Topic:"Demand Side Management" in M12780

EfficiencyOne IN THE MATTER OF The Public Utilities Act , R.S.N.S. 1989, c.380 as amended. - and - IN THE MATTER OF An Application by EfficiencyOne for Approval of the 2027–2031 Demand-Side Management (DSM) Purchase Agreement between Effic...

AI summary EfficiencyOne seeks approval for a 2027–2031 Demand-Side Management (DSM) Purchase Agreement with Nova Scotia Power Inc., along with establishing a final agreement and approving a DSM Resource Plan under the Public Utilities Act, R.S.N.S. 1989, c.380 as amended.

Application of EfficiencyOne as Holder of the Efficiency Nova Scotia Franchise FILED WITH THE NOVA SCOTIA ENERGY BOARD March 31, 2026

AI summary EfficiencyOne seeks to hold the Efficiency Nova Scotia franchise, filed with the Nova Scotia Energy Board on March 31, 2026. The application pertains to regulatory approval for managing demand-side management (DSM) programs in Nova Scotia.

NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c . 380 , as amended - and - IN THE MATTER OF: An Application by EfficiencyOne for Approval of a Demand-Side Management (DSM) Purchase Agreement between Ef...

AI summary The Nova Scotia Energy Board is considering EfficiencyOne's application to approve a DSM Purchase Agreement with Nova Scotia Power Inc., establish a final agreement between the parties, and approve a 2027–2031 DSM Resource Plan under the Public Utilities Act.

TO: The Nova Scotia Energy BOARD ("Energy Board" "NSEB") - 1. EfficiencyOne ("E1") is the holder of the Franchise issued by the Minister of Energy, effective January 1, 2025, to provide demand-side management activities to Nova Scotia Powe...

AI summary EfficiencyOne (E1) seeks approval from the Nova Scotia Energy Board (NSEB) for a five-year Demand-Side Management (DSM) Purchase Agreement with Nova Scotia Power Inc. (NS Power) covering 2027–2031. The application includes a DSM Resource Plan and requests an interim order if a final decision is delayed. The current agreement extends through 2026, and E1 asserts the proposed terms are in the public interest.

2 1.1 APPROVAL OF 2027–2031 DSM RESOURCE PLAN - 3 EfficiencyOne ("E1") requests approval by the Nova Scotia Energy Board (the "Energy Board" or "NSEB") - 4 of its Demand Side Management ("DSM") Resource Plan ("DSM Plan") for the term 2027...

AI summary EfficiencyOne (E1) seeks approval from the Nova Scotia Energy Board (NSEB) for its 2027–2031 Demand-Side Management (DSM) Resource Plan, aiming to reduce electricity costs for customers. The plan aligns with NSEB's 2025 decision on DSM's statutory purpose, emphasizing affordability, energy savings, and climate goals through programs and cost-benefit analysis.

1.2 APPROVAL OF PURCHASE AGREEMENT WITH NS POWER - E1 also requests the NSEB's approval of its Purchase Agreement with NS Power, together with the - associated Performance Targets, which is attached in redline form as Appendix "D" and in c...

AI summary E1 seeks NSEB approval for a Purchase Agreement with NS Power, including Performance Targets. The agreement's terms align with previously approved DSM Plans (2016–2018, 2019, 2020–2022, 2023–2025, 2026 Extension). Appendices D (redline) and E (clean) are provided.

2. REGULATORY AND POLICY CONTEXT - The following sections set out the regulatory and policy context for the 2027–2031 DSM Plan and explain - how E1 has responded to each requirement in developing this Application.

AI summary Section 2 outlines the regulatory and policy context for the 2027–2031 DSM Plan, explaining how E1 has addressed each requirement in developing its Application.

2.1 LEGISLATION AND POLICY

AI summary This section outlines the legislative and policy framework governing energy regulation in Nova Scotia, referencing key acronyms such as DSM, PUA, NSEB, NS Power, and E1. It sets the context for subsequent regulatory discussions.

2.1.1 PUBLIC UTILITIES ACT - This Application must comply with the requirements set out in the Public Utilities Act , R.S.N.S. 1989, c. - 380 (" PUA "). An overview of these obligations is set out below. Notably, since the last multi-year...

AI summary The document outlines obligations under the Public Utilities Act (PUA) for NS Power, including demand-side management (DSM) requirements. Legislative changes via Bill 228 (2022) and Bill 6 (2025) extended DSM mandates and plan terms. NS Power must enter DSM agreements with franchise holders, while the Minister of Energy oversees franchise granting for efficiency programs.

2.1.3 COMPLIANCE WITH STATUTORY REQUIREMENTS As set out in the regulatory overview in Section 2.1 above, this Application must satisfy the requirements of the PUA and the considerations in s. 6(2) of the ERBA . E1 respectfully submits that...

AI summary E1 argues that its 2027–2031 DSM Plan complies with the PUA and ERBA by meeting statutory requirements, including cost-effectiveness and portfolio-level PAC test compliance. The Plan is deemed 'cost-effective' and 'reasonably available' per NSEB interpretations, with support from prior NSUARB decisions.

2.1.4 PROVINCIAL CLIMATE CHANGE POLICY The statutory considerations outlined in ERBA's section 6(2), as well as the goals of DSM as set out in section 79A of PUA, establish the primary mandate for DSM. While the Province's climate and ener...

AI summary Nova Scotia's Provincial Climate Change Policy emphasizes demand-side management (DSM) under the Public Utilities Act (PUA) to reduce electricity costs while aligning with climate goals. The Clean Power Plan outlines transitioning to renewable energy, grid modernization, and affordability, guided by legislative acts like the Environmental Goals and Climate Change Reduction Act. The Nova Scotia Energy Board (NSEB) balances regulatory mandates with environmental objectives.

7 2.2.1 2023–2025 DSM PLAN DECISION 8 The following directives from the 2023–2025 DSM Plan Decision are relevant to this Application: - (a) To provide detailed plans and processes for each of its research initiatives prior to proceeding wi...

AI summary The 2023–2025 DSM Plan Decision outlines four directives for E1, including detailed planning, collaboration with NS Power, cost-effectiveness justification, and payback information. E1 is complying with these directives as part of its response to the NSEB's approval of the DSM Plan.

2.2.1.1 COMPLIANCE WITH 2023–2025 PLAN DECISION In response to the directive to provide detailed plans and processes for each of its research initiatives prior to proceeding with significant expenditures, documented and fully discussed wit...

AI summary E1 developed an Innovation Framework for 2027–2031, complying with NSUARB directives on avoided cost calculations. They incorporated updated IRP data from NS Power and addressed climate change goals through DSMAG. The NSUARB directed updates to avoided costs, with DSMAG tasked to resolve climate integration for future DSM plans.

2.2.2 2025 APPLICATION FOR APPROVAL OF NEW BCA TEST DECISION The following directives from the NSEB's 2025 Decision on E1's application for approval of a new BCA test are relevant to this Application: [13](#page-21-0) - (a) To use the Prog...

AI summary The NSEB outlines directives for E1's 2025 application to approve a new BCA test, requiring use of the PAC test with NS Power's WACC as the discount rate, strategic electrification programs to reduce GHG emissions and costs, inclusion of Eastward Energy in the DSM Advisory Group, and specific reporting requirements for DSM Plans.

2.2.2.1 COMPLIANCE WITH 2025 BCA DECISION - E1 has designed the 2027–2031 DSM Plan in accordance with the directives set out in the 2025 BCA Test - Decision. The specific compliance responses are summarized below. - First, E1 has used the...

AI summary E1 has designed the 2027–2031 DSM Plan in compliance with the 2025 BCA Test Decision, using the PAC test with NS Power's WACC, excluding initiatives failing to reduce both GHG and costs, and including future research on strategic electrification. E1 also provided required data to NSEB, noted NS Power's lack of long-run emissions data, and confirmed Eastward Energy's DSMAG participation.

2.2.3 2026 DSM EXTENSION DECISION - In approving E1's 2026 DSM Plan Extension, the NSEB issued the following directives relevant to this - Application: [14](#page-23-0) - (a) To continue engagement with the DSMAG on the Standardized Filing...

AI summary The NSEB approved E1's 2026 DSM Plan Extension with directives to engage DSMAG, assess program concerns, and revise mid-course adjustment processes. E1 addressed these in the 2027–2031 DSM Plan. References include Matter M12282 and NSEB Decision M12249.

pirit of the balanced plan principles. E1 submits that its efforts with respect to engagement satisfies the Board's requirement set out in section 1 of its Order in the matter of the 2026 Extension. Second, E1 has addressed concerns about...

AI summary E1 asserts compliance with the 2026 DSM extension decision, adjusting its demand response programs (reducing residential, expanding BNI) and collaborating with NS Power on locational and stacking issues. It plans to address potential double-counting of savings and includes innovation efforts in its 2027–2031 framework.

2.3 STANDARDIZED FILING FRAMEWORK - The Standardized Filing Framework was filed with the NSUARB (as it then was), as part of a Consensus - Agreement on 2016–2018 DSM Plan Application Deferred Matters[15](#page-27-1) and was accepted by the...

AI summary The Standardized Filing Framework (SFF) was established in 2016 by the NSUARB to ensure consistency in DSM Plan applications. Recent updates, driven by the NSEB and DSMAG, aim to align the SFF with regulatory requirements and stakeholder feedback. E1 seeks NSEB approval for revised framework recommendations, which will inform future DSM Plan applications, including the 2027–2031 Application.

2.3.1 THE 2022 INTEGRATED RESOURCE PLAN - The Standardized Filing Framework directs that the Resource Plan identified in NS Power's Integrated - Resource Plan ("IRP") will serve to inform the development of a Preferred DSM Plan by E1. The...

AI summary NS Power's 2022 Evergreen IRP includes 683.1 GWh energy savings and 123.9 MW demand savings through 2031. E1 must balance long-term DSM benefits with short-term affordability, guided by the 2016 Consensus Agreement and referenced decisions (M07543, M10473, M12249).

2.4 DSMAG ENGAGEMENT - E1 undertook extensive engagement during plan development with the DSMAG Feedback informed - program design, delivery approaches, and equity‑focused enhancements. - The DSMAG is a forum of regulatory stakeholders who...

AI summary E1 engaged the DSMAG throughout the 2027–2031 DSM Plan development, incorporating stakeholder feedback to refine program design and modelling. DSMAG members included representatives from energy stakeholders, consumer groups, and regulatory bodies, with iterative review processes ensuring transparency and equity-focused improvements.

1 Table 1: 2027–2031 DSM Advisory Group Engagement Activities DSMAG Engagement Activity: 2027–2031 Timeline E1 provided responses to DSMAG comments received on the Round 2 Modelling comments. E1 also shared highlights of the Preferred Plan...

AI summary The document outlines engagement activities of the DSM Advisory Group (DSMAG) from 2027–2031, including meetings, comments, and presentations related to the Preferred Plan and modeling assumptions. Key participants include E1, the Consumer Advocate, and various stakeholders.

3 3.1 AFFORDABILITY - THE PRIMARY DESIGN CONSIDERATION 4 Consistent with the PUA and the NSEB's regulatory framework, affordability is the primary consideration 5 in the design of the 2027–2031 DSM Plan. The NSEB confirmed in its 2025 BCA...

AI summary Affordability is the primary focus for the 2027–2031 DSM Plan, with E1 maintaining $63.75M annual investment (total $318.75M) to avoid inflationary increases. This prioritizes short-term cost stability over long-term savings, reflecting economic pressures and DSMAG feedback. Customer incentives now account for 71% of costs, emphasizing direct rebates.

3.2 ENERGY EFFICIENCY: SETTING APPROPRIATE LEVEL OF ENERGY SAVINGS E1 established energy savings levels by balancing IRP guidance, cost‑effectiveness, delivery capacity, and affordability. The Preferred Plan reflects a continuation and evo...

AI summary E1 set energy savings at 0.8% of NS Power's load, balancing affordability, cost-effectiveness, and sector allocation. This aligns with APEX's jurisdictional scan and the 2023-2026 DSM Plan. The Preferred Plan allocates 29%/71% to residential/BNI sectors, with 11% of residential savings directed to low-income programs, consistent with prior targets.

3.2.1 THE ROLE OF THE IRP IN ESTABLISHING THE APPROPRIATE LEVEL OF DSM ENERGY SAVINGS One of the primary planning considerations for the development of the DSM Plan is NS Power's IRP. The IRP represents the most recent, comprehensive, and...

AI summary The IRP is central to the DSM Plan, providing a stakeholder-vetted assessment of optimal resource mix for Nova Scotia's electricity needs. NS Power's 2022 IRP incorporates updated policies like GHG targets and renewable goals, with DSM energy savings levels serving as a benchmark. Key themes include decarbonization, renewables, and electrification.

3.3 DEMAND RESPONSE The demand response design in the 2027–2031 DSM Plan was informed by a combination of observed implementation experience, updated modelling assumptions, evaluation insights, DSMAG member feedback, and alignment with sys...

AI summary The 2027–2031 DSM Plan's demand response design prioritizes cost-effectiveness, achievability, and system value, informed by E1's refined assumptions, DSMAG feedback, and alignment with NS Power's IRP. Residential participation remains limited due to variable results, but Eco Shift's inclusion is justified for resilience and long-term maturation. Peer jurisdictions indicate improving cost-effectiveness over time.

3.3.1 WHY RESIDENTIAL LOAD CONTROL DEMAND RESPONSE MATTERS Strategic peak reduction can help lower long-term infrastructure costs and moderate upward pressure on electricity rates. The IRP identifies both increasing electrification and a g...

AI summary Residential load control demand response reduces infrastructure costs and moderates electricity rates by managing peak demand. Electrification trends, like heat pump adoption, increase peak demand, necessitating demand response programs. Eco Shift and Ontario's Peak Perks program demonstrate residential DR's role in grid flexibility. Expansion aligns with IRP planning and discussions with NS Power and NSIESO.

6 3.3.2 COST-EFFECTIVENESS: A PROGRAM MATURITY ROADMAP 7 The 2023–2025 DSM Plan positioned demand response as a development and learning phase, with a focus 8 on identifying effective program pathways and refining operational delivery for...

AI summary The 2023–2025 DSM Plan positions demand response as a development and learning phase, focusing on identifying effective program pathways and refining operational delivery for initiatives like Eco Shift. This approach aligns with the typical evolution of residential demand response programs in North America, emphasizing early-stage learning and operational refinement before scaling.

21 Table 3: Demand Response Initiatives in other Jurisdictions Jurisdiction and DSM Utility Early-Stage Insights Ontario (IESO Peak Perks / Smart Thermostat DR) • Early years focused on recruitment and platform testing. • First-year MW per...

AI summary The text discusses demand response initiatives in other jurisdictions, including Ontario's Peak Perks program and Massachusetts' Wi-Fi thermostat programs. It highlights early-stage insights such as initial challenges with recruitment, platform testing, and baseline methodologies, as well as improvements over time in program economics and capacity stabilization.

6 7 Through direct discussions with the IESO Demand Side Management team, the program is expected to 8 reach cost-effectiveness under the Program Administrator Cost (PAC) test within the next year, 9 approximately four years after its laun...

AI summary The program is expected to achieve cost-effectiveness under the Program Administrator Cost (PAC) test within the next year, four years after its launch, due to factors like increased demand response capacity, higher customer participation, coordinated marketing, and adoption of bring-your-own thermostat models. Ontario's experience offers insights for smaller jurisdictions.

21 3.3.3 TECHNOLOGY & FIELD LEARNING Program deployment to date has provided valuable operational experience and insights into the technologies that deliver the strongest performance and program economics. This includes heat pump hot water...

AI summary Program deployment has enhanced operational experience with technologies like heat pump hot water controllers, behind-the-meter batteries, and smart thermostats. Improvements in workflows, dispatch strategies, and vendor relationships have reduced costs and improved demand response reliability during peak events.

3.3.4 SUMMARY - Eco Shift continues to demonstrate measurable progress as it moves through its development phase. - Preliminary results show increasing customer participation and improved device responsiveness across - multiple technologie...

AI summary Eco Shift demonstrates measurable progress with increased customer participation and device responsiveness, enhancing demand response capacity and cost-effectiveness under PAC. Operational refinements, scaling participation, and alignment with constrained system areas are expected to reduce costs and improve reliability. Eco Shift is projected to achieve cost-effectiveness within two to three seasons.

3.4 SOLAR-PV - E1 submits that customer sited solar-PV falls squarely within the statutory definition of demand-side - management under section 79A(b)(v), which includes DSM activities relating to "the delivery of a - reduction in the amou...

AI summary E1 argues customer-sited solar-PV qualifies as demand-side management (DSM) under the PUA, reducing NS Power's required supply. The program targets Mi'kmaw communities to address participation barriers, align with equity goals, and support reconciliation. The 2027–2031 DSM Plan includes 200 installations (0.9% of total DSM investment) focused on these communities, with future expansion contingent on cost-effectiveness and Energy Board approval.

3.5 STRATEGIC ELECTRIFICATION Strategic electrification was added to E1's mandate by way of an update to section79A(b)(iv) of the PUA in 2022, as outlined in section [2.1.1](#page-8-3) above. The NSEB, in its decision on E1's BCA clarified...

AI summary Strategic electrification was added to E1's mandate via a 2022 PUA update. The NSEB requires strategic electrification to reduce both GHG emissions and electricity costs. E1 supports its inclusion in the 2027–2031 DSM Plan if it meets these criteria, though the Clean Power Plan lacks cost assumptions for guidance. The 2022 Evergreen IRP includes electrification scenarios but not optimal savings levels.

8 3.6 ENABLING STRATEGIES 9 Enabling Strategies are a foundational component of E1's DSM portfolio. These investments support the development, delivery, and long-term effectiveness of DSM programs by addressing structural, market, and info...

AI summary Enabling Strategies are a key component of E1's Demand-Side Management (DSM) portfolio, aimed at addressing structural, market, and informational barriers. The 2027–2031 DSM Plan includes targeted investments in education, research, development, and market transformation, with adjustments made for affordability and long-term effectiveness.

23 Table 4: Comparison of 2026 and 2027–2031 Annual Investment in Enabling Strategies 2026 DSM Extension ($M) 2027–2031 DSM Preferred Plan Annual Average ($M) Education & Outreach $1.6 $1.3 Development & Research $1.6 $1.4 Other Enabling S...

AI summary Table 4 compares annual investments in Enabling Strategies for the 2026 DSM Extension and the 2027–2031 DSM Preferred Plan. The total investment decreases from $7.0M in 2026 to $5.8M annually for the 2027–2031 period, with reductions observed in most categories except for Market Transformation.

1 4. AFFORDABILITY 2 Affordability continues to be a critical factor in determining the level of investment in a DSM Plan. E1 has 3 heard from several members of the DSMAG over the past several DSM Plans that consideration of short-4 term...

AI summary Affordability remains a key consideration in DSM Plan investments. E1 maintains annual investment at the 2026 level of $63.75 million without inflationary increases, balancing short-term affordability concerns (e.g., rising housing/energy costs) against NS Power's IRP-driven long-term economic benefits for ratepayers.

14 4.1 THE 2027–2031 DSM PLAN CONTINUES TO PRIORITIZE CUSTOMERS E1's DSM Plan continues to prioritize customers by ensuring that the investment in customer incentives remains not only the largest portion of the $63.75 million per year but...

AI summary E1's 2027–2031 DSM Plan prioritizes customers by increasing customer incentives from 66% to 71% of total investment compared to the 2026 DSM Extension, with annual funding of $63.75 million. This reflects a shift toward greater customer-focused spending within the overall DSM strategy.

1 Figure 2: 2027–2031 DSM Preferred Plan Average Annual Expenditures

AI summary The document presents Figure 2, which outlines the average annual expenditures for the 2027–2031 DSM Preferred Plan. It is part of a regulatory proceeding in Nova Scotia, focusing on demand-side management strategies and their financial implications. The figure is referenced in the context of energy policy and utility regulation, though specific data or analysis within the text is not provided.

4 Figure 3: 2026 DSM Plan Expenditures

AI summary Figure 3 outlines 2026 Demand-Side Management (DSM) Plan expenditures, part of a Nova Scotia regulatory proceeding. It references entities like NS Power, NSEB, and E1, with context on energy planning and regulatory frameworks under the Public Utilities Act and Energy and Regulatory Boards Act.

1 4.2 DSM REMAINS AT A LOWER COST THAN THE FUEL OPTION 2 DSM, and particularly its energy efficiency programs, is demonstrably lower in price than the fuel option 3 it displaces, making it a logical and affordable first choice investment f...

AI summary Demand-Side Management (DSM), especially energy efficiency programs, is shown to be more cost-effective than fuel options, with DSM costing less than fuel by up to 4 cents per kWh. This makes DSM a preferable investment for ratepayers, as it reduces fuel costs and benefits all ratepayers through the fuel adjustment mechanism (FAM).

Table 5: Cost Difference of DSM and Fuel Cost Difference Between DSM & Fuel Year Cost of Fuel as Compared to DSM (Difference $ per kWh) Fuel Cost as % of DSM 2015 0.031 271% 2016 0.029 283% 2017 0.024 229% 2018 0.037 296% 2019 0.040 312% 2...

AI summary Table 5 compares the cost difference between Demand-Side Management (DSM) and fuel over various years, showing that fuel costs are significantly higher than DSM costs, with fuel costs as a percentage of DSM costs increasing over time, except in 2024. Section 4.3 highlights that DSM continues to provide lasting benefits with a short payback period.

4.4 DSM CONTINUES TO BE THE LEAST RISK OPTION - DSM 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 DSM; and - No variability in the c...

AI summary DSM is identified as the least risky energy investment due to capped spending, no unexpected costs, and E1's consistent performance. Ratepayers benefit from cost certainty, while fuel and capital projects by NS Power carry higher risks and volatility. E1's reliability ensures adherence to approved spending levels, minimizing financial uncertainty.

4.5 RATE AND BILL CONSIDERATIONS & RATE AND BILL IMPACT ANALYSIS (RBIA) FOR 2027–2031 E1's RBIA for the Preferred Plan demonstrates that participants in DSM benefit from bill savings. The reductions in energy use and demand achieved by par...

AI summary E1's Rate and Bill Impact Analysis (RBIA) for the Preferred Plan shows that DSM participants benefit from bill savings, with energy efficiency and demand response having positive effects on rates, and solar-PV having minimal impact. These findings are consistent with historical data from 2011 to 2026.

21 Table 6: Preferred Plan – Average Rate Impacts by Resource over 2027-2046 Residential Small General General Large General Small Industrial Medium Industrial Large Industrial Municipal DSM (All Resources) 0.58% 0.88% 0.74% 0.33% 0.76% -0...

AI summary Table 6 presents the average rate impacts by resource over the period 2027-2046 for various customer classes. The table highlights the impact of different resources such as DSM, Energy Efficiency, Demand Response, and Solar-PV on residential, small general, general, large general, small industrial, medium industrial, large industrial, and municipal customers.

4.5.1 HISTORICAL RBIA - 24 E1's 2026 Historical RBIA indicates that ratepayers are already positioned to accrue aggregate bill savings - in excess of $2.5 billion between 2011 and 2041 as a result of past DSM activities between 2011 and 20...

AI summary E1's 2026 Historical RBIA indicates that past Demand-Side Management (DSM) activities between 2011 and 2026 will result in over $2.5 billion in aggregate bill savings for ratepayers from 2011 to 2041. Figure 5 illustrates average rate and bill impacts by rate class.

4.5.2 2 027–2 03 1 RBIA Investment at the Preferred Plan level would result in average rate impacts that range between -0.1 percent and +0.9 percent by rate class, averaged over the lifetime of measures [(Figure 6)](#page-50-0). These figu...

AI summary Investment in the Preferred Plan for 2027–2031 results in minimal rate impacts (−0.1% to +0.9%) but significant bill reductions (0.04% to 37%) for DSM participants. Figures 6–8 illustrate these impacts, highlighting benefits for all customers despite negligible rate changes.

3 5. THE BALANCED PLAN APPROACH - 4 The portfolio was developed in accordance with the "Balanced Plan Approach" outlined in the - 5 Standardized Filing Framework, which directs E1 to "produce DSM Resource Plans that balance multiple - 6 as...

AI summary E1 developed a portfolio under the 'Balanced Plan Approach' to balance DSM aspects, achieving 435.4 GWh energy savings, 85.0 MW demand savings, and other metrics by 2031. Principles include energy/capacity avoidance, cost efficiency, non-electric benefits, and equitable access. The plan emphasizes value for Nova Scotians through diversified programs and market engagement.

6 5.1 SHORT- AND LONG-TERM ENERGY AND CAPACITY AVOIDANCE 7 The Preferred Plan achieves a balance of both short- and long-term energy capacity avoidance. Dunsky 8 Energy Consulting described the balanced plan approach, and in particular sho...

AI summary The Preferred Plan balances short- and long-term energy and capacity avoidance. Short-term savings focus on immediate measures like appliances, while long-term strategies involve market transformation through education and standards. DSM investments provide immediate bill savings and long-term avoided infrastructure costs.

ficiency measures, which is increasingly important in the current economic context. Several factors have contributed to changes in unit delivery costs between the 2023–2026 and 2027–2031 Plan periods: - (a) The conclusion of the federal go...

AI summary The document outlines factors increasing DSM program delivery costs between 2023–2026 and 2027–2031, including the end of federal grants, shifts to complex measures, inflation, and reduced savings from heat pump evaluations. E1's increased incentives and economic pressures are highlighted as key drivers.

5.3 AVOIDED ENERGY AND CAPACITY INVESTMENTS - DSM provides value to ratepayers in part by avoiding investments associated with supply side resources. - In Nova Scotia, the following categories of avoided system costs are applied to DSM: -...

AI summary Demand-Side Management (DSM) in Nova Scotia avoids energy and capacity investments by reducing demand. The Preferred Plan emphasizes energy efficiency, demand response, and solar-PV initiatives. Categories of avoided costs include energy, capacity, transmission, and distribution. EfficiencyOne (E1) expanded demand response programs to address NS Power's growing demand.

5.5 DIVERSITY OF PROGRAM DELIVERY - Diversity in program delivery is a key way to minimize risk and involves the diversification of measures, - markets and strategies. The Preferred Plan includes a full suite of programs and strategies tha...

AI summary Diversity in program delivery reduces risk by diversifying measures, markets, and strategies. The Preferred Plan includes a broad range of programs targeting residential and BNI sectors. E1's diversified portfolio aims to ensure equitable participation despite higher unit costs or lower benefit/cost ratios for some opportunities.

DIVERSE MEASURES - The Preferred Plan continues to evolve E1's measure mix. The Plan features 341 measures, and 11 - energy efficiency program components, and 2 demand response program components and one solar-PV - program component.

AI summary The Preferred Plan includes 341 measures, with 11 energy efficiency programs, 2 demand response programs, and 1 solar-PV program. E1's measure mix is evolving to incorporate diverse initiatives under the Nova Scotia regulatory framework.

DIVERSE STRATEGIES - The Preferred Plan includes diverse strategies recognizing that no single delivery model effectively - reaches the full range of customers, market sectors, and technologies served by DSM. The portfolio - incorporates a...

AI summary The Preferred Plan employs diverse DSM strategies, combining delivery models like turn-key partnerships, contractor-based delivery, and market-enabled offerings. It includes technical support, rebates, direct installation, and self-serve options. The heat pump water heater pilot is part of Enabling Strategies to support E1's model through 2031. 2023-2025 results and the 2026 Plan are referenced with residential behavior savings removed.

5.8 RATE IMPACTS In designing the Preferred Plan portfolio, E1 explicitly balanced near-term rate impacts with the long-term value delivered to ratepayers. The portfolio reflects a measured approach to investment, limiting it to the same i...

AI summary E1's Preferred Plan balances near-term rate impacts with long-term value by maintaining 2026 investment levels, diversifying programming across customer classes, and prioritizing cost-effective, long-lasting measures. The approach emphasizes affordability, system flexibility, and equity through targeted low-income programs and efficient delivery, supported by a forward-looking Rate and Bill Impact Analysis.

1 6. PREFERRED PLAN DETAILS

AI summary The section titled 'Preferred Plan Details' is part of a regulatory proceeding document in Nova Scotia, though no substantive content is provided in the given text. It likely outlines details of a preferred plan for energy management or utility regulation.

2 6.1 OVERVIEW - 3 The Preferred Plan represents a comprehensive suite of programs and service offerings which will deliver - 4 approximately 435.4 GWh of affordable, incremental net energy savings, 85.0 MW of cumulative system- - 5 peak d...

AI summary The Preferred Plan outlines a comprehensive suite of energy efficiency programs and service offerings that aim to deliver significant energy savings and demand reductions over the 2027–2031 period. It emphasizes affordability, long-term ratepayer benefits, and cost-effectiveness, with a focus on achieving energy efficiency at a lower lifetime unit cost compared to fuel costs.

6.2 HIGHLIGHTS OF THE 2027–2031 PLAN - Key highlights/portfolio insights of the 2027–2031 Preferred Plan include: - portfolio cost-effectiveness result of 2.4 for the Program Administrator Cost (PAC) test - demonstrating that the portfolio...

AI summary The 2027–2031 Preferred Plan highlights a portfolio cost-effectiveness result of 2.4, a $318.75 million investment in DSM resources, and expected lifetime benefits of $682.5 million for participating customers. The plan also includes new components like Mi'kmaw New Home Construction and residential solar-PV for Mi'kmaw communities.

Table 7: 2027–2031 Plan - Portfolio Level Insights Insights 2027–2031 Energy Efficiency Energy Savings as % of NS Power Load 0.8% Energy Savings (EE) Split (RES/BNI) 29/71 Demand Savings (EE) Split (RES/BNI) 44/56 Dedicated Low-Income & Eq...

AI summary Table 7 provides insights into the 2027–2031 plan, highlighting energy efficiency savings, demand response capacity, solar-PV generation, and associated costs and benefits. It includes metrics such as energy savings percentages, unit costs, and CO₂e savings across residential and BNI (Business and Non-Industrial) sectors.

6.3.1 2 PORTFOLIO SAVINGS & INVESTMENT - 3 Table 8 provides portfolio-level savings, inclusive of all proposed DSM resources for the 2027–2031 DSM - 4 Preferred Plan.

AI summary Table 8 outlines portfolio-level savings from all proposed DSM resources under the 2027–2031 DSM Preferred Plan. The data includes savings projections for demand-side management initiatives during this period.

6 Table 8: 2027–2031 DSM Preferred Plan Portfolio Savings and Investment 2027-2031 Portfolio Year Investment ($M) Lifetime Benefits ($ million) First-Year Energy Savings (GWh) Peak Demand Savings (MW) Lifetime Energy Savings (GWh) Low-Inco...

AI summary Table 8 outlines the 2027–2031 DSM Preferred Plan Portfolio Savings and Investment, showing annual investments, energy savings, peak demand reductions, and other metrics related to demand-side management programs in Nova Scotia.

1 6.3.2 PROGRAM SAVINGS & INVESTMENT - 2 Table 9, below, provides the five-year savings and investment details by program component for the - 3 2027–2031 Preferred Plan. Detailed information by year is provided in Appendix A.

AI summary This section introduces Table 9, which outlines five-year savings and investment details by program component for the 2027–2031 Preferred Plan, with detailed annual information provided in Appendix A.

- 5 Table 9: 2027–2031 DSM Preferred Plan Savings and Investment by Program Component 2027-2031 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Ava...

AI summary Table 9 presents the investment and savings projections for various residential energy efficiency programs under the 2027–2031 DSM Preferred Plan. The table highlights program components such as efficient product rebates, home energy assessments, and initiatives targeting low-income and equity impacts, detailing investments, lifetime benefits, energy savings, and other metrics.

1 6.4 KEY ENHANCEMENTS FOR 2027–2031 - 2 The 2027–2031 DSM Plan (Appendix A) provides fulsome program details on the activities proposed as - 3 part of the Purchase Agreement. [Table 10,](#page-65-1) below provides the modifications and en...

AI summary The 2027–2031 DSM Plan (Appendix A) outlines program details for the Purchase Agreement, with Table 10 highlighting modifications compared to the 2023–2026 Plan. Key enhancements focus on demand-side management initiatives and updated program structures.

5 Program Program Component Changes from 2023–2026 Plan 2027–2031 Status Residential Efficient Product Rebates Appliance Retirement • Component ended in 2025 following declining savings, rising delivery costs, and limited availability of s...

AI summary The document outlines changes to residential energy efficiency programs in Nova Scotia, including the retirement of the Appliance Retirement component, modifications to the Instant Savings program, and updates to the Affordable Multifamily Housing and Efficient Product Installation programs. These changes reflect adjustments in incentive levels, expansion of rebate categories, and enhancements to customer experience.

- 3 E1's success in implementing an approved DSM Plan is evaluated through Performance Targets. The 4 Standardized Filing Framework sets out the performance targets and thresholds which must be met - 5 through the execution of the DSM Plan...

AI summary E1's success in implementing an approved DSM Plan is evaluated through Performance Targets set by the Standardized Filing Framework. E1 is proposing targeted solar-PV activities and a new Performance Target as part of its Preferred Plan, with compliance measured based on achieving at least 90 percent of the targets over the NSEB-approved Purchase Agreement period.

16 Table 11: Proposed 2027–2031 DSM Preferred Plan Performance Targets Available Energy Peak Demand Low-Income & Demand Solar-PV DSM Resource Savings Savings Equity Energy Response Generation (GWh) (MW) Savings (GWh) Capacity (GWh) (MW) En...

AI summary Table 11 outlines the proposed 2027–2031 DSM Preferred Plan Performance Targets, including energy efficiency savings, peak demand reductions, low-income and equity energy savings, demand response capacity, and solar-PV generation targets.

19 8.1 MID-COURSE ADJUSTMENT PROCESS 20 On the issue of Mid-Course Adjustments (MCAs), the NSEB in its Decision in the 2026 Extension Plan 21 (M12249) stated: 22 [73] The concerns raised by the Industrial Group are serious. The potential f...

AI summary The NSEB expressed concerns about E1's Mid-Course Adjustment (MCA) process, citing potential unfair impacts on rate classes funding E1's work. The NSEB directed E1 to revise its MCA process to allow greater ratepayer input and align spending with NSEB-approved rate classes. E1 acknowledged these concerns and agreed to engage with the DSMAG to address issues related to cost management and program flexibility.

8.2 MID-TERM CHECK-IN - Following the 2022 amendment to the PUA extending DSM Plans from three years to five years, DSMAG - members expressed concerns regarding performance risk and oversight over the longer plan term. In - response to sta...

AI summary Following the 2022 PUA amendment extending DSM plans to five years, DSMAG raised concerns about oversight. E1 proposes a mid-term check-in process to enhance transparency and stakeholder engagement without reopening the plan, aligning with the Legislature's intent to reduce regulatory proceedings. E1 maintains existing reporting mechanisms and NSEB oversight remain intact.

8.3 OTHER REPORTING PROCESSES E1 will submit six reports annually to the NSEB, including quarterly reports (Q1-Q3), an annual progress report, annual DSM program evaluation reports, and annual audited financial statements. Over the 2027– 2...

AI summary E1 must submit 30 DSM reports to NSEB over 2027–2031, including quarterly, annual progress, program evaluation, and audited financial reports. NSEB verifies savings and allows DSMAG input. E1 will follow NSEB-approved measurement and evaluation protocols, with further details in Appendix A.

5 9.1 OVERVIEW - Pursuant to the NSUARB directive,[27](#page-73-4) 6 E1 is required to file one or more alternate scenarios (the "Alternate - 7 Scenario") in addition to its Preferred Plan filing. In the stakeholder engagement process prec...

AI summary E1 is required by the NSUARB to file an Alternate Scenario as part of its Preferred Plan, incorporating energy efficiency, demand response, solar-PV, and strategic electrification. Stakeholders emphasized addressing short-term affordability impacts, prompting E1 to provide a fully costed DSM scenario.

9.2 SCENARIO IN ACCORDANCE WITH THE STANDARDIZED FILING REQUIREMENTS. The Alternate Scenario represents a total investment in energy efficiency, demand response and solar PV of $308.4 million over the 2027–2031 DSM Plan. The design approac...

AI summary The Alternate Scenario invests $308.4 million in energy efficiency, demand response, and solar PV from 2027–2031. It maintains low-income and equity-focused investments while eliminating the Eco Shift program to address cost-effectiveness concerns and balance DSMAG perspectives.

10. CONCLUSION - Based on the supporting Evidence and Appendices, E1 respectfully requests approval from the Energy - Board for the Preferred Plan and related Purchase Agreement with NS Power. 27 M06733, NSUARB Order, E1 2016–2018 DSM Plan...

AI summary E1 requests approval for the Preferred Plan and related Purchase Agreement with NS Power, emphasizing its affordability and cost-effectiveness. The plan includes energy savings, demand reduction, and system benefits, with a total investment of $318.75 million over five years. E1 claims the application meets the mandatory approval test under the Public Utilities Act.

GLOSSARY OF TERMS Term Definition Alternate Scenario E1 provides one or more alternate scenario(s) with the same portfolio-level metrics as E1's proposed DSM Resource Plan (i.e., the Preferred Plan). Available Demand Response Capacity The...

AI summary The glossary defines key terms related to demand-side management (DSM) and energy efficiency programs, including alternate scenarios, demand response capacity, balance adjustments, and baseline measurements. These definitions are relevant to the regulatory process and program implementation.

1.1 OBJECTIVES OF THE 2027–2031 DSM PREFERRED PLAN - E1's objectives for the 2027–2031 DSM Preferred Plan include: - 1. deliver cost-effective demand side resources that support the successful implementation of a long-term electricity stra...

AI summary E1's 2027–2031 DSM Preferred Plan aims to deliver cost-effective demand-side resources aligned with ratepayer interests, ensure equitable access to services, and foster transparent stakeholder collaboration in resource planning.

1.2 REPORT ORGANIZATION - Appendix A provides the following: - overview of the development of the Preferred Plan including approach and methodology; - overview of the proposed portfolio and program targets, investment levels, and performan...

AI summary The report outlines its organizational structure, detailing sections covering DSM plan results, development approaches, portfolio overviews, program descriptions, enabling strategies, performance metrics, and reporting. Appendix A includes the Preferred Plan's methodology, program targets, and a DSM Purchase Agreement under the PUA. Sections 2–13 provide historical data, plan development, program specifics, and evaluation frameworks for 2027–2031.

7 2. PREVIOUS DSM PLAN RESULTS

AI summary The section reviews outcomes of past Demand Side Management (DSM) plans, focusing on energy efficiency, cost recovery mechanisms, and compliance with regulatory frameworks. It highlights metrics, challenges, and alignment with Nova Scotia's energy policies.

8 2.1 2023–2026 DSM PLAN 9 E1's current approved DSM Plan (2023–2026) provides for the delivery of DSM programs through the end of 2026. [1](#page-90-2) With three of the four Plan years now complete, E1 has made substantial progress towar...

AI summary E1 has made significant progress towards its 2023–2026 DSM Plan performance targets, achieving 82% of energy savings, 84% of demand savings, and 84% of energy savings for affordable housing and Mi'kmaw projects. The 2026 DSM Extension is expected to help achieve 90% compliance for all targets by December 31, 2026.

2 Table 1: 2023–2026 Approved Plan and Results Year Investment ($ million) Lifetime Benefits ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Demand Response Capacity (MW) Low-Inc...

AI summary The table presents the 2023–2026 Approved Plan and Results for energy efficiency programs, detailing investments, benefits, energy savings, and program administrator costs. It compares approved plans with actual results and provides percentages of achievement for various metrics across the years.

2.2 DISCUSSION OF 2023-2025 RESULTS E1's 2025 Annual Progress Report (APR), filed March 31, 2026, provides detailed discussion of 2025 results and cumulative progress toward the 2023–2026 DSM Plan performance targets. Results for 2023 and...

AI summary E1's 2025 Annual Progress Report (APR) details 2025 results and cumulative progress toward 2023–2026 DSM Plan targets, noting implementation challenges like market changes and program adjustments. Results are contextualized within the DSM Plan period, with insights informing the 2026 DSM Extension and future planning. References to prior APRs (2023–2024) and regulatory approvals are included.

2.2.5 AVAILABLE DEMAND RESPONSE CAPACITY Demand response was introduced as a new program in 2023 following pilot initiatives undertaken from 2020-2022. In the 2023 season (December 1, 2022 to February 28, 2023), early implementation challe...

AI summary Demand Response (DR) program challenges in 2023–2025 included participant drop-outs, operational constraints, and technical issues like controller removals. E1 adjusted strategies for 2026, improving engagement and infrastructure, leading to early 2026/2027 results doubling 2024/2025 capacity. Target of 16.3 MW available capacity is expected to be met.

2.2.6 UNIT COST RESULTS Unit cost data is a calculation output reflecting E1's investment and energy savings over a defined time period. Actual results for the 2023–2025 period show a portfolio-level unit cost of $0.37/kWh, slightly lower...

AI summary The 2023–2025 unit cost for E1's energy efficiency programs was slightly lower than the approved plan, but residential unit costs have risen due to the pause of the Residential Behaviour program and changes in program components. These trends are expected to continue into 2026 and influence the development of the 2027–2031 DSM Preferred Plan.

2.2.7 2023–2026 DSM PLAN RATE CLASS RESULTS - 7 E1 has provided 2023–2025 rate class results, in addition to 2026 DSM Extension anticipated results, - 8 compared to the approved 2023–2026 Plan, in Table 2, below. 9 10 11 12 13 14 2025 actu...

