Topic:"Rate Design" in M10473

Annual avoided costs of energy and capacity and annual avoided $CO_2e$ emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM for Scenario 2.0C. Avoided costs of transmission and distribution were provided by NS...

AI summary The Settlement Plan, based on the 2020 IRP and updated with 2021 data, outlines energy and capacity savings, CO2e reductions, and cost-effectiveness ratios. It includes details on avoided costs, lifetime benefits, and a 10-year program life for Demand Response (DR) and Energy Efficiency (EE) initiatives.

WHY IS THE TRC TEST CONDUCTED AT THE PROGRAM LEVEL? The Board has established that the TRC test be applied at the program level, rather than the measure level, in accordance with industry best practices. Screening at the measure level is t...

AI summary The TRC test is applied at the program level rather than the measure level to allow for a more comprehensive and equitable delivery of demand-side management services. While individual measures may fail the TRC test, combining them into programs can result in overall cost-effectiveness. This approach also allows for consideration of future market developments and benefits for income-eligible customers.

6 TRC RESULTS FOR THE SETTLEMENT PLAN - 7 The Settlement Plan has an overall Benefit Cost Ratio ("BCR") of 2.0 (2.0 for energy efficiency programs - 8 and 1.1 for demand response). All programs have a BCR greater than 1 and thus pass at th...

AI summary The Settlement Plan has a Benefit Cost Ratio (BCR) of 2.0 for energy efficiency programs and 1.1 for demand response, passing the NSUARB approved level. The TRC Test results are presented in Table 2, with PAC Test results also included for informational purposes.

e Change Reduction Act and the renewable energy standard. Its assumption of an electrification implementation that is more responsive to mandatory requirements is further support for its suitability. The impact of these environmental requi...

AI summary The document discusses the impact of environmental regulations on the Integrated Resource Plan (IRP) and the Renewable Energy Standard. It references a previous application by NS Power and critiques the credit component of a rate rider for not accounting for avoided environmental compliance costs. The Environmental Goals and Climate Change Reduction Act, introduced in 2021, is highlighted as a significant development affecting these considerations.

1 Table 3: Avoided Costs Used in Assessing the Settlement Plan Item Description of Avoided Costs Avoided Costs of Energy • DSM Plan & RBIA: Avoided costs of energy were based on NS Power's 2020 IRP Reference Plan (scenario 2.0C) for energy...

AI summary The text discusses the avoided costs used in assessing the Settlement Plan, including energy, capacity, transmission and distribution, and carbon. These costs are based on NS Power's 2020 Integrated Resource Plan (IRP) Reference Plan (scenario 2.0C) and the Federal Policy Position Document, with specific assumptions for demand response and energy efficiency.

Forecast) Year Board-Approved GWh % of Electricity Load 2015 121.1 1.1 2016 133.1 1.2 2017 136.5 1.3 2018 136.3 1.2 2019 127.2 1.1 2020 119.2 1.1 2021 121.5 1.1 2022 127.1 1.2 Nova Scotia has remained stagnant at or near the 1.1% metric ov...

AI summary Nova Scotia's energy efficiency performance has remained stagnant at or near 1.1% over the last Plan period, missing cost-effective opportunities. The Settlement Plan proposes a modest increase to 1.2% of electricity load, aiming to address the widening gap and align with leading jurisdictions.

CARBON - For the Settlement Plan, it remains E1's position that it is reasonable to assign a value to carbon and - related pricing avoidance. With this in mind, E1 determined the avoided costs of carbon for the purposes - of the Settlement...

AI summary E1 argues that assigning a value to carbon and related pricing avoidance is reasonable for the Settlement Plan, using the federal carbon pricing trajectory to assess affordability. The discussion also references legislative goals under the Environmental Goals and Climate Change Reduction Act, emphasizing energy efficiency and equitable access for low-income and marginalized communities.

8.3.2 2023-2025 RBIA Investment at the Settlement Plan level would result in average rate impacts that range between -0.1% and 1.0% by rate class, averaged over the lifetime of measures [(Figure 8)](#page-55-0). These figures are calculate...

AI summary The 2023-2025 RBIA discusses the impact of DSM activities on average rates and customer bills. Investment at the Settlement Plan level would lead to average rate impacts ranging from -0.1% to 1.0% by rate class, with average participants experiencing bill reductions between 1.2% and 7.9%.

BY INCREMENTAL DSM Using the 2021 Historical RBIA, DSM induced a rate pressure that ranged from 1.8 to 4.0% across all rate classes. As the 2022 DSM investment of $41 million has already been approved, this investment is already rate-embed...

AI summary The 2021 Historical RBIA showed rate pressure from DSM ranging between 1.8% to 4.0%. The 2022 DSM investment of $41M is already rate-embedded and should not be double-counted. The 2023-2025 DSM Plan will only induce rate pressure from the incremental investment above $41M annually, which is expected to be minimal. DSM is highlighted as a long-term investment and savings mechanism with significant customer benefits.

8.6 ENERGY EFFICIENCY IS THE LEAST RISK OPTION - 18 Energy efficiency is a low-risk energy investment as there is: - Certainty with respect to the level in investment; - No unexpected costs associated with an investment in energy efficienc...

AI summary Energy efficiency is presented as the least risky investment option due to its predictable costs, capped spending, and consistent program performance. Unlike other fuel sources, it avoids unexpected costs and volatility, ensuring ratepayer stability. E1's consistent administration of efficiency programs further supports this claim.

12.1 HISTORICAL RATE AND BILL IMPACT ANALYSIS Currently, E1 files a historical RBIA on, or before, October 31 of each year. The historical RBIA estimates the high-level, long-term impact to rates and bills of all DSM activities up to and i...

AI summary E1 proposes to stop filing the historical RBIA annually except during DSM Plan Application years, citing limited utility and resource consumption. The change aims to reduce internal costs and has minimal impact on stakeholder assessments of DSM Plan performance.

2 LICO is regularly updated by Statistics Canada Program Program Component Description Target Market Segment Market and/or Participant Barriers and How they are Addressed in the Settlement Plan DEMAND RESPONSE Residential Demand Response (...

AI summary The text discusses the Residential Demand Response (DR) program, highlighting how it uses CPP rates and electric vehicle managed charging. It addresses barriers such as the hassle factor for customers, proposing solutions like enabling technologies, education, and incentives to encourage participation.

1. INTRODUCTION EfficiencyOne's (E1) 2023-2025 Demand Side Management (DSM) Resource Plan (Settlement Plan) represents a meaningful and ambitious level of energy efficiency and greenhouse gas (GHG) emission reductions at a time when the cl...

AI summary EfficiencyOne's 2023-2025 Demand Side Management (DSM) Resource Plan aims to deliver cost-effective energy efficiency and demand response initiatives to support the transition to a cleaner electricity system. The plan aligns with federal and provincial net zero goals and builds on E1's 12-year history of successful DSM programs, resulting in significant annual savings and emissions reductions.

1.1.1 2020 INTEGRATED RESOURCE PLAN RESULTS Since E1's 2020-2022 DSM Plan was developed and approved, NS Power conducted a new IRP which was used to inform the development of the Settlement Plan. NS Power's 2020 IRP reflected themes of dec...

AI summary The 2020 Integrated Resource Plan (IRP) by NS Power included demand side management (DSM) and demand response (DR) strategies, with Scenario 2.0C selected as the reference plan. The plan outlines energy savings, capacity targets, and the need for an electrification strategy. E1 anticipates participating in future initiatives but notes uncertainty around funding and implications for DSM.

1.1.2 LEGISLATED CLIMATE CHANGE GOALS Climate change policy and goals are evolving quickly and have shifted even throughout the development of the Settlement Plan. In October and November 2021, the United Nations Climate Change Conference...

AI summary The text discusses the evolving climate change goals and policies, including federal and provincial commitments to reduce greenhouse gas emissions and achieve net zero by 2050. It highlights the role of DSM in contributing to Nova Scotia's clean energy transformation and mentions the need to align the IRP Evergreen Process with recent environmental goals.

1.2.1 OVERVIEW The Settlement Plan delivers demand side resources to Nova Scotia ratepayers in support of achieving NS Power's long-term electricity strategy as provided in the IRP. The Settlement Plan offers a portfolio of DSM services th...

AI summary The Settlement Plan provides demand side management (DSM) services to Nova Scotia ratepayers as part of NS Power's long-term electricity strategy. It focuses on cost-effectiveness, accessibility, and affordability, with a shift toward peak demand reduction and capacity-focused initiatives like demand response. The plan aims to lower energy costs, support the local economy, and improve grid flexibility.

1.2.2 OBJECTIVES OF THE 2023-2025 DSM RESOURCE PLAN - There are three main objectives of the Settlement Plan: - 1. deliver cost-effective demand side resources that support the successful implementation of a long- term electricity strategy...

AI summary The 2023-2025 DSM Resource Plan aims to deliver cost-effective demand side resources, ensure equitable access to services, and conduct transparent planning that incorporates stakeholder input and supports climate and affordability goals.

2. DEVELOPMENT APPROACH & DETAILS The Settlement Plan was developed for the purpose of delivering cost-effective energy and system-peak demand savings to Nova Scotia electricity ratepayers for the three-year plan period. E1 used a multi-ph...

AI summary The Settlement Plan was developed through a multi-phase process to deliver cost-effective energy and system-peak demand savings for Nova Scotia ratepayers. E1, with support from Guidehouse and Energy Futures Group, engaged stakeholders, modelled scenarios, refined assumptions, and aligned with NS Power to finalize the 2023-2025 DSM Plan.

GUIDING PRINCIPLES Transparency – E1 will provide stakeholders and customers with information and insight into the analyses supporting plan development and results and demonstrate how received comments were considered. Accessibility & Equi...

AI summary The document outlines guiding principles for E1, emphasizing transparency, accessibility, equity, and affordability. These principles are supported by tools such as the Integrated Resource Plan, Rate and Bill Impact Analysis, and cost effectiveness testing. Strategic themes, which inform the portfolio design and initiatives for the next plan cycle, are also highlighted.

STRATEGIC THEMES The 2020 IRP Reference Plan – demand side resources are planned in support of the successful implementation of a long-term electricity strategy for delivery of safe, reliable, affordable, and clean electricity that is in t...

AI summary The 2020 Integrated Resource Plan (IRP) emphasizes demand side management (DSM) as a key strategy for achieving safe, reliable, and clean electricity while supporting climate change mitigation. The Settlement Plan aims to increase utility avoided costs for customers, based on the lowest revenue requirement identified in the IRP Reference Plan.

2.2.2 PORTFOLIO-WIDE ASSUMPTIONS & DESIGN OBJECTIVES - E1's key global assumptions and design objectives for all modelled scenarios align with both the Plan's - Guiding Principles and the Standardized Filing Framework (SFF). Specifically,...

AI summary E1's assumptions and design objectives for the 2023-2025 DSM Plan align with the Standardized Filing Framework and Guiding Principles, emphasizing balance between energy and capacity avoidance, program delivery costs, and accessibility. The Balanced Portfolio section outlines how these principles are applied in the development of the DSM Plan scenarios.

7 Table 4: Key Global Assumptions in the 2023-2025 Settlement Plan Development Key Global Assumptions Model ITEM DESCRIPTION OF MODEL INPUTS & ASSUMPTIONS EE DR • Avoided costs of both energy and capacity were based on NS Power's 2020 IRP...

AI summary The document outlines key global assumptions used in the 2023-2025 Settlement Plan Development, including avoided costs based on NS Power's 2020 IRP Scenario 2.0C and the Federal Policy Position on carbon pricing. Transmission and distribution costs are adjusted for inflation, and carbon avoided costs are calculated using a federal backstop trajectory of $170 per tonne by 2030.

3 2.3.1 OBJECTIVES OF THE MODELLING PROCESS - 4 The modelling process, and its associated software tools, were used to support the quantitative - 5 development of the Settlement Plan for both EE and DR. Modelling and software tools support...

AI summary The modelling process supports the quantitative development of the Settlement Plan for Energy Efficiency (EE) and Demand Response (DR). It provides detailed cost effectiveness, energy and demand impacts, participation estimates, and investment views to aid in regulatory processes and performance measurement.

-2025 Settlement Plan will produce incremental CO 2 e reductions of 326 kt over - 2 the three-year Plan period and cumulative net lifetime CO 2 e reductions of 1,742 kt 18 . - 4 Table 10, Table 11, and Table 12 provide the program investme...

AI summary The 2025 Settlement Plan is expected to reduce CO2e emissions by 326 kt over three years and achieve cumulative net lifetime reductions of 1,742 kt. Tables 10, 11, and 12 outline the program investment budgets and targets for 2023, 2024, and 2025.

Annual avoided costs of energy and capacity and annual avoided CO 2 e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM. Avoided costs of transmission and distribution were provided by NS Power in 2021. Cos...

AI summary The text discusses avoided costs and emissions from energy and capacity measures, citing data from NS Power's 2020 IRP and 2021 transmission and distribution costs. It also addresses cost-effectiveness ratios and the investment required for demand response (DR) and energy efficiency (EE) programs.

capacity, transmission, distribution, and carbon over the life of the program measures, using utility WACC. For DR, lifetime benefits are expressed as the 5 6 7 8 9 10 13 14 15 16 17 18 19 - avoided costs, including capacity, transmission,...

AI summary The text discusses the calculation of TRC and PAC for demand response (DR) programs, focusing on the benefit-to-cost ratios over a 10-year period. It includes avoided costs such as capacity, transmission, and distribution, and mentions E1's planned participation by low-income customers within specific rebate programs.

17 Table 17: Summary of Benefits – Efficient Product Rebates (Residential) Participant Industry Benefits Environmental Strategic DSM Portfolio Benefits Benefits Benefits • utility bill savings and improved home comfort • improved access an...

AI summary Table 17 outlines the benefits of the Efficient Product Rebates (Residential) program, focusing on utility bill savings, environmental impact reduction, and strategic alignment with provincial and federal energy efficiency goals. It highlights improvements in home comfort, increased retailer sales, reduced GHG emissions, and support for adoption of energy codes and standards.

ehouse. The DR Roadmap provides additional implementation details and considers how DR can ramp over the period 2021-2030. The DR Roadmap has been included as Attachment 5 – Demand Response Roadmap. E1's DSM Plan proposes expanding the dir...

AI summary The document discusses E1's Demand Response (DR) Roadmap and expansion of DR pathways, including behavioural DR, electric vehicle charging, and behind-the-meter battery. It highlights the inclusion of these new pathways to test technologies and delivery approaches, and to provide customers with more choices. The DR Roadmap and related studies are referenced, along with regulatory actions and legislation.

10 Table 54: Summary of Benefits – Demand Response Participant Industry Benefits Environmental Strategic DSM Benefits Benefits Portfolio Benefits • financial incentives for shifting or curtailing load • access to new controls and informati...

AI summary This table outlines the benefits of demand response (DR) programs, including financial incentives for load shifting, environmental benefits such as reduced reliance on carbon-intensive peaking plants, and strategic advantages like improved cross-utility coordination. However, the current DR pilots are primarily focused on load leveling, and modeling suggests that the costs of delivering these programs may outweigh the benefits.

6.3.1 RESIDENTIAL DEMAND RESPONSE PROGRAM COMPONENT - The Residential DR program component aims to help facilitate a more flexible residential load that may - provide residential customers with economic incentives and/or more visibility an...

AI summary The Residential Demand Response (DR) program component aims to enhance residential load flexibility and provide customers with economic incentives and greater control over their energy usage. E1 will explore five implementation pathways, including battery control and direct load control, with details outlined in Table 55 and Attachment 5.

6.5 PERFORMANCE INDICATORS - DR is a valuable tool for managing peak demand on the electricity system, offering utilities a lower-cost - alternative to acquiring additional flexible generation capacity. DR resources, sometimes called virtu...

AI summary Demand Response (DR) is highlighted as a cost-effective method for managing peak electricity demand, offering an alternative to additional generation capacity. DR involves recruiting customers, installing technologies, and connecting them to systems for load reduction during peak times. E1 proposes performance indicators for new and available demand capacity, measured during the winter peak period and claimed in the following year.

6 Table 57: 2023-2025 Demand Response Performance Indicators Year Investmenta ($ million) New DR Capacity (MW) Available DR Capacity (MW) Total Resource Cost Test (TRC)b Program Administrator Cost Test (PAC)c Participation (participants)d...

AI summary Table 57 outlines the 2023-2025 Demand Response Performance Indicators, including investment, new and available DR capacity, participation numbers, and levelized unit costs. The data shows a significant increase in participation and investment over the three years, with total investment reaching $10 million and participation exceeding 40,000 participants by 2025.

1 Table 59: Demand Response Performance Indicators – Comparison of Settlement Plan and Alternate Scenario Scenario Year Investmenta ($ million) New DR Capacity (MW) Available DR Capacity (MW) Total Resource Cost Test (TRC)b Program Adminis...

AI summary Table 59 compares the performance indicators of the Settlement Plan and Alternate Scenario for Demand Response (DR) programs, highlighting differences in investment, new and available DR capacity, participation numbers, and cost metrics across 2023 to 2025.

7.3.3.3 BENEFICIAL ELECTRIFICATION - Beneficial electrification is a form of electricity DSM focused on the conversion of existing end use applications from fossil fuel sources to electricity, with the intended result of reducing total GHG...

AI summary Beneficial electrification, as defined by E1, involves converting fossil fuel-based end uses to electricity to reduce GHG emissions, save customers money, and maintain grid flexibility. NS Power's 2020 IRP highlighted electrification as a key strategy for GHG reduction, though no costs were modeled. E1 plans to engage in the development of electrification strategies and programs, focusing on funding mechanisms, cost-effectiveness testing, and program integration with other DSM initiatives.

9.5 RATE & BILL IMPACT ANALYSIS - E1 will file its historical Rate and Bill Impact Analysis (RBIA) and forward-looking RBIA as part of each DSM - Resource Plan. The historical RBIA estimates the high-level, long-term impact to rates and bi...

AI summary E1 is required to file both historical and forward-looking Rate and Bill Impact Analysis (RBIA) as part of each Demand Side Management (DSM) Resource Plan. The historical RBIA assesses the impact of past DSM activities, while the forward-looking RBIA estimates the impact of future DSM investments approved by the NSUARB.

9.7.2 PERFORMANCE TARGETS & THRESHOLDS - Performance Target[s46](#page-44-0) apply to the period of the NSUARB-approved Supply Agreement with NS Power, rather than annually; and - E1 is deemed to be in substantial compliance with the NSUAR...

AI summary Performance targets under the NSUARB-approved Supply Agreement with NS Power apply over the agreement period, not annually. E1 is considered in substantial compliance if it achieves 90% or more of cumulative annual energy and system-peak demand savings targets. If below 90%, the NSUARB may take discretionary action.

Appendix A Attachment 1: Rate Class Payback Graphs

AI summary This section provides rate class payback graphs, which are visual representations used to analyze the financial returns of different rate classes in the regulatory proceeding.

Figure 4: Small Industrial Rate Class – Settlement Plan Payback Figure 5: Medium Industrial Rate Class – Settlement Plan Payback

AI summary The text presents two figures illustrating the payback for settlement plans in small and medium industrial rate classes, likely related to energy efficiency or demand response programs. These figures are part of a regulatory proceeding and may be used to evaluate the financial impact of such programs.

1 Figure 8: Municipal Rate Class – Settlement Plan Payback

AI summary The document presents Figure 8, which illustrates the Municipal Rate Class – Settlement Plan Payback. The figure likely outlines the financial implications or payback periods associated with a settlement plan for municipal rate classes.

C. Rate and Bill Impact Analysis E1 will use the Actual Annual AVC Energy stream (AVC 2.0C NPV 2023) of avoided costs of energy as calculated by NS Power for the IRP Reference Plan (scenario 2.0C) and provided to the DSMAG on August 20, 20...

AI summary E1 will use the Actual Annual AVC Energy stream calculated by NS Power for the IRP Reference Plan and provided to the DSMAG in August 2021 for the E1 RBIA. These values are presented in Table 2 as nominal.

- 1. E1's initial proposed method (October 2020), which accounts for the timing of reductions, but does not lend itself well to incorporation in cost-effectiveness testing, as stakeholders have pointed out that it requires the use of some...

AI summary The document discusses two methods for estimating carbon reductions from demand-side management (DSM): E1's initial method, which accounts for timing but has issues with cost-effectiveness testing, and the DICE method, which directly estimates incremental carbon reductions but only roughly estimates the timing of DSM savings.

Table 6 Calculation method Savings Intensity Difference in Carbon Emissions (DICE) with TOU adjustments • Compare annual emissions from IRP scenarios with and without DSM • Make adjustments to differences in emissions between IRP scenarios...

AI summary Table 6 outlines the DICE method for calculating carbon emissions savings from DSM programs, adjusting for timing differences and using these savings to model cost effectiveness between IRP scenarios.

November 15, 2021 Page 11 DATE FILED: 11 March 2022 ______________________________________________________________________________ Page 11 of 13 accounting for the timing of reductions and may be used in the future for historical emissions...

AI summary The DICE method is discussed as a tool for estimating carbon savings and their value stream, aligning with avoided energy and capacity costs. While it is considered reasonable and useful for the Integrated Resource Plan (IRP), improvements by Resource Insight or Synapse could enhance its application in the DSM Plan filing.

l Time Pricing (RTP), Shore Power, Extra-Large Industrial Active Demand Control (ELIADC), and Mining customers since these segments tend to be ineligible for DR programs. - 200 400 600 800 1,000 1,200 1,400 1,600 1,800 2021 2022 2023 2024...

AI summary The text discusses the exclusion of Time-of-Use rates from the DR portfolio, noting that they are solely implemented by NS Power and outside E1's scope. It also references a figure showing winter baseline peak demand by customer class and a table summarizing DR options.

Table 1. Summary of DR Options Considered in the Study DR Option Description Eligible Customer Classes Eligible End Uses Residential Electric Baseboard Direct Load Control Control of electric loads by a thermostat and/or load control Small...

AI summary Table 1 summarizes various demand response (DR) options considered in the study, including direct load control, behind-the-meter battery control, EV charging control, and critical peak pricing, along with eligible customer classes and end uses for each option.

Levelized Costs and Supply Curve As described previously, the supply curve helps determine the relative contributions from the different DR options vis-à-vis the costs for acquiring these resources. [Figure 3](#page-88-1) shows the supply...

AI summary The text discusses the supply curve for demand response (DR) options, including levelized costs and total resource cost (TRC) test costs. It also compares the Net Present Value (NPV), TRC benefit-cost ratios, and levelized costs between the Settlement Plan and Alternate Scenario, noting differences due to participation levels and excluded DR options.

1. Introduction Since the development of EfficiencyOne (E1's) 2020-2022 demand-side management (DSM) Plan, an emerging area of interest in Nova Scotia is demand response (DR). While there has been little demand response activity in Nova Sc...

AI summary The document outlines the development of a demand response (DR) portfolio by EfficiencyOne (E1) in collaboration with Nova Scotia Power Incorporated (NS Power) to meet strategic objectives and expand customer options for managing electricity usage. The DR Roadmap aims to guide E1 in developing a portfolio of DR programs, assessing potential, and establishing a trajectory for acquiring these resources.

Table 5. Market Segmentation and Applicable DR Options Customer Class in Analysis Nova Scotia Power Rate Class Residential • Residential Small Commercial • Small General • General (<100 kW avg. monthly peak load) Large Commercial • Large G...

AI summary Table 5 outlines market segmentation and applicable demand response (DR) options for different customer classes in Nova Scotia, including residential, commercial, industrial, and interruptible classes. It also mentions baseline projections for further analysis.

th 3-coincident-peak-hour demand distribution. Develop Separate Peak Demand •Use EV adoption forecast and estimated peak demand from charging to develop peak Projections for EVs demand projections The first step in this approach was to def...

AI summary The document outlines the process for defining the peak period based on hourly system load data, focusing on 5-8 pm during winter months. It uses data from NS Power and EE scenario results to estimate coincident peak demand by customer class and building type, and projects future peak demand after accounting for energy efficiency savings. The peak period definition differs from that used in the E1 2023-2025 DSM Plan.

2.1.5 Battery Adoption Projections Due to a lack of information on battery adoption projections in Nova Scotia, Guidehouse developed high-level battery adoption forecasts using assumptions drawn from Guidehouse Insights reports and industr...

AI summary Guidehouse developed high-level battery adoption forecasts for Nova Scotia, using assumptions from industry reports and expertise. The projections consider factors like upfront costs, bill savings, and payback periods, while also incorporating a noneconomic adoption adder for residential customers. The model uses a Bass-diffusion curve with a 10-year ramp rate to simulate adoption trends.

2.1.6 DR Options Characterization Once the baseline peak demand projections are developed, the next step is to characterize DR options. [Table 8](#page-101-1) summarizes the DR options included in the study. These options are based on benc...

AI summary The document outlines the process of characterizing Demand Response (DR) options following baseline peak demand projections. Table 8 summarizes the DR options included in the study, which are based on benchmarking with current and emerging DR options and existing DR pilot projects. Time-of-Use (TOU) rates are excluded from the DR portfolio as they are solely implemented by NS Power and outside the scope of E1.

Table 9. Customer Class and Applicable DR Options Customer Class DLC BNI Curtailment Behavioural DR BTM Battery Control EV Charging Control Critical Peak Pricing Time-of- Use Rates 11 Interruptible Rider - $\checkmark$ - $\sqrt{}$ - - - La...

AI summary Table 9 outlines various demand response (DR) options applicable to different customer classes, including DLC, BNI curtailment, behavioural DR, BTM battery control, EV charging control, critical peak pricing, and time-of-use rates. The table highlights which DR options are available to each customer class, such as residential and commercial customers.

x](https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/demand-response/cost-effectiveness/2016-dr-cost-effectiveness-protocols clean.docx) audits, developing and managing a load shed plan, etc. Examples of tran...

AI summary The text discusses non-energy costs associated with Demand Response (DR) programs, such as transaction costs and value of service lost, which are difficult to quantify. It notes that the Total Resource Cost (TRC) test in Nova Scotia does not currently include non-energy benefits in cost-effectiveness assessments. The findings from peak load reduction and cost-effectiveness are to be discussed in the next chapter.

3.1 DR Portfolio Assessment Results This section presents peak load reduction and cost estimates from the different DR options considered in the assessment and the cost-effectiveness findings for these options. The DR analysis conducted in...

AI summary This section presents peak load reduction and cost estimates from various demand response (DR) options analyzed for the period 2021-2030. It discusses supply curve results, benefit-cost ratios, and annual achievable peak load reduction estimates by customer class, with a one-year time shift to reflect when savings can be claimed.

Item Description Program Enrollment Assumptions • Steady state participation levels22 range from 10% to 30% of eligible customers depending on the customer segment and the type of delivery (BYOD and DI). Eligible customers are those that e...

AI summary The document outlines assumptions and parameters for a demand response program, including participation levels, event timing, unit impacts, and projected load reduction. It also discusses the BNI Curtailment Option as part of the DR Portfolio, targeting large C&I customers and projected to provide 9 MW of load reduction by 2025.

3.2.4 Critical Peak Pricing (CPP) Option The 2023-2025 DR Portfolio includes a Critical Peak Pricing offer to Residential and Small C&I customers.[25](#page-121-2) Customers enrolled in the CPP rate will be offered smart thermostats as an...

