϯ͘ SĂvŝnŐs sŚoǁn ďĂseĚ on ĂveƌĂŐe oĨ 1ϱ coolŝnŐ tons͘ Page 50 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness Eotes: NEB/impacts on a $/kWh for each end-use. Based on 2019 impact evaluation of other C&I programs 2023 cost-effectiveness ratios include evaluation expenses. If evaluation expense were removed from the program’s cost-effectiveness, the UCT and TRC would be 1.08 and 1.64, respectively. Program closed March 31, 2023. SmĂll usŝness ŝƌect /nstĂll SeŐment : Commercial ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ........................................................$357,277 $366,674 0.97 TRC Test ......................................................543,097 366,674 1.48 RIM Test ......................................................357,277 765,583 0.47 PCT ..............................................................N/A N/A N/A Cost /nputs ZeĨ Program Administration .....................................................................................$366,674 Program Incentives .............................................................................................–I dotĂl hC ..............................................................................................................$ϯϲϲ͕ϲϳϰ P Measure Equipment and Installation (Incremental Participant Cost) ................$–M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ......................................791,512 NPV Cumulative Energy (kWh) ..........................................7,139,147 $357,277 S 10% Credit (Northwest Power Act) ....................................35,728 dotĂl Electƌŝc SĂvŝnŐs ...............................................................$ϯϵϯ͕ϬϬϱ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ............................$398,909 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives...........................................$–NUI NEBs ...................................................................................$150,093 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................103% Average Customer Segment Rate/kWh ...........................................................................$0.058 Line Losses .......................................................................................................................9.60% Page 51 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness /ƌƌŝŐĂtion EĸcŝencǇ ZeǁĂƌĚs SeŐment : Irrigation ϮϬϮϯ WƌoŐƌĂm Zesults SummĂƌǇ oĨ Cost-Effectiveness Zesults dest eneĮt Cost ZĂtio UC Test ........................................................$3,511,270 $1,708,967 2.05 TRC Test ......................................................32,779,161 14,744,378 2.22 RIM Test ......................................................3,511,270 4,196,861 0.84 PCT ..............................................................32,616,398 14,247,153 2.29 Cost /nputs ZeĨ Program Administration .....................................................................................$497,225 Program Incentives .............................................................................................1,211,742 I dotĂl hC ..............................................................................................................$1͕ϳϬϴ͕ϵϲϳ P Measure Equipment and Installation (Incremental Participant Cost) ................$14,247,153 M Eet eneĮt /nputs ;EWsͿ ZeĨ Zesouƌce SĂvŝnŐs 2023 Annual Gross Energy (kWh) ......................................4,558,425 NPV Cumulative Energy (kWh) ..........................................43,546,172 $ 3,511,270 S 10% Credit (Northwest Power Act) ....................................351,127 dotĂl Electƌŝc SĂvŝnŐs ...............................................................$ϯ͕ϴϲϮ͕ϯϵϴ A WĂƌticŝpĂnt ŝll SĂvŝnŐs NPV Cumulative Participant Bill Savings ............................$ 2,487,893 B KtŚeƌ eneĮts Non-Utility Rebates/Incentives...........................................$–NUI NEBs ...................................................................................$28,916,763 NEB eneĮts ĂnĚ Costs /ncluĚeĚ ŝn EĂcŚ dest 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 ssumptions Ĩoƌ >evelŝǌeĚ CĂlculĂtions ŝscount ZĂte Nominal (WACC) ........................................................................................................7.12% Real ((1 + WACC) / (1 + Escalation)) – 1 .....................................................................4.71% Escalation Rate ................................................................................................................2.30% Net-to-Gross (NTG) ..........................................................................................................100% Minimum NTG Sensitivity ................................................................................................49% Average Customer Segment Rate/kWh ...........................................................................$0.059 Line Losses .......................................................................................................................9.60% Eotes: 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. 