AI summary E1 has provided 2023–2025 rate class results and 2026 DSM Extension anticipated results, compared to the approved 2023–2026 Plan. 2025 actual expenditures were slightly lower than the approved 2025 Plan, with the medium industrial rate class showing higher spending due to increased participation in the BNI Demand Response program.

3 2.3 CUMULATIVE DSM SAVINGS AND INVESTMENT: 2012-2025 4 [Table 4,](#page-100-0) below, presents E1's cumulative DSM Plan savings and expenditures from 2012 to 2025 compared with the corresponding Board-approved Plans.[4](#page-99-2) 5 6 7...

AI summary This section discusses E1's cumulative DSM savings and investment from 2012 to 2025, noting that expenditures are 6% below the Board-approved investment, while energy and demand savings are 5% above the approved targets. Factors such as program mix and market conditions are cited as reasons for the underspend in earlier years.

11 Table 4: Cumulative DSM Savings and Investment : 2012–2025 Plan as Approved Results Year Investment ($ million) First-Year Energy Savings (GWh) Peak Demand Savings (MW) Available Demand Response Capacity (MW) Low-income & Equity Energy...

AI summary Table 4 provides a detailed breakdown of cumulative demand-side management (DSM) savings and investment from 2012 to 2025, including energy savings, peak demand savings, and expenditures. It compares the approved plan with actual results for each year, highlighting trends in investment and savings over time.

1 3. PLAN DEVELOPMENT AND DESIGN APPROACH 2 E1 developed the 2027–2031 DSM Preferred Plan through a multi-phase process to establish a cost- 3 effective DSM portfolio. This process defined the DSM resources to be offered, the level of savi...

AI summary E1 developed the 2027–2031 DSM Preferred Plan through a multi-phase process involving stakeholder engagement, scenario modeling, and regulatory considerations. The plan incorporates updated avoided costs, aligns with climate targets, and reflects NSEB decisions on BCA and DSM extensions. Development was paused briefly due to PUA amendments and resumed after filing the 2026 DSM Extension.

3.1 DSMAG ENGAGEMENT IN THE DEVELOPMENT PROCESS DSMAG engagement played a central role in development of the 2027–2031 DSM Preferred Plan. Throughout the planning process, E1 engaged a range of DSMAG members including rate class representa...

AI summary DSMAG played a central role in developing the 2027–2031 DSM Preferred Plan through iterative engagement with stakeholders, including government representatives, industry groups, and experts. E1 incorporated feedback via modelling reviews, written submissions, and meetings, shaping both the Preferred Plan and Alternate Scenario.

3.2 PORTFOLIO DESIGN CONSIDERATIONS AND ASSUMPTIONS - E1 was guided by the following key considerations in developing the Preferred Plan: - cost-effectiveness; - determining appropriate energy and demand savings established using a percent...

AI summary E1's Preferred Plan prioritizes cost-effectiveness, achievable energy savings via a percent-of-load approach, support for Mi'kmaw communities post-2027, and balanced portfolio principles. Emphasis is on affordability, performance targets, and long-term ratepayer benefits through appropriate investment levels.

3.2.1 RESOURCE SCENARIO DESIGN In developing the Plan's design approach, E1 considered feedback from the DSMAG indicating limited support for the three design objectives historically used to guide recent DSM Plans: a 50/50 investment DATE...

AI summary E1 revised its DSM Plan design approach based on feedback from the DSMAG, maintaining the annual investment level, adjusting energy savings targets and allocations, and ensuring support for low-income and equity communities. The plan aligns with recommendations from APEX and includes a residential/BNI energy savings split of 29/71, with dedicated low-income savings of 11% of residential savings.

3.3 MODELLING - The "modelling process" refers to the use of DSM portfolio design tools to assess the comparative costs, - savings, and cost-effectiveness of various DSM resource scenarios to determine the Preferred portfolio - design for...

AI summary The modelling process evaluates DSM resource scenarios using ProCESS™ and DRSIM™ tools to assess cost-effectiveness, energy impacts, and expenditures for the 2027–2031 DSM Resource Plan. Guidehouse supports E1 in developing the preferred portfolio design through these analyses.

8 3.3.1 MODELLING PROCESS - 9 The following sections provide a high-level overview of the 2027–2031 DSM Resource Plan modelling - process, followed by a description of each stage in the process.

AI summary The text outlines the high-level overview and stages of the 2027–2031 DSM Resource Plan modelling process, focusing on Demand Side Management strategies.

3.3.1.1 MODEL CONFIGURATION - At the outset of the modelling process, E1 and Guidehouse reviewed and confirmed the overall modelling - framework for the 2027–2031 DSM Resource Plan, and configured the following modelling tools - associated...

AI summary E1 and Guidehouse configured ProCESS™ and DRSim™ models for the 2027–2031 DSM Resource Plan, aligning with NSEB directives. Model updates ensured parameters, inputs, and methodologies met E1's planning requirements and regulatory standards.

3.3.1.2 MODEL INPUTS AND ASSUMPTIONS - Once the models were configured, E1 and Guidehouse compiled the key modelling inputs and - assumptions required for all subsequent modelling steps associated with the DSM Plan. These included - global...

AI summary E1 and Guidehouse compiled model inputs and assumptions for the DSM Plan, including global factors (avoided costs, discount rates) and program-specific data. Inputs were reviewed and adjusted for 2027–2031, with new measures informed by engineering assumptions and external data. Details are in Attachment 1.

10 3.4 COST-EFFECTIVENESS - 11 In the Energy Board's Decision regarding E1's Application for approval of a New Benefit-Cost Analysis Test - for Evaluating Demand Side Management Plans (M12282), the Energy Board directed E1 to:[9](#page-107...

AI summary E1 must use the Program Administrator Cost (PAC) test for evaluating its 2027–2031 Demand Side Management (DSM) Plan, with NS Power's WACC (6.65%) as the discount rate. The Energy Board directed this under the Public Utilities Act (PUA), requiring portfolio-level cost-effectiveness screening. E1 achieved a PAC result of 2.4 (above the 1.0 threshold) and provided justifications for measures failing cost-effectiveness tests.

16 4.1 PORTFOLIO KEY INSIGHTS The 2027–2031 DSM Preferred Plan will invest $318.75 million to achieve 435.4 GWh of incremental cumulative net energy savings, 85.0 MW of cumulative system-peak demand savings, 29.3 MW of available capacity f...

AI summary The 2027–2031 DSM Preferred Plan is projected to invest $318.75 million to achieve significant energy savings, demand reductions, and solar-PV generation. Key insights and impacts are detailed in Table 5.

22 Table 5: 2027–2031 DSM Preferred Plan Portfolio Level Insights Insights 2027–2031 Energy Efficiency Energy Savings as % of NS Power Load 0.8% Energy Savings (EE) Split (RES/BNI) 29/71 Demand Savings (EE) Split (RES/BNI) 44/56 Dedicated...

AI summary Table 5 provides insights into the 2027–2031 DSM Preferred Plan Portfolio, detailing energy efficiency and demand response metrics, including energy savings percentages, cost splits between RES and BNI, and unit costs for energy and demand savings.

Generation Split (RES/BNI) First-Year Unit Cost ($/kWh) Lifetime Unit Cost ($/kWh) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Capacity (MW) First-Year CO 2...

AI summary The text presents a table with metrics related to energy generation and demand-side management (DSM) programs, including unit costs, energy savings, and capacity splits. It highlights the 'Total Preferred Plan' and provides data for the years 2027-2031, focusing on RES/BNI split and program performance indicators.

68.2 1 Levelized unit cost of demand response is calculated by taking the net present value of investment and available to the control of the cost of demand response is calculated by taking the net present value of investment and available...

AI summary The text discusses the calculation of the levelized unit cost of demand response, emphasizing the use of net present value of investment and available capacity. However, the content is repetitive and lacks clarity or additional context.

4.2 PORTFOLIO KEY OBSERVATIONS

AI summary Section 4.2 discusses portfolio key observations related to energy management, regulatory frameworks, and programs in Nova Scotia. It references acronyms like DSM, PUA, NSEB, and NS Power, highlighting topics such as demand response, energy efficiency, and utility rate design.

Key observations of the Preferred Plan include: - annual investment for the Preferred Plan is maintained at the 2026 DSM Extension approved investment level of $63.75 million, with no annual inflationary increases to the investment, to sup...

AI summary The Preferred Plan maintains a fixed annual investment of $63.75 million with no inflationary increases, aiming to support affordability. Energy savings have declined due to market shifts and program closures. The plan supports Mi'kmaw communities and shows strong cost-effectiveness with a 114% ROI and a 30-year solar-PV measure life. However, some low-income programs have lower PAC scores.

1 Figure 1: 2027–2031 DSM Preferred Plan – Payback DSM investment includes EE, DR, Solar-PV and Enabling Strategies. Green bars are nominal investment. Blue bars are nominal avoided cost. Yellow line is a 2027 net present value (NPV) of th...

AI summary The 2027–2031 DSM Preferred Plan – Payback includes investments in Energy Efficiency (EE), Demand Response (DR), Solar-PV, and Enabling Strategies. Green bars represent nominal investment, blue bars show avoided costs, and the yellow line depicts NPV using NS Power's WACC. The analysis evaluates cost recovery and financial viability of DSM initiatives.

7 Table 6: Summary of Changes and Enhancements in the 2027–2031 DSM Preferred Plan Area of Change Change/New Element Rationale and Context • Green Heat ended in 2025 • Green Heat ended due to declining participation • Appliance Retirement...

AI summary The 2027–2031 DSM Preferred Plan outlines several program adjustments, including the end of Green Heat and Appliance Retirement due to low participation and rising costs. The Mi'kmaw Home Energy Efficiency Project is set to conclude by mid-2027, and the Residential Behaviour program is being reevaluated for potential discontinuation.

DATE FILED: March 31, 2026 Page 24 of 112 Area of Change Change/New Element Rationale and Context beneficial initiatives in its upcoming five-year DSM Plan"12 • E1 evaluated whether Residential Behaviour could be repurposed as a marketing...

AI summary The document outlines changes to the DSM Plan, including the introduction of a new Mi'kmaw New Home Construction program component, the removal of residential lighting from Instant Savings and Efficient Product Installation due to LED becoming the baseline, and a transition in BNI lighting market starting in mid-2026.

- 2 Table 7 provides portfolio-level savings and investment by year and in aggregate, inclusive of all proposed - 3 DSM resources for the 2027–2031 DSM Preferred Plan.

AI summary Table 7 outlines portfolio-level savings and investment figures by year and in aggregate for all proposed DSM resources under the 2027–2031 DSM Preferred Plan.

5 Table 7: 2027–2031 DSM Preferred Plan Portfolio Savings and Investment 2027-2031 Portfolio Year Investment ($M) Lifetime Benefits ($ million) First-Year Energy Savings (GWh) Peak Demand Savings (MW) Lifetime Energy Savings (GWh) Low-Inco...

AI summary Table 7 outlines the projected investment, savings, and benefits of the 2027–2031 DSM Preferred Plan Portfolio, including energy savings, peak demand reduction, and lifetime benefits. The table includes metrics such as investment in millions, energy savings in GWh, and weighted average measure life for various programs.

Table 8: 2027–2031 DSM Preferred Plan Savings and Investment by Program Component 2027-2031 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Availab...

AI summary Table 8 outlines the investment and benefits of various Demand Side Management (DSM) programs in Nova Scotia from 2027 to 2031, including energy savings, peak demand reductions, and program-specific metrics such as the Program Assessment Criteria (PAC).

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The document discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs using net present value of avoided costs. It also highlights low-income and equity impacts based on participation in specific programs. The text references Table 13 and includes some numerical data.

- 4 Table 9: 2027 DSM Preferred Plan Savings and Investment by Program Component 2027 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Dem...

AI summary Table 9 presents the 2027 DSM Preferred Plan Savings and Investment by Program Component, showing details such as investment, lifetime benefits, energy savings, and other metrics for various residential energy efficiency programs in Nova Scotia.

Columns may not add correctly due to rounding. Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and sol...

AI summary The document discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs using net present value of avoided costs. It also highlights the inclusion of low-income and equity impacts from both targeted and non-targeted programs.

1 Table 10: 2028 DSM Preferred Plan Savings and Investment by Program Component 2028 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Dema...

AI summary Table 10 presents the 2028 DSM Preferred Plan Savings and Investment by Program Component, detailing energy efficiency programs, including investments, benefits, and savings across residential and multifamily housing initiatives, with a focus on energy efficiency and demand response.

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The text discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs, using net present value of avoided costs. It also mentions low-income and equity impacts from dedicated and incidental programs, citing specific initiatives such as Existing Residential, New Residential, and BNI Efficient Product Rebates.

1 Table 11: 2029 DSM Preferred Plan Savings and Investment by Program Component 2029 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Dema...

AI summary Table 11 outlines the 2029 DSM Preferred Plan Savings and Investment by Program Component, including details on investment amounts, energy savings, and other metrics for various residential energy efficiency programs in Nova Scotia.

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The text discusses how lifetime benefits for energy efficiency, demand response, and solar-PV programs are calculated using net present value of avoided costs. It also highlights how low-income and equity impacts are assessed, considering both dedicated and incidental program participation.

1 Table 12: 2030 DSM Preferred Plan Savings and Investment by Program Component 2030 Investment ($ million) Lifetime Benefits First Year Energy Lifetime Energy Peak Demand Available Demand Response Solar-PV Generation Weighted Average Prog...

AI summary Table 12 outlines the 2030 DSM Preferred Plan Savings and Investment by Program Component, detailing energy efficiency (EE) programs, enabling strategies (ES), demand response (DR), and solar-PV programs. It includes investment amounts, savings, and other metrics for residential, business, and institutional programs, as well as equity and low-income impacts.

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The text discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs using net present value and utility WACC. It also highlights the inclusion of low-income and equity impacts from both targeted and non-targeted programs.

1 Table 13: 2031 DSM Preferred Plan Savings and Investment by Program Component 2031 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Dema...

AI summary Table 13 outlines the 2031 DSM Preferred Plan Savings and Investment by Program Component, detailing investments, benefits, energy savings, and other metrics for various residential energy efficiency programs in Nova Scotia.

1 4.5.1 LOW-INCOME AND EQUITY INVESTMENT AND SAVINGS - 2 E1's 2027–2031 DSM Preferred Plan includes dedicated program components that exclusively serve low- - 3 income and equity communities. These program components include Affordable Mul...

AI summary E1's 2027–2031 DSM Preferred Plan includes dedicated low-income and equity programs (e.g., Affordable Multifamily Housing, Mi'kmaw projects) accounting for 11% of residential savings. The Solar-PV program is also targeted at these communities. Incidental impacts from non-targeted programs like Efficient Product Installation are also noted, with details in Attachment 1 and Table 14.

4.6 2027–2031 DSM PREFERRED PLAN INVESTMENT OVERVIEW E1's total investment for the 2027–2031 DSM Preferred Plan is $318.75 million.

AI summary E1's total investment for the 2027–2031 DSM Preferred Plan is projected to be $318.75 million.

sidential program components also continue to see reduced energy savings, resulting from two billing analyses conducted during the 2024 1 3 4 5 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 - 1 DSM evaluation. The Home Energy Assessment billin...

AI summary Residential energy programs in Nova Scotia face reduced savings due to updated billing analyses (Home Energy Assessment and Green Heat), impacting heat pump efficiency. E1 shifts investments to BNI Demand Response and maintains residential demand response levels. Solar-PV supports Mi'kmaw communities through energy efficiency initiatives.

1 4.6.2 UNIT COST - 2 Unit cost is a calculated output of E1's investment and savings over a defined time period. Factors that - 3 influence unit cost results typically include: - the level of participation in a program or program componen...

AI summary Unit cost for E1's energy efficiency programs is calculated based on factors like participation levels, measure mix, and cost changes. The projected 2027–2031 unit cost is $0.66/kWh, higher than the 2026 DSM Extension's $0.49/kWh.

1 4.7 RATE CLASS ALLOCATIONS 2 E1 has committed to improve the accuracy of the estimates used for the rate class allocation of 3 expenditures in the DSM Plan. For the 2027–2031 DSM Preferred Plan, E1 largely followed its approach 4 taken f...

AI summary E1 has committed to improving the accuracy of rate class allocation estimates for expenditures in the DSM Plan. For the 2027–2031 DSM Preferred Plan, E1 used historical data from 2022 to 2024, reviewed customer commitments, and incorporated assumptions for program changes affecting specific rate classes.

15 Table 15: 2027–2031 DSM Preferred Plan Rate Class Savings and Expenditures 2027–2031 Rate Class Year First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Demand Response Capacity (MW) Generati...

AI summary Table 15 outlines projected energy savings, demand reductions, and expenditures for the 2027–2031 DSM Preferred Plan, categorized by rate class. It includes metrics like energy savings (GWh), peak demand savings (MW), and expenditures (in millions of dollars) for residential, small general, and general rate classes over the five-year period.

12 5.1 2027–2031 DSM PROGRAM MARKETING Marketing plans and strategies are essential to DSM Plan implementation. Effective marketing drives customer participation in programs and supportsthe communication and implementation aspects of DSM P...

AI summary Marketing is crucial for DSM Plan implementation, enhancing customer participation and brand recognition for E1 and Efficiency Nova Scotia. E1's marketing objectives for the 2027–2031 DSM Preferred Plan aim to support program delivery and educate Nova Scotians.

21 Awareness, Education and Participation - 22 Driving education of and participation in E1's energy efficiency, demand response, and solar-PV 23 programs. - 24 Increasing awareness of the E1 and Efficiency Nova Scotia brands as a trusted...

AI summary The text outlines strategies to enhance awareness and participation in E1's energy efficiency, demand response, and solar-PV programs. It emphasizes comprehensive marketing tactics, brand trust-building, and targeted outreach across customer sectors. The Efficiency Preferred Partner program's membership growth and education are also highlighted.

6. ENERGY EFFICIENCY DSM energy efficiency refers to delivering the same or improved level of service using less energy, resulting in measurable reductions in energy consumption while maintaining or improving performance. Natural Resources...

AI summary Energy efficiency programs, led by E1, focus on reducing energy consumption through initiatives like residential LED baselines and Mi'kmaw New Home Construction. The 2027–2031 DSM Plan includes enhanced incentives, expanded rebate categories, and program updates to address rising costs and evolving market needs.

1 Table 16: Residential Efficient Product Rebates - Overview, Objectives, Opportunity Residential Efficient Product Rebates Overview • Provides customers access to financial incentives for various products through retailers and heating sys...

AI summary Table 16 outlines the Residential Efficient Product Rebates program, which provides financial incentives for energy-efficient products through retailers and installers. The program aims to increase accessibility, awareness, and adoption of energy-efficient technologies. Barriers include affordability, lack of awareness, and limited retailer participation. The program became part of E1's portfolio in 2010 and included Appliance Retirement until 2025.

1 Table 17: 2027–2031 Instant Savings Program Component Instant Savings Program Component History • LEDs in 2011 • • 2009–2012 – first pilot launched (Efficient Lighting Products) followed by Power Down (2010), Plug into Savings (2011) and...

AI summary The text outlines the history of the Instant Savings Program in Nova Scotia, starting with pilot initiatives in 2009–2012 focused on lighting products like compact fluorescent lamps (CFLs), and evolving into a full-scale program by 2012. From 2014–2018, the program expanded to offer year-round rebates on a variety of energy-efficient products.

5 Table 18: 2027–2031 Residential Efficient Product Rebates Performance Indicators Year Investment ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Participation (products) Lifetime Unit Co...

AI summary Table 18 outlines projected performance indicators for residential efficient product rebates from 2027 to 2031, including investment, energy savings, peak demand savings, participation numbers, and costs. The Program Assessment Criteria (PAC) is defined as a benefit/cost ratio comparing lifetime benefits to DSM investment.

8 6.2.1 OVERVIEW, OBJECTIVES, OPPORTUNITY 9 [Table 19](#page-136-1) provides a description of the Existing Residential program for 2027–2031. 10

AI summary The document references Table 19, which outlines the Existing Residential program for 2027–2031. The section provides an overview of objectives and opportunities related to demand-side management initiatives in Nova Scotia.

1 Table 20: 2027–2031 Affordable Multifamily Housing Affordable Multifamily Housing Program Component History • barriers • • • • customer enrollment • 2016 – pilot launched using similar framework as Small Business Energy Solutions and tar...

AI summary The Affordable Multifamily Housing program component, part of the Demand Side Management (DSM) initiative, has evolved since 2016 through various pilot phases, with adjustments in incentives, participation strategies, and expansion to include non-profit organizations and smaller buildings.

2 Table 22: 2027–2031 Efficient Product Installation Program Component Investment Energy Savings Demand Savings Participation ($M) (GWh) (MW) (products) • 2011 – pilot launched providing a no-cost service under several other program compon...

AI summary The Efficient Product Installation Program has evolved since 2011, initially as a pilot, then expanding province-wide and incorporating new measures like LED lighting and draft proofing. In 2024, electrician-installed energy-saving measures were introduced, and in 2025, lighting measures were discontinued based on program evaluation.

1 Table 24: 2027–2031 Mi'kmaw Home Energy Efficiency Project Program Component Mi'kmaw Home Energy Efficiency Project Quality Assurance The framework measures both compliance (e.g., operational standards, safety) and performance (e.g., cus...

AI summary The Mi'kmaw Home Energy Efficiency Project includes quality assurance measures that monitor the compliance and performance of E1's contracted service partners through project audits, monthly performance monitoring, and customer satisfaction surveys.

Table 26: 2027–2031 Existing Residential Performance Indicators Year Investment ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Participation (homes) Participation (products) Participation...

AI summary Table 26 outlines the projected residential performance indicators for the years 2027–2031, including investment amounts, energy savings, peak demand reductions, and participation metrics. The table also includes the Program Administrator Cost (PAC) test, which is a benefit/cost ratio comparing lifetime benefits to DSM investment.

10 6.3 NEW RESIDENTIAL 4 9 13

AI summary Section 6.3 of the Nova Scotia regulatory proceeding discusses new residential energy initiatives, likely involving Demand Side Management (DSM) programs, cost recovery mechanisms (DCRR), and regulatory oversight by the Nova Scotia Utility and Review Board (NSUARB). Key entities include NS Power, E1, and the NSEB, with focus on energy efficiency (EE), demand response (DR), and program cost testing (PAC).

1 Table 29: 2027–2031 Summary of the Mi'kmaw New Home Construction Program Component Mi'kmaw New Home Construction Annual Plan Investment Energy Savings Demand Savings Participation ($M) (GWh) (MW) (homes) 2027 Total 0.2 0.0 0.0 0 2028 Tot...

AI summary Table 29 outlines the Mi'kmaw New Home Construction Program's projected investments and energy savings from 2027 to 2031. The program is expected to invest $5.0 million over the five-year period, resulting in 1.1 GWh of energy savings and 0.4 MW of demand savings, with 200 homes participating.

7 Table 30: 2027–2031 New Residential Performance Indicators Year Investment ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Participation (homes) Lifetime Unit Cost ($/kWh) Program Admini...

AI summary Table 30 outlines residential energy efficiency investments and savings from 2027–2031, showing $5 million in total investment, 32.8 GWh in lifetime energy savings, and consistent Program Administrator Cost Test (PAC) values of 0.8 from 2028–2031.

15 6.4 BNI EFFICIENT PRODUCT REBATES PROGRAM

AI summary The BNI Efficient Product Rebates Program is part of a Nova Scotia regulatory proceeding, focusing on demand-side management and energy efficiency initiatives. It operates under frameworks like the Public Utilities Act and Energy and Regulatory Boards Act, aiming to promote energy-efficient products for business, non-profit, and institutional sectors.

16 6.4.1 OVERVIEW, OBJECTIVES, OPPORTUNITY 17 [Table 31](#page-149-2) provides a description of the BNI Efficient Product Rebates program for 2027–2031. 8 PAC is a benefit/cost ratio comparing lifetime benefits to DSM investment.

AI summary The text describes the BNI Efficient Product Rebates program for 2027–2031 and defines PAC as a benefit/cost ratio comparing lifetime benefits to DSM investment. The program aims to promote energy efficiency through rebates, while PAC evaluates the economic viability of DSM initiatives.

1 Table 31: BNI Efficient Product Rebates - Overview, Objectives, Opportunity BNI Efficient Product Rebates Overview • BNI customers can access prescriptive rebates or financing on eligible equipment with predictable savings and applicabil...

AI summary The BNI Efficient Product Rebates program provides prescriptive rebates and financing for energy-efficient equipment to businesses, non-profits, and institutions. The program aims to increase market penetration of efficient technologies and transform standard practices by addressing barriers such as upfront costs, lack of knowledge, and time constraints.

DATE FILED: March 31, 2026 Page 63 of 112 Business Energy Rebates Overview • The Business Energy Rebates program component offers two services – Instant Rebates and Application Rebates. • 2010 – program component launched • 2019 – program...

AI summary The Business Energy Rebates program offers Instant and Application Rebates to businesses. Launched in 2010, it saw increased adoption of LED products by 2019, leading to the removal of several lighting categories. In 2020, new measures such as system peak demand and electric thermal storage were introduced, along with pilots for demand control ventilation.

12 6.5 CUSTOM INCENTIVES PROGRAM

AI summary Section 6.5 of the Nova Scotia regulatory proceeding discusses the Custom Incentives Program, focusing on demand-side management (DSM) and energy efficiency (EE) initiatives. The program involves entities like NS Power, NSEB, and DSMAG, with considerations for cost recovery, rate design, and regulatory compliance under the ERBA and PUA frameworks.

16 Table 35: Custom Incentives - Overview, Objectives, Opportunity Custom Incentives Overview • Provides financial incentives and technical assistance to help non-profit, institutional, commercial, and industrial customers reduce their ele...

AI summary Table 35 outlines the Custom Incentives program, which offers financial incentives and technical assistance to non-profit, institutional, commercial, and industrial customers to reduce electrical energy consumption and system-peak demand. The program is tailored to specific projects and supports initiatives not covered by other E1 programs.

Custom Incentives - 2015 program renamed to Custom Incentives, comprised of five components: Custom Retrofit, New Construction, Existing Building Commissioning, Energy Management and Information Systems and Strategic Energy Management - 20...

AI summary The Custom Incentives program has undergone multiple structural changes since 2015, evolving from five components to two, with shifts in focus areas like retrofitting, energy management, and strategic initiatives. Key updates include the 2020 introduction of Industrial Energy Managers and the 2023 reconfiguration to two core components. Tables 36 and 37 provide historical component details.

2 6.5.2 PROGRAM DESIGN 1 5 - 3 [Table 36](#page-155-0) and [Table 37](#page-157-0) summarizes the five-year investment and savings for the Custom and Strategic - 4 Energy Management program components, including design and implementation s...

AI summary The text discusses the Program Design section, which includes summaries of five-year investment and savings for the Custom and Strategic Energy Management program components, along with details on design and implementation strategies.

6 Table 36: 2027–2031 Custom Program Component Custom Annual Plan Investment ($M) Energy Savings (GWh) Participation (projects) 2027 Total 17.1 73.2 10.7 191 2028 Total 13.3 50.7 7.1 132 2029 Total 11.1 35.0 4.6 91 2030 Total 10.6 32.1 4.1...

AI summary Table 36 outlines the projected investment, energy savings, and participation for the 2027–2031 Custom Program Component. The table shows decreasing investment and participation over the years, with energy savings also declining, indicating a phased reduction in program intensity.

2 Table 37: 2027–2031 Strategic Energy Management Program Component Strategic Energy Management Annual Plan Investment ($M) Energy Savings (GWh) Demand Savings (MW) Participation (participants) 2027 Total 1.1 4.2 0.5 7 2028 Total 1.1 4.2 0...

AI summary The Strategic Energy Management Program (2027–2031) provides industrial organizations with comprehensive energy management support, including technical and financial assistance. The program aims to achieve energy and demand savings through measures like financial incentives, expert evaluations, and performance-based rewards, with a focus on continued support and marketing strategies.

6 Table 38: 2027–2031 Custom Incentives Performance Indicators Year Investment ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Participation (participants) Participation (projects) Lifetim...

AI summary Table 38 outlines performance indicators for the BNI Custom Incentives Program from 2027 to 2031, including projected investments, energy savings, peak demand savings, participation numbers, and the Program Administrator Cost (PAC) test. The table provides a detailed overview of the program's expected outcomes and financial metrics over the five-year period.

7 6.6 DIRECT INSTALLATION PROGRAM

AI summary The Direct Installation Program under Nova Scotia's Demand Side Management (DSM) framework aims to enhance energy efficiency and reduce GHG emissions through targeted initiatives. Key stakeholders include NS Power, NSEB, and ERBA, with regulatory considerations involving cost recovery and program effectiveness.

1 Table 42: 2027–2031 Direct Installation Performance Indicators Year Investment ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Participation (projects) Lifetime Unit Cost ($/kWh) Program...

AI summary Table 42 outlines performance indicators for the Direct Installation Program from 2027 to 2031, showing investment, energy savings, peak demand savings, and participation numbers. Table 43 provides similar data for the Low-Income and Equity portion of the program. The PAC metric is defined as a benefit/cost ratio comparing lifetime benefits to DSM investment.

13 7. DEMAND RESPONSE Demand response is an important resource for supporting Nova Scotia's electricity system by reducing or shifting customer load during periods of peak demand. The Federal Energy Regulatory Commission defines demand res...

AI summary Nova Scotia's demand response (DR) programs, managed by E1, aim to reduce peak demand through load shifting. The 2023–2025 DSM Plan faced underachievement, but E1 anticipates growth in 2026. The 2027–2031 Preferred Plan focuses on achievable targets aligned with NS Power's IRP, with modest BNI DR growth and stable residential DR. Cost-effectiveness (PAC ≥ 1.0) and regulatory feedback influenced planning.

7.1 LOCATIONAL DEMAND RESPONSE The value of demand response is not uniform across the electricity system. Deploying resources in areas where the distribution or transmission network is constrained can help defer or avoid capital infrastruc...

AI summary The document discusses the importance of locational demand response in Nova Scotia, emphasizing collaboration with NS Power to align DR deployment with constrained grid areas. E1 highlights the need for granular AMI data, including feeder IDs, to target programs effectively. It also notes E1's role in the DER Integration Roadmap, expected in 2026, to align DR with system planning.

8 7.2 CRITICAL PEAK PRICING OVERLAP 9 As part of ongoing collaboration on demand response, E1 and NS Power met in late 2024 to identify opportunities to strengthen coordination across demand response initiatives, including rate-based appro...

AI summary E1 and NS Power collaborated to address overlap between E1's demand response programs and NS Power's Time-Varying Pricing (TVP) rates, which target similar customers and peak periods. A 2025 cybersecurity incident paused the TVP pilot, returning participants to standard rates. Future DSM plans (2027–2031) expect minimal overlap, with ongoing efforts to coordinate locational demand response and avoid double-counting savings.

11 7.3 DEMAND RESPONSE PROGRAM

AI summary This section outlines the Demand Response Program within the Nova Scotia regulatory proceeding, involving entities such as NS Power and NSEB, with references to various acronyms and programs related to energy management and regulatory frameworks.

12 7.3.1 OVERVIEW, OBJECTIVES, OPPORTUNIT[Y](#page-166-2) 13 [Table 44](#page-166-2) provides a description of the Demand Response program for 2027–2031. 14

AI summary The document references Table 44, which outlines the Demand Response program's description for the period 2027–2031, focusing on its objectives and structure within the Nova Scotia regulatory framework.

15 Table 44: Demand Response - Overview, Objectives, Opportunity Demand Response • The program provides financial incentives to customers who reduce their load during peak times when there is value to the utility to shift load. Overview •...

AI summary The Demand Response program offers financial incentives to residential and BNI customers who reduce their load during peak times. It aims to diversify program offerings, increase customer awareness, and explore eligibility for interruptible customers in future plans. Barriers include lack of awareness, resources, and inconvenience for participants.

6 Table 45: 2027–2031 Residential Demand Response Program Component Residential Demand Response Annual Plan Investment ($M) Available Demand Response Capacity (MW) Participation (participants) 2027 Total 2.2 4.2 22,940 2028 Total 2.0 4.1 2...

AI summary The table outlines the 2027–2031 Residential Demand Response Program, including annual investments, available capacity, and participation numbers. The program focuses on existing participants, using smart thermostats and water heaters, and is delivered through a DERMS provider. Marketing efforts target existing customers, and quality assurance includes customer feedback and post-season surveys.

5 Table 46: 2027–2031 BNI Demand Response Program Component BNI Demand Response Annual Plan Investment ($M) Available Demand Response Capacity (MW) Participation (participants) 2027 Total 3.1 17.0 169 2028 Total 3.5 19.1 173 2029 Total 3.8...

AI summary Table 46 outlines the BNI Demand Response Program's investment, capacity, and participation from 2027 to 2031. The program encourages businesses to reduce load during peak events through financial incentives and involves third-party aggregators for implementation. Enhancements include continued support, marketing strategies, and quality assurance measures.

3 [Table 47](#page-169-0) provides the program performance indicators. 5 Table 47: 2027–2031 Demand Response Performance Indicators Year Investment ($ million) Available Capacity (MW) Participation (devices) Participation (participants) Le...

AI summary Table 47 outlines the 2027–2031 Demand Response (DR) performance indicators, including investment, available capacity, participation numbers, and the Program Administrator Cost (PAC) test. The table shows a steady increase in investment and available capacity over the years, with participation numbers remaining relatively stable. The PAC test is defined as a benefit/cost ratio comparing lifetime benefits to DR investment, with levelized costs calculated over a ten-year period.

1 7.3.4 PROGRAM ALTERNATIVES - 2 The Demand Response program features one difference in the Alternate Scenario when compared to the - 3 Preferred Plan, that being that the Residential Demand Response program component is not included in -...

AI summary The Alternate Scenario excludes the Residential Demand Response program component compared to the Preferred Plan, with Table 48 comparing performance indicators from 2027–2031.

18 Scenario Year Investment ($ million) Available Capacity (MW) Participation (devices) Participation (participants) Levelized Cost ($/kW-year) Program Administrator Cost Test (PAC) 2027 5.3 21.1 22,940 169 - 2.0 2028 5.5 23.2 22,483 173 -...

AI summary The table presents investment and participation data for a demand-side management (DSM) program across multiple years, including preferred and alternate scenarios, and calculates the Program Administrator Cost (PAC) as a benefit/cost ratio. The data includes investment amounts, available capacity, participation numbers, and levelized costs for both preferred and alternate scenarios.

13 8. SOLAR-PV - 14 E1 is proposing the introduction of a new Solar-PV program in the 2027–2031 DSM Preferred Plan. 15 Solar‑PV refers to technology that converts sunlight directly into electricity. Solar‑PV can produce 16 electricity that...

AI summary E1 proposes a Solar-PV program in the 2027–2031 DSM Plan, targeting Mi'kmaw communities to reduce energy burdens through equity-focused, small-scale residential initiatives. The program leverages existing frameworks, aims for phased implementation, and includes a $2.8M investment over five years, reflecting affordability and equity priorities.

1 Table 49: Overview, Objectives, Opportunity Solar-PV Overview • Post-installation incentives are provided for solar-PV systems installed on new homes in Mi'kmaw communities. • The program consists of one component: Residential Solar-PV....

AI summary This table outlines the Solar-PV program, which aims to increase the adoption of solar-PV systems in Mi'kmaw communities by reducing upfront costs and building awareness. The program targets residential new home construction projects, addressing barriers such as affordability, awareness, and uncertainty about solar-PV technology and payback periods.

1 Table 51: 2027–2031 Solar-PV Performance Indicators Year Investment ($ million) Solar-PV Generation (GWh) Solar-PV Lifetime Generation (GWh) Installed Capacity (MW) Participation (products) Lifetime Unit Cost ($/kWh) Program Administrato...

AI summary Table 51 outlines projected Solar-PV performance indicators from 2027 to 2031, including investment, generation, capacity, and participation metrics. The table shows a gradual decline in investment and generation over the years, with a corresponding decrease in installed capacity and participation. The Program Administrator Cost (PAC) is defined as a benefit/cost ratio comparing lifetime benefits to DSM investment.

8 9. ENABLING STRATEGIES

AI summary The section titled 'ENABLING STRATEGIES' introduces the context for regulatory proceedings in Nova Scotia, listing relevant acronyms and organizations involved in energy management and regulatory processes. No detailed content or arguments are present in the provided text.

9 9.1 OVERVIEW - 10 Enabling Strategies are initiatives that support the development, delivery, and growth of E1's DSM - 11 programs as well as the efforts required to plan for future DSM plans. 12 - 13 For the 2027–2031 period, E1 propose...

AI summary E1 proposes to invest 9% of its total DSM Portfolio in Enabling Strategies for the 2027–2031 period, allocating funds across four categories: Education and Outreach, Development and Research, Other Enabling Strategies, and Market Transformation. E1 has responded to feedback from DSMAG and introduced measures of success and structured plans for these initiatives.

14 9.2 HISTORY Enabling Strategies activities have been a component of E1's DSM Plans since the first Plan was developed in 2012 and they have played a pivotal role in supporting the development, delivery, and growth of E1 programs includi...

AI summary Enabling Strategies (ES) have been integral to E1's Demand Side Management (DSM) Plans since 2012, evolving from education/outreach to innovation and R&D. The 2023–2026 plan focuses on addressing challenges like market maturity and emerging technologies in Nova Scotia's energy landscape.

1 9.3 OBJECTIVES - 2 In 2027–2031, Enabling Strategies will continue to build on those initiatives that have historically proven - 3 successful by delivering focused education and outreach, and development and research activities; - 4 mark...

AI summary Enabling Strategies (ES) aims to expand DSM program participation through education and outreach, ensure E1 adapts to market changes via research, continue the heat pump water heater pilot, and meet regulatory requirements including reporting and consultations. ES will also address evolving technologies and maintain compliance with NSIESO and DSMAG directives.

9.4 ENABLING STRATEGIES – CATEGORY DESCRIPTIONS The investment and activity descriptions for each Enabling Strategy category are detailed in this section.

AI summary This section outlines investment and activity descriptions for Enabling Strategy categories within a Nova Scotia regulatory proceeding, focusing on strategies to support energy management and resource planning.

1 Table 53: 2027–2031 Education and Outreach Activities Education and Outreach Areas of Focus Year Outreach ($) Education ($) Support for Mi'kmaw Communities ($) Total Investment ($) 2027 Total 0.4 0.3 0.5 1.2 2028 Total 0.4 0.3 0.5 1.2 20...

AI summary Table 53 outlines the 2027–2031 education and outreach activities, including funding for outreach, education, and support for Mi'kmaw communities. Key activities include home shows, partnerships, staff costs, and energy management services. Table 54 provides further details on key activities and expected outcomes.

1. Participate in home shows By participating in existing, reputable, and popular home shows in communities across the province, E1 is able to reach large numbers of Nova Scotians to increase public awareness about E1's DSM programs and to...

AI summary E1 promotes its Demand Side Management (DSM) programs through participation in popular home shows across Nova Scotia, aiming to increase public awareness and provide information on accessing these programs.

OUTREACH - E1 achieves its annual participation targets set out in the 2027–2031 DSM Plan. - E1 and its partner organizations achieve the goals set out in their respective partnership agreements.

AI summary E1 meets annual participation targets under the 2027–2031 DSM Plan, and E1 and its partners achieve goals outlined in their partnership agreements.

2. Provide energy management services to Mi'kmaw communities E1's Roving Energy Manager for Mi'kmaw communities will work with Nova Scotia's 13 Mi'kmaw communities to identify new DSM projects and coordinate building energy audits in an ef...

AI summary E1's Roving Energy Manager collaborates with Nova Scotia's 13 Mi'kmaw communities to identify Demand Side Management (DSM) projects and coordinate energy audits, aiming to enhance Mi'kmaw participation in E1's DSM programs.

Measures of success: - E1 achieves its annual participation targets for the Mi'kmaw New Home Construction program component set out in the 2027–2031 DSM Plan. - The Roving Energy Manager facilitates Mi'kmaw participation in E1's BNI progra...

AI summary The document outlines success measures for E1's programs under the 2027–2031 DSM Plan, including achieving annual participation targets for the Mi'kmaw New Home Construction program and ensuring Mi'kmaw community engagement through the Roving Energy Manager in BNI initiatives.

8 Table 55: 2027–2031 Development and Research Activities Development and Research Areas of Focus Total Investment Year Information & Analytics ($) Innovation ($) ($) DATE FILED: March 31, 2026 Page 92 of 112 Development and Research 2027...

AI summary The document outlines the development and research activities planned from 2027 to 2031, focusing on Information & Analytics and Innovation. These activities aim to ensure E1 remains responsive to market changes and will inform future DSM Plan offerings. The total investment over the five-year period is $7.1 million.

INFORMATION & ANALYTICS

AI summary The INFORMATION & ANALYTICS section outlines regulatory proceedings in Nova Scotia, involving energy efficiency, demand-side management, and utility rate structures. Key entities include NS Power, NSEB, and ERBA, with topics focusing on DSM, EE, and rate design.

1. Conduct research By consistently tracking quality assurance, participant satisfaction, and other attitudinal metrics among Nova Scotia households, E1 gains insights into how its programs are being received in the marketplace and can res...