AI summary The 2023-2025 DR Portfolio includes a Critical Peak Pricing (CPP) option for residential and small C&I customers, offering smart thermostats at no cost. E1 can claim only the portion of CPP savings associated with these thermostats, with projected savings of 0.03 MW by 2025, split between residential and small commercial/industrial customers.

Table 17. Critical Peak Pricing Option Characteristics Item Description Program Description • NS Power plans to offer voluntary opt-in to Residential and Small C&I customer classes starting in 2023, based on the approved CPP rate submitted...

AI summary NS Power plans to introduce a voluntary Critical Peak Pricing (CPP) rate for residential and small commercial/industrial customers starting in 2023, with a 150 cents/kWh critical peak rate. The program includes the direct installation of no-cost smart thermostats to enhance load reduction during peak events. Enrollment is expected to reach 15% of eligible customers after a 5-year period, and the CPP rate is currently a pilot subject to future NSUARB approval.

Item Description The key parameters are listed below with initial assumptions, subject to further revisions during the detailed design stage prior to launch. Operating Months • E1 plans to utilize this for winter peak reduction (Dec. throu...

AI summary The document outlines the parameters for a Critical Peak Pricing (CPP) program, including operating months, event timing, participant load reduction impacts, and projected load reduction and costs for the Settlement Plan. It notes that residential and small C&I participants can achieve varying levels of load reduction depending on enabling technology.

Table 20. Behavioural DR Option Characteristics Item Behavioural DR Description Residential customers will be offered the BDR option on an opt-in basis. BDR does not offer any financial incentives for customers to reduce their usage, nor d...

AI summary The Behavioural Demand Response (BDR) program offers residential customers an opt-in option to reduce electricity usage during high-demand periods through communication and social comparisons, without financial incentives or technology installation. It is projected to achieve a 1.1 MW peak reduction in 2025 with cumulative costs of approximately $233k over the 2023-2025 Plan period.

Program Administration, Data and Performance Analysis E1 is assumed to be primarily responsible for administering the DR program and for undertaking data and performance analysis based on data provided by NS Power and/or third-party DR ser...

AI summary E1 is primarily responsible for administering the DR program and conducting data and performance analysis using data from NS Power and third-party DR service providers. E1 will also develop a performance tracking database and support NS Power in administering the CPP rate.

Billing and Settlement For all DR options, E1 is assumed to be responsible for billing and settlement (customer incentive payments). NS Power would support this function by providing program performance tracking data necessary to undertake...

AI summary E1 is responsible for billing and settlement for all DR options, including customer incentive payments, with NS Power providing performance tracking data. NS Power administers the CPP rate directly as there are no incentive payments for CPP.

Table 22. Residential EE-DR Integration Considerations EE Program EE Program Component EE-DR Measure for Integration Corresponding DR Option for Integration Considerations Brief Description of EE-DR Integration Approach Rebates Smart Water...

AI summary This table outlines how residential energy efficiency (EE) programs can be integrated with demand response (DR) measures. It details rebate programs for smart water heaters and how customers can enroll in a direct load control option with incentives for participation.

31 Customers can also enroll in the rate without enabling technology such as smart thermostats.

AI summary The text mentions that customers can enroll in a rate without using enabling technologies like smart thermostats, indicating flexibility in participation.

Table 23. BNI EE-DR Integration Considerations EE Program EE Program Component EE-DR Measure for Integration Corresponding DR Option for Integration Considerations Brief Description of EE-DR Integration Approach Small Business Smart Thermo...

AI summary This table outlines the integration of energy efficiency (EE) and demand response (DR) measures within the BNI program, specifically focusing on the use of smart thermostats for small businesses. It details a direct load control option with a direct install approach, offering incentives for DR participation.

32 Customers can also enroll in the rate without enabling technology such as smart thermostats. EE Program EE Program Component EE-DR Measure for Integration Corresponding DR Option for Integration Considerations Brief Description of EE-DR...

AI summary The text discusses customer enrollment in a rate without requiring technology like smart thermostats. It also outlines integration approaches for energy efficiency (EE) and demand response (DR) programs, including the BNI Curtailment and Critical Peak Pricing (CPP) options. These programs offer incentives for participation and installation of energy management systems.

4.2.1 Modelling Approach to Represent EE-DR Interactions This section discusses aspects of the DR portfolio that are integrated with the inputs and outputs of ProCESSTM modelling activities conducted for energy efficiency implementation pl...

AI summary This section outlines the integration of demand response (DR) and energy efficiency (EE) programs in the ProCESSTM modelling approach. It discusses baseline peak adjustment, eligibility alignment, cost-sharing, and joint cost-effectiveness testing. Guidehouse subtracts projected EE savings from sales forecasts and uses smart thermostat adoption data to determine eligible customers for DR programs. Incremental costs are shared between EE and DR portfolios based on TRC benefits.

1. EXECUTIVE SUMMARY EfficiencyOne (E1) delivers energy efficiency (EE) programs that offer benefits to customers and the electric utility. While cost-effective energy efficiency is a key resource option for delivering clean, affordable, r...

AI summary EfficiencyOne (E1) delivers energy efficiency programs that benefit customers and the electric utility. While energy efficiency is a key resource, concerns about rate impacts can hinder investment. DSM programs typically reduce customer bills, but may cause rate increases for non-participants, raising equity concerns. E1's Rate and Bill Impact Analysis (RBIA) assesses the long-term rate and bill effects of DSM activities from 2023-2025, projecting impacts until 2039.

2. INTRODUCTION E1 files an historical RBIA to provide insight into the rate and bill impacts resulting from DSM activities that have been carried out since 2011, as well as those that have been approved by the Nova Scotia Utility and Revi...

AI summary E1 files a historical RBIA to analyze the rate and bill impacts of DSM activities from 2011 to 2022, comparing a no-DSM scenario with one that includes program investments. A forward-looking RBIA is also filed with the DSM Resource Plan Applications to assess the impacts of proposed DSM investments on rates and bills, aiding in cost-effectiveness evaluations.

3. UPDATE ON MODEL EVOLUTION - E1 filed its 2021 RBIA Report with the NSUARB on 1 November 2021. In response to requests by Synapse - and Resource Insights (RI), to increase transparency in the NS Power rate analysis, NS Power incorporated...

AI summary E1 submitted its 2021 RBIA Report to the NSUARB, incorporating transfer tables and cost allocation summaries in response to requests for greater transparency. The report also integrated updated avoided costs from the 2020 IRP Reference Plan.

3.1.1 MODEL EVOLUTION - The 2023-2025 DSM Plan includes a demand response (DR) program for the first time. In response to this - new program, E1 worked with its RBIA consultant Elenchus to integrate DR into the E1 RBIA model and NS - Power...

AI summary The 2023-2025 DSM Plan introduced a demand response program, prompting E1 and NS Power to update their models to include DR. E1 worked with Elenchus to refine the model's treatment of measure life, moving from truncating to whole numbers to using fractions for more accurate results.

4.3 CUSTOMER CLASSES - E1's RBIA model present results, by rate class, for the following NS Power customer classes: - Residential (rate codes 2, 3, 4, 5, 6, 9 and 16); - Small General (rate code 10); - General (rate code 11); - Large Gener...

AI summary The document outlines the customer classes for NS Power, including residential, small general, general, large general, small industrial, medium industrial, large industrial, and municipal classes, each identified by specific rate codes. This classification is part of the RBIA model presented by E1.

4.6 CALCULATING RATE IMPACTS - Using the RBIA approach implemented for the first time in the 2020 RBIA, rate impacts are now calculated - in NS Power's Rate Model (Attachment 6 for the Settlement Plan and Attachment 7 for the Alternate The...

AI summary This section discusses the methodology used in calculating rate impacts through the Rate Base Impact Analysis (RBIA) approach, including updates to the number of Municipal Electric Utilities (MEUs) and the integration of Demand Side Management (DSM) into NS Power's Rate Model. The RBIA isolates the effects of DSM on rates by comparing scenarios with and without DSM.

4.7.1 NO-DSM CONSUMPTION - In the no-DSM scenario, for each rate class, and for each year, the estimate of total class energy - consumption is divided by the number of customers to produce an estimate of the average customer's - consumptio...

AI summary The no-DSM scenario estimates average customer energy consumption by dividing total class energy consumption by the number of customers. These averages, combined with no-DSM rates, are used to calculate average bills for the scenario.

4.7.2 NON-PARTICIPANT CONSUMPTION AND BILL IMPACTS - In the DSM scenario, non-participants in DSM programs are assumed to use the same amount of energy as - they do in the no-DSM scenario. Their bill impacts are therefore driven only by ch...

AI summary In the DSM scenario, non-participants in demand-side management programs are assumed to maintain the same energy usage as in the no-DSM scenario. Their bill impacts are influenced only by rate changes under the with-DSM scenario. However, the percentage bill impacts differ from rate impacts due to fixed customer charges, which remain unaffected by DSM.

4.7.4 TOTAL CUSTOMER CONSUMPTION AND BILL IMPACTS - The output graphs include a third category of participants, called Total Customers. Impacts for this category - are determined by allocating DSM savings for the class equally among all cu...

AI summary The section discusses how total customer consumption and bill impacts are calculated by allocating DSM savings equally among all customers in a class, using average savings and DSM scenario rates to estimate average bill savings for Total Customers.

4.9 DEMAND RESPONSE - This section discusses how demand response has been incorporated into the E1 RBIA model and NS Power - Rate Model. - Demand Response costs, savings, measure life, and customer incentives are first calculated and provi...

AI summary The document discusses the integration of demand response into the E1 RBIA model and NS Power Rate Model. Demand response is modeled separately from energy efficiency, allowing for multiple scenarios, such as 'no DSM,' 'energy efficiency without demand response,' and 'demand response without energy efficiency.' Demand response is assumed to have no energy savings, only demand savings, and is modeled with a one-year measure life.

5.1 OVERALL RATE IMPACTS - DSM can lower rates by avoiding different types of electricity system costs (avoided energy, capacity, - transmission and distribution, and carbon costs). DSM may also increase rates, a result of recovering - pro...

AI summary Demand Side Management (DSM) can lower rates by avoiding system costs but may also increase rates due to program costs and lost revenues. The 2023-2025 DSM Plan RBIA analyzes long-term rate impacts, showing average rate changes ranging from -0.1% to +1.0% over 2023-2039, with significant upward impacts during program cost recovery (2023-2025) and smaller impacts afterward.

5.3 OVERALL PARTICIPATION IMPACTS Figures 6 through 9 present actual participation for 2011-2020 and estimates for 2021 through 2025. The estimates for 2021 and 2022 are the same as used in the revised historical 2021 RBIA (filed 20 Januar...

AI summary The document presents participation rates for energy efficiency programs from 2011 to 2025, distinguishing between tracked and untracked participants. Tracked participants are those with direct contact and identifying information, while untracked participants are those who join through point-of-sale programs. Large customer classes show 100% participation, whereas smaller classes show increasing participation rates over time.

5.4.1 RESIDENTIAL - • As modelled, the Residential class includes Rate Codes 2, 3, 6, 9 and 16 (Domestic), as well as 4 and 5 (Charitable). - The average rate impact over the study period is an increase of 0.8 percent, or 0.14 cents/kWh.

AI summary The Residential class in the rate model includes specific rate codes, and the average rate impact over the study period is projected to increase by 0.8 percent, or 0.14 cents per kWh.

5.4.2 SMALL GENERAL - As modelled, the Small General class includes Rate Code 10 only. - The average rate impact over the study period is an increase of 1.0 percent, or 0.16 cents/kWh.

AI summary The Small General class, which includes Rate Code 10, is projected to experience an average rate increase of 1.0 percent, or 0.16 cents per kWh, over the study period.

5.4.3 GENERAL - As modelled, the General class includes Rate Code 11 only. - The average rate impact over the study period is an increase of 0.5 percent, or 0.06 cents/kWh. General ↑ 0.5% Rates - Participants in the General class see an av...

AI summary The General class, which includes Rate Code 11, experiences an average rate increase of 0.5 percent. However, participants in this class see an average bill decrease of 4.2 percent, while non-participants see a 0.4 percent increase. Overall, the class sees a 3.7 percent decrease in average bills.

5.4.4 LARGE GENERAL - As modelled, the Large General class includes Rate Code 12 only. - The average rate impact over the study period is an increase of 0.3 percent, or 0.03 cents/kWh. - Participants in the Large General class see an avera...

AI summary The Large General rate class includes Rate Code 12 and shows an average rate increase of 0.3 percent, but participants experience a 4.0 percent average bill decrease. Non-participants see a 0.2 percent bill increase, while the overall class sees a 4.0 percent bill decrease. All customers are assumed to participate in BER-IR annually, leading to 100% participation by 2023.

5.4.5 SMALL INDUSTRIAL - • As modelled, the Small Industrial class includes Rate Code 21 only. - The average rate impact over the study period is an increase of 1.0 percent, or 0.15 cents/kWh. - Participants in the Small Industrial class s...

AI summary The Small Industrial class, represented by Rate Code 21, experiences an average rate increase of 1.0 percent, but participants see an average bill decrease of 6.1 percent, while non-participants face a 0.9 percent increase. Overall, the class sees a 3.8 percent average bill decrease over the study period.

5.4.6 MEDIUM INDUSTRIAL - As modelled, the Medium Industrial class includes Rate Code 22 only. - The average rate impact over the study period is an increase of 0.1 percent, or 0.01 cents/kWh. - Participants in the Medium Industrial class...

AI summary The Medium Industrial rate class (Rate Code 22) experiences a 0.1 percent rate increase and a 1.2 percent average bill decrease for participants. All customers are assumed to participate in BER-IR, leading to 100% participation by 2023. Non-participants see a 0.1 percent bill increase, though they may not exist in this class.

5.4.7 LARGE INDUSTRIAL rate class. - As modelled, the Large Industrial class includes Rate Code 23 (Large Industrial), Rate Code 25 (Large Industrial, interruptible service), and the one-part high voltage real time pricing tariff. - The av...

AI summary The Large Industrial rate class includes specific rate codes and a high voltage real time pricing tariff. The average rate impact over the study period is a decrease of 0.1 percent, or 0.01 cents/kWh.

5.4.8 MUNICIPAL - As modelled, the Municipal class includes Rate Code 24 only. - The average rate impact over the study period is an increase of 1.0 percent, or 0.14 cents/kWh. Municipal • Municipal utilities see an average bill decrease o...

AI summary The Municipal class includes Rate Code 24, with an average rate increase of 1.0% and a 2.7% decrease in average bills. All municipal electric utilities participated in E1 programs, leading to identical bill impacts for participants and total customers, though individual participation is not modelled.

1 6. COMPARISON OF SETTLEMENT AND ALTERNATE PLANS 2 Full results, by rate class, are provided in Attachments 2 and 3 for the 2023-2025 Settlement Plan and 3 Alternate Scenario, respectively. This section compares key outputs between the tw...

AI summary This section compares the 2023-2025 Settlement Plan and Alternate Scenario, noting that rate impacts are similar across classes, with the Settlement Plan having slightly higher average rate impacts due to differences in DSM program costs. The Settlement Plan also offers more customers the opportunity to participate in DSM programs.

8. CONCLUSION - Highlights from the 2023-2025 DSM Settlement Plan RBIA analysis include: - Over the 17 years of the study period, participants in DSM programs see average annual bill reductions ranging from a low of 1.2 percent (typical Me...

AI summary The 2023-2025 DSM Settlement Plan RBIA analysis highlights significant bill reductions for participants in DSM programs, with ratepayers saving $0.4 billion. The analysis also notes the evolution of the RBIA model, incorporating updated cost allocation and demand response factors to improve accuracy.

Appendix B Attachment 2: Results by Rate Class (Settlement Plan) 11 13 18 22 23 This graph shows estimated rate impacts of DSM, relative to the no-DSM scenario. This graph shows bill impacts of DSM as percentage differences relative to the...

AI summary This appendix presents visual data on the impact of demand-side management (DSM) programs on different rate classes. It includes graphs showing estimated rate impacts, bill differences between participants and non-participants, and annual program participation rates. The data is part of a settlement plan and was filed on 11 March 2022.

4. ENERGY AND DEMAND SAVINGS BY CLASS - For 2023-2025, first-year energy, lifetime energy, and demand savings developed at the program - component level were allocated to rate classes in proportion with the actual rate class allocation of...

AI summary The text discusses energy and demand savings by rate class for 2023-2025, allocating program component savings proportionally based on 2020 rate class allocations, with an exception for the Custom program using a four-year average. Demand response (DR) costs, savings, and customer incentives are calculated separately from energy efficiency inputs, with DR inputs derived from Guidehouse's DRSim™ model and allocated to NS Power rate classes based on peak load contribution.

5.1 DEMAND RESPONSE PARTICIPATION Demand response participation inputs come from Guidehouse's DRSim™ model. Customer classes in the DRSim™ model were attributed to NS Power rate classes based on NS Power class customer counts. The demand r...

AI summary The document discusses demand response participation inputs based on Guidehouse's DRSim™ model, attributing customer classes to NS Power rate classes. Participation is counted annually, and in the DSM scenario, the greater of demand response or energy efficiency participation is assumed due to a lack of historical cross-participation data.

5.2 POINT-OF-SALE PROGRAM COMPONENT PARTICIPATION COUNTS - All forecasted 2021-2025 participation, inclusive of point-of-sale program participation, was estimated - based on 2020 results, using the methodology described above. Participatio...

AI summary The document discusses the methodology used to estimate participation rates for point-of-sale programs from 2011 to 2020, including re-participation and cross-participation rates, and provides formulas for calculating annual and cumulative participation by program and rate class.

6. ENERGY AND DEMAND RATES - NS Power provided estimates for 2011-2022 of rates by class (including energy, demand, and customer - charges). Beyond 2022, energy and demand charges are assumed to escalate at 2.0% per year, while - customer...

AI summary NS Power has updated its rate model to include a blended energy and demand rate, assuming equal savings in both energy and demand. This differs from the previous RBIA model, which only included energy rate impacts. The new model simplifies calculations but may slightly affect individual bill impacts, though total customer bill impacts remain unchanged.

10. CALCULATION OF RATE IMPACTS Rate impacts are calculated in NS Power's Rate Model and used as inputs within E1's RBIA model. - Forecast Unit Revenue (¢/kWh) is made up of the following components (presented in the 'NSP Input' tab): - Fo...

AI summary Rate impacts are calculated using NS Power's Rate Model and input into E1's RBIA model. The forecast unit revenue includes components with and without DSM, but customer and demand charges remain unchanged between scenarios.

Methodology for determination of changes in NS Power's base cost rates as a result of DSM-induced changes in class usage and total system costs November 27, 2020 ____________________________________

AI summary This document outlines the methodology used to determine changes in Nova Scotia Power's base cost rates due to Demand Side Management (DSM)-induced changes in class usage and total system costs.

Cost of Service Studies COSS provides the most insight into class cost causation as based on changes in its energy and demand usage. It shows in a transparent way how rate class usage of demand and energy services within each functional ar...

AI summary Cost of Service Studies (COSS) provide insights into how different rate classes contribute to overall service costs. NS Power's Load Forecast Report and E1's annual forecasts help track changes in usage due to DSM programs. A simplified COSS analysis can be used to adjust pricing without needing detailed future investment data.

Rates and Revenues There is little that can be inferred about the cost causation process from the rate structures used by the utility to generate customers' bills. The rates are bundled and therefore do not allow tracking of cost recovery...

AI summary The document discusses the limitations of NS Power's rate structures, noting that bundled rates make it difficult to track cost recovery by functional areas. It highlights that residential and small general classes recover demand-related costs through energy charges, while other rate classes use a combination of demand and energy charges. There is a lack of alignment between revenues and costs for certain rate classes.

Conclusions Bypassing the detailed COSS ratemaking step, which is intended to show how DSM-induced, cost causative changes in usage affects rates will produce misleading results and create difficulties in interpretation. Any such rate anal...

AI summary Bypassing the detailed COSS ratemaking step leads to misleading results by failing to show how reallocation of embedded system costs affects rates. A simplified COSS process is recommended to provide more precise and insightful rate analyses, particularly regarding changes in class usage and total cost of service due to DSM.

3.0. Applied Approach The relative changes in rates due to DSM are determined by conducting two separate rate setting analyses under the "With DSM" and "No DSM" scenarios. The rate setting process under each scenario is broken out by two s...

AI summary The rate setting process for DSM considers two scenarios: 'With DSM' and 'No DSM,' each analyzed separately for FAM-related and non-FAM-related costs to determine the relative changes in rates.

3.1 Revenue Requirement The annual revenue requirements under the "With DSM" scenario are kept consistent with the test year information from the preceding rate cases. The non-FAM costs in the years following the 2014 test year from the 20...

AI summary The document outlines the annual revenue requirements for both 'With DSM' and 'No DSM' scenarios, noting that non-FAM costs remain constant until 2022 and then increase with inflation. FAM-related costs are adjusted for load changes and inflation. The 'No DSM' scenario adds incremental load effects to the 'With DSM' revenue requirements. Historic cost true-ups are excluded due to minimal impact and complexity.

3.2 Cost of Service Studies Cost of service Studies consist of an application of the following three sequential steps: - functionalization of revenue requirement to the four areas: generation, transmission, distribution and retail; - class...

AI summary Cost of service studies involve three steps: functionalizing revenue requirement, classifying costs, and apportioning costs among rate classes. Most costs are shared by all customers and allocated based on resource utilization, except for streetlight fixture costs, which are assigned to specific customers.

3.2.1 Functionalization of System Costs As indicated in the Revenue Requirement section above, NS Power has used the test year revenue requirements, already functionalized by the four areas, from the historic rate cases. In the "With DSM"...

AI summary The text discusses the functionalization of system costs, particularly in the context of the 'With DSM' and 'No DSM' scenarios. It explains how revenue requirements are adjusted for changes in load and inflation, with specific reference to the impact of the Maritime Link depreciation costs. The 'No DSM' case is derived from the 'With DSM' case by modifying revenue requirements based on load changes due to the absence of demand-side management.

3.2.3 Allocation of Costs to Rate Classes ___________________________________________________________ Annual cost requirements within each service of each functional area are apportioned to rate classes based on class share in the underlyi...

AI summary This section discusses the allocation of annual cost requirements to rate classes based on class share in the underlying usage, considering both the 'With DSM' and 'No DSM' scenarios.

FAM-related Costs The FAM-related costs are allocated to rate classes using the following two-step process: • Annual class energy usage is multiplied by the benchmark unit cost $/MWh DATE FILED: 11 March 2022 Page 7 of 16 _________________...

AI summary The FAM-related costs are allocated to rate classes using a two-step process, with benchmark unit costs derived from previous rate cases. This method does not differentiate between energy and demand-related costs, but this may be addressed in future RBIA applications due to the increasing share of demand-related costs, now at 15 percent.

Non-FAM related Costs The non-FAM-related costs are allocated to rate classes using the following two-step process: - Annual class usages of energy and demand services are multiplied by benchmark $/MWh and $/MW unit costs, respectively - o...

AI summary Non-FAM-related costs are allocated to rate classes through a two-step process. Energy and demand service usages are multiplied by benchmark costs, which differ based on whether demand-side management (DSM) is included. The resulting costs are then scaled to align with the revenue requirement for each service within each functional area.

3.2.4 Generic COSS Results The actual results from the above cost allocation process under the "With DSM" and "No DSM" scenarios are presented in the "COSS Outputs" tab within NS Power's rate model, where the long-term trends in annual rel...

AI summary This section discusses the long-term trends in annual relative unit cost of service differentials between 'With DSM' and 'No DSM' scenarios, highlighting how DSM program cost recovery affects unit costs during the historic budget period and how the out year period sees lower differentials due to expiring DSM measures. It also explains how different rate classes are affected based on their fuel cost and fixed infrastructure cost responsibilities.

Comments The applied process is a simplification of a more elaborate cost allocation process from the COSS where some FAM costs, such as fuel costs, are allocated to rate classes based on their shares in monthly energy requirements; some o...

AI summary The document discusses the allocation of FAM costs to rate classes based on energy and demand factors, using a simplified process derived from the COSS. It also outlines how non-FAM costs are treated as fixed between rate cases, with an option to apply annual inflation adjustments. Class shares in these costs change annually based on system load factor changes.

Comments The applied process is a simplification of a more elaborate cost allocation process where some FAM costs, such as fuel costs, are allocated to rate classes based on their shares in monthly energy requirements; some other FAM costs...

AI summary The text discusses a simplified cost allocation process for FAM and non-FAM costs across rate classes, using factors like monthly and annual energy requirements and system peaks. It outlines how annual non-FAM costs are calculated and prorated across different functional areas and rate classes, with adjustments for inflation from 2023 to 2035.

Comments The applied process is a simplification of a more elaborate cost allocation process in the COSS where energy- and demand- related non-FAM costs, are determined through application of rate base usage allocators developed separately...

AI summary The document discusses the simplification of a cost allocation process used in the Cost of Service Study (COSS), where energy- and demand-related non-FAM costs are determined using rate base usage allocators. The most recent rate setting procedure's class unit costs are carried forward for subsequent year simulations.

"COSS Outputs" tab The "COSS Outputs" tab provides two sets of bar graphs of percentage change in class rates due to DSM over the period 2011–2035 calculated as either arithmetic or load-weighted rate changes. The graphs within each set ar...

AI summary The 'COSS Outputs' tab presents bar graphs showing percentage changes in class rates due to demand-side management (DSM) from 2011 to 2035, calculated using arithmetic or load-weighted methods. It also includes a control panel to test the impact of inflation rates and avoided cost scenarios on unit costs and revenues.

Annual avoided costs of energy and capacity and annual avoided CO 2 e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM for Scenario 2.0C. Avoided costs of transmission and distribution were provided by NS...

AI summary The text discusses avoided costs and CO2e emissions from energy and capacity programs, including data from NS Power's 2020 Integrated Resource Plan. It outlines cost-effectiveness ratios, investment requirements for Demand Response (DR), and the calculation of Total Resource Cost (TRC) and Program Administrator Cost (PAC). Tables 3 to 5 provide program investment budgets for 2023 to 2025.

Annual avoided costs of energy and capacity and annual avoided CO 2 e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM. Avoided costs of transmission and distribution were provided by NS Power in 2021. a I...

AI summary The text discusses avoided costs and emissions from energy and capacity programs, with data provided by NS Power from the 2020 Integrated Resource Plan. It highlights investment requirements for Demand Response (DR) and Energy Efficiency (EE) programs, including the role of NS Power and E1. Metrics like TRC and PAC are used to evaluate program benefits and costs over time.

Annual avoided costs of energy and capacity and annual avoided CO 2 e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM. Avoided costs of transmission and distribution were provided by NS Power in 2021. - a...

AI summary The text discusses avoided costs and emissions from energy and capacity programs, referencing data from NS Power's 2020 Integrated Resource Plan (IRP) and 2021 transmission and distribution costs. It outlines investment requirements for demand response (DR) and energy efficiency (EE) programs, including the role of NS Power and E1, and provides definitions for TRC and dPAC metrics.

5 Q: What are the key elements of Scenario 2.0C and 2.1C? 6 A: Key elements of scenario 2.0C are a low level of future electrification, the retirement of coal 7 plants by 2040, regional integration of the electric system and greenhouse gas...