2023 cost-effectiveness ratios include evaluation expenses. If evaluation expense were removed from the program’s cost-effectiveness, the UCT and TRC would be 2.11 and 2.23, respectively. Page 52 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme Ă DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ ď nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ c EWs SD voŝĚeĚ CostsĚ EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt Coste /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ Ĩ hCd ZĂtio Ő dZC ZĂtio Ś Souƌcesͬ Eotes 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 21.64 $10.04 $3.55 $7.59 $2.50 $0.109 2.07 1.47 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 21.64 $10.04 $3.55 $1.29 $0.35 $0.109 3.71 4.00 1 Sprinklers Rebuilt or new brass impact sprinklers Worn sprinkler Unit A-Irr-Irr- Irrigation-All- All-E 6 1.92 $0.89 $16.80 $14.10 $0.50 $0.109 1.26 1.24 1 Levelers Rebuilt or new wheel line levelers Worn wheel line leveler Unit A-Irr-Irr- Irrigation-All- All-E 7 3.65 $1.92 $9.09 $4.57 $1.00 $0.109 1.37 2.25 1 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 26.09 $12.11 $27.18 $28.48 $8.00 $0.109 1.12 1.29 1 Gasket Replacement New gaskets for hand lines, wheel lines, or portable mainline Worn gasket Unit A-Irr-Irr- Irrigation-All- All-E 6 13.44 $6.24 $4.89 $2.48 $1.00 $0.109 2.53 2.98 1 Drain Replacement New drains, hand lines, wheel lines, or portable mainline Worn drain Unit A-Irr-Irr- Irrigation-All- All-E 6 9.87 $4.58 $6.83 $5.29 $3.00 $0.109 1.12 1.86 1 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 2021 IRP. TRC Test Benefit calculation includes 10% conservation adder from the Northwest Power Act. e Incremental participant cost prior to customer incentives. Based on customer reported three-year average. 2021–2023. f Average program administration and overhead costs to achieve each kWh of savings. Calculated from 2023 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_v6_1.xlsm. 2023. Weighted average of Western Idaho (17.84%), Eastern Washington & Oregon (1.94%), and Eastern & Southern Idaho (80.22%). zeĂƌ : 2023 WƌoŐƌĂm : Irrigation Efficiency Rewards DĂƌŬet SeŐment : Irrigation WƌoŐƌĂm dǇpe : Energy Efficiency Page 53 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $217.05 – $151.00 $15.00 $0.109 5.54 1.36 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 $290.44 – $168.47 $20.00 $0.109 5.54 1.59 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 $424.05 – $192.48 $25.00 $0.109 5.75 1.93 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 $456.77 – $211.40 $30.00 $0.109 5.53 1.90 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 $531.93 – $258.34 $40.00 $0.109 5.26 1.83 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 $572.46 – $285.99 $50.00 $0.109 4.94 1.79 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 $584.07 – $337.29 $60.00 $0.109 4.86 1.62 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 $601.10 – $364.58 $75.00 $0.109 4.39 1.55 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 $793.38 – $452.26 $100.00 $0.109 4.36 1.63 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 $612.06 – $327.44 $125.00 $0.109 3.30 1.74 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 $727.58 – $364.73 $150.00 $0.109 3.28 1.83 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 $965.07 – $439.08 $200.00 $0.109 3.27 1.99 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 $1,363.62 – $564.34 $250.00 $0.109 3.43 2.11 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 $1,627.87 – $570.43 $300.00 $0.109 3.42 2.40 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 $1,897.79 – $597.88 $350.00 $0.109 3.41 2.60 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 $2,151.81 – $667.77 $400.00 $0.109 3.40 2.63 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 $2,416.73 – $729.93 $450.00 $0.109 3.39 2.68 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 $2,689.00 – $788.57 $500.00 $0.109 3.40 2.74 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 $4,617.22 – $1,557.60 $600.00 $0.109 4.40 2.53 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 $5,363.90 – $1,699.33 $700.00 $0.109 4.39 2.66 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 $6,117.17 – $1,885.45 $800.00 $0.109 4.39 2.71 1 zeĂƌ : 2023 WƌoŐƌĂm : Irrigation Efficiency Rewards—Green Motors DĂƌŬet SeŐment : Irrigation WƌoŐƌĂm dǇpe : Energy Efficiency Page 54 Demand-Side Management 2023 Annual Report Supplement 1: Cost-Effectiveness eneĮt Cost ͬC dests DeĂsuƌe EĂme DeĂsuƌe escƌŝptions ZeplĂcŝnŐ DeĂsuƌe hnŝt EnĚ hse DeĂsuƌe >ŝĨe ;ǇƌsͿ Ă nnuĂl 'ƌoss EneƌŐǇ SĂvŝnŐs ;ŬtŚͬǇƌͿ ď EWs SD voŝĚeĚ Costsc EE 'ƌoss /ncƌementĂl WĂƌticŝpĂnt CostĚ /ncentiveͬ hnŝt Ěmŝn Cost ;ΨͬŬtŚͿ e hCd ZĂtio Ĩ dZC ZĂtio Ő Souƌceͬ Eotes 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 $6,867.22 – $2,078.63 $900.00 $0.109 4.38 2.75 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 $12,499.59 $- $3,924.70 $2,000.00 $0.109 3.11 2.31 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 2021 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 2023 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_v4_0.xlsm. 2022.