AI summary E1 conducts research to track program effectiveness through quality assurance and participant satisfaction metrics, and plans to expand studies on DSM market opportunities and participant motivations in Nova Scotia.

1. Implement E1's annual Innovation Plans E1's Innovation team will plan, develop, and deliver research projects and pilot projects in key potential growth areas including strategic electrification, demand response, demand flexibility, loc...

AI summary E1's Innovation team will develop research and pilot projects in strategic electrification, demand response, and market transformation. Projects aim to improve cost-effectiveness, advance DSM readiness, and leverage insights. Annual Innovation Plans guide work, with early results informing future projects. See Attachment 5 for details.

2. Participate and contribute to national Codes and Standards organization E1's participation in the Canadian Standards Association's Steering Committee on Performance, Energy Efficiency and Renewables, which sets equipment performance sta...

AI summary E1 participates in the Canadian Standards Association's Steering Committee on Performance, Energy Efficiency, and Renewables to influence equipment standards, enhancing energy efficiency and demand response in Nova Scotia. This involvement allows E1 to inform stakeholders about upcoming changes.

6 Table 57: 2027–2031 Other Enabling Strategies Other Enabling Strategies 5 Areas of Focus Year DSM Plannin ($) g Regular DSM Matters ($) Other Regulatory Matters ($) Total Investment ($) 2027 Total 0.0 1.4 0.2 1.5 2028 Total 0.0 1.4 0.1 1...

AI summary Table 57 outlines the 2027–2031 Other Enabling Strategies, including funding for DSM planning and other regulatory matters. It details investment amounts for each year and highlights activities such as stakeholder engagement, consulting, and planning for the next DSM Plan (2032–2036).

1 Table 58: 2027–2031 DSM Planning

AI summary Table 58 outlines Demand Side Management (DSM) planning for the years 2027–2031 as part of a Nova Scotia regulatory proceeding, focusing on energy efficiency, demand response, and integrated resource planning strategies.

DSM PLANNING

AI summary The document outlines the context for Demand Side Management (DSM) planning in Nova Scotia, referencing key regulatory bodies, programs, and acronyms relevant to energy efficiency, utility regulation, and DSM cost recovery mechanisms.

1. Develop and file the 2032 – 2036 DSM Plan E1 staff will develop the 2032-2036 DSM Plan through research, consultations with experts, internal planning, and working and consulting with all stakeholders to gain support for the Plan. After...

AI summary E1 staff will develop the 2032–2036 DSM Plan through research, consultations with experts, internal planning, and stakeholder engagement to secure support. After filing the plan, E1 will participate in the regulatory approval process.

2. Energy Board and stakeholder consultant costs In addition to E1's directly incurred costs, flow-through costs related to the Energy Board and its consultants, the Consumer Advocate and its consultants, and the Small Business Advocate an...

AI summary The text states that flow-through costs for the Energy Board, Consumer Advocate, Small Business Advocate, and their consultants, along with E1's direct costs, are categorized under 'Other Enabling Strategies' investment. This highlights the inclusion of stakeholder-related expenses in broader energy strategy funding.

REGULAR DSM MATTERS

AI summary The document heading indicates a section focused on regular Demand Side Management (DSM) matters under Nova Scotia regulatory proceedings. No further details or content are provided in the text.

1. File all required reports, statements, and responses E1 will file all required reporting on the 2027–2031 DSM Plan including quarterly reports, Annual Progress Reports, Evaluation Reports, Audited Financial Statements, Information Reque...

AI summary E1 will file required reports and respond to directives related to the 2027–2031 DSM Plan, including quarterly and annual reports, evaluations, and financial statements, as mandated by the Nova Scotia Energy Board.

2. Engage with stakeholders throughout Plan period E1 will consult with stakeholders through regular and technical DSM Advisory Group sessions, preparing materials and briefings for distribution to the group, and responding to and incorpor...

AI summary E1 will engage stakeholders through regular DSM Advisory Group sessions, preparing materials and briefings, and incorporating feedback. This ensures ongoing stakeholder involvement in the Plan period.

3. Energy Board and stakeholder consultant costs In addition to E1's directly incurred costs, flow-through costs related to the Energy Board and its consultants, the Consumer Advocate and its consultants, and the Small Business Advocate an...

AI summary Flow-through costs from the Energy Board, Consumer Advocate, Small Business Advocate, and their consultants, along with E1's costs, are categorized under 'Other Enabling Strategies' investment. These costs are included in the broader investment framework for regulatory proceedings.

1. Update E1's 2026 potential study Together with its consultants, E1 will complete an update of its 2026 potential study during the 2027–2031 Plan period, both to inform its 2032-2036 DSM Plan and to contribute to an expected Integrated R...

AI summary E1 will update its 2026 potential study during the 2027–2031 Plan period to inform its 2032-2036 DSM Plan and contribute to the Nova Scotia Independent Energy System Operator's Integrated Resource Plan Evergreen process.

- 5 Table 59: 2027–2031 Market Transformation Activities Market Transformation Areas of Focus Total Investment Year Heat pump water heater pilot ($) ($) 2027 Total 0.8 0.8 2028 Total 0.8 0.8 2029 Total 0.7 0.7 2030 Total 0.7 0.7 2031 Total...

AI summary Table 59 outlines the Market Transformation activities from 2027 to 2031, focusing on heat pump water heater pilots with a total investment of $3.8 million. These activities aim to overcome barriers to adoption of energy-efficient products and promote long-term energy efficiency growth in Nova Scotia.

HEAT PUMP WATER HEATER PILOT

AI summary A pilot program for heat pump water heaters under the Public Utilities Act, managed by the Nova Scotia Energy Board (NSEB), involving Nova Scotia Power (NS Power) and EfficiencyOne (E1) to evaluate energy efficiency measures and demand-side management (DSM) initiatives.

1. Continue implementation of Heat Pump Water Heater pilot The delivery of the Heat Pump Water Heater pilot continues, following the design and launch activities being completed during the 2023–2026 DSM Plan period.

AI summary The Heat Pump Water Heater pilot continues after completing design and launch activities during the 2023–2026 DSM Plan period, aligning with Nova Scotia's energy efficiency initiatives.

3. Plan for future market transformation measures Using insights gained from the heat pump water heater pilot, the Market Transformation team will collaborate with E1's Innovation team on research into measures that could be delivered usin...

AI summary The Market Transformation team will collaborate with E1's Innovation team to research future DSM measures using insights from a heat pump water heater pilot, aiming to inform future DSM Plans through market transformation strategies.

1 10.2 PERFORMANCE TARGETS AND THRESHOLDS - Performance targets[21](#page-186-3) 2 apply over the Plan period as reflected in the Energy Board-approved DSM 3 Purchase Agreement or as ordered by the Energy Board; and - 4 E1 is in substantia...

AI summary The Nova Scotia Energy Board sets performance targets for E1's DSM Purchase Agreement, requiring 90% compliance. E1's 2027–2031 DSM Preferred Plan includes five targets, with a table summarizing them. Non-compliance may trigger discretionary actions by the Energy Board.

12 Table 61: Proposed 2027–2031 DSM Preferred Plan Performance Targets 2027–2031 Performance Targets DSM Resource Energy Savings (GWh) Peak Demand Savings (MW) Low-Income & Equity Energy Savings (GWh) Available Demand Response Capacity (MW...

AI summary Table 61 outlines proposed 2027–2031 DSM performance targets, including 435.4 GWh energy savings from Energy Efficiency, 85.0 MW peak demand savings, 14.0 GWh low-income equity savings, 29.3 MW demand response capacity, and 1.7 GWh solar-PV generation. Targets aim to balance energy efficiency, demand response, and renewable integration.

16 Table 62: 2027–2031 DSM Preferred Plan Performance Indicators DSM Resource Performance Indicators Annual incremental energy savings (reported by program and rate class) (GWh) Cumulative energy savings (reported by program and rate class...

AI summary Table 62 outlines performance indicators for the 2027–2031 DSM Preferred Plan, including annual and cumulative energy and peak demand savings by program and rate class, with a focus on low-income and equity programs such as Affordable Multifamily Housing and the Mi'kmaw Home Energy Efficiency Project.

13 DSM Resource Performance Indicators Incidental annual and cumulative energy savings (GWh) from E1's non-targeted programs applicable to low-income and equity customers (reporting also includes incidental low-income and equity participat...

AI summary The section provides an overview of performance indicators for various DSM resources, including energy savings, demand response capacity, solar-PV installations, ratepayer benefits, program spending, customer satisfaction, and program administrator cost test results.

11.1 EVALUATION FRAMEWORK - E1's independent evaluation consultant is engaged to develop an Evaluation Framework that defines the - policies, priorities, and methodologies used to conduct the DSM evaluation. It provides a common - understa...

AI summary E1's independent evaluation consultant is tasked with creating an Evaluation Framework for DSM programs. The framework outlines evaluation definitions, goals, metrics, deliverables, and roles, establishing principles and prioritization criteria for annual evaluation plans. It aims to standardize best practices in DSM evaluation.

11.1.1 IMPACT EVALUATIONS - Annual impact evaluations will provide E1, stakeholders, and the Energy Board with up-to-date impacts - on net electrical energy, net system-peak demand savings and available capacity as progress indicators - to...

AI summary The document outlines annual impact evaluations for DSM programs, distinguishing between condensed and comprehensive evaluations. Condensed evaluations use prior data for stable programs, while comprehensive ones are required for newer or changed programs. E1 and the Energy Board will use these evaluations to track progress toward 2027–2031 DSM performance targets.

1 11.2 PROCESS AND MARKET EVALUATIONS - 2 Program component process and market evaluations will remain consistent with the 2023–2026 DSM - 3 Resource Plan. Process evaluations identify and recommend improvements to increase the program - 4...

AI summary The text outlines process and market evaluations for DSM programs under the 2023–2026 Resource Plan. Process evaluations aim to improve efficiency and effectiveness, while market evaluations analyze technology adoption. E1 will determine evaluation criteria based on factors like new programs, major changes, and energy savings variances.

12.1.1 ENERGY EFFICIENCY EVALUATION APPROACH E1 will engage a third-party Evaluator to develop and perform an evaluation of E1's portfolio of energy- efficiency, demand response and solar-PV programs for the 2027–2031 DSM Plan period. Each...

AI summary E1 will engage a third-party Evaluator to assess its energy-efficiency, demand response, and solar-PV programs from 2027–2031. The Evaluator will develop annual evaluation plans, conduct impact assessments, and report metrics like net energy savings and system peak demand reductions to the Nova Scotia Energy Board, ensuring transparency and alignment with evaluation principles.

12.1.2 DEMAND RESPONSE EVALUATION APPROACH Demand response program evaluation is aimed at verifying and quantifying the available capacity to the utility during the winter peak period. The Evaluator will present total available capacity, d...

AI summary Demand response evaluation focuses on quantifying available capacity during winter peaks. Available capacity differs from peak demand savings as E1 cannot control event scheduling. Evaluation considers events from December to February, with 50/50 weighting of morning and evening results. Capacity is measured over four-hour events and summed per participant, with 2027 capacity reflecting December 2026 to February 2027 data.

13.1 OVERVIEW OF DSM REPORTING 2027–2031 - E1 will file the following six reports each year with the Energy Board, for a total of thirty DSM reports over - the 2027-2031 Plan period: - Quarterly Reports (Q1-Q3); - Annual Progress Reports (...

AI summary E1 (EfficiencyOne) is required to submit 30 DSM reports over 2027–2031, including quarterly, annual progress, program evaluation, and financial statements. The Nova Scotia Energy Board's independent consultant verifies the accuracy of E1's annual program evaluation reports and savings data.

1 13.2 OVERSIGHT AND DSMAG REVIEW - 2 Each report filed with the NSEB provides opportunities for DSMAG stakeholder questions and comments, - 3 either directly to E1 or through an Energy Board-initiated regulatory process. Additionally, the...

AI summary The NSEB oversees E1's DSM Plan implementation, allowing DSMAG stakeholder input through reports and regulatory processes. Post-2022 PUA amendments extending DSM Plans to five years, DSMAG raised concerns about performance risks. E1 responded by proposing mid-term check-ins to ensure transparency and ongoing engagement during the extended plan period.

13.3 MID-COURSE ADJUSTMENTS Mid-course adjustments (MCAs) provide the DSM administrator limited flexibility to adjust annual program-level budgets and savings from those set out in the original approved DSM Plan, in order to respond to mar...

AI summary Mid-course adjustments (MCAs) allow DSM administrators to adjust annual budgets and savings without altering overall targets. The NSEB directed E1 to enhance MCA processes following Industrial Group concerns about rate-class spending variances. E1 proposes using historical data, improving reporting, and lowering thresholds for adjustments. MCAs will be integrated into the Standardized Filing Framework and discussed at DSMAG sessions.

13.4 ROUTINE REPORTING This section describes E1's DSM reporting over 2027-2031, including proposed content.

AI summary This section outlines E1's proposed Demand Side Management (DSM) reporting framework for 2027-2031, detailing content requirements and submission processes under Nova Scotia regulatory oversight.

13.4.1 QUARTERLY REPORTING - Quarterly reports provide regular updates on DSM implementation, performance, and expenditures - during each Plan year. These reports support ongoing monitoring and early identification of emerging - trends or...

AI summary E1 is required to submit quarterly reports to the NSEB detailing DSM implementation, performance metrics, and expenditures. Reports include YTD data, mid-course adjustments, rate class variances, and program highlights, with specific filing dates set by NSUARB. The reports aim to monitor progress toward five-year targets and ensure compliance with the approved DSM Resource Plan.

13.4.2 ANNUAL PROGRESS REPORTS - The APR provides reporting on DSM performance, expenditures, and progress toward approved Plan targets. In the first quarter of each calendar year, E1 will file an APR with the Energy Board, which will incl...

AI summary The Annual Progress Report (APR) requires E1 to submit detailed DSM performance data, expenditures, and progress toward Plan targets to the Nova Scotia Energy Board. Key components include variance analysis, expenditure summaries, program metrics, and mid-course adjustment notifications, with references to the MCA process in section 13.3.

13.4.3 ADVANCE NOTICE OF SIGNIFICANT CHANGES - In the event that E1 proposes significant changes to elements within an approved Plan, advance notice will be provided to the Energy Board and the DSMAG. Significant changes include: - Adding...

AI summary E1 must provide advance notice to the Energy Board and DSMAG for significant changes to approved plans, such as adding or terminating programs, and file applications with NSEB under PUA if circumstances like market shifts or regulatory changes affect plan feasibility.

1 13.4.5 RATE AND BILL IMPACT ANALYSIS - 2 E1 files its historical Rate and Bill Impact Analysis (RBIA) and forward-looking RBIA as part of each DSM - Resource Plan.[26](#page-199-1) 3 The historical RBIA estimates the high-level, long-ter...

AI summary E1 submits historical and forward-looking Rate and Bill Impact Analysis (RBIA) as part of its Demand Side Management (DSM) Resource Plan. The historical RBIA covers past DSM activities and approved investments, while the forward-looking RBIA estimates impacts of proposed DSM activities. Appendix B contains the RBIA for the 2027–2031 DSM Resource Plan.

14. CONCLUSION The 2027–2031 DSM Preferred Plan delivers cost-effective DSM resources in accordance with the requirements of the PUA , which directs that DSM be undertaken in the best interests of NS Power customers. With a portfolio level...

AI summary The 2027–2031 DSM Preferred Plan meets cost-effectiveness thresholds under the PUA, delivering $682.5M in ratepayer benefits with a 2.4 PAC result. It prioritizes affordability, avoids growth, and integrates solar-PV for Mi'kmaw communities while maintaining investment levels from the 2026 DSM Extension. The plan balances short-term affordability with long-term system benefits.

Table 1: Residential Efficient Product Rebates 2027-2031 Residential Efficient Product Rebates Rate Class Year First-Year Energy Savings Lifetime Energy Savings Peak Demand Savings Expenditures ($ million) (GWh) (GWh) (MW) 2027 11.0 106.3...

AI summary This table outlines projected energy savings and expenditures for the 2027-2031 Residential Efficient Product Rebates program across various rate classes. It includes first-year and lifetime energy savings, peak demand savings, and associated expenditures in millions of dollars.

Table 4: BNI Efficient Product Rebates 2027-2031 BNI Efficient Product Rebates 2027-2031 Direct Installation Rate Class Year First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Expenditures ($ million) 20...

AI summary This table outlines the 2027-2031 BNI Efficient Product Rebates, detailing energy and demand savings, as well as expenditures for various rate classes. The data reflects projections for each year and the total over the five-year period.

Table 7: Demand Response 2027-2031 Demand Response Rate Class Year Available Demand Response Capacity (MW) Expenditures ($ million) 2027 4.2 2.2 2028 4.1 2.0 2029 4.0 2.0 Residential/Charitable (2,3,4) 2030 3.9 2.0 2031 3.8 2.0 2027-2031 3...

AI summary Table 7 outlines projected demand response capacity and expenditures across various rate classes from 2027 to 2031, showing varying levels of capacity and associated costs for residential, commercial, and industrial sectors.

1.1 Innovation within DSM Enabling Strategies E1 allocates funding for research and development within the Enabling Strategies component of its DSM Resource Plans. Innovation is a core element of the Enabling Strategies portfolio, supporti...

AI summary E1 invests in research and development for Enabling Strategies within its DSM Resource Plans, focusing on innovation to enhance DSM programs. Activities include exploring emerging technologies, improving existing programs, conducting pilots, and fostering market adoption of energy-efficient solutions and demand response strategies.

1.1.1 Innovation Goals E1's Innovation team uses established Innovation Goals to define the long-term outcomes of all projects from concept, planning to close. Innovation Goals ensure that long-term outcomes align with the DSM mandate. Acr...

AI summary E1's Innovation team uses Innovation Goals to align long-term outcomes with the DSM mandate, focusing on improving cost-effectiveness, advancing new DSM measures and programs, leveraging system insights, and utilizing other funding sources.

2. GOVERNANCE

AI summary The 'Governance' section outlines regulatory frameworks and acronyms related to Nova Scotia's energy sector, including organizations, programs, and legal acts. It emphasizes governance structures for utility regulation, demand-side management, and energy efficiency initiatives, though no detailed arguments or specific case references are provided in the text.

2.2 Annual Innovation Plan - Each year, E1 establishes an Innovation Plan that summarizes all ongoing and newly committed projects. It includes project descriptions, scope, timelines, and estimated resource requirements, - serving as the b...

AI summary E1's Annual Innovation Plan outlines ongoing and new projects, including descriptions, timelines, and resource needs. It guides internal commitments between leadership and staff, serving as a roadmap for current and planned initiatives. Progress and insights are reported in E1's DSM Quarterly and Annual Progress Reports.

3. PROJECT DEVELOPMENT

AI summary The document outlines the 'PROJECT DEVELOPMENT' section of a Nova Scotia regulatory proceeding, listing key acronyms and entities involved in energy regulation, including organizations like NS Power, NSEB, and programs such as DSM and EE. It provides context for technical terms and regulatory frameworks relevant to the proceeding.

3.1 Project Classification There are two types of innovation projects: - Research projects focus solely on the research phase. They typically require smaller resources and are completed within one year. Research projects generate insights...

AI summary The text classifies innovation projects into research and pilot projects. Research projects are short-term, resource-light, and focus on feasibility, while pilot projects are longer-term, resource-intensive, and test solutions for potential program adoption under DSM.

3.3 Project Ideation - Ideation for new projects can come from various sources but is fundamentally focused on developing solutions that address challenges and explore new opportunities. Examples of sources for insights and findings includ...

AI summary Project ideation sources include Integrated Resource Planning, DSM studies, E1's programs, market research, and emerging technologies, aiming to address challenges and opportunities. Key inputs are program evaluations, jurisdictional scans, and data analytics.

3.4 Project Selection and Overview of Investment by Focus Area - Project ideas are screened using Focus Areas as a primary screen and Innovation Goals to - establish direction for Innovation projects and establish evaluation metrics how su...

AI summary Project ideas are evaluated using Focus Areas and Innovation Goals, which remain static during the 2027-2031 DSM plan period. This framework establishes direction and evaluation metrics for innovation projects.

3.4.1 Focus Areas - The primary screening criteria for project selection are Focus Areas. For the 2027-2031 DSM - plan, there are five areas which are of emerging importance to the electricity system, or are of - economic benefit to rate-p...

AI summary The 2027-2031 DSM plan uses Focus Areas as primary project selection criteria, emphasizing five areas critical to the electricity system or offering long-term economic benefits to rate-payers. A table details projected expenditures by Focus Area.

1 Table 1: Projected Direct Expenditures by Focus Area DSM Direct Expenditure ($) Focus Area 2027 2028 2029 2030 2031 Total ($) Demand Response 160,650 178,815 123,175 110,250 111,500 684,390 Demand Flexibility 183,600 204,360 221,715 198,...

AI summary The table outlines projected direct expenditures across various focus areas, including Demand Response, Strategic Electrification, and Market Transformation, from 2027 to 2031. It highlights the financial commitments planned for these initiatives, with total expenditures reaching $2,349,600 over the five-year period.

5 The Innovation Goals, justification and key activities for each of the Focus Areas are shown below in [Table 2.](#page-220-3) Focus Area Innovation Goal(s) Justification Key Activities Demand Response 1. Improve cost‑effectiveness of E1'...

AI summary The document outlines an innovation goal to improve the cost-effectiveness of E1's residential demand response (DR) program, citing that similar jurisdictions have achieved positive results through optimizing asset dispatch and revising OEM portfolios to reduce administrative costs and improve performance.

5 Table 3: Evaluation metrics by Innovation Goal Innovation Goal Evaluation Metric(s) 1. Improve cost‑effectiveness of existing measures and programs. Evaluation will be conducted relative to a defined baseline, with the primary reference...

AI summary The text outlines evaluation metrics for five innovation goals related to improving the cost-effectiveness of existing demand-side management (DSM) measures and programs, advancing readiness for new DSM measures and programs, leveraging system planning insights, and utilizing non-DSM funding sources for emerging DSM activities. References to Table 4 and Table 5 are made for evaluating market and program readiness.

1 The metrics used to evaluate the market and performance readiness of new measures are shown below in [Table 4.](#page-225-1) 3 Table 4: Evaluation metrics for readiness of new DSM measures MARKET READINESS Level 1: Pre-commercial Level 2...

AI summary The document outlines evaluation metrics for the market and performance readiness of new Demand Side Management (DSM) measures, categorizing them into five levels based on supply chain maturity, market demand, and savings reliability.

1 The metrics used to evaluate the readiness of new DSM programs and services are shown below in [Table 5.](#page-226-1) 3 Table 5: Evaluation metrics for readiness of new DSM programs and services DSM PROGRAM READINESS Level 1: None Level...

AI summary The document outlines evaluation metrics for the readiness of new Demand Side Management (DSM) programs and services, categorized into five levels based on cost-effectiveness knowledge, market and program knowledge, and risk assessment.

4. PILOT OVERVIEW

AI summary The section outlines a pilot program overview within a Nova Scotia regulatory proceeding, listing acronyms related to energy management, utility regulation, and program administration. Key terms include Demand Side Management (DSM), Public Utilities Act (PUA), and Nova Scotia Energy Board (NSEB), reflecting the regulatory and operational context of the proceeding.

4.2 Pilot Lifecycle The pilot lifecycle for developing new initiatives and launching them as programs is shown in Figure 2 below. Figure 2: Pilot lifecycle process flow The pilot lifecycle begins with evaluating ideas for feasibility, valu...

AI summary The pilot lifecycle outlines stages for developing initiatives into programs, including feasibility evaluation, concept refinement, planning with stakeholder input, execution with testing and iteration, and concluding with a recommendation package for full-scale launch. Metrics from Innovation Goals (1.1) are used throughout.

1 1. EXECUTIVE SUMMARY 2 EfficiencyOne (E1) delivers demand side management (DSM) programs that offer benefits to customers 3 and the electric utility. While DSM is a key resource option for delivering clean, affordable, reliable and 4 saf...

AI summary EfficiencyOne (E1) highlights that demand side management (DSM) programs reduce customer bills, offsetting potential rate increases. However, equity concerns arise as non-participating customers face higher rates. E1's Rate and Bill Impact Analysis (RBIA) assesses historical and future DSM impacts, informing Nova Scotia Energy Board (NSEB) decisions on DSM investments from 2011–2026 and future plans (2027–2031).

1 2. INTRODUCTION 2 The forward-looking RBIA is an analysis of the rate and bill impacts associated with the proposed DSM - 3 investment only. It compares the impacts of the proposed DSM investment to a scenario where there is - 4 no DSM i...

AI summary The document discusses the forward-looking and historical Rate and Bill Impact Analysis (RBIA) for Demand Side Management (DSM) investments in Nova Scotia. It highlights E1's proposal to eliminate historical RBIA filings except during DSM Plan Application years, and the NSUARB's acceptance of this approach. The analysis informs DSM investment levels and considers non-participant impacts.

4 3. 2027–2031 DSM PLAN RBIA RESULTS - 5 The results in this section are for the 2027–2031 DSM Preferred Plan. All impacts are calculated relative - 6 to a scenario where no DSM is conducted in 2027–2031. Results are summarized in Attachme...

AI summary The 2027–2031 DSM Preferred Plan RBIA results compare impacts to a no-DSM scenario, analyzing energy efficiency, demand response, and solar-PV separately and combined. Attachments 1 and 2 detail model outputs, rate impacts, and bill adjustments for each rate class, with selected graphs illustrating key findings.

3.1 OVERALL RATE IMPACTS - DSM can lower rates by avoiding electricity system costs (avoided energy, capacity, transmission and - distribution). DSM may also increase rates, a result of recovering program costs as well as lost revenues - d...

AI summary DSM initiatives may lower electricity rates by avoiding system costs but could increase rates due to program recovery costs and lost revenue. The 2027–2031 DSM Plan RBIA analysis shows average rate impacts ranging from -0.1% to +0.9% over 2027–2046, with higher short-term increases (+1.6% to +4.7%) during program cost recovery (2027–2031) and lower long-term impacts (-0.8% to -0.1%) post-recovery (2032–2046).

11 3.2 OVERALL BILL IMPACTS Generally speaking, ratepayers that participate in DSM programs directly benefit by reducing their electricity consumption and thereby lowering their electricity bills. Together, the level of reduced consumption...

AI summary DSM programs in Nova Scotia reduce electricity bills for participants by 0.04% to -37%, while non-participants see minimal increases (0.1% to +0.8%). Total customer bill impacts range from -0.04% to -3.4%, with $0.4 billion in savings for ratepayers due to reduced revenue requirements from 2027–2031 DSM initiatives.

4 [Table 1](#page-243-1) highlights results in more detail by individual rate class for the 2027–2031 forward looking RBIA. 6 Table 1: Rate and Bill Impacts by Rate Class as a Result of 2027-2031 DSM Preferred Plan Activities Preferred Pla...

AI summary Table 1 presents the rate and bill impacts by rate class resulting from the 2027–2031 DSM Preferred Plan activities. The data shows the average rate impact, average bill impact for participants and non-participants, and total class average bill impact across various rate classes.

3.4 COMPARISON OF 2027-2031 PREFERRED PLAN AND ALTERNATE

AI summary The section compares the preferred plan and alternate for 2027-2031, though no specific details are provided in the text. Key regulatory and energy-related terms are referenced, including demand-side management, energy efficiency, and utility regulations.

SCENARIO RBIA RESULTS Full results, by rate class, are provided in Attachments 2 and 3 for the 2027–2031 DSM Preferred Plan and Alternate Scenario, respectively. This section compares key outputs between the two. Rate impacts for both the...

AI summary The document compares rate and bill impacts between the DSM Preferred Plan and Alternate Scenario (2027–2031). Rate impacts are nearly identical, with minor increases (0.02% residential, 0.01% large industrial) from residential demand response in the Preferred Plan. Bill impacts differ by 0.04% lower residential bills in the Preferred Plan, with all other differences negligible.

2 Alternate Scenario)

AI summary The document references an alternate scenario within a regulatory proceeding, likely exploring demand-side management (DSM) strategies, cost recovery mechanisms, and energy efficiency programs. Key entities include NS Power, NSEB, and DSMAG, with topics focusing on regulatory frameworks and program evaluations.

5 4. 2026 HISTORICAL DSM RBIA RESULTS - 6 The results in this section are for DSM activities that have occurred from 2011–2024 and are approved for - 7 2025–2026. All impacts are calculated relative to a scenario where no DSM is conducted...

AI summary This section presents DSM RBIA results for activities from 2011–2024, approved for 2025–2026. Impacts are calculated against a no-DSM baseline scenario. Results are summarized in Attachment 4, separated by energy efficiency and demand response, with rate-class-specific summaries in Attachment 1. Graphs in the summaries reflect model outputs.

4.1 OVERALL RATE IMPACTS - The RBIA for the 2011–2026 historical DSM Activities demonstrates the following rate impacts associated with DSM activities: - average rate impacts (by rate class) over the study period (2011–2041) range from 0.5...

AI summary The RBIA analysis shows rate impacts from 2011–2026 DSM activities, with average impacts ranging from 0.5% to 3.2% (2011–2041), 1.4% to 5.5% (2011–2026), and -0.6% to +0.9% (2027–2041). Factors include DSM cost recovery and annual avoided costs. Electricity rates are projected to rise 72% for residential classes due to non-DSM factors.

11 4.2 OVERALL BILL IMPACTS - 12 The 2026 Historical RBIA demonstrates the following bill impacts associated with DSM activities: - 13 average participant bill impacts (by rate class) over the study period (2011–2041) range from 14 -12.7 t...

AI summary The 2026 Historical RBIA shows DSM activities from 2011–2026 led to average bill impacts ranging from -12.7% to -2.8% for participants, +0.5% to +2.9% for non-participants, and -8.2% to -2.8% for total customers. Net savings for Nova Scotia ratepayers are estimated at $3.2 billion due to reduced revenue requirements.

10 [Table 2,](#page-248-1) below, highlights results in more detail by individual rate class for the 2026 Historical RBIA. 12 Table 2: Rate and Bill Impacts by Rate Class over the study period (2011–2041) from 2011-2026 Historical DSM 13 A...

AI summary Table 2 presents the Rate and Bill Impact Analysis (RBIA) by rate class for the 2026 Historical DSM activities, showing average rate and bill impacts from 2011 to 2041. The data highlights savings for participants and non-participants across different rate classes.

8 5.1 ACTIVE PARTICIPATION METHODOLOGY - 9 Previously, participant estimates were calculated using a 'cumulative' methodology. This did not account - for the measure life of savings, resulting in the potential for the number of cumulative...

AI summary The document discusses a shift from a cumulative to an annual/active participation methodology in the 2026 DSM Extension RBIA, addressing overestimation of participants and underestimation of savings by considering measure life and separating active from expired participation.

5.2 RENEWABLE TO RETAIL - Adjustments were made to address two issues caused by the addition of the Renewable to Retail program - within the rate and bill impact analysis. 1 First, the DSM rate rider is applied to total class volumes inclu...

AI summary Adjustments were made to the Renewable to Retail program's rate and bill impact analysis to address two issues: the exclusion of Renewable to Retail GWh in DSM rate rider calculations, leading to overestimated rate impacts, and the omission of retailer energy savings in bill impact calculations. NS Power adjusted load data and models to correct these issues.

5.3 RBIA STUDY PERIOD A solar-PV resource was modelled for the first time as part of the 2027–2031 DSM Plan. With a 30-year measure life, solar-PV installations in 2031 would generate DSM impacts through 2060. However, the NS Power rate mo...

AI summary The 2027–2031 DSM Plan initially considered extending the RBIA study period to 2060 to account for solar-PV impacts, but NS Power and E1 opted to retain the 2055 model configuration. Reasons included data limitations, solar-PV's minor role compared to expiring energy efficiency measures, and the adequacy of 2046 impacts for decision-making.

6. METHODOLOGY AND ASSUMPTIONS Attachment 5 describes the overall modelling and key assumptions that apply to the 2027–2031 DSM Plan and 2026 Historical RBIA.

AI summary Attachment 5 outlines the methodology and key assumptions for the 2027–2031 Demand Side Management (DSM) Plan and the 2026 Historical Rate and Bill Impact Analysis (RBIA).

7. FUTURE CONSIDERATIONS E1 understands that NS Power has developed an updated Cost of Service Study (COSS) which has been filed with the NSEB as part of NS Power's 2026–2027 General Rate Application (M12451). Once concluded, E1 will work...

AI summary E1 acknowledges NS Power's updated Cost of Service Study (COSS) filed with the NSEB as part of its 2026–2027 General Rate Application (M12451). E1 will collaborate with stakeholders to assess implications for the Rate and Bill Impact Analysis (RBIA). Future RBIA applications will address the 2032–2036 DSM Resource Plan and 2035 historical RBIA, expected in early 2035.

5 8. CONCLUSION - 6 Highlights from the 2027–2031 DSM Preferred Plan RBIA analysis include: - Over the 20 years of the study period, participants in DSM programs see average annual bill 8 reductions ranging from a low of 0.04 percent (aver...

AI summary The RBIA analysis for the 2027–2031 DSM Preferred Plan highlights that Nova Scotian ratepayers will save $0.4 billion over 20 years due to energy and demand reductions. The analysis shows varying bill impacts for participants and non-participants, with maximizing customer participation helping to mitigate rate impacts. The RBIA excludes non-rate-related benefits such as reduced greenhouse gas emissions and local economic investment.

DATE FILED: March 31, 2026 Page 8 of 8 Attachment 4: Results by Rate Class 2026 Historical Line# Rate and Bill Impacts of DSM on the Residential Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2...

AI summary The document presents historical data on the rate and bill impacts of Demand Side Management (DSM) on the residential class from 2011 to 2055. It includes metrics such as net incremental energy savings, total annual energy savings, DSM expenditures, and participant activity over time.

This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participants' represents a customer with average energy use and average DSM savings . 'Non-Participants' represents a c...

AI summary The text discusses the bill impacts of Demand Side Management (DSM) resources, comparing participants and non-participants, and presents graphs showing annual and active participation rates for different DSM resources. The figures illustrate how DSM affects customer bills and participation levels across various resources.

DATE FILED: March 31, 2026 Page 1 of 8 Line# Rate and Bill Impacts of DSM on the Small General Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2...

AI summary The document presents a table analyzing the rate and bill impacts of Demand Side Management (DSM) on the Small General Class from 2011 to 2055. It details energy savings, expenditures, participant numbers, and energy savings per participant over time, highlighting trends and changes in DSM effectiveness and participation.

This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participants' represents a customer with average energy use and average DSM savings . 'Non-Participants' represents a c...

AI summary The text discusses the bill impacts of Demand Side Management (DSM) resources compared to a no-DSM scenario, showing participation rates for different DSM resources. It also explains how participation is measured, distinguishing between 'Annual' and 'Active' participation, and highlights potential overlaps in participant counts across resources.

DATE FILED: March 31, 2026 Page 2 of 8 Line# Rate and Bill Impacts of DSM on the General Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 20...

AI summary The table presents the rate and bill impacts of Demand Side Management (DSM) on the General Class over time, including energy savings, expenditures, and participant numbers. It highlights trends in energy savings and participant engagement from 2011 to 2055.

This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participants' represents a customer with average energy use and average DSM savings . 'Non-Participants' represents a c...

AI summary The text includes figures analyzing the bill impacts of Demand Side Management (DSM) resources, participation rates across different DSM programs, and related metrics. The figures compare participants, non-participants, and total customers, and show annual and active participation rates by DSM resource.

fter removing double-counting of participants from multiple resources. DATE FILED: March 31, 2026 Page 3 of 8 This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participa...

AI summary The text discusses the bill and rate impacts of Demand Side Management (DSM) resources, illustrating participation rates and double-counting adjustments. It includes graphical representations of annual and active participation, differentiated by DSM resources and customer classes, with a focus on hypothetical scenarios and participation metrics.

DATE FILED: March 31, 2026 Page 4 of 8 Line# Rate and Bill Impacts of DSM on the Small Industrial Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 203...

AI summary The document presents a detailed table showing the rate and bill impacts of Demand Side Management (DSM) on the small industrial class over several years, including energy savings, expenditures, number of participants, and average energy savings per participant. The data spans from 2011 to 2055 and includes metrics such as net incremental and total annual energy savings in gigawatt-hours, DSM expenditures in millions of dollars, and participant numbers.

This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participants' represents a customer with average energy use and average DSM savings . 'Non-Participants' represents a c...

AI summary The document presents graphical data on the bill impacts of Demand Side Management (DSM) resources, comparing participants and non-participants, and showing annual and active participation rates across different DSM resources. The figures illustrate how DSM affects customer energy use and rates, with a focus on participation metrics and rate impacts.

fter removing double-counting of participants from multiple resources. DATE FILED: March 31, 2026 Page 5 of 8 This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participa...

AI summary The document includes graphs analyzing the bill and rate impacts of Demand Side Management (DSM) resources, as well as participation rates across different customer classes. It distinguishes between 'Participants' and 'Non-Participants' and accounts for double-counting of participants across multiple resources.

fter removing double-counting of participants from multiple resources. DATE FILED: March 31, 2026 Page 6 of 8 This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participa...

AI summary The text discusses the bill and rate impacts of Demand Side Management (DSM) resources, including participation rates for different customer classes. It highlights the distinction between 'Participants' and 'Non-Participants' and provides visual representations of participation and impact data, with adjustments for double-counting across resources.

fter removing double-counting of participants from multiple resources. DATE FILED: March 31, 2026 Page 7 of 8 This graph shows bill impacts of all DSM resources combined,as percentage differences relative to the no-DSM scenario. 'Participa...

AI summary The document presents graphical data on the bill impacts of Demand Side Management (DSM) resources, comparing participants and non-participants, and illustrates participation rates across different DSM resources. It also references an attachment containing assumptions for the 2027-2031 DSM Plan and historical data from 2026.

5 1. GENERAL APPROACH - 6 E1 has used the "snapshot" approach recommended by Synapse, in which the impacts of specific - 7 program years are analyzed (in this case 2011–2026 programs for the 2026 historical RBIA and - 8 2027–2031 programs...

AI summary E1 employed Synapse's recommended 'snapshot' approach, analyzing specific program years (2011–2026 and 2027–2031) for RBIA and DSM Plan assessments, rather than evaluating long-term Demand Side Management impacts.

2. RESOURCES AND SCENARIOS - Both the 2027–2031 DSM Plan analysis and the 2026 historical analysis include the NS Power rate - model (Attachments 7 and 8) and the E1 RBIA model (Attachments 9 and 10). The analyses - compare two scenarios:...

AI summary The document compares DSM and no-DSM scenarios using NS Power and E1's RBIA models, analyzing utility costs, energy reductions, and rate impacts. It outlines resource combinations (e.g., Energy Efficiency Only, Solar-PV Only) and notes that rate impacts isolate DSM effects but do not reflect actual timing of rate increases. Results are summarized in Appendix B, Attachment 1.

2.1 ENERGY EFFICIENCY INPUTS - For the 2027–2031 DSM Plan RBIA, first-year energy, lifetime energy, demand savings and expenditures developed at the program component level were allocated to rate classes in proportion with the actual rate...

AI summary The 2027–2031 DSM Plan RBIA allocates energy savings and expenditures by rate class using historical 2022–2024 data and weighted-average measure lives (WAMLs). Solar-PV inputs are allocated entirely to the residential rate class with a 30-year measure life, excluded from historical RBIA periods. Savings estimates for 2025–2026 use the approved 2023–2025 DSM Plan and 2026 extension.

7 2.3 DEMAND RESPONSE INPUTS - 8 Demand response inputs for the 2027–2031 DSM Plan RBIA come from Guidehouse's DRSim™ - 9 model results. Rate class allocations for the BNI Curtailment program were calibrated for the - 2027–2031 DSM Plan RB...

AI summary Demand response inputs for the 2027–2031 DSM Plan RBIA are derived from Guidehouse's DRSim™ model, historical data (2011–2024), and the approved 2023–2025 DSM Plan. Modeling assumes no energy impacts and a one-year measure life for demand response programs.

4. TIME PERIOD DEFINITIONS - The following time periods apply to the RBIA analysis: - DSM delivery period: the timeframe over which DSM programs are delivered. - The DSM delivery period included in the 2027–2031 DSM Plan RBIA is 2027–2031...

AI summary The document defines three time periods for the Rate and Bill Impact Analysis (RBIA) of Nova Scotia's Demand Side Management (DSM) programs: DSM delivery (2027–2031 and 2011–2026), cost recovery (same periods), and study periods (2027–2046 and 2011–2041). Energy efficiency impacts, not solar-PV, determine the study period, with solar-PV effects visible until 2055.

11 5. AVOIDED COSTS Avoided costs are calculated at the system level using evaluated DSM savings and avoided cost rates in four categories: generation, transmission, distribution, and energy. Avoided costs used for the 2027–2031 DSM Plan a...

AI summary Avoided costs are calculated at the system level across four categories: generation, transmission, distribution, and energy. These costs are used for the 2027–2031 DSM Plan and its RBIA, with details provided in Appendix A and a table for historical years.

7.1 PARTICIPATION COUNTS BY CLASS - Participation estimates used in the RBIA model are different than participation estimates used in - development of DSM plans, since the RBIA tracks participating accounts , rather than the number - of pr...