AI summary Scenario 2.0C includes low future electrification, coal plant retirements by 2040, regional integration, and net-zero emissions by 2050. Scenario 2.1C adds medium electrification for buildings and transportation. Bill No. 57, the Environmental Goals and Climate Change Reduction Act, mandates 80% renewable electricity by 2030 and coal phase-out by 2030, conflicting with these scenarios.

6 Q: Is there a Scenario developed in NSP's 2020 IRP that more accurately reflects the milestones A: Yes. Scenario 3.1C is a better choice for at least three major reasons. First, it is based on the 9 retirement of coal by 2030 as required...

AI summary NSP's 2020 Integrated Resource Plan (IRP) includes Scenario 3.1C, which aligns with Bill 57's coal retirement by 2030 and higher renewable electricity generation targets. It also reflects mid-level electrification consistent with net zero goals, making it a more accurate reflection of current policy and planning conditions compared to Scenario 2.0C.

8 V. Efficiency and Electrification as Critical Strategic Resources to 9 Meet SDGA Targets 10 Q: Is it reasonable to anticipate levels of electrification higher than those represented in scenario ___________________________________________...

AI summary The document discusses the potential for higher levels of electrification than those represented in scenario 2.0C, as testified by David Hill on behalf of EfficiencyOne, referencing the NSP November 2020 electrification scenario details.

2 THE TRC TEST? 3 A. Common benefits calculated for the TRC test include avoided transmission 4 and distribution costs, avoided generation costs, avoided energy costs, avoided 5 environmental compliance costs associated with generation, av...

AI summary The TRC test evaluates the total resource cost by considering both benefits and costs, including avoided costs and non-energy benefits. It accounts for the perspective of both participants and non-participants, and treats incentives as transfer payments, except in low-income programs where they may be considered administrative costs.

17 Q. IS EFFICIENCYONE'S USE OF DISCOUNT RATES CONSISTENT WITH 18 CURRENT INDUSTRY PRACTICE? 19 A. Yes. EfficiencyOne applied Nova Scotia Power's Weighted Cost of Capital 20 (WACC) of 6.33% in its TRC test calculations. Using WACC as the d...

AI summary EfficiencyOne uses Nova Scotia Power's WACC of 6.33% in its TRC test calculations, which is typical. However, a more accurate approach would use discount rates reflecting each actor's perspective. Some US states use lower societal discount rates between 0.3% and 4%.

6 Q. IS EFFICIENCYONE'S TRC TEST CONSERVATIVE? 7 A. Yes, there are several areas that make EfficiencyOne's TRC test results 8 conservative relative to practices in other states or provinces. First, fixed and 9 variable administrative costs...

AI summary EfficiencyOne's TRC test is considered conservative due to factors such as allocating administrative costs at multiple levels, not exempting low-income participants, using WACC as a discount rate, and employing the minimum clearing floor cost for carbon emissions compliance. These practices align with standard evaluation methods.

26 The figure below identifies the Contract Price to be paid by NSPI allocated for each year 27 of the Term. 20202023 20212024 2022 2025 UARB Approved Investment Amount 2016 2020 – 2018 2022 DSM Plan Underspend Net Contract Amount to be Pa...

AI summary The text presents a table outlining the Contract Price to be paid by NSPI for each year of the Term, with sections related to the UARB, Approved Investment Amount, DSM Plan, and Underspend. However, specific figures and details are not provided in the text.

48 On the First Business Day of: 20202023 20212024 20222025 January February March April May June July August September October November December Total SCHEDULE C Performance Requirements I. UARB-APPROVED PERFORMANCE TARGETS, THRESHOLDS, A...

AI summary Schedule C outlines performance requirements for EfficiencyOne under the UARB-approved Plan, including targets for cumulative annual net energy and peak demand savings. Compliance is measured against 90% achievement thresholds, with a regulatory process triggered if these targets are not met. Performance indicators include energy savings, customer satisfaction, and impacts on rates.

Table 7: Implementation Status of Past Recommendations for ARet # Past Recommendations Status Comments 2018 ARet-R1 Continue to perform the metering activity and ensure the metering protocol is followed. Deferred EOne agrees with this reco...

AI summary The document discusses the deferred status of a 2018 recommendation related to the Appliance Retirement (ARET) program, specifically regarding the continuation of metering activities. EOne agrees with the recommendation but was unable to perform a metering study in 2021 due to facility restrictions, using 2017 results instead.

GHG Emission Reduction Calculations To obtain net avoided GHG emissions in CO 2 eq for ARet, the Evaluator multiplied the net energy savings by the latest Nova Scotia-specific factor for GHG emissions generated by electricity production. T...

AI summary The document describes how net avoided GHG emissions in CO2 eq for the Appliance Retirement (ARET) program were calculated by multiplying net energy savings by a Nova Scotia-specific factor derived from NS Power data.

Table 16: Evaluated 2021 ARet GHG Emission Reductions Total Net Energy Savings – at the Generator (GWh) 2.474 Nova Scotia-specific GHG Emissions Factor for Electricity Production (kg of CO2 eq/kWh) 0.5841 Gross Annual GHG Emission Reductio...

AI summary Table 16 presents evaluated 2021 GHG emission reductions from the Appliance Retirement (ARET) program, showing net energy savings, the Nova Scotia-specific GHG emissions factor, and gross annual GHG emission reductions. Section 3.4 discusses the realization rate, indicating the effectiveness of the program in achieving its emission reduction goals.

Table 37: Evaluated 2021 Instant Savings GHG Emission Reductions Total Net Energy Savings – at the Generator (GWh) 14.314 Nova Scotia-specific GHG Emissions Factor for Electricity Production (kg of CO2 eq/kWh) 0.5841 Gross Annual GHG Emiss...

AI summary Table 37 presents evaluated 2021 Instant Savings GHG emission reductions, showing net energy savings, a GHG emissions factor, and gross annual emission reductions. Section 8.4 discusses the realization rate, which is relevant to assessing the effectiveness of these reductions.

APPENDIX I ARET: TRACKING SHEET AUDIT This appendix presents the results of the tracking sheet audit performed by the Evaluator, which was aimed at: - › Verifying whether all the data fields required for the evaluation were included and fi...

AI summary This appendix outlines an audit of EfficiencyOne's tracking sheet for the ARET program, focusing on verifying data completeness, accuracy of energy and peak demand savings calculations, and consistency with previous evaluations. The audit was conducted following the implementation of a new Integrated Customer Information System in 2021.

Table 1: Verification of 2021 ARet Data Field Completeness and Accuracy Data Field Complete (Y/N/Partial) Consistent with Previous Evaluation If Incomplete or Inconsistent, Action Taken by the Evaluator Data for Each Project or Participant...

AI summary The table verifies the completeness and accuracy of 2021 ARet data fields. It highlights missing data in gross and net energy and peak demand savings for multiple participants and notes that values were calculated using line loss factors associated with rate codes.

Table 1: Summary of Existing Residential Program Evaluation Program Evaluation Type Component Impact Process Market Methodology › Tracking sheet audit › Unitary savings review HEA Condensed › Calculations using evaluation results › GHG emi...

AI summary The document presents a summary of the evaluation of existing residential programs, including methods such as participant surveys, tracking sheet audits, on-site visits, and GHG emission reduction calculations. It outlines different evaluation types, such as condensed and comprehensive, and includes specific programs like HEA, Green Heat, Efficient Product Installation, MHEEP, and AMH.

GHG Emission Reduction Calculations To obtain net avoided GHG emissions in CO 2 eq for HEA, the Evaluator multiplied the net energy savings by the latest Nova Scotia-specific factor of GHG emissions generated by electricity production. Thi...

AI summary The document discusses the methodology for calculating net avoided GHG emissions in CO2 eq for Home Energy Assessments (HEA) by multiplying net energy savings with a Nova Scotia-specific GHG emissions factor derived from NS Power data.

Table 23: Evaluated 2021 HEA Net Energy and Peak Demand Savings Total Energy Savings Gross Energy Savings – at the Meter (GWh) 3.305 NTGR 0.75 Unconverted D Assessment Spillover Energy Savings (GWh) 0.740 Net Energy Savings Without Savings...

AI summary Table 23 presents the evaluated 2021 HEA net energy and peak demand savings, including gross and net savings at the meter and generator, as well as deductions for Green Heat and EPI. The table also highlights the effective useful life and net lifetime energy savings. Applying a Nova Scotia-specific GHG factor to the savings results in 2,033 tonnes of annually avoided CO2 eq.

GHG Emission Reduction Calculations To obtain net avoided GHG emissions in CO 2 eq for EPI, the Evaluator multiplied net energy savings by the latest Nova Scotia-specific factor for GHG emissions generated by electricity production. This f...

AI summary The document outlines the method used to calculate net avoided GHG emissions for the Efficient Product Installation (EPI) program by multiplying energy savings with a Nova Scotia-specific factor derived from NS Power data. It also references the 2020-2022 Measure Assessment, which provides parameters for evaluating energy and peak demand savings from EOne's DSM program.

The annual gross savings for each category of products installed in 2021 through EPI are listed below. [Table](#page-170-0) 53 and [Table](#page-178-0) 54 below present the results for single-family homes and apartments respectively. Overa...

AI summary The annual gross savings from EPI programs in 2021 are detailed, with total energy and peak demand savings reported as 8.174 GWh and 1.143 MW respectively. These savings are calculated using line loss factors from the 2014 Cost of Service Study Progress Update submitted to the NSUARB.

As presented in [Table](#page-199-1) 59, applying the Nova Scotia-specific factor 45 for GHG emissions generated by electricity production to EPI net savings corresponds to a total of 4,563 tonnes of annually avoided CO 2 eq.

AI summary The text discusses the calculation of GHG emissions avoided through the Efficient Product Installation (EPI) program, resulting in 4,563 tonnes of annually avoided CO2 eq using a Nova Scotia-specific factor applied to EPI net savings.

45 At the time of writing, 2021 data were not yet available. The Nova Scotia-specific factor was obtained from Nova Scotia Power's 2020 total system emissions data (6,283,894 CO 2 eq tonnes) and total electricity generation (10,759 GWh) wa...

AI summary The text discusses the calculation of a Nova Scotia-specific factor based on emissions and electricity generation data from Nova Scotia Power and Emera Inc. It also notes that evaluated net energy and peak demand savings were 3% higher than those tracked by EOne, with higher NTGR values in 2021 offsetting slightly lower gross savings.

GHG Emission Reduction Calculations To obtain net avoided GHG emissions in CO 2 eq for MHEEP, the Evaluator multiplied the net energy savings by the latest Nova Scotia-specific factor for GHG emissions generated by electricity production....

AI summary The document discusses the calculation of net avoided GHG emissions for the Mi'kmaw Home Energy Efficiency Project (MHEEP) using energy savings and a Nova Scotia-specific GHG emissions factor from NS Power data. First-year savings are based on typical energy consumption, not accounting for changes due to the pandemic.

18.2.2 Peak Demand Savings Peak demand savings correspond to the demand savings that coincide in time with the peak demand period of the electricity system. The projected electricity peak demand period in Nova Scotia is between 5 p.m. and...

AI summary Peak demand savings are calculated based on the peak demand-to-energy ratio, with specific considerations for heat pump measures. The methodology used by Navigant in the 2016-2018 DSM Plan was applied, with adjustments made for heat pump measures starting in 2021, leading to higher average peak demand savings per participant.

18.3.1 Evaluated Net Savings Net savings are defined as the energy savings specifically attributable to MHEEP. Since spillover and free-ridership effects were considered nil, the net MHEEP impacts are equal to the gross savings generated b...

AI summary The evaluated net savings from the Mi'kmaw Home Energy Efficiency Program (MHEEP) are reported as 0.316 GWh of energy and 0.147 MW of peak demand savings. These savings are calculated using a Nova Scotia-specific GHG emissions factor, resulting in the avoidance of 184 tonnes of CO2 eq annually.

Table 65: Evaluated 2021 MHEEP GHG Emission Reductions Total Net Energy Savings – at the Generator (GWh) 0.316 Nova Scotia-specific GHG Emissions Factor for Electricity Production (kg of CO2 eq/kWh) 0.5841 Net Annual GHG Emission Reduction...

AI summary Table 65 evaluates the 2021 MHEEP GHG emission reductions, showing net energy savings of 0.316 GWh and net annual GHG emission reductions of 184 tonnes of CO2 eq. Section 18.4 discusses the realization rate related to these reductions.

GHG Emission Reduction Calculations To obtain net avoided GHG emissions in CO 2 eq for NHC, the Evaluator multiplied the net energy savings by the latest Nova Scotia-specific factor for GHG emissions generated by electricity production. Th...

AI summary The document outlines the method used to calculate net avoided GHG emissions for new home construction (NHC) by multiplying net energy savings with a Nova Scotia-specific GHG emissions factor derived from NS Power data. First-year savings are based on typical energy consumption and do not account for the impact of the COVID-19 pandemic.

As presented in [Table](#page-2-0) 15, applying the Nova Scotia-specific factor 10 for GHG emissions generated by electricity production, 0.5841 kg CO 2 eq/kWh, it was estimated that the net energy savings resulted in 3,320 tonnes of annua...

AI summary The text estimates that energy savings from DSM initiatives have avoided 3,320 tonnes of CO2 eq annually, using a Nova Scotia-specific GHG emissions factor of 0.5841 kg CO2 eq/kWh derived from Nova Scotia Power's 2020 emissions and generation data.

Table 15: Evaluated 2021 NHC GHG Emission Reductions Total Net Energy Savings – at the Generator (GWh) 5.683 Nova Scotia-specific GHG Emissions Factor for Electricity Production (kg of CO2 eq/kWh) 0.5841 Net Annual GHG Emission Reductions...

AI summary Table 15 presents evaluated 2021 NHC GHG emission reductions, showing net energy savings of 5.683 GWh and a reduction of 3,320 tonnes of CO2 eq. Section 3.4 discusses the realization rate, which is relevant to the efficiency and effectiveness of these emission reduction efforts.

Evaluated 2021 Mail-in Net Energy and Peak Demand Savings (Continued) Measure Category Kitchen Pumping Compressed Air Total for All Categories Energy Savings Gross Energy Savings – at the Meter (GWh) 0.031 0.016 0.007 15.408 NTGR 0.74 0.74...

AI summary The document evaluates the 2021 Mail-in Net Energy and Peak Demand Savings, presenting data on energy and peak demand savings across different categories. It highlights the impact of these savings in terms of GHG emissions, estimating 7,074 tonnes of annually avoided CO2 eq using a Nova Scotia-specific factor.

5.2.6 Evaluated Gross Savings The energy and peak demand savings associated with Instant Rebates were calculated using the unitary savings values, ISRs, and interactive effects factors revised as part of this evaluation. The savings at the...

AI summary The document calculates energy and peak demand savings from Instant Rebates using unitary savings values and line loss factors. It references the 2014 Cost of Service Study Progress Update submitted to the NSUARB and provides figures for gross energy and peak demand savings at the generator level.

Table 25: Evaluated 2021 Instant Rebates GHG Emission Reductions Total Net Energy Savings – at the Generator (GWh) 21.380 Nova Scotia-specific GHG Emissions Factor for Electricity Production (kg of CO2 eq/GWh) 0.5841 Gross Annual GHG Emiss...

AI summary Table 25 presents the evaluated 2021 Instant Rebates GHG emission reductions, showing net energy savings, the Nova Scotia-specific GHG emissions factor, and gross annual GHG emission reductions. Section 5.4 discusses the realization rate, which is likely related to the effectiveness or implementation of these rebates.

rticipate should the same service be offered in the future. Many interviewees (5 out of 6) mentioned that they were already looking at other areas or opportunities in anticipation of this eventuality. Four out of six interviewees faced cha...

AI summary Six interviewees participated in the OEM Operational Demand Savings Pilot. Five are considering other opportunities as the pilot concludes. Challenges included M&V clarity, cost justification, and resistance to change. Implementation had minimal impact on service levels. The utility rate structure does not incentivize system peak demand savings, making such projects difficult to prioritize.

23 At the time of writing, 2021 data were not yet available. The Nova Scotia-specific factor was obtained from Nova Scotia Power's 2020 total system emissions data (6,283,894 CO 2 eq tonnes) and total electricity generation (10,759 GWh) wa...

AI summary The text discusses the calculation of a Nova Scotia-specific factor using 2020 data from Nova Scotia Power and Emera Inc. It references total system emissions and electricity generation figures, and includes sources for the data.

Table 40: Evaluated 2021 EMIS GHG Emission Reductions Total Net Energy Savings – at the Generator (GWh) 0.027 Nova Scotia-specific GHG Emissions Factor for Electricity Production (kg of CO2 eq/kWh) 0.5841 Gross Annual GHG Emission Reductio...

AI summary Table 40 evaluates the 2021 EMIS GHG emission reductions, showing net energy savings of 0.027 GWh and gross annual GHG emission reductions of 16 tonnes of CO2 eq. Section 16.5 discusses the realization rate, a key metric in assessing the effectiveness of emission reduction programs.

GHG Emission Reduction Calculations To obtain net avoided GHG emissions in CO 2 eq for SEM, the Evaluator multiplied the net energy savings by the latest Nova Scotia-specific factor for GHG emissions generated by electricity production. Th...

AI summary The document discusses the calculation of net avoided GHG emissions for SEM by multiplying net energy savings with a Nova Scotia-specific factor derived from NS Power data.

20.3.1 Evaluated Net Savings Net savings are defined as the changes in energy use that are specifically attributable to SEM. Since spillover and free-ridership effects were considered nil, the net program component impacts are equal to the...

AI summary Net savings from the Smart Energy Management (SEM) program were estimated at 1.845 GWh and 0.282 MW in 2021. These savings led to an annual avoidance of 1,077 tonnes of CO2 eq emissions, calculated using a Nova Scotia-specific GHG emissions factor.

4.2.6 Evaluated Gross Savings Total gross energy and peak demand savings at the generator were respectively 0.190 GWh and 0.034 MW for the Audit path, 10.643 GWh and 2.321 MW for the DIY path, and 0.272 GWh and 0.043 MW for the Commercial...

AI summary The document provides evaluated gross savings for different energy efficiency programs, including the Audit path, DIY path, and Commercial Direct Instal (CDI) pilot, with specific figures for energy and peak demand savings at the generator. Line loss factors were applied to calculate savings, referencing a 2014 Cost of Service Study Progress Update submitted to the NSUARB.

Unitary Peak Demand Savings For electric thermal storage, an eight-hour charging period is assumed based on the residential offpeak period in Nova Scotia Power's time of day rate. It is also assumed that the stored heat will be provided eq...

AI summary The calculation for unitary peak demand savings for electric thermal storage assumes an eight-hour charging period based on Nova Scotia Power's offpeak rate and assumes even heat distribution over 16 hours. The formula uses the maximum storage capacity from manufacturer specifications.

Installation Rates Installation rates for electric thermal storage systems are estimated at 100% due to their relatively high cost.

AI summary Installation rates for electric thermal storage systems are estimated at 100% due to their relatively high cost.

Regulatory Affairs - engagement with regulatory stakeholders and the DSM Advisory Group (DSMAG) including: - o avoided Costs DSMAG session and request for written stakeholder comments; - o stakeholder written comments on the revised DSMAG...

AI summary The document outlines regulatory activities involving stakeholder engagement with the DSM Advisory Group, submission of various reports to the NSUARB, and implementation of evaluation and verification processes related to energy efficiency programs and NS Power's regulatory filings.

1 2021 Rate Class Results by Program - 2 Tables 2 through 7 provides a breakdown of the 2021 net incremental energy and net peak - 3 demand savings, expenditures, and participation achieved, by rate class, and within each - 4 program. 5

AI summary The text outlines the 2021 Rate Class Results by Program, providing a breakdown of net incremental energy and net peak demand savings, expenditures, and participation achieved, categorized by rate class and program.

NOVA SCOTIA UTILITY AND REVIEW BOARD NOTICE OF PAPER HEARING EfficiencyOne (E1) has made Application to the Nova Scotia Utility and Review Board for Approval of a Supply Agreement for Electricity Efficiency and Conservation Activities betw...

AI summary EfficiencyOne has applied for approval of a supply agreement with Nova Scotia Power Inc for electricity efficiency and conservation activities, including the 2023-2025 Demand Side Management (DSM) Resource Plan. The Board will consider this in a paper hearing, with intervenor and comment deadlines set for March 29, 2022, and May 27, 2022, respectively.

NOVA SCOTIA UTILITY AND REVIEW BOARD be joining the team. They are expected to fly home from a training facility in Philadel- SALTWIRE.COM Pitts said the dogs are a major component to the team because they can quickly search an area faster...

AI summary EfficiencyOne (E1) seeks approval for a supply agreement with Nova Scotia Power Inc. and its 2023-2025 Demand Side Management (DSM) Resource Plan, targeting 412.7 GWh energy savings and 96.7 MW peak demand savings. Separately, the Municipality of Guysborough applies for water rate and regulation amendments. The Nova Scotia Utility and Review Board will hold paper and public hearings for both matters.

Additional information about the matter is as follows: - For flat rate charges, the current quarterly water bill is $166.29, and it is proposed to increase to $193.51, (a 16.4% increase) in 2022/23; $200.62, (a 3.7% increase) in 2023/24; a...

AI summary The Utility proposes increases in flat rate and residential water bills, along with amendments to other metered services and fire protection charges. The Board may adjust these proposals in its decision. The application is available online under Matter No. M10475.

NOVA SCOTIA UTILITY AND REVIEW BOARD NOTICE OF PAPER HEARING EfficiencyOne (E1) has made Application to the Nova Scotia Utility and Review Board for Approval of a Supply Agreement for Electricity Efficiency and Conservation Activities betw...

AI summary EfficiencyOne has applied to the Nova Scotia Utility and Review Board for approval of a supply agreement with Nova Scotia Power for electricity efficiency and conservation activities, including the 2023-2025 Demand Side Management Resource Plan, which aims to achieve 412.7 GWh of energy savings and 96.7 MW of peak demand savings over three years with a $173 million investment.

Annual avoided costs of energy and capacity and annual avoided $CO_2$ e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM for Scenario 2.0C. Avoided costs of transmission and distribution were provided by N...

AI summary The text discusses avoided costs and emissions related to energy and capacity from NS Power's 2020 IRP, including DSM and DR programs. It outlines cost-effectiveness ratios and explains TRC and PAC as benefit/cost ratios, emphasizing the importance of NS Power's collaboration for DR benefits.

2 Scenario Scenario Year Investment First-Year Energy Savings Lifetime Energy Savings Peak Demand Savings Cost Test (TRC) a Program Administrator Cost Test (PAC) b Participation Participation Participation Lifetime Unit Cost ($ million) (G...

AI summary The document presents a comparison of investment, energy savings, and cost metrics across different scenarios (Settlement and Alternate) for a demand-side management (DSM) program. It includes metrics such as investment amounts, energy savings, peak demand reductions, and cost tests (TRC and PAC) for the years 2023 to 2025, along with variances between the scenarios.

Request IR-03: Reference: EfficiencyOne 2023-2025 DSM Resource Plan Filing, Evidence, Page 15 (Page 24/584 of PDF), Line 13 "E1's investment in customer incentives continues to be a significant category of spending as expected in a resourc...

AI summary E1 explains that incentive levels for customer programs do not automatically change with NS Power rate changes. However, rate increases may slightly affect project paybacks. Incentive settings are reviewed individually for Custom programs based on electricity bill savings, but not automatically tied to rate changes.

1 Request IR-04: 2 3 Reference: EfficiencyOne 2023-2025 DSM Resource Plan Filing, Evidence, Page 16(Page 25/584 4 of PDF), Line 17 5 6 Avoided energy and capacity costs have been calculated by NS Power using the 2020 IRP 7 Reference Plan 2...

AI summary The text refers to EfficiencyOne's (E1) responses to information requests regarding avoided energy and capacity costs in the 2020 Integrated Resource Plan (IRP) compared to the 2014 IRP, and the relationship between avoided costs and rate-setting mechanisms. E1 refers to its response to NSUARB IR-13 for detailed explanations.

E1 Responses to Industrial Group (IG) Information Requests NON-CONFIDENTIAL Response IR-06: (a) Consistent with historical categorization, EfficiencyOne's (E1) 2023-2025 DSM Plan portfolio has been categorized by Residential and Business,...

AI summary EfficiencyOne (E1) explains that its 2023-2025 DSM Plan is categorized by sectors (Residential, BNI) and programs like Efficient Product Rebates and Demand Response. Customer groups (Residential, BNI, Diverse & Underserved Communities) and categories (residential, small business, commercial & industrial) are used to organize target markets and report progress toward performance targets.

E1 Responses to Industrial Group (IG) Information Requests NON-CONFIDENTIAL Additionally, in its 2012 DSM Resource Plan Application, E1 requested that the TRC screening test " be applied at the program level, not at the measure level as wa...

AI summary E1 requested in its 2012 DSM Resource Plan Application that the TRC screening test be applied at the program level rather than the measure level. The NSUARB accepted this request, acknowledging the benefits and flexibility it provides. E1 argues that targeted measures not passing the TRC test at the individual level can still be included in DSM programs.

Request IR-25: - Please provide cost allocation tables, by rate class, for each year in a) E1's Preferred Plan; b) - Alternate Scenario; c) Settlement Plan, and d) a Scenario where the Low Income funding is set - at 12% of the investment....

AI summary The request seeks cost allocation tables for various scenarios, including the Settlement Plan, which replaced E1's Preferred Plan after stakeholder alignment in February 2022. Tables 1-4 detail the Settlement Plan's spending by rate class for 2023-2025.

no events are called the customer would typically be compensated based on their nominated load. Incentive payment structure, and measurement and verification (M&V) plan will be finalized as part of the implementation plan for demand respon...

AI summary The text outlines the incentive payment structure for demand response (DR) programs, including an example calculation for BNI curtailment. Residential customers are not eligible for BNI curtailment, but they may participate in other DR offerings. E1 expects NS Power to recover DR program expenditures similarly to other DSM costs.

E1 Responses to Investment Property Owners Association of Nova Scotia (IPOANS) Information Requests NON-CONFIDENTIAL Request IR-04:

AI summary EfficiencyOne (E1) responds to IPOANS's information requests, addressing regulatory compliance and transparency under NSUARB proceedings. The responses focus on rate design, cost allocation, and data disclosure, with E1 emphasizing adherence to standards and confidentiality where applicable.

E1 Responses to Municipal Electric Utilities (MEU) Information Requests NON-CONFIDENTIAL • Synapse Energy Economics (consultant to the NSUARB); • NS Power; • Industrial Group (IG); • Province of Nova Scotia; • Assembly of Mi'kmaw Chiefs; •...

AI summary EfficiencyOne (E1) responded to Municipal Electric Utilities (MEU) information requests, detailing engagement with the Demand Side Management Advisory Group (DSMAG) and collaboration with NS Power. E1 confirmed using the Federal Carbon Pollution Pricing Benchmark for avoided carbon costs and referenced prior responses to other information requests. The text also mentions confidentiality of DSMAG materials and references to specific settlement plan cost-effectiveness data.

1 Request IR-05: 2 3 Reference: Appendix A, Table 8: 2023-2025 Settlement Plan Investment and Savings, page 39 4 of 149. 5 6 Reference: Appendix A, Table 9: 2023-2025 Settlement Plan Investment and Savings, by 7 Program Component, page 40...