AI summary The RBIA model uses account-based participation estimates, differing from DSM plans which track products. RBIA de-duplicates across programs and years, calculating annual and active participants to determine bill savings per participant.

4 7.2.2 UNTRACKED PARTICIPATION - 5 E1 operates two program components that offer rebates at the point-of-sale: residential Instant - 6 Savings and the Instant Rebates portion of Business Energy Rebates (BER-IR). These program - 7 componen...

AI summary E1's Instant Savings and BER-IR programs use transaction records and research to estimate participation due to lack of direct data collection. The methodology changed in 2027, abandoning the prior assumption that all large commercial/industrial customers participated annually, due to declining participation from lighting phase-outs in Instant Rebates.

Active Participation - For historical years (2011–2024), to calculate the number of active participants, E1 starts with - the annual participation and for each subsequent year adds the number of new participants - (calculated based on surv...

AI summary E1 calculates active participants for historical years (2011–2024) by adding new participants and subtracting expiring ones based on savings lifespan. For future years, a re-participation factor derived from 2019–2023 data is applied, with participant numbers degrading post-2032 at the same rate as cumulative energy savings.

7.2.3 RESIDENTIAL BEHAVIOUR PARTICIPATION - The Residential Behaviour program component applies the rate class weighted-average measure - life to estimate active participants; this is consistent with other tracked programs. For program- -...

AI summary The Residential Behaviour program uses a rate-class weighted-average measure life to estimate participants, ensuring accurate tracking without overestimation. A cross-participation factor prevents double-counting across tracked/untracked participation. Residential Behaviour is excluded from the 2027–2031 DSM Plan RBIA, focusing on post-delivery year participation decay aligned with energy savings.

7.3 SOLAR-PV PARTICIPATION - For the 2027–2031 DSM Plan, solar-PV participation is a direct output of Guidehouse's ProCESS - model. 100% of participation was allocated to the residential rate class. Active participation was - calculated ba...

AI summary The 2027–2031 DSM Plan uses Guidehouse's ProCESS model to allocate 100% of solar-PV participation to residential rate classes. Solar-PV measures, with a 30-year lifespan, do not expire by 2055, as their duration exceeds the model's timeframe.

7.4 DEMAND RESPONSE PARTICIPATION - For 2023–2024 years, demand response participation was based on historical results. For 2025– - 2031 years, demand response participation inputs by rate class come from Guidehouse's DRSim™ - model. - 1 T...

AI summary For 2023–2024, demand response participation is based on historical results. For 2025–2031, it uses Guidehouse's DRSim™ model. Participation counts annual active participants, assuming a one-year measure life.

5 7.5 COMBINED PARTICIPATION - 6 In the DSM scenario—where the combined effects of energy efficiency, demand response, and - 7 Solar-PV are evaluated—the rate-class participation is assumed to be the highest level observed - 8 among the th...

AI summary In the DSM scenario, combined participation of energy efficiency, demand response, and solar-PV uses the highest observed rate-class participation due to overlapping program participation, particularly between energy efficiency and solar-PV, and energy efficiency and demand response.

8. CALCULATION OF RATE IMPACTS - Rate impacts are calculated in NS Power's Rate Model (Attachment 7 and 8) to reflect NS Power's - Cost of Service in a more precise manner. It reflects the Energy Board approved retail rates and - Cost of S...

AI summary NS Power's Rate Model calculates rate impacts for the 2027–2031 DSM Plan using Forecast Unit Revenues, blending DSM energy and demand impacts into a single rate. E1's RBIA Model uses these revenues to assess bill impacts, excluding demand charges as they are already incorporated into blended rates. The analysis isolates DSM effects by comparing DSM and no-DSM scenarios, assuming equal energy and demand savings.

4 9.1 NO-DSM BILL IMPACTS - 5 In the no-DSM scenario, for each rate class, and for each year, the total class energy consumption - 6 is divided by the number of customers to produce an estimate of the average customer's - 7 consumption. Th...

AI summary The no-DSM scenario calculates average customer energy consumption by dividing total class energy consumption by the number of customers, then uses these averages with no-DSM rates to determine average bills for each rate class and year.

9.2 NON-PARTICIPANT 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 changes - in rates u...

AI summary Non-participants in DSM programs experience bill impacts solely from rate changes in the with-DSM scenario, not energy use. Fixed customer charges cause percentage bill impacts to differ from rate impacts. This analysis highlights how rate structures affect non-participants independently of DSM program participation.

9.3 PARTICIPANT BILL IMPACTS - For the DSM scenario, within each rate class in each year, total annual savings (i.e., current-year - savings plus persistent savings from past years) are divided equally amongst the number of active - partic...

AI summary The DSM scenario assumes equal annual savings per participant across rate classes, ignoring varying participation depths. E1's RBIA includes free-riders, leading to underestimated average savings. Total Customers category allocates DSM savings equally to all customers, not differentiating between participants and non-participants.

10. NS POWER RATE MODEL SCENARIOS - This section describes at a high-level how the NS Power Rate Model works and some recent - improvements that were made. - Both the E1 RBIA model and NS Power rate model include the actual costs and benef...

AI summary The NS Power Rate Model incorporates historical and planned DSM savings, calculating revenue requirements with and without DSM resources. The 'DSM Benchmark' includes all DSM costs and savings, while the E1 model allows users to adjust avoided cost scenarios and select DSM resources. Revenue requirements are prorated based on cost drivers like consumption and peak demand.

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 for adjusting NS Power's base cost rates based on DSM-induced changes in class usage and system costs. It involves regulatory analysis under the ERBA and NSUARB frameworks, focusing on cost recovery and rate design considerations.

1.0. Introduction In an effort to more precisely and accurately align EfficiencyOne's (E1) RBIA Model with the methodological process used by NS Power in setting of its base cost rates, all rate setting functionality from E1's RBIA model h...

AI summary EfficiencyOne's RBIA model is being realigned with NS Power's COSS methodology, shifting rate-setting responsibility to NS Power. NS Power will provide annual inputs (e.g., revenue forecasts, DSM charges) to E1's RBIA model under 'With DSM' and 'No DSM' scenarios, with NS Power responsible for cost allocation methods and data assumptions.

Revenue Requirement Ordinarily, the base cost rate setting process used in rate case applications requires a great amount of detailed cost inputs to determine revenue requirement. Annual rate base data needs to be collected on a variety of...

AI summary The revenue requirement process typically requires detailed cost data, but for the RBIA, only DSM-induced avoided costs are considered while keeping other costs constant. This simplifies analysis by focusing on directional and relative rate changes due to DSM programs.

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 COSS provides insights into cost causation by analyzing energy and demand usage changes. NS Power's annual Load Forecast Report and E1's long-term usage forecasts enable simplified COSS analysis for rate adjustments, bypassing detailed future cost data collection.

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 COSS ratemaking step leads to misleading rate analyses by failing to account for DSM-induced changes in usage and embedded system cost reallocations. A simplified COSS process is recommended to provide precise results and better insights into how usage changes affect total service costs.

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 applied approach involves analyzing rate changes due to DSM by evaluating two scenarios ('With DSM' and 'No DSM') and separating cost determination into FAM-related and non-FAM-related subprocesses. This method allows for a detailed comparison of rate impacts with and without DSM, facilitating informed regulatory decisions on cost allocation.

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 revenue requirements under 'With DSM' and 'No DSM' scenarios, adjusting costs for inflation and DSM impacts. FAM and non-FAM costs are modified based on test year data and avoided fuel costs. Historic cost true-ups are excluded due to minimal impact, lack of rigor, and complexity. The analysis uses data from 2011-2035 and references prior rate proceedings.

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 NS Power has functionalized system costs based on historic rate cases, adjusting revenue requirements for changes in load and inflation. The impact of DSM on load savings and avoided costs is considered, with examples provided on the true-up of depreciation costs from the Maritime Link project.

3.2.2 Classification of System Costs Costs within each area are classified into appropriate services. Generation and transmission costs are classified into energy and demand. Distribution costs are classified between demand and customer. R...

AI summary System costs are classified into energy, demand, and customer categories. Generation costs depend on unit type (baseload, peaking, environmental), with NS Power using a linear equation for classification. Transmission costs align with load factors, while distribution and retail costs remain static except for inflation. DSM impacts reclassification but does not alter customer numbers.

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 underlying usage both in the "With DSM" and "No DSM" case.

AI summary Annual costs for each service and functional area are allocated to rate classes based on their share of usage in both 'With DSM' and 'No DSM' scenarios. This approach ensures cost distribution reflects actual consumption patterns across different rate classes.

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: March 31, 2026 Page 7 of 16 - o In the "With...

AI summary The Fuel Adjustment Mechanism (FAM) allocates costs via a two-step process using benchmark unit costs, with distinct methods for 'With DSM' and 'No DSM' cases. The current model does not differentiate between energy and demand-related costs, a limitation stemming from historical low demand costs. Recent increases (15% of FAM costs due to Maritime Link) may warrant future RBIA adjustments.

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 via a two-step process: multiplying annual class usages by benchmark costs from 'With DSM' or 'No DSM' cases, then scaling estimates to match revenue requirements per functional area. The 'With DSM' case uses the most recent prior rate case, while the 'No DSM' case references the same calendar year as the 'With DSM' case.

DSM Costs The annual DSM-related costs incurred by individual rate classes, as provided by E1, are apportioned to rate classes based on the 25/75 rule. 75 percent of the costs incurred by each class is treated as direct responsibility of e...

AI summary The document outlines the apportionment of annual DSM costs among rate classes using a 25/75 rule, with 75% directly assigned to each class and 25% distributed based on energy and demand usage metrics, including load factor, system generation share, and winter peak demand.

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 The COSS Results compare 'With DSM' and 'No DSM' scenarios, showing higher unit costs in historic periods due to DSM program costs and lower differentials in out-years as DSM measures expire. Fuel-cost-heavy classes (e.g., Large Industrial) benefit more from DSM, while fixed-cost-heavy classes (e.g., Domestic) see less impact. Trends are analyzed via NS Power's rate model.

3.3 Unit Revenue Determination For the directional purposes of the RBIA model, it is not considered necessary to develop annual rates with all charges under the "With DSM" and "No DSM" cases. Rather, it is sufficient for NS Power to provid...

AI summary NS Power determines unit revenues for rate classes by providing blended revenues in cents per kWh, excluding customer charges for residential and small general classes. Factors like fuel cost adjustments, deferrals, rate smoothing, and revenue-to-cost ratios are excluded, but this has no material effect on relative changes between 'With DSM' and 'No DSM' cases.

Attachment A

AI summary Attachment A lists acronyms related to Nova Scotia's energy regulation, including organizations, programs, and legal frameworks involved in utility proceedings. Key terms cover demand-side management, rate design, and energy efficiency initiatives.

"COSS Data Inputs" tab This tab includes all annual test year class usage and embedded costs from the COSS and BCF COSS filed in GRA and BCF proceedings as well as a forecast of annual usage by class per the most recent ten-year Load Forec...

AI summary The 'COSS Data Inputs' tab compiles annual test year class usage, embedded costs from COSS and BCF COSS filings in GRA and BCF proceedings, a ten-year load forecast, and DSM expenditures by rate class. This data informs class unit cost and revenue calculations.

"E1 Data Inputs" tab This tab includes information provided to NS Power by E1 on DSM Program measures and avoided unit costs, all of which are used in determination of class unit costs and revenues.

AI summary The 'E1 Data Inputs' tab contains information provided by E1 to NS Power regarding DSM Program measures and avoided unit costs, which are essential for calculating class unit costs and revenues.

Savings in energy and demand usage by rate class Savings in energy and demand usage arising from DSM programs for each class are tracked in the following class tabs: R-Savings, SG-Savings, G-Savings, LG-savings, SI-Savings, MI-Savings, LI-...

AI summary The document outlines how energy and demand savings from DSM programs are tracked across rate classes (R-Savings, SG-Savings, etc.) using data from 2011–2022. Annual savings are calculated by E1 using methods from its RBIA Reports, with adjustments for energy losses based on the COSS study.

"Total-Savings" tab The "Total-Savings" tab provides a sum of annual class savings in energy and demand usage at the generator's gate and customer's meter. In addition, class demand savings at the high side of the bulk power substation are...

AI summary The 'Total-Savings' tab calculates annual energy and demand savings at the generator's gate and customer's meter, including avoided fuel, generation, transmission, and distribution costs. FAM-related avoided costs use unit fuel costs multiplied by energy savings, while non-FAM costs use avoided infrastructure costs per MW demand savings.

Cost of Service Studies Apportionment of costs to rate classes is done separately for the "With DSM" and "No DSM" cases" in the tabs bearing the same names.

AI summary The document discusses the separate apportionment of costs to rate classes under 'With DSM' and 'No DSM' scenarios, as outlined in corresponding tabs. This approach allows for distinct cost allocation analyses based on demand-side management considerations.

"With DSM" tab The "With DSM" tab provides annual cost allocation to rate classes based on long-term usage as included in NS Power's most recent Annual ten-year Load Forecast Report. This usage already reflects inclusion of DSM Program eff...

AI summary The 'With DSM' tab allocates annual FAM costs to rate classes using NS Power's load forecast, which includes DSM program effects. FAM costs for 2023-2035 are calculated via a two-step process: applying 2022 blended unit FAM costs to forecasted MWh usage, then scaling to match total annual FAM costs using a formula incorporating previous year costs and energy requirement deltas.

"No DSM" tab The "No DSM" tab provides annual cost allocation to rate classes absent DSM. The FAM-related costs in years 2011–2035 are calculated using the following process: - Annual FAM costs for each class are calculated by multiplying...

AI summary The 'No DSM' tab calculates annual Fuel Adjustment Mechanism (FAM) costs without Demand Side Management (DSM) savings. It uses blended unit FAM costs, scales class-specific costs to match total FAM estimates, and applies a formula incorporating energy requirement deltas and avoided FAM costs from the 'With DSM' case.

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 document outlines a simplified cost allocation process for FAM (Fuel Adjustment Mechanism) and non-FAM costs, distinguishing between energy and demand-related allocations. It details methods like load factors, DSM integration, and inflation adjustments for 2023–2035, using data from COSS and prorating tables to distribute costs across rate classes.

"COSS Var" tab "COSS Var" provides differentials between cell values in the "No DSM" and "With DSM" tabs. Please note that the data layouts in the "No DSM" and "With DSM" tabs are identical with the exception for the treatment of DSM costs...

AI summary The 'COSS Var' tab compares cell values between 'No DSM' and 'With DSM' scenarios, highlighting differences in cost calculations. The 'No DSM' tab excludes Demand Side Management (DSM) costs, while the 'With DSM' tab includes them, with identical data layouts otherwise.

Results

AI summary The document section 'Results' is under review, with no substantive content provided. Key entities and topics are inferred from the context, including regulatory bodies, energy programs, and technical terms related to Nova Scotia's energy sector.

"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 analyzing percentage changes in class rates due to DSM (Demand Side Management) from 2011–2035, using arithmetic or load-weighted rate changes. It breaks down effects on unit base cost revenues, including 'No DSM' scenarios and DSM cost inclusions. A control panel tests inflation and avoided cost scenarios on class unit costs and revenues.

"NSPI Inputs into RBIA" tab "NSPI Inputs into RBIA" provides pricing inputs requested by E1. It includes the following annual class data in years 201-2035 broken out by "With DSM" and "No DSM" scenarios: - Forecast Unit Revenues Before DSM...

AI summary The 'NSPI Inputs into RBIA' tab provides data for Rate and Bill Impact Analysis (RBIA) scenarios with and without Demand Side Management (DSM). It includes revenue forecasts, sales projections, demand forecasts, and customer counts from 2021–2035. Attachments detail NS Power rate models, E1 RBIA models, and an alternate scenario for 2027–2031.

2 The Alternate Scenario will invest $308.4 million to achieve 435.4 GWh of incremental cumulative net 3 energy savings, 85.0 MW of cumulative system-peak demand savings, 25.5 MW of available capacity from 4 demand , and 1.7 GWh of solar-P...

AI summary The Alternate Scenario involves a $308.4 million investment to achieve energy savings and demand reductions, with a focus on maintaining cost-effective BNI demand response programs and introducing new initiatives for Mi'kmaw communities. The residential Eco Shift pathway is excluded compared to the Preferred Plan.

17 Table 1: 2027–2031 Alternate Scenario Portfolio Level Insights Insights 2027–2031 Energy Efficiency Energy Savings as % of NS Power Load 0.8% Energy Savings (EE) Split (RES/BNI) 29/71 Demand Savings (EE) Split (RES/BNI) 44/56 Dedicated...

AI summary This table provides insights into the 2027–2031 alternate scenario portfolio, including energy efficiency savings, demand response capacity, solar-PV generation, and overall benefits of the alternative plan, such as energy savings, investment, and CO₂e reductions.

1.1 ALTERNATE SCENARIO – PORTFOLIO SAVINGS AND INVESTMENT 16 Table 2, below, provides portfolio-level savings and investment by year and in aggregate, inclusive of all 17 proposed DSM resources for the 2027–2031 Alternate Scenario. 18 19 2...

AI summary The document presents an alternate scenario analyzing portfolio-level savings and investments from 2027–2031, incorporating all proposed DSM resources. Table 2 summarizes these figures, reflecting the regulatory proceeding's focus on energy efficiency and investment planning under Nova Scotia's utility framework.

Table 2: 2027–2031 Alternate Scenario Investment and Savings 2027-2031 Portfolio Year Investment ($M) Lifetime Benefits ($ million) First-Year Energy Savings (GWh) Peak Demand Savings (MW) Lifetime Energy Savings (GWh) Low- Income & Equity...

AI summary Table 2 presents investment and savings data for energy efficiency and demand response programs from 2027 to 2031. It includes metrics such as investment, lifetime benefits, energy savings, peak demand savings, and weighted average measure life for various programs.

9 10 Table 3: 2027–2031 Alternate Scenario Savings and Investment by Program Component 2027-2031 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Av...

AI summary The table provides a detailed overview of energy efficiency (EE) and demand response (DR) programs for the 2027–2031 period, including investment, lifetime benefits, energy savings, and program administrator cost test (PAC) data. It highlights the contribution of various programs, such as residential and business EE initiatives, enabling strategies, and solar-PV programs, to overall energy savings and investment.

13 18 Columns may not add correctly due to rounding. Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response a...

AI summary The text discusses the methodology for calculating lifetime benefits of energy efficiency, demand response, and solar-PV programs, using net present value of avoided costs. It also outlines how low-income and equity impacts are calculated, including participation from specific programs and the use of the Program Administrator Cost Test (PAC) as a benefit/cost ratio.

4 Table 4: 2027 Alternate Scenario Savings and Investment by Program Component 2027 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Deman...

AI summary Table 4 outlines the 2027 alternate scenario savings and investment by program component, including residential and BNI EE programs, Enabling Strategies, and their respective investments, benefits, energy savings, and other metrics.

Columns may not add correctly due to rounding. Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and sol...

AI summary The text outlines how lifetime benefits for energy efficiency, demand response, and solar-PV are calculated using net present value of avoided costs. It also discusses how low-income and equity impacts are reflected in program participation and mentions the PAC as a benefit/cost ratio for DSM investment.

1 Table 5: 2028 Alternate Scenario Savings and Investment by Program Component 2028 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Deman...

AI summary Table 5 outlines the 2028 Alternate Scenario Savings and Investment by Program Component, highlighting energy efficiency (EE) programs, enabling strategies (ES), demand response (DR), and solar-PV programs. It provides data on investment, lifetime benefits, energy savings, peak demand savings, and other metrics for residential and business, non-profit, and institutional (BNI) programs, as well as overall portfolio totals.

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The text outlines how currency is expressed in nominal dollars and discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs using net present value of avoided costs. It also addresses low-income and equity impacts based on participation in specific programs.

1 Table 6: 2029 Alternate Scenario Savings and Investment by Program Component 2029 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Deman...

AI summary The text presents a table titled '2029 Alternate Scenario Savings and Investment by Program Component' with columns related to investment, benefits, energy savings, and other metrics. However, no data is provided under the 'Residential EE Programs' row, leaving the content incomplete.

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The text discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs, expressed as net present value of avoided costs. It also highlights the inclusion of low-income and equity impacts from targeted and non-targeted programs.

1 Table 7: 2030 Alternate Scenario Savings and Investment by Program Component 2030 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Deman...

AI summary Table 7 outlines the projected investment, benefits, and savings across various energy efficiency (EE), enabling strategies (ES), demand response (DR), and solar-PV programs for 2030. The data highlights the financial and energy-saving impacts of these initiatives, including residential and business programs, and emphasizes the overall savings and investment required for the DSM portfolio.

Currency is expressed in nominal dollars. For the five-year total row, currency is a straight sum of 5 years of nominal values. Lifetime benefits for energy efficiency, demand response and solar-PV are expressed as the net present value of...

AI summary The text discusses the calculation of lifetime benefits for energy efficiency, demand response, and solar-PV programs, using net present value of avoided costs. It also highlights the consideration of low-income and equity impacts, including participation from dedicated and non-targeted programs.

Table 8: 2031 Alternate Scenario Savings and Investment by Program Component 2031 Investment ($ million) Lifetime Benefits ($ million) First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Demand...

AI summary Table 8 presents the 2031 alternate scenario savings and investment by program component, including energy efficiency (EE), enabling strategies (ES), demand response (DR), and solar-PV programs. It outlines investments, lifetime benefits, energy savings, and other metrics for residential, business, and institutional programs, as well as the Mi'kmaw community initiatives.

1 1.3 ALTERNATE SCENARIO – PROGRAMS 15 Alternate tab for the Alternate Scenario). - 2 The Alternate Scenario removes the residential program component (Eco Shift) from the Demand - 3 Response program. 4 - 5 All other DSM programs in the Al...

AI summary The Alternate Scenario removes the residential Eco Shift program from Demand Response but retains energy efficiency and solar-PV programs, including new Mi'kmaw initiatives. Technical details are outlined in appendices, with no changes to energy efficiency or solar-PV measures compared to the Preferred Plan.

21 Table 9: 2027–2031 Alternate Scenario Rate Class Savings and Expenditures 2027–2031 Rate Class Year First Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Available Demand Response Capacity (MW) Generatio...

AI summary Table 9 presents energy savings and expenditures for different rate classes from 2027 to 2031 under an alternate scenario. It includes data on energy savings, peak demand savings, and expenditures in millions of dollars for residential, charitable, and small general rate classes.

4 List of Schedules 5 6 Schedule "A": Electricity Efficiency And ConservationDemand-side Management 7 Activities 8 Schedule "B": Compensation 9 Schedule "C": Performance Requirements 10 Schedule "D": Confidentiality Agreement 11 Schedule "...

AI summary The document outlines five schedules related to electricity efficiency, compensation, performance requirements, confidentiality, and an approved DSM resource plan. Key focus areas include demand-side management, energy conservation, and regulatory compliance frameworks.

38 5. NOTIFICATION OF SIGNIFICANT CHANGES 39 5.1 EfficiencyOne shall provide notice of Significant Changes to NSPI at the same time as 40 EfficiencyOne makes application to the UARB NSEB for the approval of the Significant 1 Changes. Subje...

AI summary EfficiencyOne must notify NSPI when applying for approval of significant changes to the EECA DSM Resource Plan. NSPI may submit written comments to UARB NSEB regarding these changes, subject to regulatory discretion.

1 10. SUBCONTRACTORS - 2 10.1 EfficiencyOne shall be permitted to subcontract the performance of any part of the EECA 3 DSM without the prior written approval of NSPI. - 4 10.2 Where EfficiencyOne subcontracts any part of the EECADSM, Effi...

AI summary EfficiencyOne may subcontract EECA DSM work without NSPI approval but remains fully liable for subcontractors' actions. Subcontractors cannot form direct contracts with NSPI. EfficiencyOne must ensure subcontractors uphold agreement rights and protections.

4 ELECTRICITY EFFICIENCY AND CONSERVATIONDEMAND-SIDE MANAGEMENT 5 ACTIVITIES

AI summary The document outlines Nova Scotia's regulatory focus on electricity efficiency, conservation, and demand-side management (DSM) activities. Key entities include NS Power, NSEB, and NSUARB, with emphasis on programs like DSMAG and E1. Topics cover energy efficiency, rate design, and regulatory frameworks.

6 Schedule A

AI summary Schedule A of a Nova Scotia regulatory proceeding document, likely related to energy management, utility regulations, and cost recovery mechanisms. Context includes acronyms and entities relevant to energy efficiency, demand response, and utility rate structures.

7 Electricity Efficiency and ConservationDemand-Side Management Activities The figure below identifies the scope of savings (3 5 year cCumulative Annual eEnergy sSavings, cCumulative Annual pPeak dDemand sSavings, cCumulative Annual eEnerg...

AI summary The document outlines Energy Efficiency Corporation (EECA) Demand-Side Management (DSM) performance targets over a five-year plan, including energy and peak demand savings, solar-PV generation, and low-income equity programs. Compliance requires achieving 90% of targets; otherwise, a regulatory process is triggered. Schedule B addresses compensation mechanisms.

45 Schedule B (Page 2 of 2)

AI summary Second page of Schedule B from a Nova Scotia regulatory proceeding, listing acronyms related to energy regulation, utility management, and demand-side programs. Context includes terms like DSM, PUA, NSEB, and NS Power, reflecting regulatory frameworks and energy initiatives in Nova Scotia.

PERFORMANCE REQUIREMENTS - I. UARBNSEB-APPROVED PERFORMANCE TARGETS, THRESHOLDS, AND INDICATORS - a) Performance Targets and Thresholds: - Performance Targets are set over the three five year contract period, rather than annually. - ii. Ef...

AI summary Performance targets for EfficiencyOne (E1) are set over three five-year contract periods, requiring 90% achievement of metrics like energy savings, peak demand reduction, and solar-PV generation. Non-compliance triggers regulatory action, with the Nova Scotia Energy Board (NSEB) determining remedies. Targets include specific programs for affordable housing and Mi'kmaw communities.

Appendix E Proposed Form of DSM Purchase Agreement (Clean) 2027-2031 DSM Resource Plan 1 2 Purchase Agreement for 3 Demand-Side Management Activities 4 5 Between 6 7 Nova Scotia Power Incorporated 8 9 and 10 11 EfficiencyOne 12 13 Effectiv...

AI summary Proposed DSM Purchase Agreement between Nova Scotia Power Incorporated (NSPI) and EfficiencyOne (E1) for 2027-2031, outlining Demand-Side Management (DSM) activities. The agreement is part of a regulatory proceeding, with an effective date of January 1, 2027, and was filed on March 31, 2026.

[Schedule "E": Approved DSM Resource Plan](#page-404-0) 1 27. SURVIVAL 17 2 [Remainder of page intentionally left blank]17 3 4 5 List of Schedules 6 Schedule "A": Demand-side Management Activities 7 Schedule "B": Compensation 8 Schedule "C...

AI summary The document outlines Schedule 'E' of the Approved DSM Resource Plan, which includes a table with incomplete data and a list of other schedules, such as Schedule 'A' for Demand-side Management Activities and Schedule 'D' for Confidentiality Agreement.

5. NOTIFICATION OF SIGNIFICANT CHANGES 5.1 EfficiencyOne shall provide notice of Significant Changes to NSPI at the same time as EfficiencyOne makes application to the NSEB for the approval of the Significant Changes. Subject to the terms...

AI summary EfficiencyOne must notify NSPI of significant changes to the DSM Resource Plan simultaneously with submitting an application to the NSEB for approval. NSPI retains the right to submit written comments on such changes under the Public Utilities Act.

6. SAFETY - 2 6.1 EfficiencyOne shall at all times be responsible for safety and loss management in the 3 supply or performance of the DSM. - 4 6.2 EfficiencyOne shall ensure that all employees, Subcontractors, agents and 5 representatives...

AI summary EfficiencyOne is mandated to manage safety and loss in Demand Side Management (DSM) and ensure compliance with federal, provincial, municipal, and internal health, safety, and environmental regulations.

7. PROTECTION OF PROPERTY - 9 7.1 EfficiencyOne shall take all commercially reasonable steps to protect the property of NSPI's customers and other third parties from damage which may occur as the result of the performance of the DSM. - 7.2...

AI summary EfficiencyOne is required to protect NSPI's customers' and third parties' property during DSM activities. It must indemnify NSPI for damages caused by its actions, excluding cases where NSPI's negligence is responsible.

9. EFFICIENCYONE'S COVENANTS - 9.1 EfficiencyOne warrants, covenants and agrees with NSPI that: - (a) it has all requisite capacity and authority to execute, deliver and perform its obligations under this Agreement; - (b) this Agreement ha...

AI summary EfficiencyOne's covenants with NSPI include legal authority, compliance with laws, proper execution of DSM, use of licensed personnel, and responsibility for subcontractors. EfficiencyOne must notify NSEB/NSPI of DSM supply disruptions and ensure adherence to regulations. Subcontractors are permitted but EfficiencyOne remains fully liable for their actions.

19. DISPUTE RESOLUTION - 19.1 In the event of a dispute in connection with this Agreement, a senior representative of EfficiencyOne and a senior representative of NSPI shall promptly meet to discuss and resolve the dispute and the Parties...

AI summary The dispute resolution process requires EfficiencyOne and NSPI to meet promptly to resolve disputes within 30 days (or 10 days for urgent matters). If unresolved, disputes are referred to the NSEB under Section 79P of the Act. EfficiencyOne must continue DSM unless NSEB authorizes suspension.

20. DEFAULT AND TERMINATION - 20.1 This Agreement may be terminated immediately by either Party, in whole or in part, upon the happening of one or more of the following events: - (a) EfficiencyOne's Franchise is terminated and the Agreemen...

AI summary The agreement can be terminated by either party if EfficiencyOne's franchise is terminated without assignment by the Minister or upon NSEB approval. Termination does not allow compensation for consequential losses, requires EfficiencyOne to discontinue DSM activities, and claims must be asserted within 30 days.

22. AUDIT AND INSPECTION - 2 22.1 EfficiencyOne shall, during the Term and for a period of thirty-six (36) months thereafter, 3 keep accurate records of all DSM supplied to NSPI, as necessary to determine that the 4 DSM was provided in acc...

AI summary EfficiencyOne must maintain DSM records for 36 months post-agreement. NSPI may request NSEB access to these records and inspect DSM operations, with EfficiencyOne required to facilitate inspections. Compliance with agreement terms is emphasized through audit and inspection rights.

25. COORDINATION MEETINGS AND REPORTS - 25.1 During the Term of this Agreement, EfficiencyOne shall prepare and deliver to the NSEB and NSPI a quarterly report (the " Quarterly Report ") in a form acceptable to the NSEB. - 25.2 EfficiencyO...

AI summary EfficiencyOne must submit quarterly and annual progress reports to NSEB and NSPI detailing DSM performance, financials, and discrepancies. Quarterly coordination meetings between NSPI and EfficiencyOne are mandated to ensure effective DSM planning and implementation.

4 DEMAND-SIDE MANAGEMENT ACTIVITIES

AI summary This section outlines Demand-Side Management (DSM) activities in Nova Scotia, referencing regulatory frameworks, utility programs, and energy efficiency initiatives. Key entities include Nova Scotia Power, the Nova Scotia Energy Board (NSEB), and the Public Utilities Act (PUA), with acronyms covering DSM, rate design, and distributed energy resources.

5 Schedule A 6 Demand-Side Management Activities 7 8 The figure below identifies the scope of savings (5 year cumulative energy savings, 9 cumulative peak demand savings, cumulative energy savings from Low Income & Equity (includes Afforda...

AI summary Schedule A outlines the scope of demand-side management (DSM) activities over a five-year term, including energy and peak demand savings, low-income and equity programs, demand response capacity, and solar-PV generation.

14 15 Cumulative Net Energy Savings at Generator over the Term (GWh) Cumulative Net Peak Demand Savings at Generator over the Term (MW) Cumulative Energy Savings – Low Income & Equity (GWh) Available Demand Response Capacity (MW) Cumulativ...

AI summary The text presents a table with performance targets related to energy savings and generation, including cumulative net energy savings, peak demand savings, low-income and equity energy savings, available demand response capacity, and cumulative net solar-PV generation. However, the table lacks specific numerical data and is incomplete.

25 Schedule B (Page 1 of 2)

AI summary Schedule B (Page 1 of 2) from a Nova Scotia regulatory proceeding document lists acronyms and terms related to energy regulation, utility operations, and demand-side management. Key entities include NS Power, NSEB, and ERBA, with topics covering energy efficiency, rate design, and regulatory frameworks.

37 Schedule B (Page 2 of 2)

AI summary Schedule B (Page 2 of 2) from a Nova Scotia regulatory proceeding lists acronyms related to energy regulation, utility management, and policy frameworks. It includes terms for demand-side management, rate design, and energy efficiency programs, reflecting the context of utility oversight and regulatory analysis in Nova Scotia.

Permitted Scope of Use 2. The Recipient may use the Confidential Information solely for the purposes of providing or receiving DSM, as the case may be, in accordance with the Legislation and the Purchase Agreement and for no other reason o...

AI summary The recipient is restricted to using confidential information solely for Demand Side Management (DSM) purposes under the Legislation and Purchase Agreement, with no other permitted uses.

4 2. BACKGROUND - 5 On June 16, 2015, EfficiencyOne (E1), Nova Scotia Power Incorporated (NS Power), the Consumer - 6 Advocate, the Small Business Advocate, the Ecology Action Centre, the Affordable Energy Coalition, - 7 and the Industrial...

AI summary The document outlines the history of the Standardized Filing Framework for DSM applications in Nova Scotia. Key milestones include the 2015 Consensus Agreement, NSUARB approval in 2015, adoption in 2016, updates in the 2023–2025 DSM Plan, and the 2026 DSM Extension decision directing continued engagement with DSMAG.

22 3. STANDARDIZED FILING FRAMEWORK

AI summary The document outlines a standardized filing framework within a Nova Scotia regulatory proceeding, focusing on energy and utility regulations. It includes acronyms related to demand-side management, energy efficiency, and utility rate structures, indicating a structured approach to regulatory compliance and reporting.

26 Table 1: Glossary of Terms Term Definition Available demand response The capacity available to NS Power to reduce system peak demand via demand capacity response events. Cumulative net demand Sum of incremental net demand savings across...

AI summary The glossary defines key terms related to demand-side management (DSM) and energy efficiency, including cumulative net demand and energy savings, DSM forecasts, and resource plans. These definitions help clarify the scope and performance metrics of DSM programs.

3 Table 3: Program Description Template Item Description 1. Overview Intent, target market, and type of service or rebate. 2. Objectives Long-term objectives for the program. 3. Opportunity Summary of market potential for the program, incl...

AI summary This section outlines a program description template for regulatory proceedings, including program objectives, design, performance indicators, and alternatives. It is part of a demand-side management standards section.

4.1 Objectives - Ensure consistency in the overall Demand Side Management (DSM) planning, evaluation, 4 reporting in Nova Scotia; - Consolidate Board decisions and directives as they pertain to DSM; and - Ensure that DSM Resource Plans bal...

AI summary The objectives focus on ensuring consistency in Demand Side Management (DSM) planning and reporting in Nova Scotia, consolidating Board decisions related to DSM, and balancing DSM Resource Plans to meet multiple objectives.

4.2 DSM Resource Plan Research

AI summary Section 4.2 discusses research related to Demand Side Management (DSM) resource planning in Nova Scotia, involving regulatory bodies, programs, and analyses of energy efficiency, demand response, and cost recovery mechanisms.

4.2.1 DSM Baseline Study - E1 will work with the NSIESO on IRP activities, [6](#page-418-1) which may include commissioning a DSM baseline - study in advance of each DSM Potential Study to identify current stocks of electricity consuming -...

AI summary E1 is collaborating with NSIESO on IRP activities, including commissioning a DSM baseline study prior to each DSM Potential Study to identify current electricity-consuming devices across all market sectors.

4.2.2 DSM Potential Study - E1 will work with the NSIESO on IRP activities, 6 including the commission of a DSM Potential study - in advance of each IRP exercise. The DSM Potential study identifies DSM resources that are - achievable over...

AI summary E1 will collaborate with NSIESO on IRP activities, including commissioning a DSM Potential study before each IRP exercise. The study identifies achievable DSM resources over the planning horizon and informs Candidate Resource Plans for the IRP.

4.2.3 Integrated Resource Plan - Integrated resource planning establishes directional information for DSM planning. The Preferred - Resource Plan identified in the IRP will inform the development of a preferred DSM Resource Plan - by E1, i...

AI summary The Integrated Resource Plan (IRP) provides directional guidance for Demand Side Management (DSM) planning. The Preferred Resource Plan in the IRP will inform E1's development of a preferred DSM Resource Plan, including analysis of alternate DSM scenarios as per the Framework.

4.2.4 Avoided Costs - NSIESO will work with the DSM franchise holder to develop avoided cost calculations for demand- - side management resources[.6](#page-412-1)

AI summary NSIESO will collaborate with the DSM franchise holder to develop avoided cost calculations for demand-side management resources. The process involves evaluating the financial benefits of DSM initiatives to inform regulatory decisions.

4.3 DSM Resource Plan Development

AI summary This section discusses the development of a Demand Side Management (DSM) Resource Plan, focusing on strategies to manage energy demand, improve efficiency, and integrate programs like demand response and energy efficiency initiatives.

4.3.1 Balanced Plan Approach - E1 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; - Avoided...

AI summary E1 will develop DSM Resource Plans balancing energy and capacity avoidance, program costs, avoided investments, non-electric benefits, program diversity, business relationships, market access, and rate impacts to ensure equitable customer benefits.

4.3.3 Performance Metrics - The following performance metric definitions and performance requirements were established - under the 2016–2018 DSM Plan. [1](#page-408-4) - 4.3.3.1 Definitions - The following definitions are used: - Performan...

AI summary The section defines performance metrics, indicators, targets, and thresholds under the 2016–2018 DSM Plan, emphasizing their roles in tracking progress and ensuring compliance with Board-approved goals.

Performance Targets - Performance targets apply over the Plan period as reflected in the Board-approved DSM Purchase - Agreement or as ordered by the Board. - E1 is in substantial compliance if it achieves 90 percent or greater on each app...

AI summary E1 must achieve 90% or more of approved performance targets under the Board-approved DSM Purchase Agreement. Failure below 90% may trigger Board action. E1 will propose specific DSM resource targets, including energy savings, peak demand reductions, low-income equity measures, and demand response capacity, for Board approval.

Performance Indicators - E1 will propose DSM resource specific performance indicators within each DSM Resource Plan - application for consideration and approval by the Board. Performance indicators may include - annual incremental and cumu...

AI summary E1 will propose DSM-specific performance indicators for approval by the Board, including energy savings, peak demand reductions, low-income impacts, demand response capacity, ratepayer benefits, spending, and PAC test results, with the Board retaining authority to order additional metrics.

4.3.4 DSM Programs - E1 will propose DSM programs for Residential and the Business, Non-profit and Institutional (BNI) - sectors which may include Residential Efficient Product Rebates, Existing Residential, New - Residential, BNI Efficien...

AI summary E1 will propose Demand Side Management (DSM) programs targeting Residential and Business, Non-Profit & Institutional (BNI) sectors, including rebates, incentives, and demand response initiatives. The proposal outlines various program types such as residential and BNI efficient product rebates, custom incentives, and direct installation.

4.8.2 Quarterly Reports - E1 will file quarterly reports with the Board for quarters one through three of each year. Reporting - requirements were established under the 2013–2015 DSM Plan Settlement Agreement and - continue to evolve: [9](...

AI summary E1 is required to submit quarterly reports to the Nova Scotia Utility and Review Board, detailing program performance, variances, forecasts, and equity outcomes under the 2013–2015 DSM Plan Settlement Agreement. Reports must include mid-course adjustments, variance explanations, year-end forecasts, rate-class expenditures, and Enabling Strategies updates.

4 4.8.5 Rate and Bill Impact Analysis - 5 Each DSM Resource Plan application will include: - 6 a historical RBIA summarizing the long-term impact to rates and bills of all DSM activities up to and including those of the previous calendar y...

AI summary Each DSM Resource Plan application must include a historical RBIA and a forward-looking RBIA. NS Power is required to provide a rate-impact analysis for the proposed DSM Plan and alternate scenarios.

13 4.9 Demand Side Management Advisory Group - 14 The DSM Advisory Group is a forum intended to facilitate the timely sharing of information, - 15 exchanging of ideas, and meaningful discussion amount members on current or emerging DSM - 1...

AI summary The Demand Side Management Advisory Group (DSMAG) serves as a forum for members to share information, exchange ideas, and discuss current or emerging demand-side management (DSM) issues in a collaborative manner.

18 5. CONSOLIDATED ENDNOTES AND SOURCES - 1. M06733 E1 2016–2018 DSM Resource Plan, NSUARB Order, October 7, 2015. The Order approved the 2016–2018 DSM Plan and the Consensus Agreement. (Parties agreed to establish the Standardized Filing...

AI summary The document lists consolidated endnotes and sources from Nova Scotia regulatory proceedings, including approvals of DSM plans, directives on cost recovery, and the adoption of the PAC test. Key references include NSUARB decisions, the 2024 Energy Reform Act establishing NSIESO, and requirements for enhanced reporting and rate class analysis. Regulatory frameworks, cost-effectiveness criteria, and compliance with the Public Utilities Act are emphasized.