AI summary The text outlines Requests IR-05 and IR-06, which involve reproducing and modifying specific tables related to investment and savings in the Settlement Plan for different rate classes and scenarios, including adjustments to avoided energy costs and expenditure breakdowns.

Request IR-09: Reference: Appendix B, Attachment 8, Tab M-1 Participants. In the Rate and Bill Impact Modelling in this Attachment, each Municipal Utility is considered a single "participant" for the entire portfolio. For the other rate cl...

AI summary The document discusses a request regarding the availability of detailed customer participation data in E1 programs within each Municipal Electric Utility (MEU). E1 responds that it does not have this data and explains that its model uses aggregate measure uptake estimates rather than individual customer tracking.

Residual Suggested ID # Original finding Original Finding Description Status Remaining gaps Recommendations risk level timeframe 3.1 Access controls While EfficiencyOne has developed various Remediated + While EfficiencyOne has EfficiencyO...

AI summary EfficiencyOne has implemented logical access controls, but there are inconsistencies, especially with third-party IT providers, leading to a high risk. The original recommendations have been addressed, but further action is needed to align with the rate of access and permissions reviews.

rporate data warehouse with access to PI corporate data through an embedded Excel macro. warehouse Management response N/A Residual Suggested ID # Original finding Original Finding Description Status Remaining gaps Recommendations risk lev...

AI summary This chunk discusses a finding related to the redaction of social insurance numbers in EfficiencyOne's corporate data warehouse. The concern is that the current method does not fully render the numbers irrecoverable, although physical security safeguards are in place for paper forms.

14 Page 1 of 1 M10473 – EfficiencyOne (E1) Application for Approval of a Supply Agreement for Electricity Efficiency and Conservation Activities between E1 and NS Power (2023-2025 DSM Plan) E1 Responses to Nova Scotia Utility and Review Bo...

AI summary E1 responds to an information request from the NSUARB regarding the inclusion of non-electric fuel costs and water costs in TRC and PAC calculations, referencing their prior response to IR-09 and noting a prior Board decision that non-energy impacts are not considered in cost-effectiveness testing.

are appropriate to be made so close to the filing of a multi-billion dollar, ratepayer funded Three-Year Plan. Such actions erode the credibility of the foundational elements that these Three-Year Plans have been built on. With regard to t...

AI summary The Department of Energy and Environmental Regulation (DOER) criticizes the timing of actions related to a multi-billion dollar, ratepayer-funded Three-Year Plan, arguing it undermines credibility. The DOER emphasizes the importance of reliable avoided cost studies, referencing the AESC Study and prior orders, and indicates it will not reject filings solely due to procedural deficiencies in energy efficiency plans.

t reject the Three-Year Plan filings based solely on the Program Administrators’ filing and procedural deficiencies. Unlike other filings, the energy efficiency plans are designed solely for the purpose of delivering energy saving measures...

AI summary The document discusses the rejection of Three-Year Plan filings due to procedural deficiencies but emphasizes that energy efficiency programs are essential for meeting GHG reduction goals. It also highlights the nation-leading status of Program Administrators and their ability to deliver energy efficiency services.

olistic approach to overcoming the technical and financial barriers of electrification (CLF Reply Brief at 2-3, citing MEMA Brief, at 7-9). CLF argues that the EEA Secretary has stated a clear policy need to ramp up electrification and tra...

AI summary The text discusses the need for a holistic approach to electrification, emphasizing the importance of overcoming technical and financial barriers. It also highlights the Low-Income Energy Affordability Network's (LEAN) position on maintaining energy efficiency programs for low-income participants, including specific measures related to lighting and fossil fuel heating systems.

Page 84 2016-2018 Three-Year Plans Order, at 25-27; 2013-2015 Three-Year Plans Order, at 37-40. In addition, the Department considers whether the proposed programs prioritize safety, reliability, security, affordability, equity, and the GH...

AI summary The text discusses the evaluation criteria for Three-Year Plans, including safety, reliability, affordability, equity, and GHG limits. It references legal frameworks such as the Energy Act of 2018 and the Green Communities Act, emphasizing the inclusion of strategic electrification in energy efficiency programs to achieve cost-effective GHG reductions.

-Comm 12-18). The Green Communities Act states that strategic electrification may increase electricity consumption, but stipulates that such efforts must be designed to result in cost-effective reductions in GHG emissions while minimizing...

AI summary The Green Communities Act emphasizes strategic electrification's potential to increase electricity consumption but requires cost-effective GHG emission reductions and minimized ratepayer bill impacts. Program Administrators must prioritize safety, reliability, affordability, and equity in delivering electrification efforts. Weatherization is highlighted as a foundational measure to reduce energy use and prepare buildings for electrification.

D.P.U. 21-120 through D.P.U. 21-129 Page 110 enhanced incentive for prior weatherization).78 As noted above, the Program Administrators state that weatherization is provided along with heating system upgrades for low-income customers (Exh....

AI summary The Department requires Program Administrators to weatherize low-income buildings before installing heat pumps, unless impractical, and to file detailed protocols by May 2, 2022. The Department supports efforts to ensure electrification marketing reaches all customers and aligns with decarbonization goals outlined in the Massachusetts 2050 Decarbonization Roadmap.

(Program Administrator Reply Brief at 9, citing Tr. 1, at 76-77). Although biofuel is a potentially low-carbon renewable energy source, the Department agrees that, regardless of whether biofuels lower carbon emissions, the Green Communitie...

AI summary The Department acknowledges the potential of biofuels but emphasizes the need for energy efficiency measures under the Green Communities Act. It also notes the importance of considering grid decarbonization in benefit calculations and requires Program Administrators to submit a detailed report on baseline establishment methods by May 2, 2022.

ue of GHG emissions reductions and continuous need to review and update the value; and (3) comments from the federal Interagency Working Group (“IWG”) tasked with issuing guidance on the social value of GHG emissions reductions, received i...

AI summary The document discusses the social value of GHG emissions reductions, referencing a $393 per short ton value based on a one percent discount rate, and mentions cost-effectiveness screening using the Total Resource Cost (TRC) test with this value.

t to reducing GHG emissions and signals the importance of emissions reduction efforts to future generations (Program Administrators Brief at 45-46, citing Statewide Plan, Exh. 1, App. Q, Study 3, at 8-20; Exhs. DPU-Comm 1-1(c), (d); DPU-Co...

AI summary The Program Administrators argue that updating the social value of GHG emissions reductions from $128 to $393 per short ton is necessary for accurate cost-effectiveness analyses and to meet GHG reduction targets. They claim using the outdated value could hinder cost-effective projects and require revisions to the Three-Year Plans.

benefits are greater than costs) is considered cost effective. G.L. c. 25, § 21(b)(3). If a sector fails the cost-effectiveness screening, its component programs shall either be modified so that the sector meets the test or is terminated....

AI summary The text discusses the cost-effectiveness screening process for energy programs, referencing statutory provisions and guidelines. It outlines how the Department evaluates programs using the Total Resource Cost (TRC) test, which includes both benefits and costs. The Climate Act has expanded the benefits considered in this screening to include the social value of GHG emission reductions.

m 1-1(b); DPU-Comm 1-3; DPU-Comm 1-5; DPU-Comm 1-6(a); DPU-Comm 8-1; DPU-Comm 11-3). The Program Administrators admit that the literature review is not peer-reviewed research and did not contain any quantitative analysis (Tr. 2, at 282-283...

AI summary The Program Administrators' literature review on discount rates lacks peer-reviewed research and quantitative analysis, leading the Department to find insufficient support for reducing the discount rate from two to one percent. The literature review includes public comments from the IWG, but there is little consensus supporting a one percent discount rate. The Program Administrators are required to provide evidence and explanation for the avoided cost value.

bove one percent (Statewide Plan, Exh. 1, App. Q, Study 3 at 5, 13, 15-20).114 Further, the IWG currently recommends valuing the social value of GHG emissions reductions at $49 per short ton of CO2e, with a corresponding discount rate of t...

AI summary The IWG recommends valuing GHG emissions reductions at $49 per short ton of CO2e with a 3% discount rate. The AESC study group suggests assigning more weight to low-probability, high-impact climate change costs, but Program Administrators did not provide evidence supporting this approach.

02 Administrators claim that the exclusion of these benefits provides an incentive for them to pursue strategic electrification (Statewide Plan, Exh. 1, App. A at 26; Tr. 3, at 421-422). The Department is not persuaded by the Program Admin...

AI summary The Department rejects the Program Administrators' proposal to exclude marginal abatement cost benefits from the savings component, arguing that the current design avoids perverse incentives and aligns with the Green Communities Act. The standard component is seen as consistent across all programs and similar to previous three-year plans.

he year (Statewide Plan, Exh. 1, Apps. A at 38-39; C.1 – Electric (Rev.), Tables IV.B.3.1, IV.B.3.2). The electric Program Administrators propose to allocate SBC and FCM revenues to each customer sector in proportion to each class’ kWh con...

AI summary The document discusses the allocation of SBC and FCM revenues to customer sectors based on kWh consumption and the 2019 Supplemental Budget's impact on RGGI revenues. It also outlines the use of the energy efficiency reconciliation factor (EERF) to collect budget differences from non-EES funding sources.

”) tariffs (see, e.g., Statewide Plan, Exh. 1, App. A at 40; Exh. NG-Electric-5, Table IV.B.3.6 (Rev.)). Based on current Department-approved tariffs, the electric Program Administrators calculate separate EERFs for their residential, low-...

AI summary The document discusses the calculation of energy efficiency reconciliation factors (EERFs) for different customer classes and the use of local distribution adjustment factors (LDAF) by gas Program Administrators. It also notes the lack of projected revenues from other funding sources during the Three-Year Plan term and the submission of bill impacts for both participants and non-participants.

their projected budgets through the EES contained in their EERF tariffs is consistent with the Guidelines.131 Similarly, the Department finds that the gas Program Administrators’ proposal 130 NSTAR Electric incorrectly projected its SBC re...

AI summary The text discusses the alignment of projected budgets through the Energy Efficiency Surcharge (EES) within the Electric Efficiency Reconciliation Factor (EERF) and Local Distribution Adjustment Clause (LDAC) tariffs with established guidelines. It also references a prior error by NSTAR Electric in projecting SBC revenues and the requirement for electric distribution companies to revise their EERF tariffs in future rate cases.

NSUARB IR-17, Attachment 3, Page 232 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 219 5. Bill Impacts The Department must consider customer bill impacts when approving the use of ratepayer funds for energy efficiency programs. D.P.U. 08...

AI summary The Department must evaluate customer bill impacts when approving energy efficiency programs, balancing short-term costs with long-term benefits. This includes considering affordability and equity under General Laws, and assessing the reasonableness of increased budgets due to new programs and statutory requirements.

29, 2022 NSUARB IR-17, Attachment 3, Page 235 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 222 2019-2021 Three-Year Plans Order, at 105-106. For the 2022-2024 Three-Year Plans term, the Legislature has reallocated RGGI revenues such tha...

AI summary The document discusses the reallocation of RGGI revenues and the impact on energy efficiency programs, noting that funding to offset costs to ratepayers has decreased despite increased energy efficiency budgets needed to meet GHG reduction goals. Energy efficiency costs now make up a significant portion of residential gas and electric distribution rates.

owing why the proposed program budget modification should be approved. Date Filed: April 29, 2022 NSUARB IR-17, Attachment 3, Page 239 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 226 the Commonwealth’s critical energy policy goals. Ini...

AI summary The text discusses the need to balance energy policy goals with the impact on customer bills, noting that initiatives like net metering and grid modernization are funded through reconciling mechanisms that recover costs from ratepayers, contributing to approximately 25% of residential electric distribution rates.

h from these policy initiatives, the Department and policy makers must remain cognizant of the cumulative effect that these programs will have on customer bills now and in the future. 140 See, e.g., 220 CMR 18.00; Model SMART Provision, D....

AI summary The text discusses the need for regulators and policymakers to consider the cumulative impact of energy efficiency programs on customer bills. It references various Massachusetts Department of Public Utilities (D.P.U.) proceedings and mentions the use of revenue decoupling to recover program implementation costs through the Energy Efficiency Surcharge (EES).

ty that could be reinvested into their systems between rate cases. Revenue decoupling removed the disincentive to reduce load. D.P.U. 07-50-A at 27-28, 32-33, 87. Full revenue decoupling separates a distribution company’s revenues from all...

AI summary The text discusses the impact of energy policy changes on revenue decoupling, noting that the Energy Act of 2018 has altered the premise behind its adoption. It references the Green Communities Act and the benefits of demand-reducing measures, citing past decisions and regulatory orders.

29, 2022 NSUARB IR-17, Attachment 3, Page 243 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 230 During this upcoming Three-Year Plans term, the electric and gas Program Administrators have committed to making a concerted effort to promot...

AI summary The document discusses the commitment of electric and gas Program Administrators to promote electrification, particularly through the use of high-efficiency heat pump technologies, as part of a strategic shift in energy efficiency efforts under the Climate Act. The goal is to increase kWh consumption in the residential sector despite energy efficiency measures.

that, despite the energy efficiency measures designed to lower electric use, will result in a net lifetime increase in kWh consumption in the residential sector (Statewide Plan, Exh. 1, App. C.1 - Electric (Rev.), Table IV.D). As discussed...

AI summary The text discusses the impact of energy efficiency measures and strategic electrification on residential electricity consumption, noting that despite these measures, there may be a net increase in kWh usage. It also highlights the broader implications of the Climate Act and net-zero goals, including electrification efforts in transportation, and mentions the hybrid approach of the Statewide Plan combining energy efficiency and strategic electrification.

the regional power grid (Statewide Plan, Exh. 1, App. C.1 - Electric (Rev.), Table IV.D). In order to pursue a clean energy future consistent with the Massachusetts 2050 Decarbonization Roadmap, broad electrification achieved through the P...

AI summary The Department concludes that full revenue decoupling for electric distribution companies should be discontinued to align their business models with the Commonwealth's clean energy goals, reducing their neutrality and encouraging increased clean electric load.

that it is appropriate to make this policy change immediately. First, the Department finds that it is in ratepayers’ best interests to no longer make the electric distribution companies whole for lost sales if that is no longer in line wit...

AI summary The Department finds it appropriate to immediately change policy to no longer compensate electric distribution companies for lost sales, aligning with the Commonwealth’s energy policy. Timely implementation of a transition away from revenue decoupling is necessary to align business interests with strategic electric load growth and clean energy goals.

29, 2022 NSUARB IR-17, Attachment 3, Page 246 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 233 policy change now will shift the risk associated with changes in lost revenues from customers to electric distribution company shareholders,...

AI summary The Department of Public Utilities has broad ratemaking authority under G.L. c. 164, § 94, and is considering policy changes that shift revenue risk from customers to electric distribution company shareholders while promoting electrification. The Department must balance this with existing structures like performance-based ratemaking and settlement agreements.

and across time. Investigation into Rate Structures that will Promote Efficient Deployment of Demand Resources, D.P.U. 07-50 at 10 (2007). Further the Department also recognizes that the removal of the revenue decoupling mechanism comes be...

AI summary The Department of Public Utilities is directing electric distribution companies to discontinue full revenue decoupling in their next base rate proceeding, removing a disincentive for strategic electrification. Companies with approved rate plans containing stay-out provisions from settlements or performance-based ratemaking terms cannot terminate their effective rate plans to discontinue revenue decoupling. Performance incentives will continue to encourage cost-effective energy efficiency and strategic electrification.

incentives will continue to play an important role in encouraging distribution companies to pursue all cost-effective energy efficiency, including strategic electrification. Because the 145 The Department may also consider implementing a t...

AI summary The Department considers continuing incentives to promote energy efficiency and strategic electrification. It also discusses the potential implementation of a targeted decoupling mechanism in future base rate proceedings to align with electrification and GHG reduction goals. The discontinuance of full revenue decoupling is not immediate, and an electrification metric will remain for the current Three-Year Plans term.

Once full revenue decoupling is discontinued, an electrification metric will no longer be necessary in future three-year plans. E. Decoupling for Gas Program Administrators Unlike the electric Program Administrators, the proposals containe...

AI summary The document discusses the discontinuation of full revenue decoupling for electric Program Administrators and its implications for future three-year plans. It notes that revenue decoupling for gas Program Administrators will not be discontinued, as their energy efficiency programs reduce gas usage. An investigation into the role of gas distribution companies in decarbonization is also mentioned.

greater than 20 percent. 2019-2021 Three-Year Plans Order, at 174-175. No amended RCS budget proposals were filed with the Department. B. Program Administrators Proposal Each Program Administrator proposes to include its RCS budget as part...

AI summary The document discusses the Residential Existing Buildings program and the proposed RCS budget for the 2019-2021 Three-Year Plan. Program Administrators plan to recover RCS costs through the EES and have provided a breakdown of the budget, though they did not include a home energy scorecard proposal in their Three-Year Plan.

R-17, Attachment 3, Page 253 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 240 3. Department of Energy Resources DOER argues that the Department should approve the Program Administrators’ RCS budgets, which include the cost of implementi...

AI summary DOER argues that the Program Administrators’ proposed RCS budget is reasonable but they are not fully complying with the RCS statute and guidelines, particularly regarding the delayed implementation of home energy scorecards and the requirement for customer consent to disclose audit reports.

some information regarding activities they had taken during the 2019-2021 Three-Year Plans term regarding home energy scorecards, including a contractual agreement with DOE to produce a home energy score (RR-DOER-1; Exh. DOER-Comm 1-4). In...

AI summary The document discusses the need for Program Administrators to file a comprehensive proposal and itemized budget for home energy scorecards in order for the Department to evaluate the reasonableness of the proposed budgets. The Department has not received a complete proposal and thus cannot make findings regarding the budgets.

Nevertheless, as the Department has previously stated in D.P.U. 20-40-A at 23-24, there is great value in marketing the co-delivery of existing solar incentives to reduce energy bills, which delivers on the intent and goals of the Green Co...

AI summary The Department emphasizes the value of co-delivering solar incentives with strategic electrification to reduce energy bills and align with the Green Communities Act. It directs Program Administrators to explore a co-delivery strategy for energy efficiency and solar PV in their 2025-2027 Three-Year Plans, ensuring compliance with regulations and market competitiveness.

rd with its residential new construction and C&I existing buildings enhancements, but makes no substantive findings on the prudence of these incentive levels at this time. The Department again directs the Compact to complete prior to the f...

AI summary The Department of Energy and Resources requires the Compact to analyze enhanced incentives in its 2025-2027 Three-Year Plan, ensuring they are justified and necessary for participation levels. The Compact must provide detailed support for these incentives, including stakeholder review and budget breakdowns, in future filings.

ervice territories. 2019-2021 Three-Year Plans Order, at 146, citing 2016-2018 Three-Year Plans Order, at 118. Given the lack of a more specific directive, however, the Compact continued its practice of providing energy efficiency services...

AI summary The document discusses the continuation of energy efficiency services for Mutual Customers heating with natural gas by the Compact, emphasizing the need for adherence to statewide coordination protocols to ensure consistent implementation and prevent subsidization by electric ratepayers. This directive is interim and subject to final resolution in D.P.U. 16-169.

140. Certain costs that are indirect or shared between the Compact’s municipal aggregation and energy efficiency functions must be allocated between the two functions based on 174 The Compact also may apply for funding from the Massachuset...

AI summary The document discusses the allocation of shared costs between the Compact’s municipal aggregation and energy efficiency functions, referencing the 2019-2021 Three-Year Plans Order. It outlines the need for transparency and the inclusion of allocation methods and variance explanations in Annual and Term Reports.

xh. Compact-2, at 146). The Compact proposes to determine what allocation method to Date Filed: April 29, 2022 NSUARB IR-17, Attachment 3, Page 296 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 283 use for these costs based on its Govern...

AI summary The document outlines the positions of the Attorney General and the Cape Light Compact regarding the allocation of shared costs between municipal aggregation and energy efficiency programs. The Attorney General supports the proposed allocation methods, while the Compact argues that its Governing Board should determine the allocation process.

ree-Year Plans Order, at 140. While the Governing Board may work with the Compact to develop a cost-allocation proposal, the Department must ensure that the Compact spends its ratepayer- provided energy efficiency funds in a reasonable and...

AI summary The text discusses the role of the Compact as a municipal aggregator and Program Administrator, emphasizing its responsibility to ensure that energy efficiency funds are used reasonably and prudently. It also highlights the Compact’s obligation to make rate recovery filings and be subject to the same regulatory standards as investor-owned utilities.

group [of] municipalities. This will not prevent said municipality or municipalities from applying to the Massachusetts clean energy technology center for additional funds. G.L. c. 164, § 134(b). 180 Pursuant to the Green Communities Act,...

AI summary The text discusses the requirement for a fully reconciling funding mechanism (EES) under the Green Communities Act and references ongoing regulatory matters related to the Compact's energy efficiency proposals and allocation methods for the 2022-2024 Three-Year Plan term. It also notes the need to resolve tensions between the Compact's view of its Governing Board's discretion and the Department's ratemaking principles.

182 We note that previously the Compact has reiterated its erroneous belief that it has complied with the Department’s directive that it identify its allocation methods and factors and that the “method it identified to allocate shared cost...

AI summary The text discusses the Compact's incorrect belief that it has fulfilled the Department's directive to identify allocation methods and factors for shared costs. It references past orders and cases where allocation methods were discussed and approved, emphasizing the Department's authority to oversee the EES and investigate the appropriateness of funds collected through it.

method. The Department’s precedent regarding costs shared between or among related entities often involves the same costs at issue in the Compact’s filings: apportioning rent and insurance when operating out of a single facility, employees...

AI summary The text discusses the Department's precedent for allocating shared costs among related entities, citing examples such as rent, insurance, and overhead. It references past cases and rulings from the Department of Public Utilities (D.P.U.) and highlights the importance of cost-effective and nondiscriminatory allocation methods, as seen in cases involving Aquarion Water Company and Oxford Water Company.

ompany of Columbia Gas of Massachusetts, by Eversource Energy, EGMA and NSTAR Gas each share the same corporate parent.193 However, NSTAR Gas and EGMA remain separate operating companies with individual gas distribution service territories...

AI summary NSTAR Gas and EGMA, both subsidiaries of Eversource Energy, seek approval to implement a consolidated Three-Year Plan with shared program design, budget, savings goals, and incentive structures, while maintaining separate operations and service territories.

NSUARB IR-17, Attachment 3, Page 318 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 305 b. Program Budget EGMA and NSTAR Gas requests approval of an aggregated program budget (Exhs. NSTAR Gas-2, at 141; EGMA-2, at 141). NSTAR Gas and EGMA...

AI summary EGMA and NSTAR Gas request approval for an aggregated program budget for their 2022-2024 Three-Year Plan. They propose to track energy efficiency costs separately in each company’s accounting system and allocate common resource costs based on planned net benefits, energy efficiency budgets, and customer numbers in each service territory. They also plan to track spending for low-income gas energy efficiency programs and use an aggregated budget for mid-term modification triggers.

between E1 and NS Power (2023-2025 DSM Plan) E1 Responses to Nova Scotia Utility and Review Board (NSUARB) Information Requests NON-CONFIDENTIAL 1 [Evidence] 2 Request IR-29: 3 4 On p. 59 of 65, E1 stated that “the current benefits as exam...

AI summary E1 explains that while DR programming in the 2023-2025 DSM Plan has higher utility costs than benefits, it provides overall value when considering customer costs, aligning with Nova Scotia’s Total Resource Cost (TRC) test as the primary evaluation method.

1 Request IR-30: 2 3 Regarding Performance Targets, E1 currently only has two targets to satisfy. Those are 4 cumulative (3-year) annual energy savings and cumulative (3-year) annual peak demand 5 savings. The proposed 2023-2025 DSM Plan r...

AI summary E1 is requesting approval for a significant increase in spending for its DSM Plan, but faces concerns about additional performance targets. E1 argues that the increase is due to expanded low-income and small business programs and that historical data supports the effectiveness of energy efficiency investments.

1 Request IR-31: 2 3 Appendix A, page 32 of 149: please describe the modelling quality assurance process in more 4 detail. Within this response, please specially address how this process ensures accuracy in all 5 assumption and variables u...

AI summary The response to Request IR-31 details the quality assurance process used in the DSM Plan modelling, including validation of inputs, segregation of duties, and consistency checks on assumptions and variables.

ome Programs with WAP Services Level of coordination is unclear from publicly available data. Last updated: June 2017 ","Alabama does not have self-direct or opt-out provisions for large customers. Last updated: July 2017 ","Alabama Power...

AI summary Alabama Power and Alabama Gas use Rate RSE for cost recovery, allowing revenue adjustments based on return calculations. The Alabama Public Service Commission (APSC) concluded that existing IRP programs and rate structures meet federal energy efficiency requirements, avoiding new policies. No third-party access policies exist for customer energy data.

in progress. Draft rules released June 26, 2015 are available here and a ruling is still pending, but the commission has recommended utilities use the draft regulation until regulations are finalized. The state's utilities independently de...

AI summary Arizona utilities established interconnection procedures for distributed generation before the ACC's proceeding. CHP is eligible under EERS for energy savings targets, with incentives like tax exemptions and rebates. Net metering rules were updated to net billing in 2016, crediting excess generation at avoided cost rates.

ealth and safety measures shall not be used in the calculation.” Coordination of Ratepayer-Funded Low-Income Programs with WAP Services Level of coordination is unclear from publicly available data. Last updated: April 2017 ","All the majo...

AI summary The text outlines Arizona utilities' self-direct energy efficiency programs for large customers, including participation thresholds and fund retention rules. It also references ACC approvals of revenue decoupling and lost revenue adjustment mechanisms (LRAM) for Southwest Gas, APS, TEP, and UniSource Energy Services, with specific docket numbers.

rate case (Docket No. E-01345A-11-0224). In June 2013, an LRAM was also approved for Tucson Electric Power Company (Docket No. E-01933A-12-0291). UniSource Energy Services also operates under an LRAM. Arizona Public Service (APS) has a tie...

AI summary The text discusses Arizona's rate cases involving Tucson Electric Power and Arizona Public Service, including LRAM mechanisms and performance incentives. It also covers Arizona's lack of policies for energy data release and transportation-land use integration efforts through the 'Growing Smarter' Acts.

to a proposal to develop a consistent approach for weatherization programs across all Arkansas utilities, the PSC approved a uniform weatherization program in PSC Docket 13-002-U, Order No. 22 at 11. Act 1102 of 2017 (Ark. Code Ann. Sec. 2...

AI summary Arkansas has approved a uniform weatherization program for utilities, but has not implemented financial assistance programs for low-income customers as authorized by Act 1102 of 2017. Low-income energy efficiency programs are not required to meet cost-effectiveness rules, and AWP funds are coordinated with federal WAP funds to cover installation costs.

ility certification with an opportunity to execute a standard offer contract. This contract provides energy payments at the utility’s short run avoided cost and administratively-set capacity payments. Last Updated: July 2018 ","Incentives,...

AI summary The text discusses incentives and financing for combined heat and power (CHP) systems in California, including the Self-Generation Incentive Program (SGIP) with renewable fuel blending requirements. It also describes net metering under California's NEM tariff, where customers receive bill credits for excess generation and a trued-up surplus compensation at the end of each 12-month billing period.

installed measures that are common to both programs, thereby preserving LIWP funds for measures that the ESA Program does not provide. Coordination of Ratepayer-Funded Low-Income Programs with SB350 SB 350 was passed in 2015 establishing a...

AI summary The text discusses California's energy efficiency initiatives, including SB 350, which sets energy savings targets and requires studies on barriers to low-income participation. It also addresses the lack of structures for large customers to self-direct energy efficiency efforts and outlines the history of decoupling mechanisms for gas and electric utilities in California.

customers under a straight fixed-variable rate design, which continues through today. The CPUC stopped the electric decoupling mechanisms in 1996 due to restructuring of the electric power industry. In 2001, the Legislature passed Section...

AI summary The text discusses the history and current implementation of decoupling mechanisms in California, including the resumption of decoupling in 2001 and its integration with performance incentives for energy efficiency. It also references the Energy Savings and Performance Incentive (ESPI) established by the California Public Utilities Commission.

s some policies in place to encourage CHP including supportive interconnection policies and net metering rules. No new CHP systems were installed in 2018. ","Policy: Code of Colorado Regulations 723-3 Description: Modeled very closely on t...

AI summary The document discusses Colorado's interconnection standards and net metering rules for CHP systems, noting that no new CHP systems were installed in 2018. It also mentions that there are no state-wide policies to acquire energy savings or generation from CHP, but CHP may be eligible for incentives and financing from the Colorado Energy Office and Xcel Energy.

ystem peak in 2006. The Commission ruled in Proceeding No. 17A-0462EG that PSCo's goal for annual energy savings for 2019-2023 be 500 GWh, an increase from the goal of 400 GWh that had been in effect. HB 21-1238, signed in 2021, strengthen...

AI summary The document outlines energy efficiency and GHG reduction targets set by regulatory proceedings, including a 500 GWh annual energy savings goal for PSCo and incremental load reduction targets for Tri-State Generation and Transmission Association. It also references legislative actions such as HB 21-1238 and SB 21-264, which aim to strengthen natural gas efficiency and clean heat initiatives.

-energy benefits that are likely to accrue from DSM services to low-income customers.” This was increased further to 50% for low-income measures and products in April 2018 under Decision No. C18-0417. To avoid unintended impacts to calcula...

AI summary The text discusses the exclusion of low-income DSM program costs from benefit calculations when the TRC is below 1.0 and the coordination of low-income energy assistance programs with WAP services. It also mentions self-direct programs for large customers offered by Xcel Energy and Black Hills.

cost-effectiveness rules are in place for the HES-Income Eligible program. More information regarding B/C testing of efficiency programs in Connecticut can be found in Chapter 5 of the 2019-2021 Plan. Conn. Gen. Stat. §16-24a required DEEP...

AI summary The text discusses cost-effectiveness rules for the HES-Income Eligible program and references a 2013 review by the Bureau of Energy and Technology Policy (BETP) recommending against implementing a Low Income Discount Rate (LIDR) due to existing programs providing greater benefits. It also outlines the coordination between utilities and Community Action Agencies (CAAs) for the Weatherization Assistance Program (WAP) in Connecticut.

y efficiency measures for WAP projects, including: ductless heat pumps, domestic hot water measures, administrative fees, heating system replacements, insulation, LED bulbs and fixtures, and windows. Under the Energy Affordability Docket,...

AI summary The document discusses energy efficiency measures for low-income programs in Nova Scotia, including ductless heat pumps and insulation, as well as behavioral-based strategies in Connecticut to help customers reduce energy consumption. It also references legislation in Connecticut requiring decoupling of distribution revenues from sales volume.

rning Implementation of Connecticut’s Comprehensive Energy Strategy and Various Revisions to the Energy Statutes, adopted the requirement (again) of decoupling for all electric distribution companies. Currently, United Illuminating uses a...

AI summary This text discusses the implementation of decoupling mechanisms in Connecticut's electric and natural gas distribution companies, including the use of lost-based revenue recovery and performance management incentives tied to energy efficiency goals. It also outlines the introduction of new metrics for tracking energy savings and greenhouse gas emissions reductions.

mber 2020 ","Delaware does not allow for large customers to self-direct the funds they would have paid for energy efficiency, nor to opt-out entirely from participating in energy efficiency programs. Last reviewed: July 2019 ","The state e...

AI summary Delaware does not allow large customers to self-direct energy efficiency funds or opt-out of energy efficiency programs. The state evaluates decoupling on a utility-by-utility basis, and Delmarva Power's program plan did not include performance incentives. Delaware has no policy requiring the release of energy use data and adopted California's clean car program in 2010.

tment of Environmental Protection, The Office of Energy, the Florida Solar Energy Center, as well as information for Florida Weatherization Assistance and Florida's Local Weatherization Agencies List. Last reviewed: June 2020 ","Florida do...

AI summary Florida does not allow large customers to self-direct energy efficiency funds or opt-out of energy efficiency programs. The state does not have decoupling or lost revenue adjustment mechanisms for utilities, though legislation in 2008 directed the Public Service Commission to analyze decoupling. Florida Statute allows financial incentives and penalties for utilities based on energy efficiency performance, but no utilities have requested the additional return on equity.

ncy programs by 2030. Hawaii’s public utilities commission has also adopted an energy efficiency portfolio standard (Docket No. 2010-0037) with a goal of achieving 4,300 GWh of energy savings by 2030. Hawaii has decoupling in place and off...

AI summary Hawaii has implemented energy efficiency programs through a public benefits fee, supported by ratepayers of HECO. The state has adopted an energy efficiency portfolio standard with a target of 4,300 GWh of savings by 2030 and has a decoupling mechanism in place. The Hawaii Clean Energy Initiative was established through a 2008 Memorandum of Understanding with the DOE, aiming for 70% renewable energy by 2030.

21% of the funding is going to ""affordability and accessibilty - Hard To Reach"" categories, which include low-income populations. COVID-response planning also increases focus in this area for PY20. Hawaii Energy's 2019-2021 Triennial Pla...

AI summary The document discusses Hawaii's energy efficiency programs, focusing on affordability and accessibility for low-income populations, the absence of specific cost-effectiveness adjustments for low-income programs, and the implementation of a decoupling mechanism for utilities. It also highlights the lack of coordination between ratepayer-funded low-income programs and the Weatherization Assistance Program (WAP).

me Energy Assistance Charge assessed by electric and gas utilities). Last reviewed: July 2019 ","Electric customers with greater than 10 MW of demand in any 30-minute period are exempt from programs. A self-direct option is available state...

AI summary The text discusses energy efficiency programs, decoupling pilots for gas utilities, and the use of formula rates for electric utilities. It outlines exemptions, self-direct options, and regulatory approvals for these initiatives, including specific case numbers and legal references.

se utilities are using formula rates that adjust every year based on actual costs and actual sales in the previous years. The formula rate is in effect until December 31, 2022 per 220 ILCS 5/16-108.5. Illinois Public Act 99-0906 was passed...

AI summary The text discusses formula rates in Illinois that adjust annually based on actual costs and sales, with an expiration date of December 31, 2022. It also outlines the Illinois Public Act 99-0906, which introduced shareholder incentives for energy efficiency, effective January 1, 2018. The Commission has established guidelines for third-party access to energy data, referencing multiple dockets and sections of the Illinois Public Utilities Act.

"Summary: For the 2019-2023 planning period, targets vary by utility, with average incremental electricity savings of 0.89% per year and natural gas savings between 0.10% and 0.29% of retail sales. For the 2019-2023 planning period IPL set...

AI summary For the 2019-2023 planning period, Iowa's rate-regulated utilities set incremental energy savings goals, with varying targets for electricity and natural gas. The primary cost-effectiveness test used is the societal cost test, and secondary tests include the utility cost test, participant cost test, and others. Evaluations of energy efficiency programs are conducted by utilities under Iowa Administrative Code.

with investor-owned utilities, conducts and publishes an annual evaluation of the Iowa Weatherization Program. The performance assessment is used to determine technical assistance and training needs. Last reviewed: November 2020 ","Iowa Co...

AI summary Iowa's regulatory environment includes provisions for energy efficiency exemptions based on RIM test results, historical consideration of decoupling profits from sales revenue for natural gas utilities, and no current policies requiring energy use data disclosure or rewarding energy efficiency programs. Transportation and land use planning are integrated, with 4% of new vehicle registration fees supporting public transportation.

g Practices (DSESP), a resource of the National Efficiency Screening Project (NESP). Last Reviewed: January 2020 ","Requirements for State and Utility Support of Low-Income Energy Efficiency Programs No specific required spending or saving...

AI summary The text discusses energy efficiency policies in Kansas, noting the absence of specific requirements for low-income programs, no self-direct or opt-out programs, and no mandatory release of energy use data. It also mentions the Kansas Corporation Commission's consideration of decoupling and shared savings mechanisms, though no plans have been approved.

. Industrial rate class customer statewide are eligible to opt out. About 80% of eligible load has opted out, with the remaining 20% made up primarily of TVA customers. Documentation is not required. Last Updated: December 2017 ","Kentucky...

AI summary In Kentucky, industrial rate class customers can opt out of certain programs, with about 80% of eligible load having opted out. The state supports lost revenue recovery for DSM programs, with specific methods outlined in statutes and dockets. No policies exist for releasing energy use data or promoting energy-efficient transportation beyond a freight plan.

ow-income programs. Cost-Effectiveness Rules for Low-Income Energy Efficiency Programs No specific adjustments or exceptions to general cost-effectiveness rules are in place for low-income programs. In its original Quick Start portfolio fi...

AI summary The document discusses low-income energy efficiency programs in Louisiana, noting that no specific cost-effectiveness adjustments apply to them. Entergy submitted an income-qualified program that initially failed the TRC test but was later revised and approved. The Louisiana Public Service Commission authorized an LCFC mechanism for efficiency programs in its Quick Start rules, which was implemented by electric utilities starting in 2014. There is no state-level policy to decouple utility profits from sales.

achusetts's energy efficiency programs to address current challenges related to climate and technology changes by decreasing dependence on fossil fuels and actively managing energy loads in real-time. Legislation enacted in 2021 went furth...

AI summary Massachusetts has enacted legislation to strengthen climate goals, including a 2050 net-zero emissions target. The state has decoupling in place for utilities, with shareholder incentives tied to program performance. Energy efficiency programs are governed by Massachusetts General Law and administered by distribution companies with oversight from the Energy Efficiency Advisory Council.

24. The 2008 Green Communities Act requires that electric and gas utilities procure all cost-effective energy efficiency before more expensive supply resources, requiring a three-year planning cycle. In January 2019, the DPU approved the f...

AI summary The 2008 Green Communities Act mandates that electric and gas utilities procure cost-effective energy efficiency before more expensive supply resources. The 2019-2021 Mass Save plan set ambitious energy savings targets, and the 2022–24 plan emphasizes electrification, equity, and workforce development in response to climate legislation aiming for net-zero emissions by 2050. Specific GHG reduction goals were established for electric and natural gas programs.

y Efficiency Programs Massachusetts relies on the TRC test as its primary test for DSM programs, but it specifically calculates additional benefits from low-income programs in its benefit-cost ratio. D.P.U. 08-50-B specifies that an Energy...

AI summary Massachusetts uses the TRC test for evaluating DSM programs, with special consideration for non-energy benefits in low-income programs. These benefits include health improvements, productivity gains, and safety reductions. The D.P.U. 08-50-B outlines the inclusion of non-energy benefits in Energy Efficiency Plans, and there is a focus on coordinating low-income programs with WAP services.

rwise prevent the installation of cost effective weatherization in low income homes. Last updated: August 2020 ","Massachusetts does not have self-direct or opt-out provisions for large customers. Last reviewed: August 2020 ","Massachusett...

AI summary The document discusses Massachusetts' energy efficiency and regulatory policies, including the implementation of decoupling for utilities, the absence of self-direct or opt-out provisions for large customers, and the use of shareholder incentives tied to energy savings and market transformation. It also mentions the development of a statewide energy efficiency database.

Utilities but did not come to a consensus on a recommendation for an energy savings goal. Last updated: July 2019 ","There are no self-direct or opt-out provisions available to utilities in Maryland. Last updated: July 2018 ","The Public S...

AI summary The text discusses energy efficiency and data policies in Maryland, including the absence of self-direct or opt-out provisions for utilities, the approval of revenue-per-customer decoupling for certain utilities, and the prohibition on disclosing energy use data without customer consent. It also notes the lack of standardized systems for energy use data access.

onsibilities and scope of activities to be performed by the energy efficiency utility includes guidance related to project and savings eligibility for customer-sited generation including deployed CHP. Last Updated: September 2018 ","Incent...

AI summary Efficiency Vermont provides financial support for CHP projects as per the 2016 Order of Appointment for VEIC. Vermont offers a 2.4% Investment Tax Credit for eligible CHP systems up to 50 MW. Net metering is available for CHP systems up to 20 kW, and CHP is considered an eligible project for non-wires alternatives review by the Vermont System Planning Committee.

period January 1, 2018, to December 31, 2020, VEIC can earn up to $4,543,500 for meeting electric energy savings goals and other performance goals including peak savings, and total resource benefits. Vermont statute (30 VSA Sec. 218c) dire...

AI summary The text outlines Vermont's energy efficiency regulations, including statutory requirements for utilities to develop least-cost integrated plans and the decoupling mechanisms for IOUs. It also discusses Act 62 of 2019, which mandates the aggregation and release of energy usage data for multiunit buildings.

jointly with other providers, select a nonprofit to administer the programs, or opt to work with the MPSC-selected program administrator (the Independent Energy Waste Reduction Program Administrator). Energy efficiency programs are support...

AI summary Energy efficiency programs are funded through customer rates, with specific charges for residential and commercial/industrial customers. PA 295 aimed to reduce long-term costs to ratepayers by delaying the need for new power plants, and HB5524 integrated energy efficiency into the resource planning process. The MPSC must approve integrated resource plans before utilities can seek certificates of necessity for new infrastructure.

s who assist the low income with bill payment. Many utilities coordinate their energy efficiency programs with these organizations to further assist low-income households with their home energy needs. Last reviewed: August 2020 ","Self-dir...

AI summary The text discusses self-direct programs for large energy users and changes in decoupling mechanisms for energy efficiency programs. It notes that Act 342 now allows electric utilities with fewer than 100,000 customers to propose decoupling, following the overturning of previous legislation due to lack of statutory authority.

vocating Tariff Equity v. Michigan Public Service Commission, April 10, 2012). In light of the Court’s determination, the Commission dismissed all pending cases involving electric revenue decoupling. Act 295 also authorized natural gas dec...

AI summary The text discusses the implementation of decoupling mechanisms for electric and natural gas utilities in Michigan, referencing court decisions and Commission orders. It also outlines performance incentives for energy efficiency programs, including specific percentages and timeframes for various utility companies.

atewide TRM has not yet been approved by the Missouri Public Service Commission. Natural gas utilities use all five cost effectiveness tests as governed by 4 CSR 240-22.070(8) and 4CSR 240-20.093(8). Further information on cost-effectivene...

AI summary Missouri's cost-effectiveness rules for low-income energy efficiency programs include the use of the total resource cost (TRC) test and exemptions for certain programs. The state requires utilities to include funding for low-income weatherization in their rates, and coordination with WAP services is emphasized.

gh EM&V reports as a percentage of annual demand savings targets. Utilities may also propose recovery of lost revenues as measured and verified through EM&V prior to recovery on a retrospective basis. In early 2016, the Commission approved...

AI summary The document discusses the approval of DSM programs and DSIMs for Ameren Missouri, KCP&L, and KCP&L Greater Missouri Operations Company, allowing utilities to bill customers for estimated lost revenues and recover them through EM&V. Performance incentives are tied to achieving energy and demand savings targets over a 3-year period, with recovery over a 2-year period.

s funding from utility USB programs and also provides bill assistance and low-income weatherization. Energy Share and DPHHS work with Human Resource Development Councils (HRDC) to distribute funding. Last reviewed: July 2019 ","Self-direct...

AI summary The text discusses self-direct programs in Montana, including funding from utility USB programs, bill assistance, and low-income weatherization. It also covers the denial of lost revenue adjustments by the PSC for NorthWestern Energy and MDU, as well as the rejection of NorthWestern's decoupling approach by the PSC.

r, the order was appealed in court and a settlement was reached in 2011. However, the decoupling approach proposed by NorthWestern was rejected by the PSC (see Docket No. 2009.9.129, Order No. 7046i). A decoupling mechanism pilot, called a...

AI summary The text discusses a rejected decoupling approach by NorthWestern, the approval of a fixed-cost recovery mechanism (FCRM) in 2019, and Montana's lack of policies related to energy use data transparency, efficient transportation, low-income housing near transit, and appliance standards beyond federal requirements.

ocket No. 14-10018, a new multiplier method was proposed by the electric utilities. Regulations approving the multiplier methodology have been drafted but have not yet been approved by the Commission. In 2008, the Commission adopted tempor...

AI summary The document discusses the regulatory process in Nevada, including the adoption of decoupling rules for gas utilities, the implementation of a Lost Revenue Adjustment Mechanism for electric utilities, and the investigation into alternative revenue mechanisms. It also highlights the lack of standardized energy use data availability and requirements for third-party access.

cts may be eligible for financing assistance through New Hampshire’s Clean Energy Fund, which is a $6 million revolving loan program administered by the Community Development Finance Authority (CDFA). Net metering: As a result of 2011 legi...

AI summary New Hampshire's Clean Energy Fund provides financing assistance for energy projects. Net metering rules for CHP systems are outlined, with efficiency requirements and capacity limits. The Renewable Portfolio Standard (RPS) requires 23.8% of electricity to come from renewable sources by 2025, with CHP systems potentially qualifying under Tier 1.

the target will represent compliance. A penalty will be assessed if performance of the target is between 50% and 90%, and a utility will be deemed non-compliant if achieving 50% or less of its target. The New Jersey Board of Public Utiliti...

AI summary The New Jersey Board of Public Utilities (BPU) has established compliance targets for energy efficiency programs, with penalties for underperformance. Utilities are required to recover costs through surcharges, and no caps on customer rates are in place. Third-party access to energy use data is available via EDI upon request, with no formal requirements for data provision.

enewable Energy Bonding Act authorizes bonds to be issued to finance energy efficiency and renewable energy improvements in state government and school buildings. CHP systems are eligible for funding. Net metering: In January 2007, the New...

AI summary The Renewable Energy Bonding Act allows bonds to finance energy efficiency and renewable energy improvements in state and school buildings, including CHP systems. In 2007, the PRC expanded net metering in New Mexico to systems up to 80 MW, available to qualifying facilities, with credits at the utility's avoided-cost rate and no statewide capacity cap.

ities, which are not regulated by the commission, are exempt). Customers on a time-of-use tariff are permitted to net meter. There is no statewide cap on the aggregate capacity of net-metered systems. Last Updated: September 2018 ","There...

AI summary New Mexico allows net metering without a statewide capacity cap and permits time-of-use tariff customers to net meter. The state supports renewable-fueled combined heat and power (CHP) with tax credits and incentives, including a 100% Zero Carbon Resource Standard that allows for co-firing with fossil fuels. Recycled energy projects may also qualify for tax credits, and the state energy office collaborates with USDOE for support services.

tion costs, lower bad-debt expense, improved customer service, effectiveness, and other appropriate factors qualifying as utility system economic benefits” [17.7.2.9 NMAC - Rp. 17.7.2.9 NMAC, 1-1-15]. Last reviewed: July 2019 ","A self-dir...

AI summary The text discusses energy efficiency programs in New Mexico, including a self-direct option for large customers, the absence of decoupling mechanisms, and the potential adoption of such mechanisms through HB 291 (2019). It also mentions the existence of a profit incentive mechanism tied to program performance and the participation of utilities in energy efficiency initiatives.

efficiency programs—a Notice of Proposed Rulemaking was published in the NYS Register on April 15, 2015. A new case, 15-M-0252, was established for the utilities post-2015 energy efficiency programs. In January 2016, the PSC authorized NYS...

AI summary This text outlines the development of energy efficiency programs in New York, including the establishment of a Clean Energy Fund, the transition from surcharge-based funding to rate-based recovery, and the setting of energy efficiency targets and strategies. Key events include the Notice of Proposed Rulemaking in 2015 and the issuance of a white paper in 2018.

elines to be filed by August 3, 2015. The order also required electric utilities to implement a self-direct program in accordance with the Self-Direct Program Guidelines no later than January 1, 2017. The Self-Direct Program is available t...

AI summary The Self-Direct Program is available to large energy users with specific demand thresholds and requires adherence to funding and savings commitments. The Commission allowed utilities to decide whether to continue offering the program due to low enrollment. Additionally, utilities must implement decoupling mechanisms and energy efficiency incentives as mandated by past orders.

ely reaching the 17.5% cumulative savings benchmark, a goal anticipated to be surpassed in 2020. Per HB 6, a February 2020 PUCO order calls for the winding down of programs starting in September 2020. In the Public Utilities Commission of...

AI summary Ohio has not implemented policies requiring utilities to release energy use data, lacks transportation and land use integration policies, and has no state programs to incentivize low-income housing near transit. Energy efficiency programs are being phased out under HB 6, and opt-out provisions for energy efficiency have been expanded.

for the program. The jurisdictions listed here have adopted their own building codes. They represent approximately 40% of the population of Oklahoma, or 1,507,066 people (based on the 2010 Census). Last Reviewed: September 2020 "," Gap Ana...

AI summary The document discusses Oklahoma's building code compliance, including a gap analysis and strategic compliance plan developed in 2012. It also notes limited policies to encourage combined heat and power (CHP) deployment, with no interconnection standards or state-wide policies for acquiring energy savings or generation from CHP systems. Net metering for CHP systems has been available since 1988 under OCC Order 326195.

rection program. But no COUs including EPUD are subject to Public Purpose Charge requirements. Portland General Electric and Pacific Power cover approximately 80% of the electric customers in Oregon. Participants in the three participating...

AI summary The text discusses energy efficiency programs in Oregon, including decoupling mechanisms implemented by Portland General Electric and other utilities. It highlights the role of the Oregon Department of Energy in reviewing projects and the use of energy efficiency funds. The text also outlines the historical implementation of decoupling by various utilities.

a through Schedule 320 for large commercial and industrial customers. Pacific Power has historically made interval meter data available through Schedule 271. They called this service Energy Profiler. The only third party that regularly rec...

AI summary The document discusses energy data availability and management in Oregon, including how Pacific Power provides interval meter data and Energy Trust of Oregon's access to customer data. It also outlines Oregon's transportation and emissions policies, including adoption of California's Low-Emission Vehicle and Zero-Emission Vehicle programs.

2424864, for details on DR and EE, respectively). The most recent budgets for energy efficiency programs and electricity and natural gas savings can be found in the State Spending and Savings Tables. For further reading, in May 2009, as pa...

AI summary Pennsylvania utilities have expanded energy efficiency and demand response programs since the enactment of Act 129 in 2008, which established the Energy Efficiency and Conservation Act (EERS). Utilities file energy efficiency plans with the PUC, which may approve, reject, or modify them. Cost-recovery mechanisms and voluntary programs exist for natural gas and electric customers, including low-income households.

A has 13 rural electric cooperatives and several smaller municipalities that are not regulated by the Commission. The rural electric cooperatives do offer some electric efficiency programs/incentives. In 2016, the Commission approved a rat...

AI summary The text discusses energy efficiency programs in Pennsylvania, including the approval of natural gas EE&C programs by the PUC, the implementation of Phase III of Act 129, and the use of the total resource cost test as a primary cost-effectiveness test. It also mentions the absence of natural gas EERS in the state.

re are no self-direct or opt-out provisions in place. Last reviewed: June 2020 ","There is currently no policy in place that rewards successful energy efficiency programs with performance incentives. Please see the Alternative Ratemaking F...

AI summary The document discusses the absence of self-direct or opt-out provisions and performance incentives for energy efficiency programs. It references the Alternative Ratemaking Final Policy Statement and guidelines for third-party access to customer meter data, including requirements for secure web portals for energy use data.

ear energy saving targets. Enacted in 2010, House Bill 8082 authorizes revenue decoupling for electric and natural gas utilities and requires utilities to submit proposals to implement these policies. The most recent budgets for energy eff...

AI summary Rhode Island's energy efficiency programs are funded through a conservation and load adjustment factor, with a minimum surcharge of 2 mills per kilowatt-hour. The Comprehensive Energy Conservation, Efficiency and Affordability Act of 2006 mandated utilities to acquire cost-effective energy efficiency and created a statewide natural gas conservation program. Program plans are reviewed annually by the Rhode Island Public Utilities Commission.

Approaches to Account for Health and Environmental Benefits of Energy Efficiency. Last Updated: January 2019 ","Requirements for State and Utility Support of Low-Income Energy Efficiency Programs The Comprehensive Energy Conservation, Effi...

AI summary The document outlines requirements for state and utility support of low-income energy efficiency programs under the Comprehensive Energy Conservation, Efficiency and Affordability Act of 2006. It discusses funding allocations for residential income-eligible programs, cost-effectiveness rules, and the coordination of ratepayer-funded programs with WAP services.

ons of Rhode Island programs, the state has relied on Massachusetts’ benefit valuation work, as they have similar program types. Coordination of Ratepayer-Funded Low-Income Programs with WAP Services The Rhode Island Department of Human Se...

AI summary Rhode Island coordinates its Low-Income Weatherization Assistance Program (WAP) with the LIHEAP program through collaboration between the Department of Human Services (DHS) and CLEAResult. A Weatherization Technical Committee was formed to share expertise and develop policies. Additionally, revenue decoupling was enacted in 2010 and implemented by National Grid in 2011.

including low-income citizens, are met.” No minimum requirements for low-income energy efficiency spending or savings are specified. Cost-Effectiveness Rules for Low-Income Energy Efficiency Programs Dominion Energy of South Carolina, Duke...

AI summary The text discusses low-income energy efficiency programs in South Carolina, including cost-recovery mechanisms for utilities and coordination with WAP services. It also highlights programs like Project SHARE and Help My House, which provide assistance to low-income households, and mentions opt-out provisions for large commercial customers.

strial, manufacturing or retail commercial customers with 1,000,000 kWh annual usage or greater are eligible to opt-out. Self-certification only is required. Roughly 50% of eligible load is opted-out. Last Updated: July 2016 ","S.C. Code A...

AI summary The text discusses energy efficiency programs in South Carolina, including eligibility for opt-out by large commercial customers, lost revenue recovery mechanisms approved by the Public Service Commission, shared savings incentives for Duke Energy and Dominion Energy, and the absence of revenue decoupling authorization by the South Carolina General Assembly.

: August 2017 ","There are currently no state policies that provide incentives for CHP deployment. Last Updated: August 2017 ","There are currently no additional supportive policies to encourage CHP. Last Updated: August 2017 ",2 out of 20...

AI summary South Dakota's utilities have limited energy efficiency programs, with spending and savings below the national average. Energy efficiency is considered in integrated resource planning, and some utilities offer rebate programs. The South Dakota Energy Smart Initiative supports energy efficiency efforts. No state policies currently provide incentives for CHP deployment.

g Practices (DSESP), a resource of the National Efficiency Screening Project (NESP). Last Reviewed: January 2020 ","Requirements for State and Utility Support of Low-Income Energy Efficiency Programs No specific required spending or saving...