2025 DSM Annual Progress Report FILED March 31, 2026

AI summary The 2025 DSM Annual Progress Report, filed on March 31, 2026, provides an overview of progress in demand-side management initiatives in Nova Scotia. However, the document lacks detailed content beyond the heading and filing date.

1. EXECUTIVE SUMMARY - EfficiencyOne ("E1") delivers demand side management ("DSM") programs and is the - administrator and operator of the Efficiency Nova Scotia ("ENS") franchise. The 2025 Annual - Progress Report ("APR") summarizes E1's...

AI summary EfficiencyOne (E1) reports on its 2025 progress toward DSM program targets, including energy and demand savings. E1's 2023-2025 DSM Plan was approved by NSUARB in 2022, and its 2026 extension by NSEB in 2025. The approved plan includes $236.8M investment and four performance targets. In 2025, E1 achieved 82% progress toward the 528.7 GWh energy savings target.

2. 2025 PLAN AS APPROVED TARGETS & PORTFOLIO RESULTS 2025 Plan targets are 149.5 GWh of incremental annual net energy savings, 26.3 MW of annual net peak demand savings, 5.3 GWh of energy savings applicable to Affordable Single-family Home...

AI summary The 2025 DSM Plan achieved 87% of its energy savings target and 90% of its peak demand savings target, but fell short of the available capacity target. Residential and BNI programs scaled back participation in 2025, which contributed to lower-than-expected savings, although total spending remained within the approved investment level of $173 million.

2.1 2025 Portfolio and Program Results

AI summary The section outlines the 2025 Portfolio and Program Results, likely evaluating energy programs and their outcomes. Key focus areas may include Demand-Side Management (DSM) initiatives, cost analyses, and regulatory oversight by Nova Scotia energy boards.

Table 1: 2025 Results to 2025 Plan as Approved and 2025 Year-End Forecast 20: 25 Plan as Appro ved 2 025 Year-End Fo recast 2025 Results Results to Forecas t Resul its to Plan as App oved First-Year Energy Savings (GWh) Lifetime Energy Sav...

AI summary The table presents a comparison of 2025 results against the 2025 Plan as approved and the 2025 Year-End Forecast, including metrics such as energy savings, investment, and available capacity for various programs.

2025 Plan as Approved refers to the investment and savings targets as provided in the 2023-2025 DSM Resource Plan Compliance filing. See M10473, 2023-2025 DSM Resource Plan Compliance Filing, Appendix C, Schedule E, at page 42, October 4,...

AI summary The 2025 Plan as Approved refers to the investment and savings targets from the 2023-2025 DSM Resource Plan Compliance filing, which was approved by the NSUARB on November 8, 2022. The program status compares 2025 results to the 2025 year-end forecast and the 2025 Plan targets, using color codes to indicate variances. The New Home Construction program component of the New Residential program ended on December 31, 2023.

2.2 2025 Participation Result[s](#page-11-0) - [Table 2](#page-11-0) presents E1's 2025 participation results. The table provides a comparison of 2025 - participation results to those modelled in the 2025 Plan and the four-year Plan period...

AI summary E1's 2025 participation results show mixed outcomes compared to the 2025 Plan. Higher participation occurred in Instant Savings, Affordable Homes programs, and Business Energy Rebates due to retailer sales, faster project completion, and rebate promotions. Lower participation was observed in Efficient Product Installation (phasing out lighting measures), Green Heat (ended in 2025), and Demand Response (unpursued pathways). The Custom program exceeded energy savings despite lower participation.

1 Table 2: 2025 Participation Participation Results Unit 2023-2026 Plan as Approved 2025 Plan as Approved 2025 Results % of 2025 Results to 2025 Plan as Approved % of 2025 Results to 2023-2026 Plan as Approved Participation Unit Efficient...

AI summary Table 2 outlines the 2025 participation results for various energy efficiency programs under the 2023-2026 plan, showing performance metrics such as participation rates and units rebated. Many programs exceeded their 2025 targets, with some programs achieving over 100% of their planned participation.

2.3 2025 Expenditures - In 2025, E1's total expenditures were $60.4 million, $2.1 million, or 3.4%, below the 2025 Plan as - Approved spending level of $62.5 million. - The 2025 underspend represents lower spending by several programs, as...

AI summary In 2025, E1's total expenditures were $60.4 million, $2.1 million below the approved $62.5 million. Lower spending in programs like Demand Response and Enabling Strategies, along with budget management to stay within the $173 million 2023-2025 DSM Plan total, caused the underspend. Incentive expenditures remained comparable to 2023 and 2024 levels.

Figure 1: 2025 DSM Expenditures \ Expenditure amounts are unaudited and are rounded to the nearest hundred thousand. Expenditure amounts reported in previous quarters may have been updated and are reflected in the 2025 annual total.

AI summary The figure outlines 2025 DSM expenditures, noting that amounts are unaudited, rounded to the nearest hundred thousand, and may reflect updated figures from previous quarters.

2.4 2025 Unit Cost - Unit cost data is a calculation output of E1's investment and savings over a defined time period. - Factors that influence unit cost results typically include: - the level of participation in a program or program compo...

AI summary The 2025 unit cost for E1's portfolio was $0.44/kWh, higher than the 2025 Plan's $0.38/kWh but consistent with the year-end forecast. Residential unit costs were $0.60/kWh, higher than both the 2025 Plan and forecast, due to an eight-month pause in the Residential Behaviour program, which had a low unit cost but represented a significant portion of energy savings.

1 3. 2023-2026 DSM PLAN PERIOD 2 E1's four-year Plan period outlook provides additional insight on the DSM Plan implementation after the first three years. It includes 3 E1's actual savings results and expenditures from 2023, 2024, and 202...

AI summary E1's 2023-2026 DSM Plan includes a $236.8 million investment, targeting 90% compliance on four performance metrics: energy savings, demand savings, available capacity, and energy efficiency in affordable housing and Mi'kmaw homes. The plan incorporates actual 2023-2025 results and the 2026 approved plan.

10 Table 4: 2023-2026 DSM Plan Period 2023-2026 DSM Plan Period Forecast Plan Year Energy Savings (GWh) Demand Savings (MW) Available Capacity (MW) Energy Savings applicable to Affordable Single-family Homes, Affordable Multi-family Housin...

AI summary Table 4 presents the 2023-2026 DSM Plan Period forecast, including energy and demand savings, available capacity, and expenditures. The data indicates that actual results for 2023-2025 exceeded or met the approved targets, with some variances noted. The table references filings and approvals by the NSUARB and NSEB.

3.1 2026 Plan as Approved Assessment in 2023, 2024, and to a lesser extent, in 2025. As detailed in E1's 2026 DSM Extension filing, 2026 Plan targets for energy savings (116.0 GWh) and demand savings (18.9 MW) are consistent with E1's expe...

AI summary The 2026 DSM Plan targets 116.0 GWh in energy savings and 18.9 MW in demand savings, reflecting lower expected savings due to market changes and billing analysis updates. The plan includes adjustments from the closure of the Canada Greener Homes Grant and slower program implementation. The investment aligns with the legislated level of $63.75 million.

1 Table 5: 2026 Plan as Approved 2026 Plan as Approved First-Year Energy Savings (GWh) Peak EE Demand Savings (MW) Investment ($ million) Available Capacity (MW) Residential Energy Efficiency Programs Efficient Product Rebates 4.8 0.5 2.5...

AI summary Table 5 outlines the 2026 Plan as Approved, detailing energy savings, peak demand savings, investment amounts, and available capacity for various energy efficiency and demand response programs in Nova Scotia. The plan includes residential, BNI, enabling strategies, and demand response initiatives, with a total investment of $63.75 million and energy savings of 116 GWh.

4. 2025 PROGRAM RESULTS - This section provides an overview of 2025 results and activities for E1's Residential and BNI sector - programs including: - evaluation activities; - program results and highlights; - discussion of program varianc...

AI summary The section outlines E1's 2025 program results for Residential and BNI sector programs, including evaluation activities, results, variance explanations for programs with 25%+ deviations, savings for underserved communities, and Enabling Strategies highlights. Program rate class results are detailed in Attachment 1.

4.1 2025 Evaluation Activities Evaluation activities are conducted annually by E1's independent third-party evaluation consultant to ensure accurate determination of net electrical energy, net system-peak demand savings, and available capa...

AI summary E1 conducts annual evaluations by an independent consultant to assess DSM program effectiveness, including net energy savings and capacity. The 2025 reports include condensed or comprehensive evaluations, with Residential Behaviour exempt from tracking sheet audits due to its random selection method.

4.2 Residential Sector Results - The Residential sector consists of the following programs: - Efficient Product Rebates; and - Existing Residential. (Note: The New Home Construction program component under the New Residential program, ende...

AI summary The Residential sector in Nova Scotia achieved 46.8 GWh energy savings and 10.1 MW peak demand savings in 2025, below the 71.6 GWh and 11.3 MW targets. Programs include Efficient Product Rebates and Existing Residential. E1 provided variance explanations for programs missing targets by 25%.

4 Table 6: 2025 Residential Efficient Product Rebates RESIDENTIAL EFFICIENT PRODUCT REBATES (2025) Residential Efficient Product Rebates Energy Savings (GWh) Demand Savings (MW) Expenditure ($ million) 2025 Results 11.5 0.5 3.3 2025 Plan 1...

AI summary The 2025 Residential Efficient Product Rebates exceeded energy savings targets due to strong performance in the Instant Savings program, particularly in Q1. However, demand savings were lower than expected, influenced by higher uptake of low-demand-saving products and the closure of the Appliance Retirement program.

Program Components - Appliance Retirement retires old, inefficient household appliances (e.g., refrigerators, freezers, room air conditioners) by offering free appliance pick-up from homes, proper recycling, and a financial incentive. The...

AI summary The Appliance Retirement program retired inefficient appliances until January 2025, offering incentives and recycling. Instant Savings provides rebates for energy-efficient purchases. Both programs aim to improve energy efficiency and reduce consumption.

2 4.2.2 Existing Residential - 3 The Existing Residential program consists of the following program components: - 4 Affordable Multifamily Housing; - 5 Affordable Single-family Homes; - 6 Efficient Product Installation; - 7 Green Heat; - 8...

AI summary The Existing Residential program includes components such as Affordable Multifamily Housing, Efficient Product Installation, and Green Heat. It references the 2025 DSM Programs Evaluation Reports, Final DSM Reports, and the Residential Efficient Product Rebates Program.

1 Table 7: 2025 Existing Residential EXISTING RESIDENTIAL (2025) Existing Residential Energy Savings (GWh) Demand Savings (MW) Expenditure ($ million) 2025 Results 35.3 9.6 24.7 2025 Plan 60.6 10.2 23.6 - Existing Residential did not achie...

AI summary The 2025 Existing Residential program did not meet its energy savings targets due to the pause of the Residential Behaviour program component from May to December 2025, caused by a cybersecurity incident at NS Power and the unavailability of AMI customer data. This resulted in no energy savings being generated through this program component for eight months.

Affordable Multifamily Housing and Non-Profit Organizations Highlights - Affordable Multifamily Housing energy savings achieved were consistent with 2024, but lower than set out in the 2025 Plan as Approved, with 98 projects being complete...

AI summary Affordable Multifamily Housing energy savings in 2025 were lower than the 2025 Plan's targets, with 98 projects completed and 71 initiated (down from 2024). Key factors included reduced prescriptive mini-split heat pump savings due to 2024 Green Heat evaluation adjustments and the end of provincial DSM incentive top-ups since 2021. Mitigation efforts included process improvements, cross-team collaboration, and targeted marketing.

Efficient Product Installation Highlights • Efficient Product Installation energy and demand savings results were lower than the 2025 Plan as Approved targets, as the program component phased out its lighting measures as of July 1, 2025 Da...

AI summary Efficient Product Installation program savings fell short of 2025 targets due to phasing out lighting measures by July 2025 and shifting focus to electrician-installed measures (smart thermostats, sensors). Despite a 12% drop in average energy savings per participant, higher unitary savings from new measures offset some losses. Air-sealing and water-saving measures were paused in 2025 but reintroduced in 2026. The program also supported Residential Demand Response with 13,687 devices installed in 2025.

1 4.3 Business, Non-Profit and Institutional (BNI) Sector Results - 2 The BNI sector is comprised of the following programs: - 3 Efficient Product Rebates; - 4 Custom Incentives; and - 5 Direct Installation. 6 - 7 In 2025, the BNI sector a...

AI summary The BNI sector in Nova Scotia achieved 82.6 GWh energy savings and 13.5 MW peak demand savings in 2025, exceeding 2025 Plan targets. Key programs include Efficient Product Rebates, Custom Incentives, and Direct Installation. E1's Energy Manager initiative contributed to DSM savings, with 30 Energy Managers active by year-end. Variance explanations were provided for programs deviating by ±25% from targets.

23 4.3.1 Efficient Product Rebates 24 The 2025 Efficient Product Rebates program is marketed as Business Energy Rebates.

AI summary The 2025 Efficient Product Rebates program, marketed as Business Energy Rebates, is discussed in the context of Nova Scotia's regulatory proceedings. The NSUARB and NSEB are involved in reviewing demand-side management (DSM) initiatives, with program administrator costs (PAC) being a relevant factor.

Program Component • The Business Energy Rebates program component provides financial incentives in the form of prescriptive rebates to BNI participants through both the Application Rebates and the Instant Rebate service. Application Rebate...

AI summary The Business Energy Rebates program offers financial incentives through Application Rebates (requiring project applications to E1 via Efficiency Nova Scotia's website) and Instant Rebates via participating distributors across Nova Scotia.

2 4.3.2 Custom Incentives - 3 The Custom Incentives program consists of the following two program components: - 4 Custom; and - 5 Strategic Energy Management. 6

AI summary The Custom Incentives program includes two components: 'Custom' and 'Strategic Energy Management.' This section outlines the structure of the program within the context of a Nova Scotia regulatory proceeding involving utility and energy board oversight.

Custom Highlights • Custom exceeded its 2025 Plan as Approved energy and demand savings targets as several highsavings projects closed in 2025, consistent with a trend seen in 2024. All Custom services – Building Optimization, Retrofit, Ne...

AI summary Custom exceeded its 2025 energy and demand savings targets due to high-savings projects closing in 2025, consistent with 2024 trends. All Custom services completed projects in 2025.

Strategic Energy Management (SEM) - Strategic Energy Management supported 12 participants in 2025; nine continuing participants and three new participants. Eleven of the 12 participants achieved a combined 4.0 GWh in energy savings, which...

AI summary Strategic Energy Management (SEM) supported 12 participants in 2025, achieving 4.0 GWh in energy savings. Compressed air leak repair measures accounted for 54% of the savings. Performance-based incentives were offered to customers, with additional incentives for those in the Large Industrial initiative. The service provider contract was renewed for the same provider since 2018.

4 Table 10: 2025 Direct Installation DIRECT INSTALLATION (2025) Direct Installation Energy Savings (GWh) Demand Savings (MW) Expenditure ($ million) 2025 Results 7.9 1.4 6.3 2025 Plan 12.6 2.6 6.8 - Energy and demand savings for Direct Ins...

AI summary The 2025 Direct Installation program achieved energy and demand savings lower than the approved targets, mainly due to the program team managing spending and participation levels to align with the investment level set for the 2023-2025 DSM Plan period.

Small Business Energy Solution Highlights - Interest in the program remained strong and the number of applications was high throughout 2025, following changes to the program component in Q2 2024 – increasing the eligibility cap for busines...

AI summary The Small Business Energy Solution program saw strong interest in 2025 due to 2024 changes, including higher eligibility caps, extended preapproval windows, and increased incentives. Market research found that commercial fixture markets are LED-dominated, but lamp markets lag with non-LED inventory still present.

DIRECT INSTALLATION (2025) to serve customers who have not done a full LED retrofit, and DSM program administrators are shifting programs in response to the BNI LED transformation. As recommended by the evaluator, E1 will phase out lightin...

AI summary E1 plans to phase out lighting rebates in Small Business Energy Solutions by 2028 due to the BNI LED transformation, prompting DSM program administrators to adjust their programs.

2 4.4 Demand Response Program Results - 3 E1 launched its Demand Response program in 2023, an initiative outlined in the 2023-2025 Plan - 4 and the 2026 DSM Extension with a Performance Target at the end of 2026 of 16.3 MW of - 5 available...

AI summary E1 launched its Demand Response program in 2023, targeting 16.3 MW of available capacity by 2026. The program includes BNI (Smart Synergy) for commercial/industrial curtailment and Residential (Eco Shift) with devices like smart thermostats and EV chargers. Table 11 provides 2025 results.

17 Table 11: 2025 Demand Response DEMAND RESPONSE (2025) Demand Response New Available Demand Response Capacity (MW) Available Demand Response Capacity (MW) Expenditure ($ million) 2025 Results -1.3 6.8 3.6 2025 Plan 7.8 17.9 5.0 • Results...

AI summary In 2025, the available demand response capacity decreased from 8.1 MW in 2024 to 6.8 MW, resulting in a negative new available capacity of -1.3 MW. This underperformance was due to factors that prevented E1 from meeting its approved capacity target.

DEMAND RESPONSE (2025) - o In the Residential Demand Response program component, fewer domestic hot water direct load controllers were installed than planned, and enrolment of batteries and EV telematics and charger devices, fell short of...

AI summary The 2025 Demand Response programs faced underperformance due to lower-than-expected installations of domestic hot water controllers, reduced battery and EV device enrolment, and challenges in BNI program participation. E1, a new program, struggled with customer understanding. Expenditures remained high despite lower capacity results due to early-year foundational activities and cost structures.

Residential Demand Response Highlights

AI summary This document highlights residential demand response initiatives in Nova Scotia, involving the Nova Scotia Utility and Review Board (NSUARB) and Nova Scotia Energy Board (NSEB). It discusses Demand-Side Management (DSM) and Program Administrator Cost (PAC) within regulatory proceedings.

2024/2025 season (December 1, 2024 to February 28, 2025) results - The Residential Demand Response program component, marketed as Eco Shift, achieved 0.9 MW of available capacity during the 2024/2025 season (December 1, 2024 to February 28...

AI summary The Eco Shift demand response program achieved 0.9 MW of available capacity in the 2024/2025 season, below the 2025 Plan target. Underperformance was attributed to delayed controller installations, low EV device enrollment, and weak battery participation. Smart thermostats were the most common enrolled device.

2025/2026 season (December 1, 2025 to February 28, 2026) preparations - Eco Shift device installation ramped up throughout 2025, with 13,687 demand response eligible devices (smart thermostats and domestic hot water direct load controllers...

AI summary Eco Shift program installed 13,687 demand response devices in 2025, with 18,234 total since August 2024. E1 ensured device readiness, ran marketing campaigns, and expects residential demand response capacity to double in 2025/2026. Efforts focus on optimizing thermostat strategies and connectivity.

BNI Demand Response Highlights

AI summary The document outlines BNI's Demand Response program, emphasizing its role in Demand-Side Management (DSM) and Program Administrator Cost (PAC) under the oversight of the Nova Scotia Utility and Review Board (NSUARB) and Nova Scotia Energy Board (NSEB). Key focus areas include regulatory proceedings and cost structures.

2 4.5 Low-Income, Diverse, Underserved Communities - 3 In 2025, E1 updated its assumptions and estimation methodology for calculating impacts from - 4 E1's dedicated program components (Affordable Multifamily Housing, Affordable Single-Fam...

AI summary E1 updated its methodology for calculating low-income and equity impacts from its DSM programs in 2025. Dedicated programs like Affordable Multifamily Housing and the Mi'kmaw Home Energy Efficiency Project exclusively serve low-income communities. Non-targeted programs saw changes, including the Appliance Retirement program's end and revised assumptions for Business Energy Rebates. The methodology was filed with E1's 2026 DSM Extension Application.

4.5.1 Performance Target For the 2023-2026 Plan as Approved, the NSEB established a Performance Target of 19.8 GWh for cumulative annual energy savings applicable to Affordable Single-family Homes, Affordable Multifamily Housing, and Mi'km...

AI summary The NSEB set a 19.8 GWh energy savings target for the 2023-2026 Plan. E1 exceeded its 2025 target for Affordable Single-family Homes but fell short in Affordable Multifamily and Mi'kmaw projects, though overall targets were met. E1 forecasts achieving the 19.8 GWh cumulative target by 2026. Table 12 details 2025 results.

6 202 5 Plan as Ap proved 2025 Forec ast (Year-En d) 2025 Results Program Components First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Investment ($ million) Participation (#) First-Year Energy Savings...

AI summary The table presents projected and actual energy savings and investments for various energy efficiency programs in Nova Scotia, including Affordable Multi-family Housing, Affordable Single-family Homes, and the Mi'kmaw Home Energy Efficiency Project. The data includes metrics such as energy savings, peak demand savings, investment amounts, and participation numbers.

1 Table 13: 2025 Results Applicable to Low-Income and Underserved Communities, Non-Targeted Programs 2025 Plan Performance Indicators 2025 Forecast (Year-End) 2025 Results First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak...

AI summary Table 13 presents 2025 results for low-income and underserved communities under non-targeted programs, including energy savings, participation numbers, and expenditures. The table covers various programs such as efficient product rebates, appliance retirement, and residential behavior initiatives, with data on first-year and lifetime energy savings, peak demand reductions, and investment figures.

1 4.6 Enabling Strategies - 2 The Enabling Strategies component in the 2023-2026 DSM Plan focuses on the following three - 3 categories: - 4 Education and Outreach; - 5 Development and Research; and - 6 Other Enabling Strategies. 7 8 [Tabl...

AI summary The 2023-2026 DSM Plan's Enabling Strategies component includes three categories: Education and Outreach, Development and Research, and Other Enabling Strategies. Table 14 outlines E1's 2025 Enabling Strategy activities.

10 Table 14: 2025 Enabling Strategies ENABLING STRATEGIES 2025 Enabling Strategies category 2025 Plan as Approved expenditures ($ million) 2025 Year-end forecast expenditures ($ million) 2025 Actual Expenditures ($ million) Education and O...

AI summary 2025 Enabling Strategies actual expenditures exceeded approved plans, driven by Regulatory department activities on the 2026 DSM Extension application, E1's BCA test approval, and the 2027-2031 DSM Plan development. The plan includes strategic electrification and solar-PV resources.

Innovation activities in 2025 included: - The deep retrofit navigator pilot concluded in Q2, with all participants completing their upgrades and final paperwork. The aim of the pilot, conducted in partnership with the Halifax Regional Muni...

AI summary In 2025, Nova Scotia launched multiple innovation pilots: a deep retrofit navigator pilot with HRM, a heat pump water heater market transformation pilot, a load flexibility demand response pilot, and research on mixed electric heating control solutions. Pilots highlighted challenges like cost and time, while emphasizing navigators' role in retrofit accessibility and exploring new demand response event types. E1 also installed monitoring systems to improve heat pump efficiency.

Regulatory Affairs E1 filed the following reports (matter numbers are in brackets) with the NSUARB (January 1 to March 31, 2025) and the NSEB (April 1 to December 31, 2025): - 2024 DSM Evaluation Reports and 2024 Annual Progress Report (M1...

AI summary E1 submitted multiple reports and responses to information requests to the NSUARB and NSEB, covering DSM evaluations, financial compliance, and BCA applications. Engagement with the DSMAG included stakeholder feedback, technical sessions, and plan development. Regulatory activities included public hearings, evaluation implementation, and DSM Plan development for 2027-2031.

4.8 Incentive Reporting - In the NSUARB's Decision on the 2023-2025 DSM Plan, E1 was directed to "identify any instances - where E1 has adjusted the per unit incentive amount for a measure by more than 10% from the - amount included in its...

AI summary The NSUARB directed E1 to report any adjustments exceeding 10% in per-unit incentive amounts from the 2023-2025 DSM Plan. E1 confirmed no such adjustments occurred in Q4, complying with the directive.

4.9 Avoided CO2e emissions - E1 proactively provides the annual net avoided CO2e emissions from DSM measures installed - during each Plan year. Using the most recent NS Power emissions intensity data, E1's Evaluation - Consultant identifie...

AI summary E1 reports annual net avoided CO2e emissions from DSM measures, estimating 60,748 tonnes for 2025 using NS Power's emissions intensity data. This data is part of E1's proactive disclosure under the Plan.

5. CONCLUSION - In 2025, E1 achieved 129.4 GWh of incremental annual net energy savings (87% of the 2025 Plan - target of 149.5 GWh), 23.6 MW of annual net peak demand savings (90% of the 2025 Plan target - of 26.3 MW), 6.8 MW of available...

AI summary E1 achieved significant energy savings and demand reductions in 2025, meeting most of its 2025 DSM Plan targets. It also exceeded its target for energy savings applicable to affordable housing and the Mi'kmaw Home Energy Efficiency Project. E1 expects to meet its 2023-2026 DSM Plan performance targets and is scheduled to file its Q1 2026 DSM report on May 25, 2026.

Rate Class Expenditures - E1 reports on planned and actual DSM expenditures by rate class to aid in cost recovery - allocations.[29](#page-52-0) - The following sections provide information on E1's rate class allocation methodology, an - o...

AI summary E1 reports on planned and actual Demand-Side Management (DSM) expenditures by rate class to support cost recovery. The document outlines E1's allocation methodology, 2025 results by rate class, and the outlook for the 2023-2026 DSM Plan period.

1. RATE CLASS SPENDING ALLOCATION METHODOLOGY - As part of efforts to enhance rate class spending reporting, E1 introduced a new rate class - allocation methodology for quarterly and annual (where applicable) forecasts in 2025. This - meth...

AI summary E1 introduced a new rate class spending allocation methodology in 2025 for quarterly and annual forecasts, used to calculate 2026 DSM Plan allocations. This marks a shift from the allocation approach used in the 2023-2025 DSM Plan.

1.1 Rate class allocation for 2023-2025 DSM Plan - Rate class investment allocations for the 2023-2025 DSM Plan were the sum of rate class - allocations calculated by program component. For each program component, the spending by - rate cl...

AI summary The 2023-2025 DSM Plan's rate class allocations are determined by applying 2020 spending percentages to total program costs, except for one component where 2017-2020 data was used due to high variations.

1.2 Rate class allocation for 2026 Plan as Approved, and rate class forecasts Date Filed: March 31, 2026 Page 1 of 8 The October 7, 2015 NSUARB Order directed NS Power to file its proposed accounting treatment and cost recovery for the 201...

AI summary The 2026 rate class allocation method uses spending percentages from 2022-2024 applied to 2026 plan costs, excluding industrial classes from Education and Outreach in Enabling Strategies. The NSUARB Order of October 7, 2015, directed NS Power to file cost recovery proposals for DSM programs, referenced in M06733.

2. 2025 RESULTS BY RATE CLASS 2025 actual expenditures were slightly lower than the 2025 Plan as Approved expenditures. Similar to 2024, the medium industrial rate class had the highest spending increase compared to the 2025 Plan, driven b...

AI summary 2025 actual expenditures were slightly lower than the approved plan, with medium industrial rate class spending rising due to higher BNI Demand Response participation. Municipal and small general rate classes exceeded planned spending from increased BNI Efficient Product Rebates participation, while large general and small industrial classes had lower spending due to reduced participation in Demand Response and Custom Incentives programs. Program timing and participant mix influenced outcomes.

9 Table 1: 2025 Planned and Actual DSM Expenditures by Rate Class 2025 Expenditures by Rate Class Rate Class 2025 Plan as Approved ($ million) 2025 Forecast Expenditures ($ million) Actual 2025 Expenditures ($million) 2025 Expenditures as...

AI summary Table 1 presents the 2025 planned and actual DSM expenditures by rate class, showing that most rate classes exceeded their planned and forecast expenditures, with some classes like Large General and Small Industrial showing significant variances. The 2025 Plan as Approved refers to the 2023-2025 DSM Resource Plan Compliance filing, which was approved by the NSUARB on November 8, 2022.

1 Table 2: 2025 Residential Efficient Product Rebates Rate Class Results Residential Efficient Product Rebates (2025) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Expenditures ($ million) Housing U...

AI summary Table 2 presents the 2025 Residential Efficient Product Rebates Rate Class Results, showing energy and demand savings, expenditures, and the number of housing units/products across various rate classes. The data includes first-year and lifetime energy savings, peak demand savings, and expenditures in millions of dollars.

9 Table 3: 2025 Existing Residential Rate Class Results Existing Residential (2025) First-Year Lifetime Peak Housing Energy Energy Demand Expenditures Units / Savings Savings Savings ($ million) Products (GWh) (GWh) (MW) (#) Residential/Ch...

AI summary Table 3 presents the 2025 existing residential rate class results, showing energy and demand savings across various categories, along with expenditures and housing units. The data includes savings in gigawatt-hours and megawatts, as well as financial expenditures in millions of dollars.

1 Table 4: 2025 BNI Efficient Product Rebates Rate Class Results BNI Efficient Product Rebates (2025) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Expenditures ($ million) Units Rebated (#) Residen...

AI summary Table 4 presents the 2025 BNI Efficient Product Rebates Rate Class Results, showing energy and demand savings across various rate classes, along with expenditures and number of units rebated. Savings are net of free-ridership and spillover, and expenditures are unaudited.

13 Custom Incentives includes the Custom program component and the Strategic Energy Management program component. Strategic Energy 14 Management participants are each counted once, but their participation is ongoing throughout the year. 15...

AI summary The text describes the Custom Incentives program, which includes the Custom program component and the Strategic Energy Management program component. Strategic Energy Management participants are counted once but remain active throughout the year. The program also includes certain residential customers, such as farms and rental buildings. BNI Efficient Product Rebates similarly includes some residential participants.

1 Table 6: 2025 Direct Installation Rate Class Results Direct Installation (2025) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Expenditures ($ million) Products (#) Residential/Charitable (2,3,4) 0...

AI summary Table 6 outlines the 2025 Direct Installation Rate Class Results, showing energy and demand savings, expenditures, and number of products across various rate classes. The data indicates significant savings in energy and peak demand for residential, small general, and general rate classes, while some industrial and municipal classes show minimal or no savings.

5 Direct Installation includes the Small Business Energy Solutions program component. - 7 [Table 7 p](#page-57-0)rovides a breakdown of available capacity, expenditures, and participation achieved, by - 8 rate class within the Demand Respo...

AI summary The text references a table that provides a breakdown of available capacity, expenditures, and participation achieved by rate class within the Demand Response program, and mentions that Direct Installation includes the Small Business Energy Solutions program component.

3. 2023-2026 DSM PLAN PERIOD [Table 8 p](#page-59-0)rovides actual expenditures by rate class for 2023, 2024, and 2025, and the variances between the Plan and actuals. The table also provides the 2026 Plan as Approved expenditures by rate...

AI summary The 2023-2026 DSM Plan period shows variances in expenditures due to participation levels in programs like BNI Demand Response and Custom Incentives. Medium industrial spending rose due to higher-than-expected participation, while large general and small industrial spending fell due to lower participation. Large industrial spending increased in 2023 but aligned with the Plan in 2024-2025.

1 Table 8: 2023-2026 DSM Plan Period by Rate Class 2023 2024 2025 2026 2023-2026 Plan Rate Class Plan as Approved 2023 ($ million) Actual 2023 ($ million) 2023 Expenditures as % of 2023 Plan as Approved Exependitures Plan as Approved 2024...

AI summary This table presents the 2023-2026 DSM Plan Period by Rate Class, showing approved and actual expenditures for various rate classes. It highlights the percentage of planned expenditures against actuals for each year and the overall plan period, with references to regulatory filings and approvals.

Table 1 Update on Implementation of 2022-2023 Evaluation Recommendations Year Evaluation/ Verification Recommendation Text Source Status Comments Expected Period of Completion 2022 For any future Retrofit indoor horticultural lighting proj...

AI summary The 2022-2023 evaluation recommends that EOne use the IPMVP Option C approach for M&V in future indoor horticultural lighting projects. E1 agrees and is exploring methods and trialing a project, though delays have pushed the assessment to 2026.

6 Table 1: 2023, 2024, 2025 PAC Results 2023 2024 2025 Program Administrator Cost (PAC) Test Results (including carbon) Plan as Approved PAC Actual PAC Plan as Approved PAC Actual PAC Plan as Approved PAC Actual PAC Efficient Product Rebat...

AI summary This table presents Program Administrator Cost (PAC) results for various energy efficiency and demand response programs in Nova Scotia for the years 2023, 2024, and 2025. It includes both planned and actual costs across different initiatives, such as Efficient Product Rebates, Appliance Retirement, and Demand Response. The data is derived from the 2023-2025 DSM Resource Plan Compliance filing approved by the NSUARB.

11 was calculated. This method captures the benefits and costs over the expected lifetime of the program, including Critical Peak Pricing (CPP), an 12 estimate of NS Power costs, and benefits and costs from 2022-2031. E1's capacity and cos...

AI summary The text discusses the calculation method used for a program that includes Critical Peak Pricing (CPP) and considers the costs and benefits from 2022-2031. It references the 2023-2025 DSM Plan and the actual results from the 2023, 2024, and 2025 PAC, incorporating DR 10-year annuity payment costs and benefits.

2025 DSM PROGRAMS EVALUATION REPORTS Final DSM Reports March 24, 2026 In Collaboration with:

AI summary Final evaluation reports for 2025 Demand Side Management (DSM) programs, submitted on March 24, 2026. The document outlines collaboration efforts but lacks detailed content in the provided text.

2025 DSM PROGRAMS EVALUATION Final Report

AI summary The document presents a final report evaluating the 2025 Demand Side Management (DSM) programs in Nova Scotia, assessing their effectiveness, outcomes, and alignment with regulatory goals. It likely includes analysis of program performance, cost-benefit assessments, and recommendations for future improvements.

DEFINITIONS Accuracy Reflects the proximity of measurements to the true value. Adjustment ratio The ratio of evaluated results to tracked results. This ratio expresses the adjustment made to tracked savings or other tracked values such as...

AI summary The text provides definitions related to energy efficiency and demand response programs, including terms such as adjustment ratio, available demand response capacity, and baseline. These definitions are critical for understanding how energy savings and program effectiveness are measured.

EfficiencyOne (E1), an independent, non-profit organization, is responsible for helping Nova Scotians improve the energy efficiency of their homes and workplaces by designing, marketing, and delivering demand-side management (DSM) for Nova...

AI summary EfficiencyOne (E1), a non-profit organization, delivers demand-side management (DSM) programs through the Efficiency Nova Scotia (ENS) franchise. E1's 2025 DSM program portfolio achieved significant energy and demand savings, including 129.444 GWh in net electrical energy savings and 60,748 tonnes of CO2 eq in avoided emissions. Econoler, along with other evaluators, conducted the evaluation of these programs.

1 Evaluation Scopes and Objectives The 2025 Portfolio Evaluation Plan was based on the Evaluation Schedule outlined in the Overall Strategic Evaluation Plan[4](#page-10-1) that provides the framework and approach to guide evaluation planni...

AI summary The 2025 Portfolio Evaluation Plan is based on the Overall Strategic Evaluation Plan and outlines factors for prioritizing evaluation activities, including program savings, uncertainty, changes in program design, regulatory requirements, and evaluation scheduling. The plan includes three evaluation categories: impact, process, and market evaluations.

Table 1: 2025 Portfolio Evaluation Plan PY2025 Program Components Impact Process Market Residential DSM Program Components Appliance Retirement Condensed Instant Savings Condensed Affordable Multifamily Housing Condensed Affordable Single-...

AI summary Table 1 outlines the 2025 Portfolio Evaluation Plan, detailing the evaluation approach for various program components under residential and BNI DSM programs. Most programs are evaluated using a condensed approach, while some, like Residential Behaviour and Strategic Energy Management, require comprehensive evaluations. The table also notes that certain programs have ended or are subject to specific evaluation conditions.

1.1 Impact Evaluation Objectives and Scope The impact evaluation activities were aimed at determining: - › Gross electrical energy and peak demand savings at the meter and at the generator - › Available DR capacity for DR programs - › Net-...

AI summary The impact evaluation objectives include assessing energy savings, demand response capacity, net-to-gross ratios, effective useful life, and GHG emissions. Two evaluation types (comprehensive and condensed) are outlined, with factors like program maturity and complexity influencing their application.

Demand-side Management Measure Assessment Document The impact evaluation scope for 2025 also included an update of the Demand-side Management Measure Assessment (DSM MA) document. The DSM MA was updated to include new products added to pro...

AI summary The 2025 update to the DSM MA document focused on aligning with updated program offerings, removing outdated products (e.g., lighting from Instant Savings), revising algorithms for residential and commercial measures, and correcting technical inconsistencies. Annual adjustment ratios were also updated. Key changes included additions like smart thermostat load control and removals such as specific LED fixtures and heat pump water heaters.

Table 2: 2025 Participant and Non-participant Surveys Program Component Number of Respondents BNI Business Energy Rebates – Application Rebates 57 Demand Response Residential Demand Response 103 Total 160 › In-depth interviews with program...

AI summary Table 2 presents survey data from 2025 participant and non-participant surveys, including 160 respondents across BNI programs such as Business Energy Rebates and Residential Demand Response. In-depth interviews were conducted with 70 market actors and stakeholders between May 2025 and January 2026 to evaluate program impacts, including free-ridership and spillover effects.

Table 3: 2025 Interviews Completed Program Component 1 Program Manager/ E1 Staff/Business Development Manager Service Providers/ Distributors/Retailers/Builders Participants Program Manager in Other Jurisdictions Residential Appliance Reti...

AI summary Table 3 outlines the number of interviews conducted in 2025 for various program components, including Residential, Business Energy Rebates, and Demand Response. The data indicates the involvement of program managers, service providers, participants, and managers from other jurisdictions.

Site Visits and Project Reviews with Follow-up Site Visits or Interviews The Evaluator performed a total of 133 project reviews during the summer and fall of 2025, 49 of which were complemented through site visits and 24 were complemented...

AI summary The Evaluator conducted 133 project reviews in 2025, including site visits and phone interviews, to assess various energy efficiency programs. These reviews included validation of EFLHs for Affordable Multifamily Housing and technical reviews for Business Energy Rebates and other programs, with follow-ups to gather data on free-ridership and participant feedback.

Table 4: 2025 Site Visits and Project Reviews with Follow-up Site Visits or Interviews Program Component Project Reviews Followed by Site Visits Project Reviews Followed by Phone Interviews Project Reviews Without Site Visits or Phone Inte...

AI summary Table 4 outlines the 2025 site visits and project reviews conducted under various programs, including Affordable Multifamily Housing, Business Energy Rebates, Strategic Energy Management, and Demand Response, with specific numbers of reviews followed by site visits, phone interviews, or no follow-up.

2.1.4 Metering or Billing Data Analyses In 2025, a Residential Behaviour billing analysis was performed on the months for which AMI data were available (i.e. January to April 2025)[7](#page-18-3) to calculate net electrical energy savings,...

AI summary In 2025, a Residential Behaviour billing analysis used AMI data (Jan-April 2025) to assess net electrical energy savings via difference-in-difference methods. Metering data analyses for Residential Demand Response updated inservice rates and DR capacities for smart thermostats, EV controls, and batteries during Dec 2024–Feb 2025, focusing on winter DR events.

Table 5: Comparison of 2025 Evaluated and Tracked Electrical Energy Savings at the Generator a Program Component Tracked Results Evaluated Results DSM Program Annual Gross Savings (GWh) Annual Net Savings (GWh) Annual Gross Savings (GWh) N...

AI summary Table 5 compares the evaluated and tracked electrical energy savings from various programs in 2025. It includes data on residential and BNI programs, showing gross and net savings, net-to-gross ratios, lifetime savings, and net realization rates for each component.

Table 6: Comparison of 2025 Evaluated and Tracked Peak Demand Savings at the Generator a Program Component Tracked Results Evaluated Results Difference DSM Program Annual Gross Savings (MW) Annual Net Savings (MW) Available Capacity (MW) A...

AI summary Table 6 compares the evaluated and tracked peak demand savings at the generator for various programs in 2025. It highlights differences in net savings and available capacity across residential, BNI, and demand response programs, with varying net realization rates.

4.1.1 Residential DSM Programs

AI summary The section outlines residential demand-side management (DSM) programs, focusing on initiatives to improve energy efficiency and reduce consumption in residential sectors through various measures and incentives.

Instant Savings - › Instant Savings surpassed its net electrical energy savings target by 18% and fell short of its peak demand savings target by 52%. - › Following the removal of LED lighting products and dehumidifiers from the Instant Sa...

AI summary Instant Savings exceeded its net electrical energy savings target by 18% but missed its peak demand savings target by 52%. Participation dropped 71% after removing LED lighting and dehumidifiers. Controls now account for 61% of rebated products and 68% of energy savings. Discrepancies exist between evaluator and E1 tracked savings, and the program's NTGR was updated to 0.77 in 2025.

Existing Residential In 2025, the net electrical energy savings for Existing Residential reached 35.274 GWh at the generator, while the net peak demand savings amounted to 9.584 MW at the generator. Existing Residential is comprised of Aff...

AI summary In 2025, Existing Residential programs achieved 35.274 GWh net electrical energy savings and 9.584 MW peak demand savings. The programs include Affordable Multifamily Housing, Affordable Single-family Homes, Efficient Product Installation, Green Heat, Home Energy Assessment, Mi'kmaw Home Energy Efficiency Project, and Residential Behaviour.

Residential Behaviour - › Residential Behaviour has been paused since May 2025 due to a cybersecurity incident at NS Power in spring 2025 whereby AMI data were no longer available. The evaluation was, therefore, limited to the four months...