AI summary South Dakota does not have specific spending or savings requirements for low-income energy efficiency programs, and coordination with WAP services is unclear. Lost revenue adjustments are used by utilities, with mechanisms approved by the Public Utilities Commission. Performance incentives are in place, using fixed percentages to cover lost revenues from energy efficiency programs. No policy mandates the release of energy use data to customers or third parties.

o and total program-level screening. The rules for benefit-cost tests are not specified. Some exceptions of flexibility exist in the application like low-income programs, pilots, and new technologies. Coordination of Ratepayer-Funded Low-I...

AI summary The text discusses Tennessee's energy efficiency policies, noting the absence of self-direct or opt-out programs, decoupling of utility profits from sales, and lack of policies rewarding successful energy efficiency programs. The Alignment and Usage Adjustment (AUA) mechanism was implemented to align ratepayer and utility interests, with a 2% accrual on margin recoveries. No policy requires utilities to release energy use data.

targeted low-income energy efficiency program are not less than 10% of the utility’s energy efficiency budget for the program year.” Cost-Effectiveness Rules for Low-Income Energy Efficiency Programs In an Order adopted September 28, 2012,...

AI summary The text discusses cost-effectiveness rules for low-income energy efficiency programs, specifically the use of the Savings-to-Investment ratio (SIR) methodology in Texas. It also outlines the separation of utility-administered low-income programs from WAP services and notes that Texas does not decouple utilities’ profits from sales, with a failed decoupling bill in 2009.

rect Programs. Last Updated: July 2017 ","Texas does not decouple utilities’ profits from their sales. In 2009, the state considered a bill on decoupling, but the legislation did not pass (SB 1972). All investor-owned utilities have a shar...

AI summary Texas does not decouple utilities’ profits from their sales, and a 2009 bill on decoupling did not pass. Investor-owned utilities in Texas have a shared benefit incentive where performance bonuses are awarded for exceeding demand and energy reduction goals. Third-party access to energy usage data is available through the Smart Meter Texas portal, and PUCT rules require utilities to provide read-only access to advanced meter data. Texas has legislation supporting complete streets but lacks policies encouraging efficient transportation systems.

gram uses a wide definition of ""alternative"" energy, including biomass, petroleum coke and shale oil. The incentive itself can be up to a 100% credit of new state taxes over the life of the project. Net Metering: Utah law requires their...

AI summary Utah supports combined heat and power (CHP) through incentives like the Alternative Energy Manufacturing Tax Credit and the U-Save Energy Efficiency Fund. Net metering is available for renewable energy systems up to 25 kW for residential and 2 MW for non-residential. The state's Energy Resource and Carbon Emission Reduction Initiative sets a voluntary renewable portfolio goal, allowing utilities to pursue renewables only if cost-effective.

.gov/~2016/bills/static/SB0115.html). The bill requires the PSC to authorize a large-scale electric utility that is allowed to charge a customer for demand side management under Subsection (2)(a) to: (i) if requested by the large-scale ele...

AI summary The bill authorizes the PSC to allow a large-scale electric utility to capitalize and amortize demand side management costs over 10 years, apply a carrying charge, and recover these costs in customer rates. Schedule 193 and Schedule 194 are balancing account mechanisms used to fund energy efficiency and STEP programs outside of general rate case proceedings.

/load management programs and STEP programs approved by the PSC and managed by PacifiCorp. Charges for these programs appear on customer bills as a line item labeled Customer Energy Services and Step. On October 5, 2006, Questar Gas, now D...

AI summary The document discusses load management and STEP programs managed by PacifiCorp and approved by the PSC, as well as Dominion Energy Utah's Conservation Enabling Tariff (CET) and Demand-Side Management (DSM) Pilot Program. It includes details on rebate programs and legislative support for efficiency initiatives, such as 2009 HJR 9 and HB 307 from 2019.

all ensure that measures to reduce the cost of residential heating are available for low-income households..."" and EMT allocates a minimum of 10% to Low-Income Initiatives. See 35-A MRS §10109(4)(A). Following the passage of LD 1766 in 20...

AI summary The text discusses Maine's efforts to ensure low-income households have access to residential heating cost reductions, including the allocation of LIHEAP funds for heat pump installations. It also covers cost-effectiveness rules for low-income energy efficiency programs and coordination with WAP services.

es a study of bad debt avoidance attributable to energy efficiency to quantify the impact."" EMT, Triennial Plan IV, at pp. 4-7 Coordination of Ratepayer-Funded Low-Income Programs with WAP Services The Maine State Housing Authority admini...

AI summary The document discusses the coordination of low-income energy efficiency programs in Maine, including the integration of the Weatherization Assistance Program (WAP) with other initiatives like the Central Heating Improvement Program (CHIP) and the use of federal funds. It also outlines that large electricity customers in Maine are not eligible for certain energy efficiency incentives due to regulatory provisions.

iency Maine Trust. Instead, electric efficiency incentives for these customers are funded with Forward Capacity Market (FCM) revenues, Maine Power Reliability Program (MPRP) Settlement, or RGGI funds. Until recently, Maine’s largest natura...

AI summary Efficiency Maine Trust funds electric efficiency incentives for large natural gas customers using Forward Capacity Market revenues, Maine Power Reliability Program settlements, or RGGI funds. Large non-generator users are now included in the Natural Gas Efficiency Procurement, with exceptions for certain industries. Efficiency Maine, a quasi-state agency, implements efficiency programs with oversight from the Maine Public Utilities Commission (MPUC), and statutory provisions allow for decoupling mechanisms.

ility, serving roughly 80% of statewide load, proposed and was granted decoupling in its rate case in 2014 (Docket No. 2013-00168). Last reviewed: September 2020 ","Guidelines for Third Party Access In 2007, Maine's Electronic Business Tra...

AI summary Maine's energy sector has implemented decoupling in its rate case, allowing Efficiency Maine access to individual meter data through a Commission Order. Guidelines for third-party access and electronic data interchange standards have been established to support retail competition and data dissemination.

(c) defining the standard criteria that shall be satisfied by an applicant in order to notify the utility, including means of evaluation measurement and verification and confidentiality requirements.” Last Updated: December 2020 ","Virgini...

AI summary Virginia's 2020 Clean Economy Act provides performance incentives for utilities achieving energy savings goals, with additional rewards for exceeding targets. Natural gas utilities are allowed to decouple profits from sales, while electric utilities are not. A 2008 plan implemented by Virginia Gas includes an Energy Conservation Plan and a decoupling mechanism called the RNA Rider.

ral gas decoupling mechanism that provides for a sales adjustment to customers’ monthly bills. The ECP and RNA Rider became effective on January 1, 2009 (Docket No. PUE-2008-00060; December 23, 2008). Virginia Code Section 56-585.1 provide...

AI summary Virginia has no policy requiring utilities to release energy use data. The state has not adopted the Advanced Clean Cars program, though it was recommended in the 2018 Virginia Energy Plan. The state does fund transportation initiatives and has passed complete streets legislation.

s for conservation. Highly efficient CHP systems – that is, systems with a useful thermal energy output of no less than 33% of the total energy output – count towards a utility’s conservation target. Last Updated: July 2018 ","Net metering...

AI summary The text outlines policies related to combined heat and power (CHP) systems and net metering in Washington. It specifies that highly efficient CHP systems contribute to conservation targets and describes the state's net metering law, which applies to systems up to 100 kW. It also discusses the 2015 legislation (H.B. 1095) that promotes CHP development and provides financial support for renewable energy technology manufacturers.

to submit a plan to reach 60% of the current energy assistance need by 2030, and 90% of the current energy assistance need by 2050. Cost-Effectiveness Rules for Low-Income Energy Efficiency Programs Washington specifies the total resource...

AI summary Washington State requires utilities to submit plans to meet increasing energy assistance needs by 2030 and 2050. The state uses the Total Resource Cost (TRC) test as the primary cost-effectiveness criterion for low-income energy efficiency programs, with a minimum TRC ratio of 0.67. Non-energy benefits are included in the TRC test, and utilities are encouraged to fund low-income conservation measures, as outlined in the Weatherization Manual. The commission revised rules in Docket UE-131723 to allow, rather than require, utilities to pursue cost-effective low-income conservation programs.

represented 84.6% of the qualifying load. More information on large customer self-direct programs can be found in the ACEEE report, Follow the Leaders: Improving Large Customer Self-Direct Programs. Last reviewed: July 2019 ","The proposed...

AI summary The text discusses decoupling mechanisms implemented by Avista, Puget Sound Energy, and Pacific Power and Light, which involve commitments to increase electric conservation savings and support low-income programs. It also notes that consumer-owned utilities are not subject to state regulation of retail rates and may adjust rates as needed.

gy Program funds, the WV Office of Energy is working with the Homebuilders Association of West Virginia Foundation and Energy Efficient West Virginia to provide training on the 2009 IECC and beyond. Last Reviewed: September 2020 ",,"CHP sy...

AI summary The document discusses the status of CHP systems in West Virginia, noting that they are eligible for net metering but lack supportive policies. It also mentions the repeal of the Alternative and Renewable Energy Portfolio Standard in 2015, which affected CHP's eligibility for energy generation incentives.

ndards that apply to CHP and CHP is an eligible resource in the state's renewable portfolio standard. No new CHP systems were installed in 2018. ","Policy: Wisconsin Administrative Code Chapter PSC119 Description: Established in 2004, Wisc...

AI summary The document discusses Wisconsin's interconnection standards, energy efficiency resource standards, and net metering policies. Combined heat and power (CHP) is eligible under interconnection standards but not specifically identified in energy efficiency standards. Net metering allows CHP systems up to 20 kW, with credits based on renewable or non-renewable status.

programs. Municipal and retail electric cooperative utilities can collect the dollars and participate in the Focus on Energy program or can elect to operate their own Commitment to Community programs. Program cost recovery is handled via i...

AI summary The document outlines how program cost recovery is managed through rate cases and escrow accounts, with the Public Service Commission of Wisconsin overseeing the programs. Investor-owned utilities established SEERA to administer energy efficiency programs under Act 141. Focus on Energy offers residential and non-residential energy efficiency and renewable energy programs.

on Activities between E1 and NS Power (2023-2025 DSM Plan) E1 Responses to Small Business Advocate (SBA) Information Requests NON-CONFIDENTIAL 1 stakeholder engagement on the 2023-2025 DSM Plan in support of Beneficial 2 Electrification. E...

AI summary E1 discusses its role in the 2023-2025 DSM Plan, emphasizing its involvement in NS Power’s Electrification Strategy and noting that a final Beneficial Electrification Strategy for Nova Scotia has not been completed. E1 also mentions that it has not developed a framework for evaluating the cost-effectiveness of beneficial electrification measures and that such measures may increase customer electricity bills.

Program costs, energy savings, and demand savings by participating rate class

AI summary The text provides an overview of program costs, energy savings, and demand savings categorized by participating rate classes. It highlights the relationship between different rate classes and their respective contributions to energy and demand savings through various programs.

te is shown in the Attachment as “Retrofit/Replacement”, however it is 25 possible to acquire that rebate and then install the lamp in a new building or addition built onto 26 an existing home. Date Filed: April 29, 2022 E1 (SBA) IR-12 Pag...

AI summary EfficiencyOne (E1) is responding to information requests from the Small Business Advocate (SBA) regarding changes in avoided cost calculations due to increased focus on decarbonization. E1 refers to its response to NSUARB IR-13 for details.

on Activities between E1 and NS Power (2023-2025 DSM Plan) E1 Responses to Small Business Advocate (SBA) Information Requests NON-CONFIDENTIAL 1 Request IR-16: 2 3 Please provide the answers to the following questions regarding individual...

AI summary E1 responds to the Small Business Advocate's request regarding the 2023-2025 DSM Plan, explaining that the model includes program costs and cannot confirm if all measures pass TRC and PAC tests without reconfiguring the model. The Settlement Plan meets the NSUARB's requirement for TRC ratios above 1.0 at the program level.

1 [Evidence] 2 Request IR-11: 3 4 Please refer to p. 61, Section 12.1, on the historical rate and bill impact analysis. 5 6 (a) Please indicate the source of the requirement for E1 to conduct a historical RBIA. If the 7 source is a Board O...

AI summary The document discusses a request for information regarding the historical Rate and Bill Impact Analysis (RBIA) required for EfficiencyOne (E1) under a Board Order from the 2016-2018 DSM Resource Plan (M06733). The request includes inquiries about the source of the requirement, the scope of the RBIA, and communication with other DSMAG members.

IT IS HEREBY ORDERED that: - 1. The Board approves a DSM Plan for 2016-2018 in the aggregate amount of $102,150,000 with a target of total cumulative energy savings of 405.9 GWh and demand savings of 62.5 MW. Approved spending is $33,210,0...

AI summary The Nova Scotia Utility and Review Board (NSUARB) approves a DSM Plan for 2016-2018 with a total budget of $102,150,000 and sets targets for energy and demand savings. It also approves agreements, outlines reporting and research requirements, and directs the submission of alternate DSM budget scenarios and rate impact analyses.

26. GENERAL - 26.1 This Agreement shall only be renewed in accordance with the provisions of the Act. - 26.2 This Agreement shall extend to, be binding upon and enure to the benefit of the respective successors and permitted assigns of the...

AI summary This section outlines the general terms of the agreement, including its renewal conditions, binding nature, governance by Nova Scotia law, and the role of EfficiencyOne as an independent contractor. It also addresses the enforceability of the agreement, language requirements, and execution procedures.

SCHEDULE C (PAGE 2 OF 2) PERFORMANCE REQUIREMENTS - ix. An analysis of the impact on rates through the implementation of the 2016-2018 programs will be included as part of EfficiencyOne's historical-looking rate and bill impact analysis, f...

AI summary This section outlines performance requirements for EfficiencyOne, including the analysis of program impacts on rates, reporting on low-income program participation, and the breakdown of performance indicators by rate class as part of its reporting to the UARB.

1. INTRODUCTION 1 2 3 4 5 The 2016-2018 Demand-Side Management (DSM) Resource Plan has been developed based on ENS's growing experience and history in delivering successful DSM programs and services to Nova Scotians. As part ofthe process,...

AI summary The 2016-2018 Demand-Side Management (DSM) Resource Plan is developed by ENS with input from consulting firms, aiming to provide a comprehensive suite of programs and services for Nova Scotia electricity users. The Plan balances affordability, rate impacts, and long-term planning, and complies with the UARB's 2015 Decision. It outlines investment amounts and revised targets for achieving energy and demand savings.

3) PERFORMANCE TARGETS, INDICATORS AND THRESHOLDS - a) The parties agree to the following Performance Targets and Performance Indicators: - i) Performance Targets are set over the three-year contract period, rather than annually. - ii) Eff...

AI summary The parties agree on performance targets and indicators for a three-year contract period. EfficiencyOne must achieve at least 90% of two key targets—cumulative annual energy and peak demand savings—or face a regulatory process. Additional performance indicators include energy savings, customer satisfaction, and low-income program participation, with reporting requirements specified.

6) RATE AND BILL IMPACT ANALYSIS - a) As with prior filings of its rate and bill impact analysis, EffidencyOne agrees to develop, in consultation with the DSM Advisory Group, assumptions to its rate and bill impact analysis. This will incl...

AI summary EfficiencyOne agrees to collaborate with the DSM Advisory Group to develop assumptions for its rate and bill impact analysis, including contribution to fixed costs, and to file historical analyses annually by October 31st.

Testimony 1. Pennsylvania PUC R‐2022‐3031211. Columbia Gas of Pennsylvania – Rate Case. March 2022. Three‐year energy efficiency plan proposal. 2. Ontario Energy Board (OEB), EB‐2021‐0002. Enbridge Gas Inc. – Multi Year Demand Side Managem...

AI summary The document lists various regulatory proceedings from different jurisdictions, focusing on energy efficiency plans, demand-side management, and utility rate cases. These include analyses of program goals, implementation, and impacts on affordability and bill management.

4 Q WHAT PROGRAMS HAS E1 PROPOSED? - 5 A The programs that E1 proposes to study and the expected effect are shown in Figure 4 - of the Guidehouse report:[8](#page-11-0) 6 8 Application, Appendix A, Attachment 5, PDF 290. Of the six program...

AI summary E1 proposes six programs, but four (EV Charging, Critical Peak Pricing, Behavioral DR, BNI Curtailment) offer minimal peak reduction and are redundant. Only BTM Battery Control and Direct Load Control (DLC) show potential, though DLC is already administered by NS Power and Battery Control forecasts are speculative.

1 Q WHAT IS YOUR EVALUATION OF THE DEMAND CONTROL PROGRAMS? 2 A Developing more demand control load is worthwhile. NS Power can certainly benefit 3 from increased ability to reduce system peak demand. However, this is essentially a rate 4...

AI summary The evaluation highlights that developing demand control programs is worthwhile, as NS Power benefits from reducing peak demand. However, this is primarily a rate design matter for NS Power, with E1's role limited to supplying equipment like smart thermostats, which is considered a utility service.

7 Q WHY SHOULD THIS BE HANDLED MOSTLY BY NS POWER? 8 A It is unclear how much value is added by having E1 work on developing and demand 9 control rates. alongside of NS Power. For example, the Guidehouse report shows E1 10 playing a "suppo...

AI summary The response argues that NS Power, not E1, should handle demand response (DR) rate design due to its historical expertise in interruptible power rates and rate administration. E1's role is described as supportive, while NS Power manages core functions like billing and technology installation. Examples include the Large Industrial Interruptible Rate and comparisons to Tampa Electric's services.

Application, Appendix A, Attachment 5, PDF 301. Utilities With Small Load Interruptible Services 14 that estimates battery adoption based on simple payback analysis. Detailed 15 modelling of battery projections was outside the scope of the...

AI summary The applicant recommends that E1's proposed incentives be adjusted to be more transparent and rigorous, and that NS Power take the lead in developing and administering small customer interruptible rates. The applicant also suggests reducing E1's budget for this work, except for direct equipment costs.

1 Immediately prior to joining Daymark Energy Advisors, I worked as an independent 2 consultant with Direct Energy developing retail electric business plans. From 2001 to 2005, 3 I was an Associate Director of North American Electric Power...

AI summary The individual has extensive experience in energy planning, market analysis, and regulatory affairs, including roles at Cambridge Energy Research Associates and Northeast Utilities Service Company. They have worked on Integrated Resource Planning, energy efficiency programs, and rate design.

4 A. BNI programs are slated to receive investment of $68.2 million dollars through the three 5 years of the Plan. E1's analysis on rate impact over the 2023-2039 period as featured in 6 Figure 9 of the Plan filing is listed below. This sh...

AI summary The document discusses the impact of the BNI program investment on small business electricity rates over the next 17 years, highlighting potential rate increases of 0.4% to 1% and near-term increases of 3.5% to 4.5% over four years. It emphasizes the importance of participation in programs to achieve bill reductions, with non-participants facing higher bill increases.

A. Not necessarily. Many measures are still cost effective for the residential class that could directly lower a residential customer's bills and still have overall system cost savings. Additional investment in the most cost-effective prog...

AI summary The text argues that investing in cost-effective measures across all sectors, including residential and BNI, can lead to overall system cost savings and lower electricity rates for all customers. It emphasizes that focusing solely on the residential class may not be the most effective approach if it leads to higher costs from non-carbon generation.

Exhibit E13 – Response to SBA IR-05. Exhibit E17 - Response to SBA to H. Gil Peach IR-01. 1 component only achieved 77% of its 2021 target13 . The BNI Sector as a whole achieved 2 only 86.4% of the savings target for 2021, resulting in a D...

AI summary The response to SBA IR-05 discusses the underperformance of the BNI Sector in meeting its 2021 energy savings targets, achieving only 86.4% of the savings goal. The review highlights differences in cost effectiveness between customer classes, higher spending in the first year of the Plan, and the lack of discussion on the cost effectiveness of marginal DSM measures. It also raises concerns about the significant rate and bill impacts on non-participating small businesses.

Vice President and Principal Consultant John provides clients with valuable insights and strategic perspective based on his diverse electric industry experience on matters including utility resource planning, energy efficiency program desi...

AI summary John, Vice President and Principal Consultant, offers strategic insights in utility resource planning, energy efficiency programs, ratemaking, and competitive markets. He has testified before U.S. and Canadian regulatory agencies, leveraging his extensive electric industry experience to inform clients.

Electric utility leadership included: - Created the branding and marketing functions for Select Energy's retail energy sales, which was then the largest retail provider in New England - Developed a service offering and negotiated a contrac...

AI summary Electric utility leadership roles included branding for Select Energy's retail energy sales, leading rate departments during restructuring, managing integrated resource planning, and negotiating flexible rate tariffs with commercial/industrial customers. Key achievements involved creating New England's largest energy aggregation and pioneering municipal aggregation through Cape Light Compact.

Expert Testimony FORUM ON BEHALF OF MATTER Nova Scotia Utility and Review Board Nova Scotia Small Business Advocate Public Utilities Act, R.S.N.S. 1989, c.380, as amended Application by NS Power for approval of the 2023 Annual Capital Expe...

AI summary The text lists multiple regulatory proceedings involving Nova Scotia Utility and Review Board and other entities, including applications for capital expenditure plans, rate adjustments, and financing structures. These matters involve various stakeholders and legal frameworks, such as the Public Utilities Act.

- Q. Please state your name, title, and employer. - A. Ms. Napoleon: My name is Alice Napoleon. I am a Principal Associate at - Synapse Energy Economics ("Synapse"), located at 485 Massachusetts Avenue, - Cambridge, MA 02139. - A. Mr. Taka...

AI summary This text introduces two witnesses from Synapse Energy Economics, detailing their roles and expertise in energy regulation, policy analysis, and energy efficiency programs. The witnesses provide background on Synapse's work in electricity and gas industry regulation, planning, and analysis.

- Q. What do you conclude regarding E1's inclusion of non-electric fuel costs and reduced water costs in the BCA? - A. Since these avoided costs do not have an impact on electric system costs, they should not be included in the PAC in any...

AI summary The discussion addresses whether non-electric fuel and reduced water costs should be included in the BCA for the TRC test, concluding they should not be included in the BCA but may be in the TRC. It also recommends emphasizing the PAC for cost-effectiveness testing or developing a jurisdiction-specific test aligned with provincial policy priorities.

4 Q. Do you support the inclusion of the demand response programs in the 2023– 5 2025 DSM Plan? 6 A. Yes. Demand response offers a variety of benefits to the electric system, to the 7 consumers in the province, and to the environment. Dema...

AI summary The respondent supports the inclusion of demand response programs in the 2023–2025 DSM Plan, citing benefits such as cost savings, renewable energy integration, and grid management. However, concerns are raised about the Behavioral DR program's reliance on summer-focused studies for winter peak load reduction estimates.

PROFESSIONAL EXPERIENCE Synapse Energy Economics Inc, Cambridge, MA. Senior Associate, 2015–present; Associate , 2004‒2015. Analyzes technologies, policies, and regulations associated with supply- and demand-side energy resources. Assesses...

AI summary The text outlines professional experience in energy economics, focusing on energy efficiency, renewable energy, and regulatory analysis. It details work at Synapse Energy Economics Inc., research on distributed resources, and roles in policy analysis, including ratemaking, market trends, and clean energy programs.

Measure. Synapse Energy Economics for Bloom Energy. Takahashi, K., B. Havumaki, J. Kallay, T. Woolf. 2019. Bloom Fuel Cells: A Cost-Effectiveness Brief. Synapse Energy Economics for Bloom Energy. Camp, E., B. Fagan, J. Frost, D. Glick, A....

AI summary The text lists reports by Synapse Energy Economics on energy topics including fuel cells, rate mitigation for the Muskrat Falls Project, energy efficiency planning, and decarbonization strategies. These studies were commissioned by organizations such as Bloom Energy, Newfoundland and Labrador's utility board, and the Natural Resources Defense Council.

TESTIMONY Pennsylvania Public Utility Commission (Docket No. M-2020-3020824): Revised Direct Testimony of Alice Napoleon and Kenji Takahashi regarding PPL Electric Utilities' proposed Act 129 Phase IV Energy Efficiency and Conservation. On...

AI summary Alice Napoleon and Kenji Takahashi provided testimony across multiple regulatory proceedings, representing the Natural Resources Defense Council (NRDC) and other entities on energy efficiency programs, rate mechanisms, and demand-side management (DSM) plans. Their testimonies addressed issues related to utility rate structures, DSM plan reviews, and regulatory compliance in various jurisdictions.

3. Demand Response The IG's consultant, Mark Drazen, provides the following comments regarding the proposed costs for the development and implementation of demand response (DR) programs: Developing more demand control load is worthwhile. N...

AI summary The Industrial Group's consultant, Mark Drazen, argues that NS Power should primarily handle demand response (DR) program development and rate design, with E1's role limited to equipment supply. NS Power agrees but notes E1's role as the DSM franchise holder. Both parties support proceeding by paper process, citing no need for an oral hearing.

4.4 E1'S ROLE AND VALUE IN DEMAND RESPONSE Industrial Group In his testimony on behalf of the Industrial Group, Mark Drazen stated that while Demand Response is a worthwhile venture, it is essentially a rate design matter and should be han...

AI summary The Industrial Group argues Demand Response is a rate design matter for NS Power, citing limited peak reduction and uncertainty in battery control forecasts. E1 counters that as the independent DSM Administrator, it collaborates with NS Power on Demand Response pilots and that transferring responsibilities to NS Power would not benefit ratepayers, emphasizing legislative mandates under the Public Utilities Act.

Annual avoided costs of energy and capacity and annual avoided CO 2 e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM. Avoided costs of transmission and distribution were provided by NS Power in 2021. Cos...

AI summary The document provides annual avoided costs and emissions from energy and capacity programs, including EE and DR. It outlines cost-effectiveness ratios, investment requirements, and benefit/cost calculations using WACC and other metrics. NS Power's collaboration is noted as essential for DR benefits.

4.9 E1'S BEHAVIOURAL PROGRAM COMPONENT AND NS POWER'S CEM REPORTING - The Board has directed E1 to provide updates in its quarterly reports leading up to the establishment and - operation of E1's behavioural programs and NS Power's Custome...

AI summary The Board has directed E1 to provide quarterly updates on its behavioural programs and NS Power's Customer Energy Management (CEM). E1 plans to reintroduce a residential behavioural program similar to the Home Energy Report and collaborate with NS Power's CEM to avoid double-counting and improve efficiency.

4.10 IMPLEMENTATION OF NEW INCENTIVES IN THE DEMAND RESPONSE PROGRAM The Board has directed E1 to liaise with NS Power and stakeholders, and then seek Board approval before implementing new incentives to compensate customers for reducing t...

AI summary The Board has directed E1 to collaborate with NS Power and stakeholders before implementing new incentives in the Demand Response Program. Concerns were raised about the effectiveness of behavioral demand response programs in reducing winter peak load and the potential overlap with recently approved pilot tariffs for time-varying pricing. E1 plans to evaluate and adjust the program's implementation based on initial results.

1.2.1 OVERVIEW The Settlement Plan delivers demand side resources to Nova Scotia ratepayers in support of achieving NS Power's long-term electricity strategy as provided in the IRP. The Settlement Plan offers a portfolio of DSM services th...

AI summary The Settlement Plan provides demand-side management (DSM) resources to Nova Scotia ratepayers, aligning with NS Power's long-term electricity strategy. It includes energy efficiency and demand response initiatives, aiming to improve affordability, accessibility, and equity. The plan emphasizes cost-effectiveness and the long-term benefits of DSM, supported by analyses like the Rate and Bill Impact Analysis and cost-effectiveness testing.

1.2.2 OBJECTIVES OF THE 2023-2025 DSM RESOURCE PLAN - There are three main objectives of the Settlement Plan: - 1. deliver cost-effective demand side resources that support the successful implementation of a long- term electricity strategy...

AI summary The 2023-2025 DSM Resource Plan aims to deliver cost-effective demand-side resources aligned with climate goals and affordability, ensure equitable access to services, and promote transparent, collaborative planning with stakeholder input.

2. DEVELOPMENT APPROACH & DETAILS The Settlement Plan was developed for the purpose of delivering cost-effective energy and system-peak demand savings to Nova Scotia electricity ratepayers for the three-year plan period. E1 used a multi-ph...

AI summary The Settlement Plan for the 2023-2025 period was developed using a multi-phase process to ensure cost-effective energy and demand savings for Nova Scotia ratepayers. E1 collaborated with Guidehouse and Energy Futures Group, engaging stakeholders such as the DSMAG and NS Power throughout the process to refine assumptions, model scenarios, and align on the final plan.

DSM (for both energy efficiency and demand response) from Navigant's DSM - Potential Study[9](#page-44-0) . This level of energy and capacity savings informed the development of the Settlement - Plan. - E1's Settlement Plan aligns, rather...

AI summary The text discusses EfficiencyOne's Settlement Plan, which aligns with the Integrated Resource Plan's Reference Plan and aims to achieve energy and demand response savings. The plan considers historical savings, industry capacity, and affordability, and emphasizes portfolio design that is responsive to customer needs, technologies, and regulatory requirements.

14 Table 3: Balanced Plan Aspects Addressed in the Settlement Plan Balanced Plan Aspects 2023-2025 Settlement Plan Access to programs by all market sectors and rate classes by addressing barriers to participation • low-income investment –...

AI summary The Settlement Plan addresses program accessibility and rate impacts. It includes low-income investments, energy savings distribution, and new program components targeting residential and BNI sectors. A RBIA was performed on DSM model results, and cumulative avoided costs are expected to exceed initial investments by 2027.

7 Table 4: Key Global Assumptions in the 2023-2025 Settlement Plan Development Key Global Assumptions Model Administrative Costs • The fixed cost category includes costs such as rent, insurance, office and salary expenses and have been set...

AI summary The document outlines key global assumptions for the 2023-2025 Settlement Plan, focusing on administrative costs and codes & standards. Administrative costs include fixed expenses like rent and salaries, allocated based on FTE staff. DR administrative costs are estimated using updated FTE figures. Lighting and heat pump standards are addressed with forward-looking assumptions.

2.3.2.2 DEMAND RESPONSE MODEL Guidehouse completed DR modelling using its DRSim™ model, which was also used in E1's 2019 Potential Study. The steps to running the model are outlined i[n Table 5.](#page-52-0) These steps were updated for th...

AI summary Guidehouse used its DRSim™ model for demand response (DR) modelling, which was also used in E1's 2019 Potential Study. The model's steps were updated for the 2023-2025 DR model. DR modelling relies on potential study frameworks due to limited historical data, unlike energy efficiency (EE) modelling which uses actual historical results.

8 2.4.1 TOTAL RESOURCE COST TEST - Best practice[16](#page-57-3) 9 recommends the use of one consistent cost-effectiveness test to screen both EE and DR. - The TRC was used as the primary test of E1's DSM investments, per the NSUARB decisi...

AI summary The document discusses the use of the Total Resource Cost (TRC) test as the primary method for evaluating Demand Side Management (DSM) investments by E1, as mandated by the NSUARB. It notes that while the TRC should be applied consistently, certain components differ between energy efficiency (EE) and demand response (DR) programs, with further details provided in Table 6.

6.5 PERFORMANCE INDICATORS - DR is a valuable tool for managing peak demand on the electricity system, offering utilities a lower-cost - alternative to acquiring additional flexible generation capacity. DR resources, sometimes called virtu...

AI summary Demand Response (DR) is highlighted as a cost-effective method to manage peak electricity demand, offering an alternative to new generation capacity. DR involves recruiting customers, installing technologies, and connecting them to systems for demand management. Performance indicators for DR programs are discussed, with a focus on measuring available demand capacity during the winter peak period.

1 Table 59: Demand Response Performance Indicators – Comparison of Settlement Plan and Alternate Scenario Scenario Year Investmenta ($ million) New DR Capacity (MW) Available DR Capacity (MW) Total Resource Cost Test (TRC)b Program Adminis...

AI summary Table 59 compares the performance indicators of the Settlement Plan and Alternate Scenario for demand response programs, including investment, new and available DR capacity, participation numbers, and levelized unit costs. The Alternate Scenario shows significantly lower investments, capacity, and participation compared to the Settlement Plan.

8. EVALUATION E1's measurement and evaluation activities are a crucial component of its Regulatory Affairs functions. Through independent, third-party measurement and evaluation processes, E1 is able to stay accountable to its tracked perf...

AI summary E1 emphasizes the importance of evaluation activities in its Regulatory Affairs functions, using third-party processes to ensure accountability and improve EE and DR programs. Evaluation will be conducted annually for each program over three years, with a focus on accurately determining energy and demand savings, similar to the approach taken in the 2020-2022 DSM Resource Plan.

9.5 RATE & BILL IMPACT ANALYSIS - E1 will file its historical Rate and Bill Impact Analysis (RBIA) and forward-looking RBIA as part of each DSM - Resource Plan. The historical RBIA estimates the high-level, long-term impact to rates and bi...

AI summary E1 is required to file historical and forward-looking Rate and Bill Impact Analyses (RBIA) as part of each Demand Side Management (DSM) Resource Plan. The historical RBIA covers past DSM activities and approved future investments, while the forward-looking RBIA estimates the impact of proposed DSM activities on rates and bills.

Appendix A Attachment 1: Rate Class Payback Graphs

AI summary Appendix A includes Attachment 1, which presents Rate Class Payback Graphs. The graphs are visual representations used to analyze the financial implications of different rate classes, likely in the context of utility regulation and cost recovery.

1 Figure 4: Small Industrial Rate Class – Settlement Plan Payback 3 Figure 5: Medium Industrial Rate Class – Settlement Plan Payback Figure 6: Large Industrial Rate Class – Settlement Plan Payback Figure 7: Large General Rate Class – Settl...

AI summary The document presents several figures illustrating settlement plan payback for different industrial and general rate classes, including small, medium, and large industrial rate classes, as well as a large general rate class. These figures likely relate to cost recovery or financial planning within a regulatory proceeding.

Figure 8: Municipal Rate Class – Settlement Plan Payback

AI summary Figure 8 presents a visual representation of the Settlement Plan Payback within the Municipal Rate Class. It likely illustrates how costs or revenues are distributed or recovered over time as part of a regulatory settlement agreement.

Approach This DR assessment establishes the foundation for DR portfolio development. Therefore, a specific task under the portfolio development exercise was to assess peak load reduction estimates from different DR options that E1 could co...

AI summary The document outlines a Demand Response (DR) assessment for E1's 2023-2025 portfolio plan, using a bottom-up analysis and Guidehouse's DRSimTM model. It includes two scenarios—Settlement Plan and Alternate Scenario—and compares peak load reduction and cost estimates, noting differences in peak demand definitions and excluded customer segments.

Levelized Costs and Supply Curve As described previously, the supply curve helps determine the relati[ve contrib](#page-14-1)utions from the different DR options vis-à-vis the costs for acquiring these resources. Figure 3 shows the supply...

AI summary The text discusses the supply curve for demand response (DR) options, showing levelized costs and contributions in the Preferred Plan and Alternate Scenario. The Alternate Scenario has lower benefit-cost ratios and higher costs due to lower participation and the absence of EV Charging Control and Behavioural DR.

1. Introduction Since the development of EfficiencyOne (E1's) 2020-2022 demand-side management (DSM) Plan, an emerging area of interest in Nova Scotia is demand response (DR). While there has been little demand response activity in Nova Sc...

AI summary The document introduces the development of a demand response (DR) portfolio by EfficiencyOne (E1) in collaboration with Nova Scotia Power (NS Power) to meet strategic objectives and provide customers with more options to manage energy usage. It outlines the purpose of the DR Roadmap, which includes estimating DR potential, presenting a DR portfolio, and discussing implementation considerations.

2. Demand Response Analysis Approach DR assessment establishes the foundation for DR portfolio development. Therefore, a specific task under the portfolio development exercise was to assess peak load reduction estimates from different DR o...

AI summary The document outlines the approach for assessing demand response (DR) peak load reduction estimates as part of E1's three-year portfolio plan development. This assessment forms the foundation for DR portfolio development and is a specific task under the portfolio development exercise.

2.1 Analysis Approach The DR assessment is based on a bottom-up analysis that utilizes primary data from E1 and relevant secondary sources of information. The assessment was conducted using Guidehouse's DRSimTM model, which was customized...

AI summary The DR assessment uses a bottom-up approach with primary data from E1 and secondary sources, utilizing Guidehouse's DRSimTM model customized for E1's customer base. The process involves characterizing DR options, estimating costs, and evaluating peak load reduction and cost-effectiveness across different market segments.

2.1.1 Market Segmentation Market segmentation is the first step in the DR assessment process. Table 5 presents the different levels of market segmentation for this assessment. The segmentation by customer size is based on Nova Scotia Power...

AI summary Market segmentation is the initial step in the demand response (DR) assessment process. The segmentation is based on Nova Scotia Power's electricity rate classes, as presented in Table 5.

Table 8. Summary of DR Options Considered in the Study DR Option Description Eligible Customer Classes Eligible End Uses Residential Electric Baseboard Direct Load Control Control of electric loads by a thermostat and/or load control Small...

AI summary Table 8 summarizes various demand response (DR) options considered in the study, including Direct Load Control, BNI Curtailment, Behind The Meter Battery Control, EV Charging Control, Critical Peak Pricing, and Behavioural Demand Response. Each DR option includes a description, eligible customer classes, and eligible end uses. The text also notes that there is no empirical evidence that Time-of-Use (TOU) rates are more effective when combined with enabling technologies like smart thermostats.

Table 9. Customer Class and Applicable DR Options Customer Class DLC BNI Curtailment Behavioural DR BTM Battery Control EV Charging Control Critical Peak Pricing Time-of- Use Rates 11 Interruptible Rider - $\checkmark$ - $\checkmark$ - - -...

AI summary Table 9 outlines various demand response (DR) options available to different customer classes, including DLC, BNI curtailment, behavioural DR, BTM battery control, EV charging control, critical peak pricing, and Time-of-Use rates. The table highlights which customer classes are eligible for each DR option.

ge-30-1"> ______________________________________________________________________________ 15 [https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/demand-response/cost](https://www.cpuc.ca.gov/-/media/cpuc-websit...

AI summary The text discusses the treatment of non-energy benefits and costs in demand response (DR) programs, highlighting transaction costs and value of service lost. It notes that Nova Scotia's Total Resource Cost (TRC) test does not currently include non-energy benefits in benefit calculations, unlike the CPUC protocol which provides guidelines for estimating these costs.

EfficiencyOne Demand Response Roadmap Figure 14. Supply Curve of DR Options for Preferred Plan BTM battery control is the least cost option and provides around 65 MW of peak demand savings in 2031. DLC (including both Bring Your Own and Di...

AI summary The EfficiencyOne Demand Response Roadmap outlines various DR options, with BTM battery control being the least costly and providing the highest peak demand savings. DLC follows with significant savings but higher costs. The Alternate Scenario has lower benefit-cost ratios and higher costs due to lower participation and exclusion of certain DR options like EV Charging Control and Behavioural DR.

3.2.4 Critical Peak Pricing (CPP) Option The 2023-2[025](#page-47-2) DR Portfolio includes a Critical Peak Pricing offer to Residential and Small C&I customers.25 Customers enrolled in the CPP rate will be offered smart thermostats as an e...

AI summary The 2023-2025 DR Portfolio includes a Critical Peak Pricing (CPP) option for residential and small C&I customers, offering smart thermostats to enhance response to the rate. E1 claims only the CPP savings associated with the smart thermostats, projecting 0.03 MW of savings by 2025, with half from residential customers and the rest from small commercial and industrial customers.

Table 17. Critical Peak Pricing Option Characteristics Item Description Program Description • NS Power plans to offer voluntary opt-in to Residential and Small C&I customer classes starting in 2023, based on the approved CPP rate submitted...

AI summary NS Power plans to offer a Critical Peak Pricing (CPP) rate to residential and small C&I customers starting in 2023, with a 150 cents/kWh critical peak rate. The program includes the installation of no-cost smart thermostats to enhance load reduction during peak events. Enrollment is expected to reach 15% of eligible customers over a 5-year period, and the CPP rate is currently a pilot subject to NSUARB approval.

Program Administration, Data and Performance Analysis E1 is assumed to be primarily responsible for administering the DR program and for undertaking data and performance analysis based on data provided by NS Power and/or third-party DR ser...

AI summary E1 is primarily responsible for administering the DR program and conducting data and performance analysis using data from NS Power and third-party providers. E1 will develop a performance tracking database and support NS Power in administering the CPP rate.

Table 22. Residential EE-DR Integration Considerations EE Program EE Program Component EE-DR Measure for Integration Corresponding DR Option for Integration Considerations Brief Description of EE-DR Integration Approach Rebates Smart Water...

AI summary The table outlines residential energy efficiency (EE) and demand response (DR) integration considerations, focusing on smart water heaters and the Direct Load Control (DLC) option with a 'Bring Your Own Device' (BYOD) delivery approach. It mentions rebates under E1 and Instant Savings program components.

31 Customers can also enroll in the rate without enabling technology such as smart thermostats.

AI summary The text mentions that customers can enroll in a rate without requiring the use of smart thermostats or other enabling technologies.

Table 23. BNI EE-DR Integration Considerations EE Program EE Program Component EE-DR Measure for Integration Corresponding DR Option for Integration Considerations Brief Description of EE-DR Integration Approach Direct Installation Energy...

AI summary The BNI Custom Incentive Program integrates energy efficiency (EE) and demand response (DR) measures, such as direct installation of smart thermostats with Critical Peak Pricing (CPP). Customers are offered a discounted off-peak rate to encourage switching from their Otherwise Applicable Tariff (OAT).

1.1.1 2020 INTEGRATED RESOURCE PLAN RESULTS - Since E1's 2020-2022 DSM Plan was developed and approved, NS Power conducted a new IRP which was used to inform the development of the Settlement Plan. NS Power's 2020 IRP reflected themes of d...

AI summary NS Power's 2020 Integrated Resource Plan (IRP) included demand side management (DSM) and demand response (DR) scenarios, with Scenario 2.0C selected as the Reference Plan. The IRP proposed an Electrification Strategy and a DR Strategy targeting 75 MW of capacity by 2025. E1 anticipates participating in these initiatives and has incorporated support for them in its Settlement Plan, though uncertainty remains regarding future ratepayer funding.

1.2.1 OVERVIEW The Settlement Plan delivers demand side resources to Nova Scotia ratepayers in support of achieving NS Power's long-term electricity strategy as provided in the IRP. The Settlement Plan offers a portfolio of DSM services th...

AI summary The Settlement Plan provides demand side management (DSM) resources to Nova Scotia ratepayers, supporting NS Power's long-term electricity strategy. It emphasizes cost-effectiveness, accessibility, and affordability, with a focus on both energy efficiency and demand response initiatives. The plan includes measures such as electric thermal storage units and building optimization incentives, and aims to lower energy costs, support the local economy, and improve grid capacity.

2.2.2 PORTFOLIO-WIDE ASSUMPTIONS & DESIGN OBJECTIVES E1's key global assumptions and design objectives for all modelled scenarios align with both the Plan's Guiding Principles and the Standardized Filing Framework (SFF). Specifically, the...

AI summary E1's assumptions and design objectives for the 2023-2025 DSM Plan scenarios align with the Plan's Guiding Principles and the Standardized Filing Framework (SFF). The DSM Standards emphasize balancing energy and capacity avoidance, program delivery costs, and ensuring accessibility and equity in program design.

4 Table 3: Balanced Plan Aspects Addressed in the Settlement Plan Balanced Plan Aspects 2023-2025 Settlement Plan Rate impacts • RBIA performed on DSM model results, as part of Plan development • cumulative value of avoided costs will exce...

AI summary The 2023-2025 Settlement Plan includes a rate impact analysis based on DSM model results, with the cumulative value of avoided costs expected to exceed initial investments by 2027.

1 Table 4: Key Global Assumptions in the 2023-2025 Settlement Plan Development Key Global Assumptions Model Low-Income Investment Levels • Incidental EE low-income impact weightings from 2020 (i.e. energy savings, demand savings, investmen...

AI summary The text outlines key global assumptions used in the 2023-2025 Settlement Plan Development, including the application of 2020 low-income impact weightings and the use of NS Power's 2021 pre-tax WACC of 6.33% and an annual inflation rate of 2% in calculating avoided utility costs.

12 2.3.2.2 DEMAND RESPONSE MODEL - 13 Guidehouse completed DR modelling using its DRSim™ model, which was also used in E1's 2019 Potential - 14 Study. The steps to running the model are outlined i[n Table 5.](#page-104-0) These steps were...

AI summary Guidehouse used the DRSim™ model for demand response (DR) modelling, which was also used in E1's 2019 Potential Study. The model's steps were updated for the 2023-2025 DR model. A potential study framework is utilized for DR modelling due to the lack of historical data, unlike energy efficiency (EE) modelling.

2.4 COST-EFFECTIVENESS Cost effectiveness testing is used to quantitatively assess and evaluate demand side resources through a comparison of benefits and costs expressed as both the dollar value of the net benefit (or cost) and as a ratio...

AI summary The document discusses cost-effectiveness testing for demand-side management (DSM) resources, highlighting the use of the Total Resource Cost (TRC) and Program Administrator Cost (PAC) tests. Nova Scotia Power (E1) incorporated avoided carbon costs into these tests following a 2019 directive from the NSUARB. The tests use the Weighted-Average Cost of Capital (WACC) as a discount rate and were applied to both energy efficiency (EE) and demand response (DR) portfolios.

1 2.4.1 TOTAL RESOURCE COST TEST 6 - Best practice[16](#page-109-2) 2 recommends the use of one consistent cost-effectiveness test to screen both EE and DR. - The TRC was used as the primary test of E1's DSM investments, per the NSUARB dec...

AI summary The Total Resource Cost (TRC) test is recommended as a consistent cost-effectiveness measure for evaluating both energy efficiency (EE) and demand response (DR) programs. Nova Scotia Power (E1) has applied the TRC test at the program level for its DSM investments, as per the NSUARB decision. However, some components of the TRC calculation differ between EE and DR, as outlined in Table 6.

15 Table 7: Program Administrator Cost Test Components Component Description Benefit or Cost Avoided Cost of Transmission & Distribution EE & DR – the avoided cost of transmission and distribution represents the costs avoided, due to DSM,...

AI summary The document outlines the components of the Program Administrator Cost Test, focusing on avoided costs from energy efficiency (EE) and demand response (DR) programs, including transmission, distribution, capacity, energy, and carbon costs, as well as program administration and incentive costs. It explains how these components are evaluated in the Program Administrator Cost (PAC) test and contrasts them with the TRC test.

Annual avoided costs of energy and capacity and annual avoided CO₂e emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM for Scenario 2.0C. Avoided costs of transmission and distribution were provided by NS Po...

AI summary The text discusses annual avoided costs and CO₂e emissions from energy and capacity programs, using data from NS Power's 2020 Integrated Resource Plan (IRP) and 2021 transmission and distribution costs. It outlines cost-effectiveness ratios, including TRC and PAC, and highlights the need for NS Power collaboration in demand response (DR) programs.

3.3 SETTLEMENT PLAN – COST-EFFECTIVENESS The cost effectiveness results for the Settlement Plan are shown below as part o[f Table 14,](#page-121-0) which provides cost effectiveness results associated with the Settlement Plan, for both the...

AI summary The Settlement Plan's cost effectiveness is evaluated using the TRC and PAC tests. The TRC test is used for cost effectiveness screening at the program level in Nova Scotia, while the PAC test provides a utility-specific perspective on cost-effectiveness. The plan includes various NSUARB programs such as Efficient Product Rebates and Demand Response.

10 Table 54: Summary of Benefits – Demand Response Participant Industry Benefits Environmental Strategic DSM Benefits Benefits Portfolio Benefits • financial incentives for shifting or curtailing load • access to new controls and informati...

AI summary Table 54 outlines the benefits of Demand Response (DR) programs, highlighting financial incentives, better energy management, environmental advantages, and strategic benefits for the Integrated Resource Plan (IRP). It emphasizes the integration of DR with energy efficiency, support for emerging technologies, and improved grid services.

6.5 PERFORMANCE INDICATORS - DR is a valuable tool for managing peak demand on the electricity system, offering utilities a lower-cost - alternative to acquiring additional flexible generation capacity. DR resources, sometimes called virtu...

AI summary The text discusses demand response (DR) as a tool for managing peak demand and compares it to energy efficiency. It outlines how DR capacity is measured during the winter peak period and explains E1's proposal for performance indicators related to new and available demand capacity, which are claimed in the second calendar year following the winter period.

11 Table 57: 2023-2025 Demand Response Performance Target and Indicators Year Investmenta ($ million) New DR Capacity (MW) Available DR Capacity (MW) Total Resource Cost Test (TRC)b Program Administrator Cost Test (PAC)c Participation (par...

AI summary Table 57 outlines the 2023-2025 Demand Response (DR) performance targets and indicators, including investment, new and available DR capacity, participation numbers, and levelized unit costs. The table provides data for each year and a total row summarizing the figures.

Appendix AB Attachment 1: Rate Class Payback Graphs

AI summary This section of the document includes Attachment 1, which features Rate Class Payback Graphs. These graphs likely illustrate the financial payback periods for different rate classes, providing insights into cost recovery and investment returns.

Attachment 1: Rate Class Payback Graphs Attachment 2: Avoided Costs Brief Attachment 3: Guidehouse Participation Memorandum Attachment 4: 2023-2025 Settlement Plan Measure-level Energy Efficiency Technical Tables Compliance Filing (Filed E...

AI summary The document contains various attachments related to energy efficiency, demand response, and compliance measures for a regulatory proceeding in Nova Scotia, including rate class payback graphs, avoided costs briefs, and technical tables for a settlement plan.

1.2.1 OVERVIEW The Settlement Plan delivers demand side resources to Nova Scotia ratepayers in support of achieving NS Power's long-term electricity strategy as provided in the IRP. The Settlement Plan offers a portfolio of DSM services th...

AI summary The Settlement Plan outlines demand side management (DSM) initiatives aimed at supporting Nova Scotia's long-term electricity strategy. It emphasizes cost-effectiveness, accessibility, and affordability, with a focus on both energy efficiency and demand response. The plan includes historical successes and future expansions, such as capacity-focused initiatives, to reduce peak demand and improve grid reliability.

3 Table 2: DSMAG Stakeholder Engagement Timelines in the 2023-2025 Settlement Plan Development First Quarter of 2021 Discussions with NS Power to consider alignment on the Settlement Plan. Engaged rate class advocates as part of the discus...

AI summary In the first quarter of 2021, discussions with NS Power were held to align on the Settlement Plan, with engagement of rate class advocates during February 17 to March 4.

GUIDING PRINCIPLES 7 9 13 15 Transparency – E1 will provide stakeholders and customers with information and insight into the analyses supporting plan development and results and demonstrate how received comments were considered. Accessibil...

AI summary The document outlines guiding principles for the 2023-2025 Settlement Plan, emphasizing transparency, accessibility, equity, and affordability. It highlights the use of the Integrated Resource Plan and cost-effectiveness testing to ensure long-term affordability for ratepayers.

) . This level of energy and capacity savings informed the development of the Settlement Plan. E1's Settlement Plan aligns, rather than continues to move away from, the achievement of savings in the IRP's Reference Plan. These annual savin...

AI summary The Settlement Plan aligns with the IRP's Reference Plan and aims to achieve long-term energy savings for Nova Scotians. It considers historical savings, industry capacity, and affordability, and emphasizes diversity, accessibility, and system-peak demand reduction in its portfolio design.

$ million) First-Year Energy Savings Lifetime Energy Savings Peak EE Demand Savings Available DR Capacity (MW) ource Cost (TRC) c Prog Administr Test ( ator Cost

AI summary The text presents a table outlining the 2023-2025 Settlement Plan, detailing investment and savings by program component, including energy savings, peak demand savings, available demand response capacity, source cost, program administrative test cost, and other related metrics.

3.3 SETTLEMENT PLAN – COST-EFFECTIVENESS The cost effectiveness results for the Settlement Plan are shown below as part o[f Table 14,](#page-90-0) which provides cost effectiveness results associated with the Settlement Plan, for both the...

AI summary The Settlement Plan's cost-effectiveness is evaluated using the TRC and PAC tests. The TRC test is used for decision-making at the NSUARB program level, requiring each program to pass a cost-effectiveness screening test. The PAC test provides a utility-specific cost-effectiveness perspective. Results are detailed in Table 14.

6.3.1 RESIDENTIAL DEMAND RESPONSE PROGRAM COMPONENT - The Residential DR program component aims to help facilitate a more flexible residential load that may - provide residential customers with economic incentives and/or more visibility an...

AI summary The Residential Demand Response Program aims to increase residential load flexibility through five pathways, including battery control and behavioral DR. E1 will collaborate with NS Power and stakeholders, seeking Board approval for new incentives. Details are outlined in Table 55 and Attachment 5.

9.2 QUARTERLY REPORTS - E1 will file quarterly reports with the NSUARB for quarters one through three of each year[43](#page-189-4) . The reports - will provide quarterly status updates and service highlights and communicate course adjustm...

AI summary E1 is required to submit quarterly reports to the NSUARB, including updates on DSM program performance, savings targets, mid-course adjustments, and collaboration with NS Power. Reports must be filed by specific dates and include metrics such as investment by rate class, sector highlights, and demand response progress.

9.3 MID-COURSE ADJUSTMENTS & FLEXIBILITY - E1 often makes limited adjustments to an approved DSM Resource Plan to reflect changes in market conditions and updated insights from program and organizational evaluations unknown at the time of...

AI summary E1 makes limited adjustments to approved DSM Resource Plans based on market changes and evaluations. Mid-Course Adjustments (MCAs) for 2023-2025 will follow the same approach as 2020-2022. E1 will explain changes with variances of 25% or more and consider impacts on customer rate classes annually. Advance notice will be provided in APRs and Q1 reports, but not for adjustments based on third-party evaluations.

of Mahone Bay, and the Town of Antigonish (collectively known as the "Municipal Electric Utilities" (MEUs)). Board Counsel participated in the proceeding with the filing of evidence by Synapse Energy Economics, Inc. (Synapse). NS Power als...

AI summary The document discusses a Settlement Plan proposing increased DSM investment for low-income, Mi'kmaw, and diverse communities, supported by NS Power and most intervenors but raised concerns about cost-effectiveness, allocation, and avoided cost calculations. The Board found E1's plan reasonable, recognizing efforts to address past under-service and improve equity in DSM programs.