AI summary Residential Behaviour program was paused in May 2025 due to a cybersecurity incident at NS Power, limiting evaluation to January-April 2025. Achieved 5.555 GWh savings, falling short of the planned 29.771 GWh.

4.1.2 Business, Non-profit, and Institutional DSM Programs

AI summary This section outlines demand-side management (DSM) programs targeting business, non-profit, and institutional sectors in Nova Scotia, focusing on initiatives like energy efficiency incentives, rebates, and demand response strategies to reduce energy consumption and costs.

Business Energy Rebates - › In 2025, BER achieved 40.244 GWh in net electrical energy savings and 5.332 MW in net peak demand savings at the generator, thus exceeding by 5% the planned net electrical energy savings of 38.451 GWh and fallin...

AI summary In 2025, Business Energy Rebates (BER) exceeded planned electrical energy savings by 5% but fell 26% short of peak demand savings targets. Participation in Application Rebates dropped 36%, reducing overall savings. Adjustments to ratios for lighting and HVAC measures, along with higher NTGR values, impacted tracking accuracy. Revisions to the tracking sheet slightly increased savings but raised error risks.

Custom Incentives In 2025, Custom Incentives achieved 34.519 GWh in net electrical energy savings and 6.744 MW in net peak demand savings at the generator through its two components, namely Custom and Strategic Energy Management. Custom co...

AI summary In 2025, Custom Incentives achieved 34.519 GWh in net electrical energy savings and 6.744 MW in net peak demand savings through its Custom and Strategic Energy Management components. Custom includes Retrofit, Pay-for-Performance, New Construction, and Building Optimization services.

Custom - › Custom achieved 30.487 GWh in net electrical energy savings and 6.372 MW in net peak demand savings at the generator in 2025, thereby surpassing by 26% the planned electrical energy savings of 24.160 GWh and by 32% the planned p...

AI summary Custom program achieved 30.487 GWh in electrical energy savings and 6.372 MW in peak demand savings in 2025, exceeding targets by 26% and 32% respectively. Participation trends, adjustment ratios (0.993–1.011 for Retrofit), free-ridership levels (8%–38%), and a 8% discrepancy between Evaluator and E1 savings tracking were reported.

Strategic Energy Management - › In 2025, SEM achieved 4.031 GWh in net electrical energy savings and 0.372 MW in net peak demand savings at the generator, thus exceeding the 2.657 GWh target by 52% and the planned 0.289 MW in net peak dema...

AI summary In 2025, Strategic Energy Management (SEM) exceeded energy and peak demand savings targets by 52% and 29%, respectively, with 11 completed projects. However, energy savings per participant declined. Compressed air leak repairs contributed 54% of savings, and E1's measurement guidelines were largely followed despite evaluator adjustments.

4.1.3 Demand Response DSM Programs

AI summary The section discusses Demand Response DSM Programs, focusing on their role in demand-side management, including program design, participant incentives, and evaluation metrics. Key aspects include the integration of demand response with broader energy efficiency initiatives and regulatory oversight.

The Evaluator reviewed the EUL values of all measures offered by E1 and their associated lifetime electrical energy savings. The Evaluator found that the DSM portfolio generated 1,476.864 GWh in lifetime net electrical energy savings. [17]...

AI summary The Evaluator analyzed the EUL values of measures in the E1 DSM portfolio, finding that the portfolio generated 1,476.864 GWh in lifetime net electrical energy savings. The weighted average EUL of the measures is 11.4 years, with building envelope measures like insulation contributing significantly to lifetime savings.

Table 8: 2025 Evaluated Net Lifetime Electrical Energy Savings at the Generator DSM Program Program Component Annual Net Electrical Energy Savings (GWh) Lifetime Net Electrical En ergy Savings (GWh) Weighted Average EUL (years) Share of An...

AI summary Table 8 presents the 2025 evaluated net lifetime electrical energy savings at the generator for various DSM programs, including appliance retirement, efficient product rebates, and home energy assessments. The table highlights the contribution of residential and BNI programs to annual and lifetime energy savings, with the residential subtotal contributing 36% of annual and 45% of lifetime savings, and BNI programs contributing 64% of annual and 55% of lifetime savings.

The Evaluator established the reduced GHG emissions due to the DSM portfolio at 60,748 tonnes of CO2 eq in terms of annually avoided net GHG emissions. [Table](#page-36-1) 9 below presents the GHG emission reductions of each program compon...

AI summary The Evaluator determined that the DSM portfolio resulted in 60,748 tonnes of CO2 eq in annual avoided net GHG emissions. Table 9 provides a breakdown of GHG emission reductions by program component and the overall portfolio in 2025.

Table 9: 2025 Evaluated GHG Emission Reductions DSM Program Program Component Gross Annual Avoided GHG Emissions in CO2 eq Tonnes Net Annual Avoided GHG Emissions in CO2 eq Tonnes Residential Efficient Appliance Retirement 96 54 Product Re...

AI summary Table 9 presents evaluated GHG emission reductions from various DSM programs in 2025, showing both gross and net annual avoided emissions in CO2 eq tonnes. The data includes contributions from residential and business programs, with specific values for each component such as appliance retirement, efficient product rebates, and home energy assessments.

5 DSM Portfolio Performance This section presents a comparison of evaluated savings with E1 planned savings at the program and component levels. It also presents satisfaction results, annual savings performance, as well as the historical p...

AI summary This section compares evaluated savings with E1 planned savings at program and component levels, detailing satisfaction results, annual savings performance, and historical contributions of individual program components to overall portfolio savings.

Table 10: 2025 Planned Net Savings and Evaluated Results Planned Savings Evaluated Results Variance Program Component and DSM Program Net Electrical Energy Savings (GWh) Net Peak Demand Savings (MW) Available DR Capacity (MW) Net Electrica...

AI summary Table 10 outlines the 2025 planned net savings and evaluated results for various residential and BNI programs under Demand Side Management (DSM). The data highlights discrepancies between planned and actual savings and capacity, with some programs showing significant variances.

5.3 Historical Portfolio Analysis This subsection presents year-over-year program performance (GWh electrical energy savings) and the contribution of individual program components to portfolio savings (% electrical energy savings). [Table]...

AI summary This subsection provides a year-over-year analysis of program performance in terms of electrical energy savings (GWh) and the contribution of individual program components to overall portfolio savings (% electrical energy savings). Tables 11, 12, and 13 offer a historical overview of program component performance and changes in the DSM portfolio composition.

Table 11: Evaluated Net Electrical Energy Savings at the Generator, 2020-2025 Electrical Energy Savings (GWh) Electrical Energy Savings (%) DSM Program Program Component 2020 2021 2022 2023 2024 2025 2020 2021 2022 2023 2024 2025 Residenti...

AI summary This table presents evaluated net electrical energy savings by program and year from 2020 to 2025, highlighting contributions from residential and BNI (Business, Non-profit, and Institutional) programs. It includes energy savings from initiatives like appliance retirement, efficient product rebates, and home energy assessments, with percentages indicating the share of total savings.

b Residential Behaviour was introduced in 2024. c Custom includes four services: Retrofit, Pay-for-Performance, New Construction, and Building Optimization. d Strategic Energy Management includes Energy Management Information System since...

AI summary The text introduces new developments in residential behavior programs, outlines custom services under the Residential Behaviour initiative, and notes the merger of Strategic Energy Management with Energy Management Information Systems in 2022.

Table 12: Evaluated Net Peak Demand Savings at the Generator, 2020-2025 DSM Peak Demand Savings (MW) Peak Demand Savings (%) Program Program Component 2020 2021 2022 2023 2024 2025 2020 2021 2022 2023 2024 2025 Residential Residential Appl...

AI summary Table 12 evaluates the net peak demand savings from various energy efficiency programs in Nova Scotia from 2020 to 2025, highlighting the contributions of residential, BNI, and overall portfolio programs in reducing peak demand in megawatts and percentages.

c Strategic Energy Management includes Energy Management Information Systems. In 2023, the two program components were merged. b Custom includes four services: Retrofit, Pay-for-Performance, New Construction, and Building Optimization.

AI summary Strategic Energy Management has been expanded to include Energy Management Information Systems, and in 2023, two program components were merged. Custom services include Retrofit, Pay-for-Performance, New Construction, and Building Optimization.

Table 13: Evaluated Net Available DR Capacity, 2023-2025 DSM Program Component (MW) Available DR Capacity Available DR Capacity (%) Program 2023 2024 2025 2023 2024 2025 Demand Response Demand Residential Demand Response 0.058 0.057 0.854...

AI summary Table 13 shows the evaluated net available demand response (DR) capacity for 2023-2025, with BNI Demand Response contributing the majority of capacity. In 2025, E1 achieved 129.444 GWh in net electrical energy savings and 23.556 MW in net peak demand savings, but both metrics decreased compared to 2024.

uction can be achieved for the grid. - › Program documentation has not kept pace with program changes. - The Evaluator noted that Residential DR program changes, dates of program changes. and rationales thereof are not clearly documented i...

AI summary The Residential Demand Response (RDR) program faces documentation gaps, with program changes not clearly recorded. While participant retention is high (90%), integration with EPI (Efficient Product Installation) has led to 40% non-enrollment in RDR among EPI participants. Issues include lack of unique identifiers and incomplete device data collection by installers.

Business Energy Rebates – Instant Rebates To validate 2024 market evaluation results and determine timing for when a baseline for Business Energy Rebates – Instant Rebates LED fixtures should take effect as well as to identify the implicat...

AI summary A market study evaluated the Business Energy Rebates – Instant Rebates program, noting increased LED adoption in commercial lighting markets, declining prices, and shifts in distributor practices. The study also identified implications for baseline adjustments and program adaptations in response to market transformation.

CONCLUSIONS AND RECOMMENDATIONS Overall, 2025 evaluated net electrical energy savings and peak demand savings for the E1 DSM portfolio were 129.444 GWh and 23.556 MW respectively above the values tracked by E1, while available DR capacity...

AI summary The 2025 evaluation of the E1 DSM portfolio shows energy and peak demand savings above tracked values, but DR capacity was below. A cross-cutting recommendation calls for reviewing how savings are distributed between DSM-funded and government-funded programs, especially for whole home renovations, to ensure clear and aligned savings calculation approaches.

Table 14: 2025 Recommendations on Residential Program Components No. Recommendation ASFH/HEA/MHE EP – R1 Review how savings are distributed between DSM-funded and government-funded programs for whole home renovation program components (HEA...

AI summary The recommendation focuses on reviewing how savings are distributed between DSM-funded and government-funded programs for whole home renovation components, ensuring that savings calculation approaches are clearly defined and aligned, particularly for households with both electric and non-electric heating systems.

Components Bibliographic References Southern California Edison, Pool Pump Demand Response Potential, June 2008, p. 19. Northeast Energy Efficiency Partnership (NEEP), Mid-Atlantic Technical Reference Manual Version 10, May 2020, p. 195. Hy...

AI summary The document lists bibliographic references from various studies and reports on energy efficiency, demand response, and load forecasting, including works by Southern California Edison, Hydro-Québec, and Nova Scotia Power. These sources cover topics like heat pump systems, technical reference manuals, and energy use analysis.

Program Components Bibliographic References National Renewable Energy Laboratory, "Chapter 21: Estimating Net Savings – Common Practices", The Uniform Methods Project, October 2017, p. 3, available at: https://www.nrel.gov/docs/fy17osti/68...

AI summary The document includes references to energy efficiency evaluation methods and programs, citing sources such as the National Renewable Energy Laboratory and the Nova Scotia Utility and Review Board. It also references reports from Nova Scotia Power and Emera Inc. related to emissions and annual performance.

Calculation of the Weighted Average of Adjustment Ratios In 2025, the Evaluator used a stratified sample for BNI DR, selecting the 20 largest projects and 10 randomly selected projects among the 138 remaining projects. Therefore, the weigh...

AI summary In 2025, the Evaluator calculated a weighted average adjustment ratio of 0.615 for BNI DR using a stratified sample of 30 projects, combining 20 largest and 10 randomly selected projects from 138. The formula incorporated stratum weights and capacity metrics to reflect project distribution.

Calculation of the Standard Error Since the overall adjustment ratio is based on a stratified weighted average, the Evaluator also calculated a stratified weighted standard error for the adjustment ratio instead of a simple standard error....

AI summary The Evaluator calculated a stratified weighted standard error for the adjustment ratio using a formula from the Uniform Methods Project (UMP) Chapter 11, resulting in a standard error of 160 for evaluated available DR capacity. This approach accounts for stratified sampling in adjustment ratio calculations.

Where: H is the number of strata (2) and h represents each stratum. - $N_h$ is the number of projects in the population for a stratum. - $n_h$ is the number of projects in the sample for a stratum. & lt;sup>2 Khawaja, M.S., Rushton, J. and...

AI summary The text outlines statistical methods for calculating adjustment ratios in demand response (DR) capacity evaluations, using strata-based sampling. It presents formulas for weighted standard error calculations and notes a weighted standard error of 160 for BNI DR projects. The methodology references the Uniform Methods Project by NREL.

Calculation of the Margins of Error The margin of error on the adjustment ratio of BNI DR available DR capacity was established by using the following formula, which compares the error in evaluated available DR capacity divided by the eval...

AI summary The margin of error for BNI DR's adjustment ratio was calculated using a 90% confidence level (t=1.699) and a sample size of 30, resulting in a 7.1% margin. For small programs like SEM, a census approach was used, eliminating the need for margin calculations. The methodology applies to BER-AR, Custom, and BNI DR programs in 2025.

NTGR Calculations Free-ridership algorithm Low Free-i Partici • High Free-ric Participa Medium Free-ri Participa D5. [ASK ONLY IF DLC Premium=YES] Without the Business Energy Rebates Program, what is the ikelihood that you would have purch...

AI summary The text presents a table related to free-ridership algorithms and includes questions about the Business Energy Rebates Program and the likelihood of purchasing DLC Premium LED lighting products without the program. It also references efficiency scores and energy-efficient lighting products.

RESIDENTIAL EFFICIENT PRODUCT REBATES PROGRAM Final Report 2025 DSM EVALUATION March 4, 2026

AI summary Final Report on the 2025 DSM Evaluation for the Residential Efficient Product Rebates Program, dated March 4, 2026. The document assesses the program's effectiveness in promoting energy-efficient product adoption and its alignment with broader demand-side management goals.

ABBREVIATIONS ARCA ARCA Canada Inc. ARet Appliance Retirement ASFH Affordable Single-family Homes BNI Business, non-profit, and institutional DA Delivery agent DR Demand response DSM Demand-side management DSM MA Demand-side Management Mea...

AI summary This document provides a list of abbreviations and their full forms used in the Nova Scotia regulatory proceeding, including terms related to energy efficiency, demand-side management, and utility programs.

[Table](#page-83-0) 2 below presents the participation levels, NTGRs, evaluated gross and net savings at the generator, annual GHG emission reductions, as well as effective useful life (EUL) values for each program component and for Reside...

AI summary The text discusses the 2025 DSM MA, a reference document that provides parameters for calculating energy and peak demand savings from E1's DSM program portfolio. It includes effective useful life values for all measures and refers to these values for the evaluation conducted during the last year of the 2023-2025 DSM cycle.

Instant Savings Findings and Recommendations This subsection presents the key findings from the 2025 Instant Savings evaluation. The Evaluator has no specific recommendation for Instant Savings. 2025 Instant Savings-Finding: Instant Saving...

AI summary The 2025 Instant Savings program exceeded its net electrical energy savings target by 18% but missed peak demand savings by 52%. Participation dropped 71% after removing LED lighting and dehumidifiers. Controls now dominate rebated products (61%), and discrepancies exist between evaluated and tracked savings (NTGR: 0.77 vs. 0.98).

Program Tracked and Evaluated Savings [Table](#page-85-0) 3 below compares E1 tracked electrical energy and peak demand savings to evaluated savings at the generator. The realization rate and NTGR are also presented and correspond to the r...

AI summary The table compares E1 tracked electrical energy and peak demand savings to evaluated savings at the generator, highlighting realization rates and NTGR values, which are calculated as the ratio of net savings to gross savings.

INTRODUCTION EfficiencyOne (E1), an independent and non-profit organization, is responsible for helping Nova Scotians improve the energy efficiency of their homes and workplaces by designing, marketing, and delivering demand-side managemen...

AI summary EfficiencyOne (E1), a non-profit organization, manages demand-side management (DSM) programs in Nova Scotia, funded by Nova Scotia Power (NS Power) ratepayers. E1's 2025 DSM program portfolio includes the Residential Efficient Product Rebates program, which has two components: Appliance Retirement (ARet) and Instant Savings. ARet was discontinued in January 2025, and an evaluation report was commissioned by E1.

Table 4: Types of Evaluation Conducted for Each Program Component, 2025 2025 Program Program Component Process Market Impact Residential Efficient Product Rebates ARet Condensed Instant Savings Condensed For each program, the Evaluator pre...

AI summary Table 4 outlines the types of evaluation conducted for each program component in 2025, including the Residential Efficient Product Rebates and Instant Savings. The Evaluator prepared a DSM evaluation report detailing key findings, energy savings, peak demand savings, and GHG emissions avoided.

1.1 ARet Description Through ARet, E1 promotes the retirement of old, inefficient household appliances such as refrigerators, freezers, room air conditioners, and dehumidifiers. ARet educates Nova Scotians about the cost of maintaining old...

AI summary ARet, managed by E1, retires inefficient household appliances in Nova Scotia, offering rebates and free pick-up services. ARCA Canada Inc. handles collection and recycling. Eligibility requires appliances to be 10+ years old, with specific size and rebate criteria. The program aimed for 1.247 GWh energy savings in 2025 but was discontinued in January 2025.

3.2.2 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 7...

AI summary Peak demand savings in Nova Scotia occur during 5 p.m.–7 p.m. on non-holiday weekdays from December to February. Unitary peak demand savings remained unchanged in 2025, with detailed calculations provided in the 2025 DSM MA.

3.2.3 Interactive Effects Interactive effects occur when the implementation of an energy efficiency measure has an impact on the energy consumption of other elements such as heating and cooling equipment. For ARet, retiring old appliances...

AI summary Interactive effects from appliance retirement (ARet) influence heating and cooling loads, with older appliances releasing more waste heat. The 2025 DSM MA evaluates these effects, concluding they are negligible (0% factor). This impacts energy consumption calculations for efficiency programs.

5.3 Participation History In 2025, 113,696 eligible products were rebated in participating stores across Nova Scotia, a total that represents a decrease of 71% compared to 2024. As presented in [Table](#page-103-1) 13 below, sales of ENERG...

AI summary In 2025, rebate participation in Nova Scotia saw a significant decrease in sales of ENERGY STAR certified LED products, attributed to changes in the Instant Savings program following the 2024 'Lights Out' campaign. However, sales of control products, such as timers and thermostats, increased substantially, contributing the majority of energy savings.

Table 14: 2025 Instant Savings Evaluation Approach Evaluation Objective Research Question Methodology Calculate gross results › Are the data in the tracking sheet complete, accurate, and consistent? › Are the unitary savings for appliance...

AI summary This section outlines the evaluation approach for the 2025 Instant Savings program, focusing on calculating both gross and net results. It includes methods such as tracking sheet audits, DSM Measure Assessment updates, literature reviews, and GHG emission reduction calculations.

Measure Assessment Update A unitary savings review was conducted for certain measures to update the DSM MA following the change to a LED baseline assumption for residential lighting. This prompted the removal of all rebates on LED lamps an...

AI summary The DSM MA was updated following a LED baseline assumption change, removing LED lamp rebates (except motion-sensor units), adjusting lighting control wattage, and revising EUL values. Savings algorithms for smart thermostats and fans were also updated. Amendment 18 to Canada's Energy Efficiency Regulations was reviewed but found to have no impact on Instant Savings during this evaluation period.

7.2.1 Installation Rates The installation rates of products sold under Instant Savings are assumed to be 100% except for smart power controllers for audiovisual equipment (smart power strips) for which the installation rate is assumed to b...

AI summary Installation rates for products under Instant Savings are assumed to be 100%, except for smart power strips at 86%. The 2025 DSM MA provides further details on these assumptions.

7.2.2 Unitary Energy Savings [Table](#page-108-1) 15 below summarizes the tracked and evaluated electrical energy savings values for the product categories rebated through Instant Savings, which were revised as part of the 2025 DSM MA upda...

AI summary The document discusses revisions to unitary energy savings values for LED products, lighting controls, and smart thermostats as part of the 2025 DSM MA update. Changes are attributed to new baseline assumptions and algorithm updates. The Evaluator also reviewed Amendment 18 to Canada's Energy Efficiency Regulations and found no impact on unitary savings for rebated products.

Table 15: 2025 Instant Savings Tracked and Evaluated Unitary Energy Savings[15](#page-108-4) Product Tracked Savings [kWh/year] Evaluated Savings [kWh/year] Dimmer Switches 8.20 3.42 Indoor Motion Sensors with Dimmer Switches 25.9 10.8 Out...

AI summary Table 15 presents the tracked and evaluated energy savings for various products under the 2025 Instant Savings program. The data shows a significant difference between tracked and evaluated savings, indicating potential discrepancies in the actual energy savings achieved by these products.

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 defined as the coldest days (with an on-peak t...

AI summary The document discusses updates to unitary peak demand savings for energy efficiency measures, particularly LED products and lighting controls, as part of the 2025 DSM MA. These updates were made following discussions with the Evaluator and changes to the LED baseline assumption for residential lighting products. The table summarizes the tracked and evaluated savings for rebated products.

Table 16: 2025 Instant Savings Tracked and Evaluated Unitary Peak Demand Savings Product Tracked Savings [W] Evaluated Savings [W] ENERGY STAR Certified LED Fixtures with Motion Sensors 32.6 2.37 Dimmer Switches 1.33 0.554 Solar Fixtures 1...

AI summary Table 16 presents the tracked and evaluated unitary peak demand savings for various energy-efficient products in 2025. The table includes products like LED fixtures, dimmer switches, and bathroom fans, with significant differences between tracked and evaluated savings. Section 7.2.4 discusses interactive effects related to these savings.

7.2.5 Effective Useful Life The Evaluator validated the EUL values based on the 2025 DSM MA. The EUL values are used in the calculation of electrical energy savings that are expected to persist over time. [Table](#page-109-3) 17 below summ...

AI summary The Evaluator validated updated Effective Useful Life (EUL) values based on the 2025 DSM MA, which are used to calculate electrical energy savings over time. EUL values for LED fixtures with motion sensors and solar fixtures were updated due to a change in the LED baseline assumption, while other measures remained unchanged. The gross and net weighted average EUL for Instant Savings was set at 9.3 years.

Table 18: Evaluated 2025 Instant Savings Gross Electrical Energy and Peak Demand Savings LED Non-A- type Lamps LED ENERGY STAR LED Fixtures 0.44 Product Category R, BR, and Decorative Others Recessed Downlight Fixtures Without Motion Senso...

AI summary Table 18 presents evaluated 2025 instant savings for gross electrical energy and peak demand savings across various product categories, including LED lamps, fixtures, and motion sensors. It includes metrics such as unitary energy savings, installation rates, and lifetime energy savings.

Evaluated 2025 Instant Savings Gross Electrical Energy and Peak Demand Savings (Continued) Product Category Efficient Combined Washers/Dryers Room Air Purifiers Dehumidifiers Pool Pumps Heat Pump Water Heaters High-efficiency Dishwashers B...

AI summary The document evaluates the 2025 Instant Savings Gross Electrical Energy and Peak Demand Savings for various product categories. It includes data on the number of units installed, energy savings, and peak demand savings, along with adjustments for interactive effects. Smart thermostats for electric heat and dimmer switches are noted as having the most significant impact on savings revisions.

Table 23: Evaluated 2025 Instant Savings Net Electrical Energy and Peak Demand Savings LED Non-A-ty /pe Lamps LED EN ERGY STAR Fixture es · Dimensor Indoor Outdoor #Product Category R, BR, and Decorative Others Recessed Downlight Fixtures...

AI summary Table 23 presents evaluated 2025 instant savings for net electrical energy and peak demand savings across various product categories, including LED lamps, fixtures, and motion sensors, with calculations for gross and net savings, NTGR, line loss factors, and effective useful life.

7.4 Realization Rate [Table](#page-122-1) 24 below compares the electrical energy and peak demand savings established through this evaluation to those tracked by E1. It also includes the realization rate, representing the ratio of evaluate...

AI summary This section discusses the realization rate, which is the ratio of evaluated net savings to tracked net savings for electrical energy and peak demand savings. It references a table comparing 2025 Instant Savings tracked by E1 and evaluated savings at the generator.

Gross Savings NTGR Net Savings Realization Rate Value Unit Value Value Unit Value Electrical Energy Savings Tracked Savings by E1 16.337 GWh 0.98 15.981 GWh 72% Evaluation Results 14.817 GWh 0.77 11.430 GWh Tracked Savings by E1 0.757 MW 0...

AI summary The table presents energy savings data, including gross and net savings, NTGRs, and realization rates for electrical energy savings tracked by E1 and evaluation results. NTGRs are calculated as the ratio of net savings to gross savings and vary by product category.

APPENDIX IV Instant Savings Net-to-Gross Ratio Literature Review

AI summary This literature review examines the Instant Savings Net-to-Gross Ratio (NTGR), a metric used to evaluate the effectiveness of energy efficiency programs. It focuses on how NTGR quantifies the relationship between immediate cost savings and total program costs, influencing decisions on demand-side management (DSM) and incentive structures.

EfficiencyOne

AI summary The document introduces EfficiencyOne (E1) within the context of Nova Scotia's regulatory proceedings, focusing on energy efficiency programs and related acronyms. It highlights topics such as demand-side management, appliance retirement, and heat pump initiatives, while referencing Efficiency Nova Scotia and Nova Scotia Power.

EXISTING RESIDENTIAL PROGRAM Final Report 2025 DSM EVALUATION March 13, 2026

AI summary The document presents the Final Report of the 2025 Demand-side Management (DSM) Evaluation for the Existing Residential Program, dated March 13, 2026. It assesses the program's performance and outcomes as part of Nova Scotia's energy efficiency initiatives.

EXECUTIVE SUMMARY This report presents the 2025 demand-side management (DSM) results of the Existing Residential program administered by EfficiencyOne (E1). This program is comprised of seven components: (1) Affordable Multifamily Housing...

AI summary This report details the 2025 demand-side management (DSM) outcomes for EfficiencyOne's Existing Residential program, which includes components like Affordable Multifamily Housing, Efficient Product Installation, and Home Energy Assessments. The program promotes energy efficiency through financial incentives and direct installations in residential and affordable housing sectors.

Table 2: Overall 2025 Existing Residential Participation and Evaluated Savings Participation Level Gross Savings NTGR Net Savings Value Unit Value Unit Value Value Unit AMH Electrical Energy Savings 98 Projects 1.378 GWh 1.00 1.378 GWh Lif...

AI summary Table 2 presents the 2025 residential participation and evaluated savings across various programs, including energy savings, GHG emission reductions, and net-to-gross ratios (NTGR). The data highlights participation levels, gross and net savings, and the effective useful life (EUL) of different initiatives such as AMH, ASFH, EPI, Green Heat, HEA, MHEEP, and Residential Behaviour.

AMH Findings and Recommendations This subsection presents the key findings from the 2025 AMH evaluation. The Evaluator has no specific recommendation for AMH. 2025 AMH-Finding: In 2025, AMH achieved 1.378 GWh in net electrical energy savin...

AI summary The 2025 AMH evaluation found that the program achieved 1.378 GWh in net electrical energy savings (27% below target) and 0.648 MW in peak demand savings (13% above target). Participation increased by 18% to 98 projects, with 19% higher energy savings and 14% higher peak demand savings compared to 2024. EFLH values were correctly applied to prescriptive heat pump projects, and savings aligned with E1 tracking.

ASFH Findings and Recommendations This subsection presents the key findings from the 2025 ASFH evaluation. The Evaluator has no specific recommendation for ASFH. 2025 ASFH-Finding: ASFH achieved 6.135 GWh in net electrical energy savings a...

AI summary The 2025 ASFH program exceeded its energy and peak demand savings targets by 114% and 183%, respectively, with 1,920 homes participating—a 59% increase from 2024. Energy savings were 1% higher than E1-tracked figures due to inclusion of 2024 unclaimed savings from non-modelled heat pump measures.

Residential Behaviour Findings and Recommendations This subsection presents the key findings from the 2025 Residential Behaviour evaluation. The Evaluator has no specific recommendation for Residential Behaviour. 2025 Residential Behaviour...

AI summary The 2025 Residential Behaviour evaluation found the program paused since May 2025 due to a NS Power cybersecurity incident, limiting data to January–April 2025. Achieved 5.555 GWh savings (vs. target 29.771 GWh). No specific recommendations were made.

Table 3: Comparison of 2025 Tracked and Evaluated Savings at the Generator Gross Savings NTGR Net Savings Realization Rate Value Unit Value Unit Electrical Energy Savings Tracked Savings by E1 1.378 GWh 1.00 1.378 GWh 100% Evaluation Resul...

AI summary Table 3 compares tracked and evaluated savings for various energy efficiency programs in Nova Scotia in 2025, including electrical energy and peak demand savings. The table includes data for programs such as Affordable Multifamily Housing, Affordable Single-family Homes, Efficient Product Installation, Green Heat, and others, with metrics like Net-to-Gross Ratios and Realization Rates.

EfficiencyOne (E1), an independent and non-profit organization, is responsible for helping Nova Scotians improve the energy efficiency of their homes and workplaces by designing, marketing, and delivering demand-side management (DSM) for N...

AI summary EfficiencyOne (E1) is an independent, non-profit organization responsible for designing, marketing, and delivering demand-side management (DSM) programs in Nova Scotia through the Efficiency Nova Scotia (ENS) franchise. E1's 2025 DSM program portfolio includes residential and BNI programs, and it commissioned Econoler to evaluate these programs. The evaluation report focuses on the Existing Residential program and outlines comprehensive and condensed impact evaluation methods.

Table 4: Types of Evaluations Conducted for Each Program Component, 2025 2025 Program Program Component Process Market Impact Existing Residential AMH Condensed ASFH Condensed EPI Condensed Green Heat Condensed HEA Condensed MHEEP Condense...

AI summary Table 4 outlines the types of evaluations conducted for each program component in 2025, including program components like AMH, ASFH, EPI, Green Heat, HEA, and MHEEP, with a focus on impact assessments. The Residential Behaviour component received a comprehensive evaluation involving cumulative billing analysis using AMI data.

1.1 AMH Description AMH provides affordable housing owners and non-profit organizations, such as rehabilitation or transition houses, with incentives for building-wide energy retrofit projects with the intent of reducing electrical and non...

AI summary AMH provides incentives for energy retrofits in affordable multifamily housing and non-profits, requiring energy audits unless prescriptive measures are used. Funding comes from electricity ratepayers and the Province of Nova Scotia, with updated incentive amounts and energy savings targets for 2025. Two project paths (comprehensive and prescriptive) are outlined, with savings calculated via modeling tools or the 2025 DSM MA.

EUL Update Using the effective useful life (EUL) values for common measures presented in the 2025 Demand-side Management Measure Assessmen[t](#page-166-2) 2 (DSM MA) and the proportions of savings generated by individual measures implement...

AI summary The Evaluator calculated an average Effective Useful Life (EUL) for comprehensive projects using EUL values from the 2025 DSM MA and savings proportions from AMH projects. The 2025 DSM MA serves as a reference for calculating energy savings and EUL values for E1's DSM program measures.

3.2.1 Electrical Energy Savings For AMH, the Evaluator typically multiplies tracked savings by adjustment ratios to establish evaluated savings. In 2025, no previously established adjustment ratios were applied to electrical energy savings...

AI summary The Evaluator discusses electrical energy savings evaluation methods for AMH, noting that 2025 adjustments omitted ratios due to high error margins. A 2024 EFLH value update for mini-split heat pumps was validated via desk reviews, allowing tracked savings to be used for 2025 evaluations. Other projects also relied on tracked savings due to unacceptably high error margins in prior adjustment ratios.

3.2.2 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 defined as the colde...

AI summary Peak demand savings in Nova Scotia are calculated during cold peak periods (Dec-Feb, 5-7 PM) using a 0.283 W/kWh ratio from the 2025 DSM MA for comprehensive projects and equations for prescriptive ones. The 2025 AMH evaluation used tracked savings directly without adjustment ratios.

3.2.3 Interactive Effects In a home, interactive effects occur when the implementation of energy efficiency measures has an impact on the energy consumption of other factors such as heating and cooling. The interactive effects of space hea...

AI summary Interactive effects in energy efficiency measures impact heating and cooling in homes. Comprehensive projects already account for these effects via engineering calculations or simulations, while the 2025 DSM MA includes them for prescriptive projects when applicable.

3.4 Realization Rate [Table](#page-172-1) 10 below compares the electrical energy and peak demand savings established through the 2025 evaluation to those calculated in the 2025 tracking sheet. It also includes the realization rate, repres...

AI summary This section discusses the realization rate, comparing evaluated net savings from the 2025 evaluation to tracked net savings in the 2025 tracking sheet, focusing on electrical energy and peak demand savings.

4 AMH Key Findings and Recommendations As mentioned previously, the main objectives of the 2025 AMH evaluation were as follows: › Calculate AMH gross and net results, namely first-year and lifetime electrical energy savings, peak demand sa...

AI summary The 2025 AMH evaluation found that while net electrical energy savings targets were unmet (1.378 GWh vs. 1.880 GWh target), peak demand savings exceeded expectations (0.648 MW vs. 0.572 MW target). Participation reached a record high with 98 projects, and EFLH values were correctly applied to heat pump projects. Savings tracked by E1 aligned with evaluator calculations.

Table 11: Implementation Status of Past Recommendations for ASFH # Past Recommendations Status Comments 2024-ASFH-R7 Update the DA/contractor training guides on the record keeping/reporting processes and use of the software tools to reflec...

AI summary The document discusses the implementation status of past recommendations for Affordable Single-family Homes (ASFH), specifically the update of DA/contractor training guides. E1 has completed the recommendation by updating training guides and providing regular training sessions, including monthly meetings and ad-hoc training related to software tools.

7.2 Gross Savings For ASFH, the gross savings associated with building envelope and heat pump measures are calculated based on pre-retrofit and post-retrofit HOT2000 simulations, while the gross savings associated with smart thermostats ar...

AI summary The section outlines methodology for calculating gross savings for Affordable Single-family Homes (ASFH), including simulation approaches for building envelope and heat pump measures, unitary values for smart thermostats, and retroactive adjustments to non-modelled heat pump calculations post-2024 DSM evaluation. The Evaluator applied updated methods retroactively from April 2024, affecting reported savings.

Non-modelled Energy Savings Smart thermostats are not modelled in HOT2000. Instead, electrical energy savings are calculated based on unitary energy savings values from the 2025 Demand-side Management Measure Assessment (DSM MA),[10](#page...

AI summary Non-modelled energy savings for smart thermostats and heat pumps are calculated using the 2025 DSM MA and 2024 Green Heat analysis. Savings are allocated between electrical and non-electrical sources based on electric space heating percentages in ASFH programs, with no modifications to unitary savings values in the 2025 DSM MA.

7.2.2 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 7...

AI summary Peak demand savings in Nova Scotia are calculated using a 0.283 MW/GWh ratio from Navigant's 2016-2018 DSM Plan for ASFH, with exceptions for heat pumps. The 2025 DSM MA provides unitary peak demand savings values, which were not revised in 2025. Smart thermostats use separate calculations, and the Evaluator validated Navigant's method.

7.2.3 Interactive Effects In a home, interactive effects occur when the implementation of energy efficiency measures has an impact on the energy consumption of other factors such as heating and cooling. Since ASFH building envelope and hea...

AI summary The text explains that interactive effects occur when energy efficiency measures impact other home energy factors. ASFH and heat pump measures directly target heating/cooling loads, so no additional factors are applied. Smart thermostats aren't modeled in HOT2000 and don't affect other elements, so no interactive effects for them.

7.2.4 Effective Useful Life As part of the 2025 DSM MA activities, the Evaluator reviewed the EUL values used in the calculation of electrical energy savings that are expected to persist over time. The EUL values for building envelope upgr...

AI summary The Evaluator reviewed Effective Useful Life (EUL) values for building envelope upgrades and space heating equipment in 2025 DSM MA activities. These values, based on installations by HEA and ASFH participants, remained unchanged for all ASFH measures in 2025.

7.3.1 Evaluated Net Savings Net savings are defined as the changes in energy use that are specifically attributable to ASFH. Since spillover and free-ridership effects were considered nil, the net electrical energy savings are equal to the...

AI summary Evaluated Net Savings for Affordable Single-family Homes (ASFH) show 114% and 183% exceedance of electrical energy and peak demand targets. Net savings equal gross savings due to nil spillover and free-ridership. GHG emission reductions match gross reductions. Data sources include Nova Scotia Power and Emera Inc.

7.4 Realization Rate [Table](#page-186-1) 18 below compares the electrical energy and peak demand savings established through this evaluation to those calculated in the 2025 tracking sheet. It also includes the realization rate, representi...

AI summary The text introduces a realization rate, which is the ratio of evaluated net savings to tracked net savings, comparing electrical energy and peak demand savings from the current evaluation to those in the 2025 tracking sheet.

8 ASFH Key Findings and Recommendations As previously mentioned, the main objectives of the 2025 ASFH evaluation were as follows: › Calculate gross and net ASFH results, namely electrical first-year and lifetime energy savings, peak demand...

AI summary The 2025 ASFH program exceeded electrical energy and peak demand savings targets by 114% and 183%, respectively. Participation grew by 59% compared to 2024, with 1,920 homes enrolled. Evaluator results aligned closely with E1's tracking, differing by only 1% due to unclaimed 2024 savings from non-modelled heat pumps.

9.1 EPI Description EPI provides participants with free-of-charge direct installations of energy efficient products. EPI has played a pivotal role in transforming the residential lighting market by making energy efficient products more aff...

AI summary EPI provides free direct installations of energy-efficient products, focusing on electrician-installed measures to support residential demand response. The program has shifted its focus from lighting to other energy-efficient products since June 2025. E1 contracts service providers to deliver EPI across the province, and the program is available to both homeowners and renters.

Table 20: Implementation Status of Past Recommendations for EPI # Past Recommendations for EPI Status Comments 2024- EPI-R1 Recommendation #1: To improve the smart thermostat installation rate, explore and implement strategies to reduce th...

AI summary This table outlines the implementation status of past recommendations for the Efficient Product Installation (EPI) program. Recommendation #1 focused on improving smart thermostat installation rates by reducing participant dissatisfaction and disconnections through follow-up calls, installer education, and additional educational materials. E1 implemented several measures, including automated emails, refresher training, mandatory installations, and communication protocols. The Evaluator acknowledges the improvements made.

9.3 Participation History As presented in [Figure](#page-190-1) 9 below, EPI had 9,245 DSM participants, which represents a 7.5% decrease in participation compared to 2024 levels.[14](#page-190-2) In 2025, 90,666 efficient products were in...

AI summary EPI's DSM participation dropped 7.5% in 2025, with efficient product installations declining 40% due to LED phase-out. Despite lower product volumes, average savings fell only 12% due to higher efficiency from electrician-installed products. Smart thermostats now drive 51% of energy savings despite comprising only 11% of installations.

Calculations Using Evaluation Results Building on all the above methods and collected data, the Evaluator calculated first-year and lifetime electrical energy and peak demand savings per the calculation methodology presented in Subsection...

AI summary The Evaluator calculated first-year and lifetime electrical energy and peak demand savings using collected data and methodologies outlined in Subsection 11.2, focusing on energy efficiency and demand-side management outcomes.

11.2 Gross Savings For EPI, gross savings correspond to the change in energy consumption resulting from installing energy efficient products in participant homes compared to the consumption level had those installations not occurred. [16](...

AI summary Gross savings for EPI are calculated as the energy consumption reduction from installing efficient products in homes, compared to baseline consumption. The Evaluator used the 2025 DSM MA and applied a 2019 adjustment ratio to correct discrepancies in lamp replacement tracking.

11.2.2 Unitary Energy Savings For EPI, E1 establishes separate unitary savings values for single-family homes and apartments. For the 2025 evaluation, the Evaluator used the unitary savings values from the 2025 DSM MA. That document provid...

AI summary EfficiencyOne (E1) establishes separate unitary energy savings values for single-family homes and apartments using the 2025 DSM MA document, which details inputs, references, and calculations for EPI's product types.

11.2.3 Unitary 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 demand peak period in Nova Scotia is between 5 p...

AI summary Unitary peak demand savings refer to demand reductions during Nova Scotia's peak electricity period (5-7 PM, Dec-Feb). The Evaluator uses the 2025 DSM MA, which provides parameters for calculating energy and peak demand savings for E1's DSM programs, including effective useful life values for measures.

11.2.4 Interactive Effects In a home, interactive effects occur when the implementation of energy efficiency products has an impact on the energy consumption of other elements such as heating and cooling. In the case of EPI, replacing ligh...

AI summary Interactive effects occur when energy efficiency products, like LED lighting and hot water insulation, alter heating and cooling demands in homes. The 2025 evaluation used factors from the DSM MA to calculate energy savings, considering product type, location, and home type.

11.2.6 Effective Useful Life The EUL values used in the calculation of electrical energy savings that are expected to persist over time are presented in the 2025 DSM MA. The equivalent EUL values are applied to each product gross and net f...

AI summary The Effective Useful Life (EUL) values in the 2025 DSM MA are used to calculate long-term electrical energy savings. Equivalent EUL values are applied to gross and net first-year savings, resulting in differing weighted average EUL values for gross and net lifetime savings. Subsections 11.2.7 and 11.3.4 provide further details.

Table 22: Evaluated 2025 EPI Gross Electrical Energy and Peak Demand Savings per Measure - Single-family Homes LED Lamps Product Category 9 W Replacing 29 W 40 W 43 W 60 W 72 W 100 W 150 W Number of Units Number of Units 238 244 7,833 498...

AI summary Table 22 evaluates the 2025 EPI gross electrical energy and peak demand savings per measure for single-family homes, focusing on LED lamps replacing various wattage bulbs. The table provides data on installation rates, energy savings, and adjustment ratios across different wattage categories.

Evaluated 2025 EPI Gross Electrical Energy and Peak Demand Savings per Measure - Single-family Homes (Continued) Consumer Electronics and Accessory Lighting Product Category Solar Security Fixtures Indoor Motion Sensors Outdoor Motion Sens...

AI summary The document evaluates the 2025 EPI Gross Electrical Energy and Peak Demand Savings per Measure for single-family homes, providing data on various product categories including solar security fixtures, motion sensors, and dimmer switches, with details on installation rates, energy savings, and peak demand reductions.

LED Lamps Product Category 18 W Replacing 100 W PAR20 7 W Replacing 50 W PAR38 15 W Replacing 90 W PAR38 15 W Replacing 120 W PAR38 15 W Replacing 150 W Number of Units Number of Units 55 39 - - - Installation Rate (%) 94% 94% 94% 94% 94%...

AI summary The table provides details on LED lamp installations, including the number of units, installation rates, energy savings, and peak demand savings for various product categories. It includes factors such as interactive effects, line loss, and adjustment ratios, which are used to calculate gross energy savings at the meter and generator.

Table 24: Evaluated 2025 EPI Gross Electrical Energy and Peak Demand Savings Total for Single family Homes Total for Apartments Grand Total Number of Units Number of Units 87,456 3,210 90,666 Installation Rate (%) 91% 92% 91% Number of Uni...

AI summary Table 24 evaluates the 2025 EPI (Efficient Product Installation) program's gross electrical energy and peak demand savings, showing data for single-family homes and apartments. It includes metrics like installation rates, energy savings, and line loss factors, with calculations based on weighted averages for different product types and rate codes.

GHG Emission Reduction Calculations To calculate net avoided GHG emissions (in CO₂ equivalent) for Green Heat, the Evaluator multiplied net energy savings by the most recent Nova Scotia-specific GHG emission factor for electricity generati...

AI summary The document outlines methods for calculating net avoided GHG emissions for Green Heat by multiplying energy savings with Nova Scotia-specific emission factors from NS Power. It references the 2025 DSM MA as a key resource for evaluating energy savings and useful life values of DSM measures.

15.2 Gross Savings For Green Heat, gross savings correspond to the change in energy consumption resulting from actions taken by participants compared to the consumption level had those actions not occurred. [22](#page-30-0) For the 2025 ev...

AI summary The text defines gross savings for Green Heat as the change in energy consumption due to participant actions, referencing the 2025 DSM MA for evaluation. It emphasizes measuring consumption differences between scenarios with and without program participation.

15.2.2 Unitary Energy Savings To establish Green Heat unitary savings, the Evaluator relied on a combination of billing analyses, energy models, engineering algorithms, and literature reviews. The 2025 DSM MA provides a detailed descriptio...

AI summary The Evaluator used billing analyses, energy models, and literature reviews to establish Green Heat unitary savings. The 2025 DSM MA provides detailed inputs and calculations for measure categories, with no updates to unitary energy savings values.

15.2.3 Unitary 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 defined as...

AI summary Peak demand savings in Nova Scotia are defined as savings occurring during the coldest days (−15 °C) between 5 p.m. and 7 p.m. from December to February on non-holiday weekdays. No updates were made to unitary peak demand savings values in the 2025 DSM MA, referencing NREL's Uniform Methods Project for definitions.

15.3 Effective Useful Life As part of the 2025 DSM MA activities, the Evaluator reviewed the EUL values used in the calculations of electrical energy savings that are expected to persist over time. All EUL values used in previous years rem...

AI summary The 2025 DSM MA review confirmed that EUL values from prior years remained unchanged. Equivalent EUL values were applied to gross and net first-year electrical energy savings to calculate lifetime savings, resulting in differing weighted average EUL values (18.0 years for gross savings).

Table 34: Evaluated 2025 Green Heat Gross Electrical Energy and Peak Demand Savings MS MSHPs Measure Fully Electrical Mainly Electrical CASHPs Air-to-water Heat Pumps Wood Stoves Pellet Stoves Number of Units 649 16 16 1 121 29 Electrical...

AI summary Table 34 evaluates the 2025 Green Heat gross electrical energy and peak demand savings for various heating measures, including fully electrical and mainly electrical systems, as well as heat pumps and stoves. It provides unitary and gross energy savings at both the meter and generator levels, along with effective useful life and peak demand savings.

Evaluated 2025 Green Heat Gross Electrical Energy and Peak Demand Savings (Continued) Measure Wood Fireplace Wood Furnaces/Boilers – Inserts Electric Resistance Baseline ETS DHW Heater Timers Total Number of Units 3 1 79 29 944 Electrical...

AI summary The document presents a table evaluating the 2025 Green Heat Gross Electrical Energy and Peak Demand Savings for various measures, including Wood Fireplace Inserts, Electric Resistance Baseline, ETS, and DHW Heater Timers. It highlights energy savings at the meter and generator levels, along with peak demand savings, and notes that tracked and evaluated savings were the same for all measures in 2025.

Table 38: Evaluated 2025 Green Heat Net Electrical Energy and Peak Demand Savings MS HPs D. H. ( Measure Measure Fully Electrical Mainly Electrical CASHPs AWHPs Wood Stoves Pellet Stoves Electrical Energy Savings Gross Electrical Energy Sa...

AI summary Table 38 evaluates the 2025 Green Heat program's net electrical energy and peak demand savings, showing significant shortfalls compared to targets. The data includes savings from various measures and factors like line loss and effective useful life.

Table 39: Comparison of 2025 Green Heat Tracked and Evaluated Savings at the Generator Gross Savings Net Savings Realization Value Unit NTGR Value Unit Rate Electrical Energy Savings Tracked Savings by E1 1.414 GWh 0.53 0.749 GWh Evaluatio...

AI summary Table 39 compares tracked and evaluated savings from the 2025 Green Heat program, showing gross and net energy and peak demand savings, along with realization rates. The table includes data from EfficiencyOne (E1) and evaluation results, with NTGR values provided as a ratio of net to gross savings.

19.2.1 Installation Rates Installation rates represent the proportion of products recorded in the tracking sheet and that remain installed in participant homes. Based on the 2025 DSM MA, installation rates for all HEA measures were estimat...

AI summary Installation rates track the proportion of products installed in participant homes. The 2025 DSM MA estimates 100% installation rates for HEA measures, confirmed by EAs during the E assessment.

Reporting Requirements HEA incentives originate from three sources of funding: Nova Scotia Power ratepayers for DSM, the Province of Nova Scotia, and the Government of Canada (CGH Grant). The inclusion of the CGH Grant as a co-funder of en...

AI summary HEA incentives are funded by Nova Scotia Power ratepayers (DSM), the Province of Nova Scotia, and the Canada Greener Homes Grant (CGH). Savings are reported to NSEB via DSM evaluations and the Province via government-funded reports. DSM focuses on electrical savings, while government reports emphasize participation and GHG reductions. Equations in Appendix XI address double-counting, and solar PV savings are included in DSM reports regardless of heating source.

19.2.3 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 demand peak period in Nova Scotia is defined as the cold...

AI summary Peak demand savings refer to electricity demand reductions during Nova Scotia's peak period (coldest days between 5-7 PM in Dec-Feb). Calculations differ for measures modeled in HOT2000 versus prescriptive measures under Home Energy Assessments.

Measures Modelled in HOT2000 For measures modelled in HOT2000, peak demand savings are calculated by differentiating between MSHP savings and all other modelled measure savings using the following procedure: › For participants who installe...

AI summary The text explains how peak demand savings are calculated in the HOT2000 model for measures, particularly distinguishing between MSHP (Mini-split Heat Pump) savings and all other modelled measure savings. Calculations depend on whether participants meet specific conditions, including the use of a peak demand-to-energy ratio of 0.283 MW/GWh for non-MSHP measures.

Table 43: Unitary Peak Demand Savings Values for Mini-split Heat Pumps Variable Symbol Value Rated Heating Capacity of the New Heat Pump at Outdoor Air Temperature of -15 °C [kBTU/h] 𝐻𝐶𝑚𝑖𝑛 Specification data for each installed system Coeff...

AI summary Table 43 outlines the unitary peak demand savings values for mini-split heat pumps, including parameters such as rated heating capacity, coefficient of performance for baseline and new equipment, and conversion factors. The table provides specification data for each installed system.

Table 44: Evaluated 2025 HEA Gross Electrical Energy and Peak Demand Savings Measure Category HOT2000 Modelled Measures Wood Burning Equipment HPWHs Energy Efficiency Measure Subtotal Solar PV Measures Total Number of Participants 2,775 17...

AI summary Table 44 evaluates the 2025 Home Energy Assessment (HEA) gross electrical energy and peak demand savings across various measures, including heat pump and building envelope measures, wood burning equipment, and heat pump water heaters. The table provides data on participants, installed capacity, energy savings, and peak demand savings with and without adjustment ratios.

Table 49: 2025 HEA Unconverted D Assessment Spillover Savings Parameters Total Number of Unconverted D Assessment Participants 2,069 Ratio of Unconverted D Assessment Participants Who Implemented at Least One Measure 54% Total Number of Un...

AI summary Table 49 discusses the 2025 HEA Unconverted D Assessment Spillover Savings, detailing participants who implemented energy efficiency measures and the associated energy and demand savings. It notes that some participants previously had savings attributed to them but later participated in HEA, necessitating the reversal of prior savings to prevent double counting.

Table 50: 2025 HEA Unconverted D Assessment Spillover Reversals Parameters Spillover Savings Claimed Prior to 2024 Spillover Savings Claimed in 2024 Total Total Number of Unconverted D Assessment Spillover Participants from Previous Years...

AI summary Table 50 outlines the 2025 HEA Unconverted D Assessment Spillover Reversals, showing the number of participants, savings ratios, and energy savings metrics. The data highlights the impact of reversing prior spillover savings claims and the effectiveness of energy efficiency measures.

Table 51: 2025 Program Overlap Savings Deducted from HEA Overlap Net Electrical Energy Savings at the Generator (GWh) Net Peak Demand Savings at the Generator (MW) Overlap with Green Heat (0.008) (0.009) Overlap with EPI (0.077) (0.013) To...

AI summary Table 51 presents the net electrical energy and peak demand savings from program overlaps in 2025, specifically with the Green Heat and EPI programs, resulting in total savings of -0.085 GWh and -0.021 MW, respectively. Section 19.3.6 discusses the evaluated net savings from these overlaps.

19.4 Realization Rate [Table](#page-58-1) 53 below compares the electrical energy and peak demand savings established through this evaluation to those calculated in the 2025 tracking sheet. It also includes the realization rate, representi...

AI summary This section compares the electrical energy and peak demand savings from the evaluation to those in the 2025 tracking sheet, including the realization rate, which is the ratio of evaluated net savings to tracked net savings for both energy and peak demand.

20 HEA Key Findings and Recommendations As mentioned previously, the main objectives of the 2025 HEA evaluation were as follows: › Calculate gross and net results, namely electrical first-year and lifetime energy savings, peak demand savin...

AI summary The 2025 HEA evaluation found that HEA exceeded energy savings targets but saw a drop in participation linked to the CGH Grant closure. Average savings per home fell due to reduced solar PV measures, and savings matched E1's tracking.

21.3 Participation History As presented in [Figure](#page-61-0) 25 below, 157 participants completed projects and achieved electrical energy savings under MHEEP in 2025, representing an 18% decrease in participation (i.e. participants who...

AI summary In 2025, MHEEP saw an 18% drop in participants achieving electrical energy savings compared to 2024, despite stable average savings per participant. Total program savings fell by 16% for energy and 34% for peak demand, attributed to reduced participation.

22 MHEEP Evaluation Approach The 2025 MHEEP evaluation comprised a condensed impact evaluation. The main objectives of the 2025 MHEEP evaluation were as follows: › Calculate MHEEP gross and net results, namely first-year and lifetime elect...

AI summary The 2025 MHEEP evaluation focused on calculating gross and net results, including first-year and lifetime electrical energy savings, peak demand savings, and avoided GHG emissions, through a condensed impact evaluation approach.

Non-modelled Measures Programmable thermostats are not modelled in HOT2000. Instead, resulting energy savings are calculated based on unitary electrical energy savings values from the 2025 Demand-side Management Measure Assessment (DSM MA)...

AI summary Programmable thermostats are not modeled in HOT2000, with energy savings calculated via unitary electrical values from the 2025 DSM MA. The document notes no modifications to non-modelled MHEEP measures in the 2025 evaluation, referencing the DSM MA as a detailed resource for E1's DSM program parameters and savings calculations.

23.2.2 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 in Nova Scotia are calculated during winter evenings (5-7 p.m., Dec-Feb). MHEEP uses a 0.283 MW/GWh ratio for space heating, validated by Navigant's 2016-2018 DSM Plan. Heat pumps are treated separately since 2021, with unitary savings based on capacity factors. Programmable thermostats use unitary values from the 2025 DSM MA, with no 2025 revisions.

23.2.3 Interactive Effects In a home, interactive effects occur when the implementation of energy efficiency measures has an impact on the energy consumption of other elements such as heating and cooling. The interactive effects of the spa...

AI summary The text discusses interactive effects in energy efficiency measures, noting that HOT2000 simulations already account for these effects. Programmable thermostats, not modelled in HOT2000, are stated to have no interactive impacts, so no adjustments are required for this measure in the 2025 DSM MA.

23.2.4 Effective Useful Life As part of the 2025 DSM MA activities, the Evaluator reviewed the EUL values used in the calculation of electrical energy savings that are expected to persist over time. The EUL values for building envelope upg...

AI summary The Evaluator reviewed Effective Useful Life (EUL) values for building envelope upgrades and space heating equipment in the 2025 DSM MA activities, noting that EUL values for MHEEP measures remained unchanged. Calculations rely on data from HEA and MHEEP participants' installed measures.

23.2.5 Evaluated Gross Savings Non‑modelled measures were not installed under MHEEP in 2025. Accordingly, all MHEEP annual gross savings are generated from modelled measures, the results of which are presented in [Table](#page-67-0) 56 bel...

AI summary Non-modelled measures were not installed under MHEEP in 2025, so all annual gross savings are from modelled measures, as detailed in Table 56.

23.4 Realization Rate A comparison of the gross and net electrical energy and peak demand savings values established through this evaluation and those tracked by E1 is presented i[n Table](#page-69-0) 58 below. The table also includes the...

AI summary This section compares gross and net electrical energy and peak demand savings values from the evaluation with those tracked by E1, presenting a realization rate that represents the ratio of evaluated net savings to tracked net savings for both electrical energy and peak demand savings.

25 Residential Behaviour Overview This section describes the Residential Behaviour program component, follows up on past evaluation recommendations, and provides an overview of participation history.

AI summary This section outlines the Residential Behaviour program, its evaluation follow-ups, and participation history. It emphasizes program oversight and historical engagement data as key components of the regulatory analysis.

25.1 Description Residential Behaviour, publicly branded as Efficiency Insights, is designed to help Nova Scotia Power (NS Power) residential customers reduce their electricity consumption. The component provides a subset of customers with...

AI summary Residential Behaviour (Efficiency Insights) by Nova Scotia Power helps customers reduce energy use via personalized Home Energy Reports and advice. Funded under E1's 2023-2025 DSM Plan, the program was paused in 2025 due to a cybersecurity incident disrupting AMI data access.

26 Residential Behaviour Evaluation Approach The 2025 Residential Behaviour evaluation consisted of an impact evaluation using a billing analysis for the months in 2025 for which AMI data were available (i.e. January to April 2025). The pr...

AI summary The 2025 Residential Behaviour evaluation aimed to calculate electrical first-year energy savings and avoided GHG emissions using a billing analysis of AMI data from January to April 2025. The process evaluation was postponed due to the timing of report delivery.

Table 60: 2025 Residential Behaviour Evaluation Approach Evaluation Objectives Research Questions Methodology Calculate net results › What are the evaluated first-year net electrical energy savings? › Is the participation level in other EN...

AI summary Table 60 outlines the 2025 Residential Behaviour Evaluation Approach, focusing on calculating net results through billing analysis and GHG emission reductions. The evaluation examines first-year energy savings, participation levels in ENS programs, and GHG emission reductions using AMI data from January to April 2025.

27 Residential Behaviour Impact Evaluation The objectives of the 2025 Residential Behaviour impact evaluation were to determine net electrical energy savings. The savings calculation methodology for Residential Behaviour is based on evalua...

AI summary The 2025 Residential Behaviour Impact Evaluation aims to quantify net electrical energy savings using a randomized controlled trial (RCT) methodology, comparing outcomes between treatment and control groups to ensure unbiased savings estimates.

27.2.1 Treatment and Control Group Selection and Equivalency Check To yield accurate and unbiased results when calculating savings under a RCT approach, the treatment and control groups must be selected properly so that the two groups are...

AI summary The document discusses the selection and equivalency check of treatment and control groups in the 2024 DSM evaluation. The Evaluator ensured statistical equivalence by comparing pre-program energy consumption data and geographical locations. No changes were made to the groups in 2025, except for inactive participants or those who switched to solar rate codes.

Table 62: Distribution of Geographical Locations of Households Active in 2025 Wave Region Control Treatment Number of Accounts43 16,204 91,877 HRM 38.83% 38.90% 1 – High Users Cape Breton 14.20% 14.23% Rest of Mainland NS 46.97% 46.87% Num...

AI summary Table 62 presents the geographical distribution of households active in 2025, categorized by wave (High, Medium, Low Users), region (HRM, Cape Breton, Rest of Mainland NS), and treatment (Control vs. Treatment). The data shows slight variations in distribution across regions and waves, with HRM consistently having the highest proportion of active households.

Where: - › _ℎ = The average control group daily consumption over the given post-program period - › _ℎ = The average treatment group daily consumption over the given post-program period - › _ℎ = The average control group daily consumption o...

AI summary The Evaluator adjusted the cumulative savings calculation to account for varying numbers of participating households with AMI data. Savings percentages remain below 1% after 12 months, as the Residential Behaviour program is still ramping up.

Table 63: 2025 Evaluated Cumulative Electrical Energy Savings Parameters and Results Cumulative Savings Wave 1 – High Users Initial Number of Active Participants - Treatment Group 91,877 Attrition Rate (%) 1.1% Total Number of Treatment Da...

AI summary Table 63 presents the 2025 evaluated cumulative electrical energy savings from three waves of a program, showing varying levels of savings across high, medium, and low users. The highest savings are observed in the high user group, with total savings of 3.716 GWh, while the low user group shows no measurable savings.

27.2.4 Peak Demand Savings No peak demand savings targets were set for Residential Behaviour and no peak demand savings were calculated as part of the 2025 evaluation.

AI summary No peak demand savings targets were established for Residential Behaviour, and no such savings were calculated in the 2025 evaluation.

27.2.6 Effective Useful Life For Residential Behaviour, energy savings are assessed annually through a billing analysis that serves to calculate the change in electricity consumption between the program evaluation year (post-program period...

AI summary Residential Behaviour programs assess annual energy savings using billing analysis comparing pre- and post-program electricity consumption. A one-year Effective Useful Life (EUL) is applied because savings calculations reflect both first-year and long-term savings. This approach aligns with practices in Massachusetts, Illinois, Vermont, and New York.

Table 65: First-year Savings Deductions Calculation for 2025 Wave Program Component Average Net Savings per Household (GWh)45 Proportion of Increased Participation in Treatment Group (%) Average Number of Active Treatment Participants in 2...

AI summary Table 65 calculates first-year savings deductions for the Green Heat program under Wave 2 – Medium Users. The average net savings per household is 0.000793 GWh, with 0.0821% participation increase in the treatment group and 91,358 active participants in 2025, resulting in 0.0198 GWh of savings deductions.

Savings Deductions to Be Applied in 2025 [Table](#page-85-0) 66 below presents the total savings deduction to be applied in 2025 for increased participation in other programs, which corresponds to the sum of 2025 first-year savings deducti...

AI summary The document discusses the application of savings deductions in 2025 for increased participation in other programs, noting that savings for Residential Behaviour were calculated only for the first four months of 2025 and adjusted by a factor of 4/12.

Table 66: 2025 Savings Deductions Program Compone/nt Savings Deduction Year of the Program EUL Savings Deduction to Be Applied in 2025 Wave 1 – High Users Lifetime Savings Deductions Green Heat 2024 Year 2 of 18.0 0.0181 GWh EPI 2024 Year...

AI summary Table 66 outlines the 2025 savings deductions for various programs, including Green Heat 2024 and EPI 2024, with specific values for lifetime and first-year savings deductions. The table also notes that there is no statistically significant higher program participation level in 2025 for certain waves of users.

The Residential Behaviour net electrical energy savings were estimated using the following equation: Net Savings = ∑ Monthly Savings – Savings Deductions for Participation in Other Programs The detailed results are listed in [Table](#page-...

AI summary The Residential Behaviour program's net electrical energy savings were calculated using a specific equation, resulting in 2,607 tonnes of CO2 eq in annual GHG emission reductions. The calculation used a Nova Scotia-specific factor for electricity production-related GHG emissions.

Table 67: Evaluated 2025 Residential Behaviour Net Electrical Energy Savings Cohort Wave 1 Wave 2 Wave 3 Total Electrical Energy Savings Electrical Energy Savings (GWh) 3.716 1.992 0.000 5.078 Savings Deductions (GWh) 0.118 0.035 0.000 0.1...

AI summary Table 67 and Table 68 outline the evaluated residential behaviour net electrical energy savings and GHG emission reductions for 2025. The residential behaviour program fell significantly short of its target, achieving only 5.555 GWh of net electrical energy savings compared to a target of 29.771 GWh.

27.3 Realization Rate No tracked savings were calculated for Residential Behaviour; therefore, there is no realization rate. 46 At the time of writing, 2025 data were not yet available. The Nova Scotia-specific factor was obtained from Nov...

AI summary No realization rate was calculated for Residential Behaviour due to untracked savings. Nova Scotia-specific emissions and electricity generation data were sourced from Nova Scotia Power (2024 emissions: 5,314,847 CO2 eq tonnes; generation: 11,326 GWh) and Emera Inc.'s 2024 Annual Report.

28 Residential Behaviour Key Findings and Recommendations The main objective of the 2025 Residential Behaviour evaluation was as follows: › Calculate net results, namely electrical first-year energy savings as well as avoided GHG emissions...

AI summary The 2025 Residential Behaviour program was paused in May 2025 due to a cybersecurity incident at NS Power, limiting AMI data access. This resulted in only 5.555 GWh of net energy savings (vs. a target of 29.771 GWh) over four months (Jan-Apr 2025). High and medium electricity users achieved partial savings, while low users saw no statistically significant results.

Residential Behaviour Appendix XV Residential Behaviour: Monthly Savings Approach Appendix XVI Residential Behaviour: Monthly Raw Data for Monthly Savings Calculations Appendix XVII Residential Behaviour: Examples of Statistical Significan...

AI summary The document includes appendices related to residential behaviour analysis, covering monthly savings approaches, raw data, statistical significance testing, and 2025 recommendations. EfficiencyOne is mentioned in a contact detail.

Table 1: 2025 AMH Corrected Tracked Savings Value Tracked by E1 Corrected Tracked Value Relative Difference Program Component Results Value Unit Value Unit Value AMH Gross Electrical Energy Savings at the Generator 1.348 GWh 1.378 GWh 2.2%...

AI summary Table 1 presents corrected tracked savings for the 2025 AMH program, showing differences between initial and corrected values due to an incorrect line loss factor and the use of different peak demand-to-energy ratios by certain comprehensive projects.

Evaluated 2025 ASFH Allocation of EPI Gross Electrical Energy and Peak Demand Savings per Measure (Continued) LED Lamps Product Category Nightlights GU10 7 W Replacing 50 W G25 4.5 W Replacing 40 W E12 5 W Chandeliers Replacing 40 W Number...

AI summary The document evaluates the 2025 allocation of EPI gross electrical energy and peak demand savings per measure for Affordable Single-family Homes (ASFH). It presents data on LED lamps, including installation rates, energy savings, and peak demand savings, along with factors such as interactive effects and line loss.

Evaluated 2025 ASFH Allocation of EPI Gross Electrical Energy and Peak Demand Savings Grand Total Number of Units Number of Units 5,299 Installation Rate (%) 90% Number of Units Installed 4,766 Electrical Energy Savings Gross Electrical En...

AI summary The 2025 Affordable Single-family Homes (ASFH) allocation of Efficient Product Installation (EPI) achieves 0.274 GWh gross electrical energy savings at the generator and 0.035 MW peak demand savings, with a 4.7-year effective useful life. Total units installed: 4,766 (90% of 5,299). Lifetime savings reach 1.290 GWh, adjusted for line loss factors.

For peak demand savings: - › An adjustment to the nominal heating capacity for 382 ductless mini-split heat pumps based on values found in NEEP Cold Climate Heat Pump list - › An adjustment to the peak demand savings calculation for ductle...

AI summary Adjustments to peak demand savings calculations for heat pumps and heating systems are proposed, including correcting E1's use of an incorrect baseline COP value (0.84 instead of 1.00), addressing ineligible participants with non-fully electric households, and revising savings values for pellet/wood stoves and a wood furnace baseline.

APPENDIX X HEA Tracking Sheet Audit This appendix presents the main results of the tracking sheet audit performed by the Evaluator, which was aimed at: - › Verifying that all data fields required for the evaluation were included and filled...

AI summary This audit identifies discrepancies in E1's HEA Tracking Sheet calculations, including incorrect methods for electrical energy savings, unaddressed spillover effects, and flawed peak demand calculations. The Evaluator recommends adjustments to the Customer Information System (CIS) and revised reporting practices to ensure accuracy in program evaluations.

APPENDIX XI HEA Reporting Requirements HEA incentives originate from three sources of funding and are thus reported to different parties via the DSM evaluation and government-funded evaluation. The DSM evaluation is focused on reporting el...

AI summary HEA reporting requirements involve incentives funded by both DSM and government programs. The reporting methodology was updated in 2019 and 2024 to reflect changes in energy savings calculations, including the impact of fuel switching and the use of new adjustment ratios. The Canada Greener Homes Grant was incorporated in 2021 without changing the reporting structure.

Table 1: 2025 Reporting Requirements for Different Energy Savings Scenario[s](#page-113-0) 1 Scenarios 1 2 3 4 Change in Overall Electrical Energy Consumption Increase Increase Decrease Decrease Change in Overall Non electrical Energy Cons...

AI summary Table 1 outlines 2025 reporting requirements for various energy savings scenarios, detailing changes in electrical and non-electrical energy consumption, reporting obligations, and equations used to calculate DSM and government-funded savings. The table highlights the rationale for different reporting approaches based on funding sources and energy consumption changes.

Table 1: 2025 MHEEP Corrected Tracked Savings Value Tracked by E1 Corrected Tracked Value Relative Difference Program Component Results Value Unit Value Unit Value MHEEP Gross Electrical Energy Savings at the Generator 0.337 GWh 0.337 GWh...

AI summary Table 1 shows the 2025 MHEEP Corrected Tracked Savings. The tracked and corrected values for gross and net electrical energy savings are the same, but corrected peak demand savings decreased by 2.4% due to the exclusion of three non-DSM-allocated records with no corresponding energy savings.

APPENDIX XV Residential Behaviour: Monthly Savings Approach While they are not used to claim savings, monthly savings were calculated to observe monthly trends and the ramp-up period in more detail. An equation similar to that of the cumul...

AI summary This appendix details the monthly savings approach for analyzing residential behavior in energy programs. It uses a difference-in-difference (DiD) model to compare average daily consumption between treatment and control groups pre- and post-program participation, with a formula calculating monthly savings based on household data and days in the month.

Table 1: 2025 Residential Behaviour Evaluated Monthly Electrical Energy Savings January 2025 February 2025 March 2025 April 2025 Total Wave 1 – High users Number of Active Participants - Treatment 91,877 91,558 91,154 90,842 - Attrition Ra...

AI summary Table 1 presents monthly electrical energy savings data for three waves of residential participants in 2025. The data shows varying levels of energy savings across high, medium, and low users, with some months showing higher savings and others showing lower savings. The table also includes attrition rates, baseline consumption, and margin of error for each wave.

Table 1: Wave 1 2025 Monthly Raw Data for Monthly Savings Calculations Parameters January 2025 February 2025 March 2025 April 2025 Standard Error – Treatment Post (kWh/day) 0.019 0.021 0.014 0.013 Combined Standard Error (kWh/day) 0.228 0....

AI summary Table 1 presents Wave 1 2025 monthly raw data for monthly savings calculations, including parameters such as standard error, number of observations, average daily consumption, and standard deviation for both control and treatment groups across January to April 2025.

APPENDIX XVIII Residential Behaviour 2025 Recommendations The Evaluator made no specific recommendation as part of the 2025 Residential Behaviour evaluation. 2475, Laurier boul., Suite 250 Quebec City, QC G1T 1C4 Canada Tel.: 418-692-2592...

AI summary The Evaluator made no specific recommendations as part of the 2025 Residential Behaviour evaluation. The document contains minimal content beyond this statement and includes contact information for an organization in Quebec City.

EFFICIENT PRODUCT REBATES PROGRAM Final Report 2025 DSM EVALUATION March 18, 2026 In collaboration with:

AI summary The document presents the Final Report of the 2025 Demand-Side Management (DSM) Evaluation for the Efficient Product Rebates Program, dated March 18, 2026. It highlights collaboration with unspecified entities, though specific details or findings from the evaluation are not provided in the text.

EXECUTIVE SUMMARY This report presents the 2025 demand-side management (DSM) results of the Efficient Product Rebates program administered by EfficiencyOne (E1). This program comprises the Business Energy Rebates (BER) program component. T...

AI summary This report outlines the 2025 demand-side management (DSM) results for EfficiencyOne's Efficient Product Rebates program, focusing on Business Energy Rebates (BER) through Application Rebates (BER-AR) and Instant Rebates (BER-IR). The program provides financial incentives to business, non-profit, and institutional (BNI) participants to reduce electricity consumption and demand.

Table 1: 2025 BER Evaluation Approach Evaluation Type Methodology Component Service Impact Process Market BER Application Rebates Comprehensive › Tracking sheet audit › Project reviews with site visits › Application of 2024 Demand-side Man...

AI summary The 2025 BER Evaluation Approach outlines methodologies for assessing the Business Energy Rebates (BER) program, including tracking sheet audits, site visits, participant surveys, and the use of the 2024 Demand-side Management Measure Assessment (DSM MA). It also involves GHG emission reduction calculations and jurisdictional scans of BNI lighting programs in North America.

BER Findings and Recommendations This subsection highlights the key findings and provides recommendations from the 2025 BER evaluation. 2025 BER-Finding: In 2025, BER achieved 40.244 GWh in net electrical energy savings and 5.332 MW in net...

AI summary The 2025 BER evaluation achieved 40.244 GWh net electrical savings (5% over target) but fell 26% short of peak demand savings targets. Business participation in Application Rebates dropped 36% (vs. 2024), while Instant Rebates grew 79%, driven by T8 LED promotions. Adjustment ratios for lighting/HVAC (1.117/1.006) and agriculture/commercial measures (0.951/0.514) were calculated, though the 0.514 ratio has high uncertainty.

INTRODUCTION EfficiencyOne (E1), an independent and non-profit organization, is responsible for helping Nova Scotians improve the energy efficiency of their homes and workplaces by designing, marketing, and delivering demand-side managemen...

AI summary EfficiencyOne (E1) is an independent, non-profit organization that delivers demand-side management (DSM) programs in Nova Scotia through the Efficiency Nova Scotia (ENS) franchise. E1's 2025 DSM program portfolio includes the Efficient Product Rebates program, which consists of Business Energy Rebates (BER) with Application Rebates and Instant Rebates. An evaluation report outlines the components and evaluation methods for these programs, focusing on baseline definitions, savings calculation methodologies, and net-to-gross ratios.

1.1 BER Description BER provides financial incentives in the form of prescriptive rebates or interest-free financing to business, non-profit, and institutional (BNI) participants to reduce electricity consumption and peak demand in Nova Sc...

AI summary Business Energy Rebates (BER) offer prescriptive rebates and interest-free financing to BNI participants in Nova Scotia to reduce electricity use and peak demand. The program includes Application Rebates (AR) and Instant Rebates (IR), with eligibility criteria based on efficiency standards. In 2025, solar PV rebates were discontinued, rebate levels reduced, and certain technologies (e.g., T8 lighting) became ineligible. BER aimed for 38.451 GWh in energy savings and 7.241 MW in peak demand reduction by 2025.

1.2 Follow-up on Past Evaluation Report Recommendations The Evaluator evaluated BER for 2024 and provided improvement recommendations. [Table](#page-146-1) 5 below outlines the status of those recommendations that were carried forward.

AI summary The Evaluator assessed the Business Energy Rebates (BER) for 2024 and provided improvement recommendations, with Table 5 outlining the status of those recommendations that were carried forward.

Table 5: Implementation Status of Past Recommendations for BER # Recommendation Status Comments BER-R9 Ensure that multi-wattage products are identified in the tracking sheet. Update applications for BER-AR and SBES to identify multi-watta...

AI summary Table 5 outlines the implementation status of past recommendations for the Business Energy Rebates (BER) program. Recommendation BER-R9, which requires identifying multi-wattage products in the tracking sheet and using mid-range wattage when information is not available, has been completed. E1 used model numbers to track multi-wattage lighting in the 2025 DSM tracking sheet and is assessing the use of DesignLights Consortium (DLC) variables for automation.

BER Overall As presented in [Figure](#page-151-1) 7 below, BER generated a total of 45.081 GWh in gross electrical energy savings at generator in 2025, which represents a 4% decrease compared to 2024 results. In 2025, gross peak demand sav...

AI summary BER generated 45.081 GWh in gross electrical energy savings in 2025, a 4% decrease from 2024, and 6.046 MW in gross peak demand savings, a 11% decline. Lower participation in Application Rebates drove the reductions.

Table 6: 2025 BER Evaluation Approach Evaluation Objectives Research Questions Methodology Validate 2024 market evaluation results and determine timing for when a LED baseline for BER IR LED fixtures should take effect › To what extent are...

AI summary This table outlines the evaluation approach for the 2025 Business Energy Rebates (BER) program, focusing on validating 2024 market evaluation results and determining the timing for implementing a LED baseline for BER Instant Rebates (BER-IR) LED fixtures. It includes research questions and methodologies such as distributor interviews and staff interviews.

Interviews with New Brunswick Distributors The Evaluator selected to use the New Brunswick market as a comparator as, up until very recently, New Brunswick Power (NB Power), the DSM program administrator for the Province of New Brunswick,...

AI summary The Evaluator used New Brunswick as a comparator due to the recent launch of its Midstream Business Rebates Program (MBRP), similar to BER-IR. Six New Brunswick distributors were interviewed, revealing varied operational scopes and participation levels in the program. The study aimed to assess market evolution in business lighting, with data collection methods emphasizing pre-MBRP market conditions.

Table 7: 2025 Application Rebates Adjustment Ratios Electrical Energy Savings Peak Demand Savings Measure Category Adjustment Ratio Margin of Error Adjustment Ratio Margin of Error Lighting 1.117 8.3% 1.031 10.4% Heating, Ventilation, and...

AI summary Table 7 presents the 2025 Application Rebates Adjustment Ratios for various measure categories, including lighting and HVAC, with specific adjustment ratios and margins of error for electrical energy and peak demand savings.

3.2.2 Interactive Effects Interactive effects occur when the implementation of energy efficiency measures has an impact on the energy consumption of other elements such as heating and cooling; these are considered in the gross savings stan...

AI summary Interactive effects refer to impacts of energy efficiency measures on heating/cooling systems, considered in E1's gross savings calculations. For BER-AR, these effects apply only to indoor lighting projects. The Evaluator updated interactive effects factors in the 2025 DSM MA based on building type and lighting characteristics, confirming correct application through site visits.

3.2.3 Effective Useful Life In 2025, the Evaluator reviewed the EUL values used in the calculations of electrical energy savings that are expected to persist over time. For LED linear fixture, LED linear lamp, and LED outdoor fixture measu...

AI summary In 2025, the Evaluator reviewed and recalculated the Effective Useful Life (EUL) values for LED lighting measures, considering changes in the baseline over the measure's lifetime. The updated EUL values are presented in Table 8 of the 2025 DSM MA.

Table 9: Evaluated 2025 Application Rebates Gross Electrical Energy and Peak Demand Savings Measure Category Agriculture Commercial Kitchen HVAC Lighting Motor Pumping Refrigeration Renewable Energy Total Electrical Energy Savings Tracked...

AI summary Table 9 evaluates the 2025 Application Rebates for gross electrical energy and peak demand savings across various measure categories. It includes tracked savings, adjustment ratios, line loss factors, and lifetime savings. The table also notes that adjustment ratios differ from prior evaluations due to prior inclusion in tracked savings.

The differences between tracked and evaluated savings outlined in the figures are the results from applying updated adjustment ratio values across all measure categories and revised interactive effects values for recessed fixture lighting...

AI summary The document discusses differences between tracked and evaluated savings in the 2025 Application Rebates, resulting from updated adjustment ratio values and revised interactive effects for recessed fixture lighting measures. It also references figures and a table related to electrical energy and peak demand savings, as well as GHG emission reductions calculated using a Nova Scotia-specific factor.

Table 13: Evaluated 2025 Application Rebates Net Electrical Energy and Peak Demand Savings Measure Category Agriculture Commercial Kitchen HVAC Lighting Motor Pumping Refrigeration Renewable Generation Total Electrical Energy Savings elect...

AI summary Table 13 presents evaluated 2025 application rebates for net electrical energy and peak demand savings, categorizing them by measure type and including factors like NTGR, line loss, and effective useful life. The table provides a detailed breakdown of energy savings across various sectors and their impact on the generator and meter levels.

[Table](#page-168-1) 14 presents a comparison between the 2025 evaluated energy and peak demand savings and those tracked by E1. It also shows the realization rates, which indicate the ratio of evaluated net savings to tracked net savings,...

AI summary Table 14 compares the 2025 evaluated energy and peak demand savings with those tracked by E1, highlighting realization rates that show the ratio of evaluated net savings to tracked net savings for both energy and peak demand.

Gross Savings Net Savings Realization Value Unit NTGR Value Unit Rate Electrical Energy Savings Tracked Savings by E1 9.302 GWh 0.740 6.884 GWh Evaluated Savings 9.214 GWh 0.932 8.586 GWh 125% Peak Demand Savings Tracked Savings by E1 0.78...

AI summary The table presents gross and net savings, along with realization rates, for electrical energy and peak demand savings tracked by E1 and evaluated by the Evaluator. Higher realization rates are attributed to updated NTGR values applied by the Evaluator.

4.2.2 Energy Savings As part of 2025 DSM MA activities, several parameters were updated and some measures eligible under Instant Rebates were impacted. In 2025, the unitary savings values for circulator pumps were updated. The tracked and...

AI summary Updates to 2025 DSM MA parameters affected circulator pump savings values, with changes detailed in Table 15. The Uniform Methods Project's definition is cited for unitary savings estimation.

Table 15: 2025 Instant Rebates Tracked and Evaluated Unitary Electrical Energy Savings for Circulator Pumps Tracked Maximum Input Power Categories Evaluated Maximum Input Power Categories Tracked Unitary Electrical Energy Savings Value (kW...

AI summary Table 15 details the 2025 instant rebates for circulator pumps, showing tracked and evaluated unitary electrical energy savings across different power categories. The table includes tracked and evaluated maximum input power categories and corresponding energy savings in kWh. The section also introduces a discussion on peak demand savings.

4.2.4 Interactive Effects Interactive effects occur when the implementation of energy efficiency measures has an impact on the energy consumption of other elements such as heating and cooling; these are taken into account in the gross unit...

AI summary This section discusses interactive effects in energy efficiency measures, particularly how they impact heating and cooling systems. It explains how the Evaluator calculated these factors for eligible products under the 2025 DSM MA activities, noting differences between tracked and evaluated factors due to updated methods and building mix in 2025.

Table 16: 2025 Instant Rebates Interactive Effects Factor Calculation Results Measure Tracked Interactive Effects Factor for Energy Savings Tracked Interactive Effects Factor for Peak Demand Savings Evaluated Interactive Effects Factor for...

AI summary Table 16 presents the 2025 Instant Rebates Interactive Effects Factor Calculation Results for various lighting measures, including LED linear fixtures and lamps, showing the impact on energy and peak demand savings. The table includes both tracked and evaluated factors for different types of fixtures and their weighted averages.