2.2 Alternate Scenario [21] In Matter M06733, the Board ordered that future DSM Plan applications by E1 must include alternate DSM scenarios, in addition to E1 's proposed plan. E1 complied with that order in this application, filing a ful...

AI summary In Matter M06733, E1 submitted an alternate DSM scenario with lower investment than the proposed Settlement Plan, citing challenges in scaling demand response and reliance on the 2020 IRP. The alternate scenario projects $160.1M in DSM investments and 377.3 GWh of first-year energy savings, 12% less than the Settlement Plan. Stakeholders had previously signaled a need for higher DSM spending due to legislative changes accelerating fossil fuel shutdowns.

by 2025. The cumulative Settlement Plan investment level over the period of the Plan aligns generally, in aggregate, with the Reference Plan investment level ($173M v. $188M). [Exhibit E-1, p. 41] - [40] The Board notes that no party in th...

AI summary The Settlement Plan for DSM spending from 2023-2025 aligns with the Reference Plan, with total investment levels of $173M versus $188M. No party opposed the proposed spending level, though the Industrial Group suggested reducing the $10M demand response budget, except for equipment costs. NS Power supports the plan, emphasizing its benefits for low-income and First Nations communities and its contribution to GHG reduction goals.

that performance targets be established. - [52] Under the Settlement Plan, E1 will allocate $35.8 million toward DSM programs for underserved markets and diverse communities. This increase is nearly three times the 2020-2022 investment lev...

AI summary The Settlement Plan proposes increased funding for DSM programs targeting underserved markets and diverse communities, including Mi'kmaw communities. Consultants recommend establishing performance targets to ensure effective use of funds and to ensure that low-income communities benefit from energy efficiency programs.

4.5 Allocation of Program Costs [74] Ei said it applied the following "guiding principles" in developing its 2023 2025 DSM Resource Plan: Transparency - E1 will provide stakeholders and customers with information and insight into the analy...

AI summary E1 outlines guiding principles for its 2023–2025 DSM Resource Plan, emphasizing transparency, accessibility, equity, and affordability. It aligns with the 'Balanced Plan Approach' from the 2016 Consensus Agreement, referencing Exhibit E-1, Appendix A, p. 19.

4.3.1 BALANCED PLAN APPROACH EfficiencyOne will produce DSM Resource Plans that balance multiple aspects of DSM for the benefit of customers, including: - Short-term and long-term energy and capacity avoidance; - Program delivery costs; -...

AI summary EfficiencyOne (E1) outlines a balanced DSM Resource Plan emphasizing energy and capacity avoidance, cost efficiency, non-electric benefits, and equitable access. The Settlement Plan includes 17-22% low-income investment, 50/50 residential-to-BNI splits, and increased innovation funding. E1 aligns these objectives with census data and load forecasts, prioritizing equity and diverse community outreach.

is a fundamental consideration for the approval of electricity efficiency and conservation activities, but there are other considerations. [101] Subsections 79L(8) and (9) identify further criteria: - (8) The Board shall approve an agreeme...

AI summary The Board considers affordability and long-term cost principles when approving electricity efficiency programs. Subsections 79L(8) and (9) of the Act require assessing programs' affordability and alignment with customers' best interests. The Board previously discussed affordability in 'Re EfficiencyOne' (2015 NSUARB 204), emphasizing balancing short-term rate impacts with long-term costs.

4.6 Demand Response [142] In its application, E1 stated: For the first time, E1 is proposing targeted Demand Response activities under its Settlement Plan. These DR activities are intended to facilitate direct electricity customer response...

AI summary E1 proposes targeted demand response (DR) activities under its Settlement Plan, aiming for a 17.9 MW reduction over three years. The Board notes prior DR initiatives, like the Klondike pilot, and directs E1 to establish the target as a performance target, not an indicator. NS Power supports the DR amount but emphasizes its role in rate design. The Board requires quarterly updates on DR projects and progress.

4.9 Municipal Electric Utilities [166] According to ETs application, the MEUs in the province are the only customers in NS Power's Municipal rate class. The MEUs participate in the DSMAG. Each MEU is considered a participant by E1 "when an...

AI summary The document discusses the role of Municipal Electric Utilities (MEUs) in Nova Scotia's energy sector, their participation in DSMAG, and E1's approach to modeling MEU customers. MEUs question E1's methods for DSM cost allocation and rate analysis, arguing for separate evaluations due to distinct avoided cost factors. E1 acknowledges the need for Board approval on certain issues but remains open to discussion.

4.10 DSM Advisory Group [177] As a result of the Consensus Agreement approved by the Board for the 2020-2022 DSM Plan, revised Terms of Reference for the DSMAG were developed. This was intended to reinvigorate the then-existing DSMAG. By S...

AI summary The DSM Advisory Group (DSMAG) was restructured under the 2020-2022 DSM Plan Consensus Agreement to enhance stakeholder engagement. E1 and NS Power aligned on the Settlement Plan, but disagreements arose regarding stakeholder input and investment allocation. E1 emphasized transparent engagement, while Mr. Athas argued against binding investment splits. Disputes were noted between SBA, the Industrial Group, and E1 over DSMAG's role and issue-raising processes.

IN THE MATTER OF THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF AN APPLICATION by EfficiencyOne (E1) for Approval of a Supply Agreement for Electricity Efficiency and Conservation Activities between E1 and Nova Scotia Power Inc. (NS Pow...

AI summary EfficiencyOne (E1) applied for approval of a supply agreement and a 2023-2025 DSM Resource Plan with Nova Scotia Power Inc. (NS Power). The Board approved the application, setting a total funding of $173 million with specific energy and demand savings targets. Adjustments may be required if targets are not met, and the Board accepted evaluation and verification reports for the 2021 DSM year.

mments throughout the engagement process, which has culminated in this settlement Plan. In support of its Application for Approval of the 2023-2025 DSM Resource Plan, EfficiencyOne's filing includes: - Notice of Application - Evidence on b...

AI summary EfficiencyOne seeks approval for its 2023-2025 DSM Resource Plan and a DSM Supply Agreement with NS Power, aligning with the Public Utilities Act and the 2014 Electricity Efficiency and Conservation Restructuring Act. The agreement outlines EECA provision terms and payment structures.

NOTICE OF PAPER HEARING EfficiencyOne (E1) has made Application to the Nova Scotia Utility and Review Board for Approval of a Supply Agreement for Electricity Efficiency and Conservation Activities between E1 and Nova Scotia Power Inc, and...

AI summary EfficiencyOne has applied for approval of a supply agreement with Nova Scotia Power Inc. for electricity efficiency and conservation activities, including the 2023-2025 Demand Side Management (DSM) Resource Plan. The plan aims for 412.7 GWh of energy savings and 96.7 MW of peak demand savings over three years with a total investment of $173 million. The Board will consider the matter in a paper hearing.

NOTICE OF INTERVENTION TO: The Nova Scotia Utility and Review Board ("Board") AND TO: EfficiencyOne ("E1") 1. The BERWICK ELECTRIC COMMISSION , the RIVERPORT ELECTRIC LIGHT COMMISSION , the TOWN OF MAHONE BAY , and the TOWN OF ANTIGONISH (...

AI summary The Berwick Electric Commission, Riverport Electric Light Commission, Town of Mahone Bay, and Town of Antigonish (collectively, Municipal Utilities) seek intervenor status in a Nova Scotia Utility and Review Board proceeding. They purchase power from NSPI under the BUTU rate and are impacted by OATT and Spill Tariff rates, requesting intervention to address rate-related issues.

Request IR-29: - On p. 59 of 65, E1 stated that "the current benefits as examined through the DSM Plan development process have indicated that the utility costs for DR programming outweigh the benefits". - a) Given that indication, please...

AI summary E1 asserts that demand response (DR) programming costs exceed benefits, yet requests funding for DR pilots and designation as a Performance Indicator. The proceeding questions E1's rationale for allocating funds and whether ratepayers should hold E1 accountable for DR performance.

Request IR-30: Regarding Performance Targets, E1 currently only has two targets to satisfy. Those are cumulative (3-year) annual energy savings and cumulative (3-year) annual peak demand savings. The proposed 2023-2025 DSM Plan requests ap...

AI summary E1 currently has two performance targets for energy and peak demand savings. The proposed 2023-2025 DSM Plan requests a 57% increase in funding compared to the previous 3-year approval, raising concerns about rates and the need for additional performance targets for E1, a mature organization.

Document: 294149 Date Filed: April 14, 2022 Synapse (E1) Page 5 of 9 1 2 with the cost data in these figures. It appears that labels in the two figures are mislabeled. If this is correct, please provide corrected figures and/or tables. 3 4...

AI summary The text contains several requests for clarification and correction of figures and assumptions in a regulatory document. It highlights inconsistencies in labeling and color coding of figures, as well as questions regarding assumptions and methodologies used in battery adoption projections and EV charger load reductions.

1 Request IR-2: - 2 Please provide cost allocation tables, by rate class, for each year in a) E1's Preferred Plan; b) - 3 Alternate Scenario; c) Settlement Plan, and d) a Scenario where the Low Income funding is set - 4 at 12% of the inves...

AI summary Request IR-2 seeks cost allocation tables by rate class for four scenarios: E1's Preferred Plan, Alternate Scenario, Settlement Plan, and a Scenario with Low Income funding set at 12% of investment. The request aims to compare cost distributions across different planning approaches and funding levels.

1 Please explain whether this percentage includes money spent by NS Power ratepayers for 1 2022 M10473 14 15 16 17 18 19 20 "E1's investment in customer incentives continues to be a significant category of spending as expected in a resourc...

AI summary The text discusses EfficiencyOne's (E1) investment in customer incentives and how they are set using a methodology from the CLEAResult study. It also asks whether E1 has considered NS Power's rate increases in the current General Rates Application and references avoided energy and capacity costs calculated using the 2020 IRP Reference Plan.

30 1 2 (a) Please restate the 2023-2025 Plan, using the most current Statistics Canada data for Low-Income classification, i.e. 12.1%? 3 4 (b) If the spend on low income components is reduced to 12.1%, and the funds reallocated, please con...

AI summary The request asks EfficiencyOne to restate the 2023-2025 DSM Plan using updated low-income classification data and to provide a detailed breakdown of the proposed DR pilot programming costs. It also inquires about research on similar programs by other utilities, differences in DR offerings, and the potential use of existing demand control experience in new DR rates.

tes that DSM, and specifically its energy efficiency portfolio, is the only resource option available to ratepayers that generates true bill savings." - a) Is this statement true for non-participants? - b) What other resource options were...

AI summary The text questions whether DSM is the sole resource option for bill savings, requests workpapers on risk mitigation and carbon emission analysis, and references sections of the EfficiencyOne 2023-2025 DSM Resource Plan. It seeks clarification on program delivery risks, investment allocations for carbon reductions, and details on beneficial electrification initiatives.

2023-2025 DSM Resource Plan, Appendix A, Page 10 of 149, Table 1: New Initiatives and Key Enhancements in the 2023-2025 Settlement Plan and Section 7.3.3.3 Beneficial Electrification, Page 134 of 149. - a) Beneficial Electrification is lis...

AI summary The document contains questions and requests related to Nova Scotia's 2023-2025 DSM Resource Plan, focusing on Beneficial Electrification, program cost-effectiveness, and data transparency. Key issues include program leadership, non-electric bill savings, and alignment with DSM principles.

eater than 20 years - b) Table 1 showing only residential programs - c) Table 1 showing only BNI programs - d) Table 1 showing data estimated for customers in the following rate classes; - i) General, - ii) Small General - iii) Small Indus...

AI summary The document outlines regulatory requests for clarifications on EfficiencyOne's 2023-2025 DSM Resource Plan, including data on residential and BNI programs, savings from new buildings, equipment installation details, avoided cost calculations for decarbonization, and explanations of 'evolving customer needs' by customer class. Requests focus on budget adjustments, methodological transparency, and alignment with climate goals.

d any changes to current Appliance Efficiency Standards in developing the Settlement Plan? Please describe in detail if it affected participation, incentive levels, or cost effectiveness calculations. c) Does EfficiencyOne participate in a...

AI summary The text outlines requests for information regarding EfficiencyOne's Settlement Plan, including appliance efficiency standards, participation in reviews, data transparency, and clarification of figures. Key issues involve cost-effectiveness, program expenditures, and alignment with NS Power's interests. Requests focus on workpapers, jurisdictional data, payback analysis, and TRC test assumptions.

19 Questions: 21 (a) E1 refers to its Application as a "Settlement Plan". Please confirm that no Settlement 22 Agreement has been signed in relation to E1's Application with any party that would 23 preclude stakeholders from raising any is...

AI summary The document outlines 19 questions regarding E1's Settlement Plan, stakeholder input, changes to DSM scenarios post-NS Power's rate application, and meetings with municipal utilities. It seeks confirmation of no preclusive agreements, details on stakeholder input incorporation, DSM scenario modifications, and meeting minutes. References include carbon cost calculations using the Federal Carbon Pollution Pricing Benchmark.

12 Questions: 13 14 (a) Please confirm that the Total Resource Cost Test (TRC) and Program Administrator 15 Cost Test (PAC) were conducted assuming that all energy and capacity savings were 16 calculated using the annual avoided costs of e...

AI summary The document includes several questions directed to EfficiencyOne (E1) regarding the Total Resource Cost Test (TRC), Program Administrator Cost Test (PAC), and Demand Response (DR) under the 2023-2025 DSM Plan. Questions focus on avoided costs, transmission and distribution projects, and the impact of DSM spending on specific service territories and rate classes.

4 Questions: 5 6 (a) Please reproduce this table for the Alternate Scenario. 7 8 (b) Please provide a breakdown of the proposed Settlement Plan Expenditures for the 9 Municipal Rate Class (24) of $1.0M in 2023, $1.0M in 2024, and $1.1M in...

AI summary The document outlines five questions directed at EfficiencyOne (E1) regarding the Settlement Plan Expenditures for municipal rate classes, allocation methodologies, DSM Plan assumptions, and payment arrangements. E1 explains its approach to mid-course adjustments, including reliance on third-party evaluations and providing advance notice for changes exceeding 25% variance.

Business, Non-Profit and Institutional (BNI) investment target allocation is consistent with El's Guiding Principles and the Standardized Filing Framework, and concerns were not raised by stakeholders 1 Exhibit N-29. El Rebuttal Evidence F...

AI summary The SBA and Mr. Athas support El's alignment of BNI investment targets with Guiding Principles but argue for stricter cost-effectiveness standards. They recommend reallocating funds from TRC <1.0 measures to more effective programs, asserting this reduces costs and improves savings for ratepayers.

CLOSING STATEMENT AFFORDABLE ENERGY COALITION (AEC) Correction: AEC Evidence May 19, 2022, pp 2: "From 2001 to 2012 electricity rates increased by. During the same period home oil heating prices increased even more." This should have read...

AI summary The Affordable Energy Coalition (AEC) corrects previous statistics, stating electricity rates increased by 58% (2001-2012) and 95% (2001-2022), while home oil heating prices rose 90% (2001-2012) and 120% (2001-2022). By May 2022, oil prices had surged 263% from 2001, emphasizing energy cost disparities.

General Comments NS Power appreciates E1's transparency and engagement with DSM Advisory Group (DSMAG) members in setting out the principles, assumptions, inputs and scenario development and adjustment that lead to the development of the p...

AI summary NS Power supports E1's proposed 2023-2025 DSM Settlement Plan, which includes energy and demand savings targets and increased investment for low-income and First Nations communities. The plan is seen as important for decarbonization efforts in Nova Scotia.

CLOSING SUBMISSION OF THE BERWICK ELECTRIC COMMISSION, THE RIVERPORT ELECTRIC LIGHT COMMISSION, THE TOWN OF ANTIGONISH, AND THE TOWN OF MAHONE BAY ("MEUs") Please accept the following as the Closing Submission of the MEUs. On May 20, 2022,...

AI summary The MEUs (Berwick Electric Commission, Riverport Electric Light Commission, Town of Antigonish, and Town of Mahone Bay) submit their closing arguments, including evidence from Don Regan and Al Dominie, which outline three recommendations. The evidence was filed on May 20, 2022, and references Al Dominie's prior role at NS Power's Rates and Regulations Department.

RECOMMENDATION #3 At page 18 of its Rebuttal Evidence, E1 stated as follows: "The MEUs have recommended that MEUs in the wholesale market be permitted to pay all allocated and Board-approved DSM costs directly to E1, subject to the specifi...

AI summary E1 supports the MEUs' recommendation to pay DSM costs directly but argues it exceeds the DSM Plan Application's scope, citing statutory requirements. MEUs agree but will address the issue in NS Power's General Rate Application, acknowledging the need for regulatory review.

INCENTIVE SETTING PROCESS AND PAYBACK ANALYSIS The Industrial Group maintains that the incentive setting process and payback analysis requires additional scrutiny and direction and filed evidence by its consultant Mark Drazen to that effec...

AI summary The Industrial Group argues for stricter scrutiny of incentive-setting processes and payback analysis, citing Mark Drazen's evidence that incentives should minimize bill reductions. E1 counters that its methodology is settled under matter M07544, approved by the Board, and that payback periods are not part of its approved approach. E1 also admits incentives do not adjust with NSPI rate changes.

THE TRC TEST OF MEASURES AND PROGRAMS Within the Plan there has been a creeping departure from the first principles which were intended to guide the approval of cost-effective DSM measures and programs.

AI summary The document critiques a deviation from foundational principles in the approval of cost-effective demand-side management (DSM) measures and programs under the TRC Test framework, suggesting a gradual erosion of initial guidelines intended to ensure program effectiveness.

he Ecology Action Centre, page 3. & lt;sup>19 M10473, E1 2023-2025 DSM Plan Application, Exhibit E-19, Evidence of the Affordable Energy Coalition, page 2. & lt;sup>20 M10473, E1 2023-2025 DSM Plan Application, Exhibit E-27, Statement of t...

AI summary The document discusses E1's 2023-2025 DSM Plan Application, emphasizing cost-effectiveness, participation rates, and Indigenous consultation. Evidence from the Affordable Energy Coalition, Mi'kmaw Chiefs, and Synapse highlights benefits of energy efficiency programs, while the Small Business Advocate stresses participation's role in reducing bills. E1 commits to increasing small business participation.

hibit E-25, Evidence of Alice Napoleon and Kenji Takahashi, page 6, lines 14-17. & lt;sup>38 Exhibit E-20, Evidence of Theodore M. Love, page 13, lines 3-8 & lt;sup>39 M10473, E1 2023-2025 DSM Plan Application, Exhibit N-29, Rebuttal Evide...

AI summary The document discusses E1's 2023-2025 DSM Plan, proposing $10M for 17.9 MW of DR capacity through incentives and behavioral programs. Synapse supports the plan but raises concerns about residential DR's effectiveness in winter peak reductions and initial scale. Demand response is highlighted as broader than rate design, requiring additional control considerations.

of Mahone Bay, and the Town of Antigonish (collectively known as the "Municipal Electric Utilities" (MEUs)). Board Counsel participated in the proceeding with the filing of evidence by Synapse Energy Economics, Inc. (Synapse). NS Power als...

AI summary The Settlement Plan by E1 proposes increased DSM investment for low-income, Mi'kmaw, and diverse communities, supported by NS Power and most intervenors but raised concerns about cost-effectiveness and allocation. The Industrial Group and SBA questioned if the plan achieves maximum savings at minimal cost. The Board found the plan reasonable and equitable.

2 .0 BACKGROUND [13] ETs 2023-2025 DSM Resource Plan application uses the Standardized Filing Framework (Framework), developed in consultation among E1, NS Power, and stakeholders, and filed with the Board in a Consensus Agreement on July...

AI summary The document outlines the use of the Standardized Filing Framework for E1's 2023-2025 DSM Resource Plan application, developed collaboratively with NS Power and stakeholders. The Framework ensures consistent DSM plan filings, requires alternate scenarios, and promotes a balanced approach. E1 asserts its plan aligns with NS Power's Integrated Resource Plan (IRP) reference plan.

2.2 Alternate Scenario [21] In Matter M06733, the Board ordered that future DSM Plan applications by E1 must include alternate DSM scenarios, in addition to E1 's proposed plan. E1 complied with that order in this application, filing a ful...

AI summary In Matter M06733, the Board required E1 to include alternate DSM scenarios in future DSM Plan applications. E1 submitted a fully costed alternative scenario, but it involved lower DSM investment than the proposed Settlement Plan. E1 explained that the Settlement Plan's energy efficiency investment slightly exceeded the Base DSM scenario from the 2020 IRP, but the DR investment was lower due to challenges in ramping up to the Base DR level by 2025. The alternate scenario projects energy savings of 4,469 GWh over 12.6 years with a first-year savings of 377.3 GWh.

by 2025. The cumulative Settlement Plan investment level over the period of the Plan aligns generally, in aggregate, with the Reference Plan investment level ($173M v. $188M). [Exhibit E-1, p. 41] - [40] The Board notes that no party in th...

AI summary The Settlement Plan proposes DSM spending levels for 2023-2025, aligning closely with the Reference Plan. No party opposed the spending level, though the Industrial Group suggested reducing the demand response budget. NS Power supports the plan, emphasizing its benefits for low-income and First Nations communities and its contribution to GHG reduction goals.

4.3.1 BALANCED PLAN APPROACH EfficiencyOne will produce DSM Resource Plans that balance multiple aspects of DSM for the benefit of customers, including: - Short-term and long-term energy and capacity avoidance; - Program delivery costs; -...

AI summary EfficiencyOne (E1) outlines a Balanced Plan Approach for Demand Side Management (DSM) that balances energy avoidance, costs, equity, and accessibility. The plan includes specific investment targets (e.g., 17-22% low-income focus) and emphasizes diversity, innovation, and outreach. It aligns with NS Power's forecasts and aims to ensure equitable access for all rate classes.

4.5.1.1 Findings [98] Although the Industrial Group suggested that the Board's jurisdiction to approve E1's "policy decision to subsidize low-income and underserved communities" warranted consideration, none of the parties in this proceedi...

AI summary The Board did not make a specific finding on subsidizing low-income communities due to lack of active pursuit by parties. The Industrial Group raised jurisdictional concerns, but other parties supported E1's programs or suggested alternative cost-effectiveness tests. The Board clarified it is approving a supply agreement under s. 79L, not exercising authority under s. 67(1) of the Act, referencing Dalhousie Legal Aid Service .

Q. ARE THERE OTHER ASPECTS OF AFFORDIBILITY THAT SHOULD BE CONSIDERED? A. Yes. One of the most important aspects of affordability is the effect of DSM investments on classes of customers who are most acutely affected by changes in energy c...

AI summary Affordability considerations include the impact of DSM on vulnerable customers (low-income, tenants, First Nations). The Board's discretion under PUA allows evaluating factors like bill disparities between DSM participants and non-participants, emphasizing equitable access and long-term cost efficiency.

4.6 Demand Response [142] In its application, E1 stated: For the first time, E1 is proposing targeted Demand Response activities under its Settlement Plan. These DR activities are intended to facilitate direct electricity customer response...

AI summary E1 proposes targeted Demand Response (DR) activities in its Settlement Plan, aiming for 17.9 MW reduction over three years. The Board directs this target to be a performance target, not an indicator, requiring quarterly reporting. NS Power supports DR programs but emphasizes rate design as its responsibility. Past initiatives like the Klondike pilot are noted, with E1's role as DSM franchise holder acknowledged.

4.9 Municipal Electric Utilities [166] According to ETs application, the MEUs in the province are the only customers in NS Power's Municipal rate class. The MEUs participate in the DSMAG. Each MEU is considered a participant by E1 "when an...

AI summary Municipal Electric Utilities (MEUs) are the sole customers in NS Power's Municipal rate class and participate in E1's DSMAG. E1 models MEUs as single customers, raising concerns from MEUs about direct DSM cost payment, engagement, and individual tracking. MEUs argue for separate evaluation of DSM spending due to differences from bundled service customers.

4.10 DSM Advisory Group [177] As a result of the Consensus Agreement approved by the Board for the 2020-2022 DSM Plan, revised Terms of Reference for the DSMAG were developed. This was intended to reinvigorate the then-existing DSMAG. By S...

AI summary The DSM Advisory Group (DSMAG) was restructured under the 2020-2022 DSM Plan Consensus Agreement, with revised Terms of Reference filed by September 2021. E1 and NS Power aligned on the Settlement Plan through stakeholder engagement, but disagreements arose over DSMAG's role and investment allocation. E1 claimed stakeholder feedback was limited during plan development, while Mr. Athas argued against binding investment splits.

James Gogan Direct +1 (902) 563 5920 [email protected] 292 Charlotte Street Suite 300 Sydney NS Canada B1P 1C7 Tel +1 (902) 563 1000 Fax +1 (902) 563 1113 Our File: 190771-217173 September 14, 2022 Nova Scotia Utility & Review...

AI summary EfficiencyOne and Nova Scotia Power (NS Power) request a two-week extension to submit a Compliance Filing, including an executed Supply Agreement, to the Nova Scotia Utility & Review Board. This follows the Board's September 6, 2022 decision and the ongoing GRA hearing where EfficiencyOne is an intervenor.

James Gogan Direct +1 (902) 563 5920 [email protected] 292 Charlotte Street Suite 300 Sydney NS Canada B1P 1C7 Tel +1 (902) 563 1000 Fax +1 (902) 563 1113 Our File: 217173 October 25, 2022 Nova Scotia Utility & Review Board 3rd...

AI summary EfficiencyOne submits documents responding to the Industrial Group's letter regarding its Compliance Filing under M10473 and concerns about variance account adjustments in NS Power's 2022-2024 GRA. The filing seeks approval of a supply agreement with NS Power and a 2023-2025 DSM Resource Plan.

Industrial Group's Request for Clarification In its letter to the Board, the Industrial Group is requesting that the frequency of variance adjustments to the Supply Agreement be clarified. That is, the Industrial Group wishes to confirm wh...

AI summary The Industrial Group is requesting clarification on the frequency of variance adjustments to the Supply Agreement, seeking confirmation whether adjustments will occur annually in alignment with NS Power's DSM Cost Recovery Rider (DCRR) applications or at the end of the DSM Plan period, matching EfficiencyOne's DSM Resource Plan periods.

EfficiencyOne's Position Consistent with the current Board-approved approach and past established practices, it is EfficiencyOne's position that rate class adjustments resulting from a difference between planned expenditures, which inform...

AI summary EfficiencyOne argues that NS Power should address rate class adjustments at the conclusion of the DSM plan period, not during, and that amending the Supply Agreement is unnecessary. They align with current Board-approved practices and past methodologies.

IN THE MATTER OF THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF AN APPLICATION by EfficiencyOne (E1) for Approval of a Supply Agreement for Electricity Efficiency and Conservation Activities between E1 and Nova Scotia Power Inc. (NS Pow...

AI summary EfficiencyOne (E1) applied for approval of a supply agreement with Nova Scotia Power Inc. (NS Power) and a 2023-2025 Demand Side Management (DSM) Resource Plan. The Board approved the application, setting a total energy savings target of 412.7 GWh and demand savings target of 96.7 MW, with specific allocations for low-income and underserved communities. The agreement is effective from January 1, 2023, and includes provisions for adjusting targets if savings goals are not met.