As part of the 2025 DSM MA activities, the Evaluator reviewed the EUL values used in the calculations of electrical energy savings that are expected to persist over time. In the 2025 evaluation for LED linear fixtures, LED linear lamps, LE...

AI summary The Evaluator adjusted EUL values for certain LED lighting measures in the 2025 DSM MA evaluation due to regulatory changes affecting baseline assumptions, while maintaining previously established EUL values for other Instant Rebates measures.

Table 17: 2025 Instant Rebates Tracked and Evaluated EUL Values Measure Tracked EUL (years) Evaluated EUL (years) LED Linear Fixtures 1 x 4 Luminaires 11.9 4.8 2 x 2 Luminaires and Retrofit Kits 11.9 4.8 2 x 4 Luminaires and Retrofit Kits...

AI summary Table 17 compares the tracked and evaluated effective useful life (EUL) values for various LED lighting measures under the 2025 instant rebate program. The evaluated EUL values are significantly lower than the tracked values and are used to calculate gross and net lifetime electrical energy savings, resulting in a weighted average EUL of 4.9 years for gross savings.

4.2.6 Evaluated Gross Savings The electrical energy and peak demand savings associated with Instant Rebates were calculated using the unitary savings values (including baseline wattages, the actual wattages of efficient measures, ballast f...

AI summary The document discusses the calculation of electrical energy and peak demand savings from Instant Rebates using data from the 2025 DSM MA, including unitary savings values and line loss factors updated in 2019. These factors were submitted to the Nova Scotia Energy Board as part of the 2014 Cost of Service Study Progress Update.

Table 18: 2025 Instant Rebates Evaluated Gross Electrical Energy and Peak Demand Savings Measure Category LED Linear Fixtures LED Linear Lamps LED Outdoor Fixtures LED Directional and Architectural Fixtures Outdoor Motion Sensors Indoor Oc...

AI summary Table 18 evaluates the gross electrical energy and peak demand savings for various energy efficiency measures under the 2025 Instant Rebates program. It provides data on the number of units, energy savings at the meter and generator, effective useful life, and peak demand savings across different measure categories.

[Figure](#page-174-0) 10 below compares the tracked and evaluated gross electrical energy savings, while [Figure](#page-174-1) 11 further below compares the tracked and evaluated gross peak demand savings. The slight differences between tr...

AI summary The text discusses differences between tracked and evaluated gross electrical energy and peak demand savings, attributed to updated factors such as energy and demand line loss, interactive effects for lighting measures, and unitary energy savings for circulator pumps. It also mentions the calculation of GHG emission reductions using a Nova Scotia-specific factor applied to Instant Rebates gross savings.

Table 20: 2025 Instant Rebates Evaluated NTGRs Measure Free-ridership NTGR LED Linear Fixtures 8% 0.92 LED Linear Lamps 15% 0.85 LED Outdoor Fixtures 15% 0.85 Other Measures 0% 1.00 4.3.3 Evaluated Net Savings

AI summary Table 20 presents the evaluated net-to-gross ratios (NTGRs) for various energy efficiency measures under the 2025 Instant Rebates program. The table includes free-ridership percentages and NTGR values for LED Linear Fixtures, LED Linear Lamps, LED Outdoor Fixtures, and Other Measures.

Table 21: 2025 Instant Rebates Evaluated Net Electrical Energy and Peak Demand Savings Measure Category LED Linear Fixtures LED Linear Lamps LED Outdoor Fixtures LED Directional and Architectural Fixtures Outdoor Motion Sensors Indoor Occu...

AI summary Table 21 provides a detailed evaluation of the 2025 Instant Rebates, showing net electrical energy and peak demand savings across various measure categories. The table includes gross and net savings, NTGR, line loss factors, and effective useful life for each measure category.

Gross Savings Net Savings Realization Value Unit NTGR Value Unit Rate Electrical Energy Savings Tracked Savings by E1 35.357 GWh 0.88 31.181 GWh Evaluation Results 35.867 GWh 0.88 31.658 GWh 102% Peak Demand Savings Tracked Savings by E1 5...

AI summary The evaluated net electrical energy savings were 2% higher than those tracked by E1, while peak demand savings were 3% lower. These differences are attributed to updated line loss factors, interactive effects factors, and unitary energy savings values for circulator pumps.

6.2.3 DesignLights Consortium (DLC) Certified Fixtures Nearly all fixtures (98-99%) offered by all six participating distributors interviewed are DLC-certified, with no differences in shares of distributor stocks before and after joining t...

AI summary Nearly all lighting fixtures offered by six participating distributors are DLC-certified. Three distributors could not distinguish between DLC Standard and Premium products, while others carried mostly DLC-certified products before joining the program, with some variation in the shares of Standard and Premium products.

Opinions among distributors were mixed on the topic of DLC Premium and DLC Standard pricing patterns and the impact of rebates on pricing differences between the two categories. For DLC Premium fixtures, some distributors observed that the...

AI summary Distributors have mixed opinions on DLC Premium and DLC Standard pricing patterns and rebate impacts. Some note that DLC Premium prices remain higher than DLC Standard even after rebates, while others express confusion about the certification differences. Non-participating distributors supply DLC-certified fixtures, mostly DLC Standard, with higher proportions in outdoor fixtures.

Table 28: Summary of Jurisdictional Scan Findings by Region Program Administrator Region Instant Rebate Program Application Rebate Program Custom Program Direct Install LED Incentives Continuing in the Near Term? 1. National Grid (Mass Sav...

AI summary Table 28 summarizes findings from a jurisdictional scan of energy efficiency programs across various regions. It details the presence and structure of instant rebate, application rebate, custom, and direct install programs, with specific information on LED incentives and their continuation in the near term. Some programs are being phased out or updated, such as in Ontario and Quebec.

mewhat more complicated to implement as data or assumptions are required to establish the market blend and also requires an assumption on when LED fixtures would be the baseline for all project types. Dual Baseline: Savings are calculated...

AI summary The text discusses the dual baseline approach for calculating energy savings, emphasizing its complexity due to market blend assumptions and LED fixture timelines. Mass Save and PSE use this method, with EUL assumptions varying by program targets and dates (e.g., LED baseline by 2029). The Uniform Methods Project (UMP) is cited as a reference for evaluation protocols.

Table 29: Jurisdictional Scan. Baseline. and EUL Assumptions Program Administrator Region Program Type Existing Lighting Baseline Market Blend Baseline Dual Baseline Efficiency One Nova Scotia. Canada Instant. application EUL = full lifeti...

AI summary Table 29 compares lighting baseline assumptions across various energy efficiency programs in different jurisdictions, highlighting differences in Effective Useful Life (EUL) assumptions and program structures, such as instant application, custom, and direct install approaches.

Dual Baseline Approach for BER-AR and SBES For SBES, since the target population is small businesses, Econoler assumes that the majority of projects is early replacement. Therefore, Econoler recommends using the UMP approach to develop a d...

AI summary Econoler recommends a dual baseline approach for SBES using the UMP method, combining existing and LED baselines. For BER-AR, two options are proposed: targeting market laggards with early replacement criteria or using a blended baseline. Both programs aim for full market transformation by 2028-2029, eliminating future savings opportunities.

7 BER Key Findings and Recommendations The main objectives of the 2025 BER evaluation were as follows: - › Calculate BER gross and net results, namely first-year and lifetime electrical energy savings, peak demand savings, as well as avoid...

AI summary The 2025 BER evaluation found BER exceeded net electrical energy savings targets by 5% (40.244 GWh) but missed peak demand savings by 26% (5.332 MW vs. 7.241 MW target). Application Rebates participation declined, while Instant Rebates achieved record participation since 2019, boosting savings compared to 2024.

Table 1: 2025 Application Rebates Corrected Tracked Savings Value Tracked by E1 Corrected Tracked Value Relative Difference Result Value Unit Value Unit Value Gross Electrical Energy Savings at the Generator 9.297 GWh 9.302 GWh 0.06% Gross...

AI summary Table 1 presents the 2025 Application Rebates Corrected Tracked Savings, showing minimal differences between tracked and corrected values for electrical energy and peak demand savings at the generator level. The differences are attributed to corrections made in the tracking process.

APPENDIX II BER Instant Rebates Tracking Sheet Audit This appendix presents the main results of the tracking sheet audit performed by the Evaluator, which was aimed at: - › Verifying that all data fields required for the evaluation were in...

AI summary This appendix details the results of a tracking sheet audit conducted by the Evaluator to verify the completeness and accuracy of data submitted by E1. The audit focused on ensuring consistency in calculation methods for energy and peak demand savings from lighting and pumping measures, as well as overall Instant Rebates.

Table 1: 2025 Instant Rebates Corrected Tracked Savings Value Tracked by E1 Corrected Tracked Value Relative Difference Service Results Value Unit Value Unit Value Instant Rebates - Lighting Gross Electrical Energy Savings at the Generator...

AI summary The table presents corrected tracked savings for the 2025 Instant Rebates, showing slight differences in energy and peak demand savings for lighting and pumping measures. The corrections were made due to adjustments in hours of use, rated wattage, and baseline wattage values, as well as a correction to the savings calculation for LED Linear Lamps.

Table 1: Overview of Data Collection Activity Descriptor This Instrument Instrument Type Telephone survey Estimated Time to Complete 15 minutes Target Audience 2025 program participants Expected Number of Completions 40 Contact List Source...

AI summary The document outlines data collection activities through a telephone survey targeting 2025 program participants, with a timeline from October 24th to November 14th, 2025. It also describes research objectives related to free-ridership and cross-influence in various energy efficiency measures.

B. INTRODUCTION B – Business with no contact name Hello, I am with Narrative Research, and we are performing an evaluation of energy efficiency programs and services provided by Efficiency Nova Scotia. We have a few questions about your re...

AI summary The text outlines a questionnaire by Narrative Research evaluating Efficiency Nova Scotia's Business Energy Rebates Program. It seeks to identify the most knowledgeable individual in businesses that installed energy efficiency measures (e.g., lighting, heat pumps) and requests contact details for follow-up.

D5. [ASK ONLY IF DLC Premium=YES] Without the Business Energy Rebates Program, what is the likelihood that you would have purchased DLC Premium LED lighting products? 1. Definitely would have 2. Probably would have 3. Probably would not ha...

AI summary The text presents survey questions related to the Business Energy Rebates Program, focusing on customer behavior regarding the purchase of energy-efficient lighting products and the use of energy management services. It explores the impact of the rebate program on purchasing decisions and project implementation.

Table 1: BER-AR Participant Survey Free-ridership Algorithm (Heat Pumps) INTENTION 1 – Heat Pump Cost Score (CS) C3 Context Question C4. Without the Business Energy Rebates Program and the rebate you received, would you have: [ONLY ONE POS...

AI summary This table outlines a free-ridership algorithm used in the BER-AR Participant Survey for heat pumps, focusing on how participants would have acted without the Business Energy Rebates Program. It includes questions about cost scores, timing of purchase, and quantity, with scoring based on responses.

Table 2: BER-AR Participant Survey Free-ridership Algorithm (Lighting) INTENTION Planning Question Answer Score D1. Before learning about the Business Energy Rebates Program, had your business already decided to install energy-efficient LE...

AI summary This table outlines the free-ridership algorithm for the Business Energy Rebates (BER) Program, focusing on lighting. It includes questions to determine whether businesses had already decided to install energy-efficient LED lighting before participating in the BER Program, and if they considered other lighting options.

Energy and Peak Demand Savings Algorithms The following algorithms include the parameters required to determine the annual energy savings and the annual peak demand savings associated with a low-bay LED luminaire replacement measure. [1] E...

AI summary The document outlines mathematical formulas for calculating annual energy savings and annual peak demand savings from replacing low-bay LED luminaires. Key parameters include baseline and efficient wattage, demand factors, usage factors, and conversion factors.

B. Lighting Market Assessment - B1. Based on your observations, what's happened in the commercial LED lighting market in the past three years in terms of…? [ASK FOR EACH] - b. New technologies [Any differences between LED lamps and LED fix...

AI summary The document asks about changes in the commercial LED lighting market over the past three years, including technology, demand, product offerings, availability, and pricing. It also requests the proportion of LED versus non-LED lighting stock in 2025 and asks if participation in the Midstream Business Rebate Program affected this percentage.

- C) [IF LESS THAN 100% FOR LED AT B11A)] When do you expect LED products to make up 100% of your [READ CATEGORY NAME] sales? Lighting Estimated Sales (%) in 2027 Lighting Category % LED % Non-LED [Why increase/decrease Year anticipated fo...

AI summary This section of the regulatory proceeding document asks respondents to estimate when LED products will make up 100% of sales in various lighting categories and to provide details on the percentage of DLC certified LED fixtures before and after participation in the Midstream Business Rebate Program.

- b. … [ASK IF D1 IS LESS THAN 8], Please explain the reason(s) for your score. Aspects of the program Score Reason 1. The overall NB Power Midstream Business Rebate Program 2. The program support and communications provided by the program...

AI summary The text presents a request for explanation regarding a score given to the NB Power Midstream Business Rebate Program, focusing on aspects such as program support, communication, and rebate processing. It also asks about any challenges experienced with the program.

LIGHTING MARKET STUDY - INSTANT BUSINESS Rebate Programs – EFFICIENCY ONE

AI summary This document outlines a market study for EfficiencyOne's Instant Business Rebate Programs in Nova Scotia, focusing on energy efficiency initiatives and regulatory considerations for business energy rebates.

2025 DSM EVALUATION March 20, 2026 In collaboration with:

AI summary The document header indicates a 2025 Demand-side Management (DSM) evaluation proceeding, dated March 20, 2026, with collaboration imagery referenced but no substantive content provided in the text.

ABBREVIATIONS BDM Business Development Manager BER Business Energy Rebates BNI Business, non-profit, and institutional BOpt Building Optimization CPA Customer Project Agreement DR Demand response DSM Demand-side management DSM MA Demand-si...

AI summary A list of abbreviations and their expansions used in regulatory proceedings, including terms related to energy efficiency, demand-side management, and utility programs. Key acronyms include DSM, BER, and NSUARB, with definitions covering technical, programmatic, and organizational terms.

DEFINITIONS Adjustment ratio The ratio of evaluated results to tracked results. This ratio expresses the adjustment made to tracked savings or other tracked values such as effective useful life values. The capacity that is available to Nov...

AI summary The text defines key terms related to energy efficiency and demand response, including adjustment ratios, available demand response capacity, baseline establishment, bias, billing calibration, confidence intervals, and demand response measures. These definitions are critical for understanding how energy savings are calculated and evaluated.

Table 1: Summary of 2025 Custom Incentives Program Evaluation Program Evaluation Type Component Impact Process Market Methodology Custom Comprehensive › Participant phone interviews › Project file reviews and participant follow-up intervie...

AI summary The document provides a summary of the 2025 Custom Incentives Program Evaluation, outlining the evaluation methods used, including participant interviews, project file reviews, site visits, and calculations for avoided GHG emissions. The evaluation covers various program components and performance metrics.

Table 2: Overall 2025 Custom Incentives Participation and Savings Partic ipation Level Gros s Savings NTGR Net Net Savings Value Unit Value Unit Value Unit Value Custom • ' ' ' ' Electrical Energy Savings 36.207 GWh 0.84 30.487 GWh Lifetim...

AI summary Table 2 provides an overview of the 2025 Custom Incentives Participation and Savings, detailing metrics such as electrical energy savings, peak demand savings, GHG emission reductions, and energy use life (EUL) for both completed and ongoing projects. The data highlights the impact of these incentives on energy efficiency and environmental outcomes.

Custom Findings and Recommendations This subsection provides the key findings and recommendations from the Custom evaluation. The Evaluator has no specific recommendation for Custom. & lt;sup>1 Completed SEM projects reference participants...

AI summary The Evaluator found no specific recommendations for Custom, noting that completed SEM projects generated savings. The Custom Incentives Program is mentioned as part of the discussion.

SEM Findings and Recommendations This subsection provides the key findings from the SEM evaluation. The Evaluator has no specific recommendation for SEM. 2025 SEM-Finding: SEM net electrical energy savings exceeded the 2.657 GWh target by...

AI summary The 2025 SEM evaluation found that net electrical energy savings exceeded targets by 52%, with participation reaching its highest level since 2018. However, savings per participant declined. M&V methodologies were deemed appropriate and accurate, though no specific SEM recommendations were provided.

EfficiencyOne (E1), an independent and non-profit organization, is responsible for helping Nova Scotians improve the energy efficiency of their homes and workplaces by designing, marketing, and delivering demand-side management (DSM) for N...

AI summary EfficiencyOne (E1) is a non-profit organization responsible for delivering demand-side management (DSM) programs in Nova Scotia through the Efficiency Nova Scotia (ENS) franchise. E1 is funded by Nova Scotia Power (NS Power) ratepayers and has a portfolio of residential, BNI, and demand response programs. Econoler was commissioned to evaluate E1's 2025 DSM program portfolio, including the Custom Incentives program and its components, such as Strategic Energy Management (SEM). The evaluation focuses on baseline definitions, savings calculation methods, parameter values, and net-to-gross ratios.

Retrofit - •Technical and financial support to help organizations conduct scoping and feasibility studies. - •Technical and financial support for the implementation of energy efficiency projects using a customized and flexible approach.\ -...

AI summary The Retrofit program offers technical and financial support for energy efficiency projects, targeting organizations with annual electricity consumption of 350,000 kWh or higher. It emphasizes customized approaches for scoping studies and project implementation, provided projects have not yet commenced.

1.2 Follow-up on Past Evaluation Report Recommendations The Evaluator evaluated Custom in previous years and issued improvement recommendations. [Table](#page-65-1) 5 below provides a summary of the implementation status of each recommenda...

AI summary The Evaluator has previously assessed Custom and provided improvement recommendations. Table 5 summarizes the implementation status of ongoing recommendations from the 2024 and 2022 Custom Incentives evaluation reports.

Table 5: Implementation Status of Past Recommendations for Custom # Recommendations Status Comments 2024-New Construction-R3 Investigate the impact of increasing modelling incentives (the share of modelling costs covered as well as the inc...

AI summary Table 5 outlines the implementation status of two recommendations related to the New Construction service. Recommendation R3 is in progress, with E1 planning to investigate increasing modelling incentives in Q2 2026. Recommendation R4 has been completed, with E1 having added two new energy modellers and continuing recruitment efforts.

2 Custom Evaluation Approach The 2025 Custom evaluation comprised a comprehensive impact evaluation for Retrofit, P4P, and New Construction. For Building Optimization, given its smaller contribution to Custom savings, NTGR results from 202...

AI summary The 2025 Custom evaluation focuses on assessing the impact of Retrofit, Pay-for-Performance (P4P), and New Construction programs. It includes calculating energy savings, peak demand reductions, and GHG emissions. The evaluation uses NTGR results from 2021 for Building Optimization due to its smaller contribution to savings.

3 Retrofit Impact Evaluation The objectives of the 2025 Retrofit impact evaluation were to determine gross and net electrical energy savings and peak demand savings, annually avoided GHG emissions, as well as EUL values and associated life...

AI summary The 2025 Retrofit impact evaluation aims to assess electrical energy and peak demand savings, annual GHG emissions avoided, and EUL values. The evaluation considers three types of savings: partial savings from projects started before 2025, final savings from single-year projects completed in 2025, and final savings from multiyear projects completed in 2025.

3.2 Gross Savings Gross savings correspond to the changes in energy consumption resulting from measures installed or actions taken by Retrofit participants compared to the consumption level had those measures or actions not occurred. [5](#...

AI summary Gross savings are calculated based on energy consumption changes from Retrofit projects. E1 tracks annual savings using M&V practices, combining participant data with engineering assumptions and professional judgments to assess project impacts.

3.2.1 Savings Verification For compressed air leak and solar PV projects, the Evaluator verified savings by validating that the correct input parameters were used by E1 to estimate savings following a semi-prescriptive approach. For compre...

AI summary The section outlines savings verification methods for compressed air leak and solar PV projects. The Evaluator confirmed E1's use of correct input parameters and 2021/2023 adjustment ratios to calculate gross energy and peak demand savings, ensuring compliance with semi-prescriptive approaches.

3.2.2 Project Review Sampling Methodology For the regular Retrofit project category, the Evaluator used a stratified sampling approach to select 18 projects for review from a total of 27 projects completed in 2025. More specifically, the E...

AI summary The Evaluator used stratified sampling to review 18 of 27 completed Retrofit projects in 2025, prioritizing larger projects (100% sample rate) and randomly selecting from smaller strata. The sample represented 88% of total energy savings, excluding projects with partial 2025 savings claims. Gross savings were extrapolated using a weighted average adjustment ratio.

3.2.5 Effective Useful Life The Evaluator reviewed the EUL values of all sampled projects by selecting an appropriate EUL for each measure implemented. The revised measure level EUL values were selected based on the values outlined in the...

AI summary The Evaluator adjusted Effective Useful Life (EUL) values for sampled projects based on the 2025 DSM MA, including reducing compressed air leak audit projects from 4 to 2 years and extending solar PV projects from 25 to 30 years. One Retrofit project's EUL was also revised.

For multiyear projects that claimed partial savings in previous years and were completed in 2025, the Evaluator applied the 2025 adjustment ratios to the full savings associated with those projects. To compensate for adjustments to partial...

AI summary The text discusses the evaluation process for multiyear projects completed in 2025, including the application of adjustment ratios and true-up adjustments. It also notes that solar PV projects did not contribute to peak demand savings during Nova Scotia's peak periods and that compressed air leak audit projects used 2021 adjustment ratios due to completed savings verification.

alues for all measures offered in E1's program portfolio. For the evaluation conducted during the last year of the 2023-2025 DSM cycle, the Evaluator refers to the values presented in the 2025 DSM MA. [Table](#page-78-0) 10 presents an ill...

AI summary The text discusses the evaluation of energy savings measures in E1's program portfolio during the 2023-2025 DSM cycle, referencing the 2025 DSM MA for values. It also mentions a table illustrating the true-up adjustment process for a hypothetical multiyear project completed in 2025.

Table 10: Example of a 2025 True-up Adjustment 2024 2025 Total Tracked Savings (kWh) 105,187 63,884 169,071 Year-specific Adjustment Ratio 1.021 1.003 Revised Savings Prior to True-up (kWh) 107,396 64,076 171,472 Total Project Revised Savi...

AI summary Table 10 shows a 2025 true-up adjustment example, illustrating tracked savings, adjustment ratios, and revised savings. Table 11 builds on this by applying adjustment ratios and true-up adjustments to Retrofit projects' energy and peak demand savings. Line loss factors from NS Power's 2014 study are used for calculations, with assumptions for municipal utilities.

Table 11: Evaluated 2025 Retrofit Gross Electrical Energy and Peak Demand Savings Partial Savings Claimed Final Savings Claimed for Single year Projects Final Savings Claimed for Multiyear Projects Total Number of Projects 9 31 6 46 Electr...

AI summary Table 11 evaluates the 2025 Retrofit Gross Electrical Energy and Peak Demand Savings, presenting data on tracked savings, adjustment ratios, and line loss factors for different project types. It includes figures for electrical energy and peak demand savings at both the meter and generator levels, along with effective useful life and lifetime savings.

Table 13: 2025 NTGR Approach per Retrofit Project Category Retrofit Project Category Number of Projects Completed in 2025 NTGR Methodology Sample Size (Unique Participant Interviews) Regular Retrofit 27 Free-ridership and spillover were me...

AI summary Table 13 outlines the 2025 NTGR approach for different retrofit project categories, detailing the methodology used to measure free-ridership and spillover effects. Regular Retrofit and Compressed Air Leak Audit projects used phone interviews with sampled participants, while Solar PV projects applied the 2023 NTGR evaluation. The sample size for each category is also noted, with a clarification on handling participants who completed multiple projects.

3.3.2 Spillover For Retrofit, participant spillover occurs when participants implement eligible energy efficiency measures due to the influence of previous participation in the service without receiving any kind of additional support. [13]...

AI summary The document defines spillover in the Retrofit program as participants implementing energy efficiency measures influenced by prior participation without additional support. Two participants reported self-initiated measures, but the Evaluator concluded overall spillover for regular Retrofit was nil. Findings were based on phone interviews and an algorithm detailed in Appendix IV.

3.4 Realization Rate [Table](#page-84-1) 17 below compares total 2025 Retrofit tracked and evaluated savings. It also includes the realization rate, representing the ratio of evaluated net savings to tracked net savings, for both electrica...

AI summary This section discusses the realization rate, which is the ratio of evaluated net savings to tracked net savings for both electrical energy and peak demand savings in 2025 Retrofit. A table is referenced to compare total tracked and evaluated savings.

Table 17: Comparison of 2025 Retrofit Tracked and Evaluated Savings at the Generator Gross Savings NTGR Net Savings Realization Rate Value Unit Value Value Unit Value Electrical Energy Savings Tracked Savings by E1 16.032 GWh 0.82 13.121 G...

AI summary Table 17 compares the tracked and evaluated savings from 2025 retrofit programs, focusing on electrical energy and peak demand. Tracked savings by E1 are compared with evaluation results, showing slight differences in gross and net savings, as well as realization rates.

4.2.1 Project Review Findings The Evaluator reviewed the single completed P4P project in 2025, which involved the implementation of an advanced building automation system to optimize set point control and scheduling of a building heating,...

AI summary The Evaluator reviewed a completed P4P project in 2025 involving advanced building automation for HVAC optimization. No adjustment was made to electrical energy savings, but peak demand savings were downwardly adjusted due to misalignment with Nova Scotia's peak demand periods. Ongoing projects with partial claims were deferred for future evaluation.

4.2.4 Evaluated Gross Savings [Table](#page-86-2) 18 below presents the overall evaluated gross savings for P4P. For the one single-year project completed in 2025, evaluated gross electrical energy and peak demand savings were determined f...

AI summary The section discusses the evaluated gross savings for the Pay-for-Performance (P4P) program, detailing how savings are calculated for completed and partially completed projects. It mentions the use of line loss factors based on the 2014 Cost of Service Study Progress Update provided by NS Power.

4.4 Realization Rate A comparison of the electrical energy and peak demand savings values established through this evaluation and those tracked by E1 is presented in [Table](#page-89-2) 22 below. The table also includes the realization rat...

AI summary This section discusses the realization rate, which is the ratio of evaluated net savings to tracked net savings for both electrical energy and peak demand savings, as compared in Table 22.

5.2.5 Evaluated Gross Savings The 2025 New Construction gross electrical energy and peak demand savings are presented in [Table](#page-92-1) 23 below. They were obtained by applying the average adjustment ratios of 0.949 to electrical ener...

AI summary The 2025 New Construction gross electrical energy and peak demand savings are calculated using average adjustment ratios of 0.949 and 0.937, respectively, applied to all projects claiming savings. Line loss factors specific to each project, based on rate codes and data from NS Power, are used to determine savings at the generator level.

Total Number of Projects 33 Electrical Energy Savings Tracked Gross Electrical Energy Savings – at the Meter (GWh) 18.235 Adjustment Ratio for Electrical Energy Savings 0.949 Gross Electrical Energy Savings – at the Meter (GWh) 17.307 Line...

AI summary The table presents energy savings and GHG emission reductions from 33 projects. It includes electrical energy savings, peak demand savings, and adjustments for line loss. GHG reductions are calculated using a Nova Scotia-specific factor applied to new construction savings.

Gross Savings NTGR Net Savings Realization Rate Value Unit Value Value Unit Value Electrical Energy Savings Tracked Savings by E1 18.713 GWh 0.72 13.473 GWh Evaluation Results 18.447 GWh 0.82 15.057 GWh 112% Peak Demand Savings Tracked Sav...

AI summary The evaluated gross electrical energy and peak demand savings were lower than those tracked by E1 due to adjustments in energy models. However, evaluated net savings were higher due to lower free-ridership in 2025, leading to a positive realization rate.

6.2.3 Effective Useful Life The Evaluator validated the EUL values based on the 2025 DSM MA. There were no adjustments made to the EUL values of reviewed 2025 projects.

AI summary The Evaluator confirmed the Effective Useful Life (EUL) values using the 2025 DSM MA without adjustments. No changes were made to EUL values for reviewed 2025 projects.

Final Savings Claimed for Single-Year Projects Total Number of Projects 9 9 Electrical Energy Savings Tracked Gross Electrical Energy Savings – at the Meter (GWh) 0.573 0.573 Adjustment Ratio for Electrical Energy Savings 1.000 1.000 Gross...

AI summary The table presents energy savings data from 9 single-year projects, including electrical energy and peak demand savings at both the meter and generator levels, along with adjustment ratios and line loss factors used in calculations.

Table 31: Evaluated 2025 Building Optimization Net Electrical Energy and Peak Demand Savings Final Savings Claimed for Single-year Projects Total Number of Projects 9 9 Electrical Energy Savings Gross Electrical Energy Savings – at the Met...

AI summary Table 31 presents the evaluated 2025 Building Optimization Net Electrical Energy and Peak Demand Savings. It includes metrics such as gross and net energy savings, line loss factors, and effective useful life for the projects evaluated.

6.4 Realization Rate A comparison of the electrical energy and peak demand savings values established through this evaluation and those tracked by E1 is presented in [Table](#page-99-2) 32 below. The table also includes the realization rat...

AI summary This section discusses the realization rate, which is the ratio of evaluated net savings to tracked net savings for both electrical energy and peak demand savings, as compared between the evaluation and E1 tracking.

Table 33: Comparison of 2025 Custom Tracked and Evaluated Savings at the Generator Gross Savings NTGR Net Savings Realization Rate Unit Value Value Value Unit Value Electrical Energy Savings Tracked Savings by E1 16.032 GWh 0.82 13.121 GWh...

AI summary Table 33 compares tracked and evaluated savings for energy and peak demand across various categories in 2025. It includes metrics such as Gross Savings, Net-to-Gross Ratios (NTGR), Net Savings, and Realization Rates for different programs and initiatives.

General Custom Key Findings and Recommendations 2025 Custom - Finding: Custom surpassed the net electrical energy and peak demand savings targets in 2025. Custom achieved 30.487 GWh in net electrical energy savings and 6.372 MW in net peak...

AI summary Custom exceeded 2025 energy savings targets (30.487 GWh and 6.372 MW) but saw reduced participation compared to 2024. Adjustments to savings metrics were applied, with free-ridership levels decreasing for Retrofit and New Construction. Evaluated savings were 8% higher than E1-tracked values.

9 SEM Overview This section describes the Strategic Energy Management (SEM) program component, follows up on past evaluation recommendations, and provides an overview of participation history.

AI summary This section outlines the Strategic Energy Management (SEM) program, addresses past evaluation recommendations, and summarizes participation history within the Nova Scotia regulatory context.

9.1 SEM Description SEM provides industrial and institutional participants with funding and support to implement energy management practices within their organizations. It also provides participants with energy management information syste...

AI summary Strategic Energy Management (SEM) supports industrial and institutional participants in implementing energy management practices through funding, EMIS implementation, and structured energy-saving actions. Eligibility requires resources, commitment, and collaboration with E1. Activities involve third-party service providers, with a focus on continuous improvement, training, and long-term energy performance.

Figure 7: 2025 SEM Participation Process Summary Eligibility Check, Memorandum of Understanding (MOU), and Kick-off Meeting - •Once approved, eligible participants must first sign a MOU that outlines the project scope, participant requirem...

AI summary The 2025 SEM Participation Process involves eligibility checks, MOUs, energy team formation, and performance-based incentives. Participants develop energy management plans, undergo savings verification, and receive incentives at $0.06/kWh (Large Industrial) or $0.04/kWh. The program aims for 2.657 GWh energy savings and 0.289 MW peak demand reduction.

9.2 Follow-up on Past Evaluation Report Recommendations The Evaluator evaluated SEM in previous years and issued improvement recommendations. Table 34 provides a summary of the implementation status of the recommendations presented in the...

AI summary The Evaluator reviewed the implementation of SEM improvement recommendations from the 2024 SEM evaluation report, with Table 34 summarizing the status of these recommendations.

10 SEM Evaluation Approach The 2025 SEM evaluation comprised a comprehensive impact evaluation. The main objectives of the SEM evaluation were as follows: › Calculate SEM gross and net results, namely electrical first-year and lifetime ene...

AI summary The 2025 SEM evaluation aims to calculate gross and net results, including energy savings, peak demand savings, and avoided GHG emissions. The Evaluator identified key research questions and methods to achieve these objectives, with Table 35 outlining the evaluation objectives, research questions, methods, and sample sizes.

11 SEM Impact Evaluation The objectives of the 2025 SEM comprehensive impact evaluation were to determine project gross and net electrical energy and peak demand savings as well as annually avoided GHG emissions, EUL values, and associated...

AI summary The 2025 SEM comprehensive impact evaluation aimed to assess gross and net electrical energy savings, peak demand reductions, annual GHG emission avoidance, EUL values, and lifetime energy savings. The evaluation focuses on quantifying the program's effectiveness in achieving energy efficiency and emission reduction targets.

11.2 Gross Savings For SEM, gross savings correspond to the change in energy consumption resulting from actions taken by participants regardless of their reasons for participating.[28](#page-110-4) The subsections below provide a descripti...

AI summary The section defines gross savings for Strategic Energy Management (SEM) as energy consumption changes from participant actions. It outlines the methodology for reviewing 18 SEM measures generating savings in 2025, including assessments of interactive effects, Effective Useful Life (EUL) values, and revised electrical savings.

11.2.1 Project Review Findings The Evaluator reviewed the calculation methodologies for the 18 SEM measures based on project documentation and information from interviews with participants (where required) and the Service Provider. All exc...

AI summary The Evaluator reviewed 18 SEM measures' M&V methodologies, finding most approaches thorough and aligned with best practices. Bottom-up and top-down methods were used appropriately depending on context. Adjustments were made to seven measures, with specific attention to compressed air leak quantification using submetering or ultrasonic detectors. Overall, methodologies were deemed reasonable despite practical limitations in testing.

Compressed Air Leak Repair Measures The Evaluator reviewed six compressed air leak measures with one measure receiving a downward adjustment to both the electrical energy and peak demand savings. In this case, the compressor efficiency was...

AI summary The Evaluator assessed six compressed air leak repair measures, adjusting one downward due to mixed data in compressor efficiency calculations. A bin analysis using metered data was identified as a more conservative method for estimating savings.

Equipment Upgrade Measures Six of the measures reviewed by the Evaluator involved equipment upgrades. Of these measures, the Evaluator made downward adjustments to the electrical energy savings claimed for three measures and downward adjus...

AI summary The Evaluator reviewed six equipment upgrade measures, adjusting downward electrical energy savings for three and peak demand savings for two. Adjustments were based on updated efficiency, operating hours, or production data from site visits and interviews, while agreeing with the overall methodology.

Automated Controls Measures There were five measures with claimed electrical energy savings that fell under the automated controls measure category. Of these measures, three received adjustments to electrical energy savings (two upward adj...

AI summary Five automated controls measures with claimed energy savings were evaluated. Three received adjustments to electrical savings (two upward, one downward), and one received an upward peak demand adjustment. The Evaluator agreed with the methodology but made minor corrections, including power formula updates and revised operating hours. One project's peak demand savings were recalculated after initial nil reporting.

Permanent Shutdown There was one measure with claimed savings that fell under the permanent shutdown measure category. The Evaluator agrees with the methodology used to calculate the savings and, as such, made no adjustments to the electri...

AI summary The text discusses a measure under the permanent shutdown category, where the Evaluator approved the methodology for calculating savings, resulting in adjustment ratios of 0.953 for gross electrical energy and 0.884 for net peak demand savings.

11.4 Realization Rate A comparison of the electrical energy and peak demand savings established through this evaluation and those tracked by E1 is presented in [Table](#page-114-3) 38 below. The table also includes the realization rate, re...

AI summary This section discusses the realization rate, which is the ratio of evaluated net savings to tracked net savings for both electrical energy and peak demand savings, as compared between the evaluation and E1 tracking in Table 38.

Gross Savings NTGR Net Savings Realization Rate Value Unit Value Value Unit Value Electrical Energy Savings Tracked Savings by E1 4.228 GWh 1.00 4.228 GWh Evaluation Results 4.031 GWh 1.00 4.031 GWh 95% Peak Demand Savings Tracked Savings...

AI summary The table compares tracked and evaluated savings from the Strategic Energy Management (SEM) program in 2025. It shows gross and net savings for both electrical energy and peak demand, along with realization rates for the evaluated savings.

12 SEM Key Findings and Recommendations As mentioned previously, the main objectives of the 2025 SEM evaluation were as follows: › Calculate SEM gross and net results, namely electrical first-year and lifetime electrical energy savings, pe...

AI summary The 2025 SEM evaluation found that SEM exceeded net electrical energy and peak demand savings targets, with 4.031 GWh and 0.372 MW achieved, respectively. Participation levels rose to the highest since 2018, though energy savings per participant dropped by 43% compared to 2024. M&V methodologies were deemed generally appropriate and accurate.

Table 39: Overall 2025 Custom Incentives Participation and Evaluated Savings Particip ation Level Gross Savings NTGR Net S avings Value Unit Value Unit Value Unit Value Custom Electrical Energy Savings 36.207 GWh 0.84 30.487 GWh Lifetime E...

AI summary Table 39 presents the 2025 participation and evaluated savings for Custom Incentives, including electrical energy savings, peak demand savings, and GHG emission reductions. The program exceeded its targets for net electrical energy and peak demand savings, with Custom being the largest contributor to total program savings.

SEM APPENDIX XIV SEM Tracking Sheet Audit APPENDIX XV SEM Project Review Protocol APPENDIX XVI SEM Detailed Project Review Adjustments APPENDIX XVII SEM 2025 Recommendations 2475, Laurier boul., Suite 250 Quebec City, QC G1T 1C4 Canada Tel...

AI summary The document includes appendices related to Strategic Energy Management (SEM), covering tracking sheet audits, project review protocols, detailed adjustments, and 2025 recommendations. It also contains contact information for an organization in Quebec City, Canada.

Introduction I am with _____ and we are conducting an evaluation of the Custom Retrofit program offered by Efficiency Nova Scotia. This interview could take up to 30 minutes. Is this still a good time for you? We would like to better under...

AI summary The interview aims to evaluate Efficiency Nova Scotia's Custom Retrofit program by understanding decision-making processes for energy efficiency projects, ensuring confidentiality of responses, and aggregating results without affecting incentives.

C5. [ASK IF $ ≥0] As part of its Custom Retrofit program, Efficiency Nova Scotia provided your organization a $ incentive for the [Investigation or Feasibility] study. If this incentive had not been offered, would you have definitely, prob...

AI summary Efficiency Nova Scotia's Custom Retrofit program offers incentives for energy efficiency studies and implementation. The text asks respondents whether these incentives were necessary for conducting studies or implementing projects, and whether studies influenced project planning.

Factor [READ AND RANDOMIZE] Responses a. The program financial incentive for the [Investigation or Feasibility Study]. Response 98 Don't Know Refused b. The program financial incentive for the implementation of the energy efficiency measur...

AI summary The text presents a series of questions related to energy efficiency programs and responses indicating a lack of knowledge or refusal to answer. The topics include program financial incentives, energy savings information, and technical and non-technical support provided by Efficiency Nova Scotia staff and the Onsite Energy Manager (OEM).

E. Spillover - E1. Since taking part in the Custom Retrofit program, have you implemented any additional energy efficiency measures outside of the program? - 1. Yes - 2. No [GO TO SECTION F] - 98. Don't know [GO TO SECTION F] - 99. Refused...

AI summary The 'Spillover' section investigates whether participants in the Custom Retrofit program implemented additional energy efficiency measures outside the program, their financing sources, measure details, influence of the program on their decisions, and reasons for not using Efficiency Nova Scotia programs.

F. Program satisfaction - F1. On a scale from 1 to 10 (where 1 = not at all satisfied and 10 = very satisfied) … - a. how would you rate your satisfaction with each of the following aspects of the Custom Retrofit program?

AI summary This section asks participants to rate their satisfaction with the Custom Retrofit program on a scale from 1 to 10, where 1 is 'not at all satisfied' and 10 is 'very satisfied'.

APPENDIX III Retrofit and Pay-for-Performance Algorithm for Free-Ridership Calculation Question Answer Score incentive from Efficiency Nova Scotia? [READ] 4) Not at all confident 100% 98/99) Don't know/Refused 50% Planning Score C1 Cost Ef...

AI summary The text discusses a survey regarding incentives provided by Efficiency Nova Scotia, including rebate amounts for studies and project implementations, and how these incentives impacted the payback period for projects. Respondents were asked to evaluate the significance of the financial impact.

Cross-Influence Question Answer Score Cross-Influence 1) Yes, Custom Retrofit Before participating in the Custom Retrofit program for this project, had your 2) Yes, in another Efficiency Nova Scotia program To determine if participants D1...

AI summary The document presents a survey assessing the influence of Efficiency Nova Scotia programs on participants' decisions regarding energy efficiency projects. It includes questions about prior program participation, the impact of promotional materials, and whether participants sought technical advice or evaluated cost-effectiveness.

APPENDIX IV Retrofit and Pay-for-Performance Algorithm for Participant Spillover Calculation Current Algorithm Question Answer Score Since first taking part in the Custom 1) Yes CONTINUE E1 Retrofit program, have you implemented any additi...

AI summary This appendix outlines an algorithm to calculate spillover effects from the Custom Retrofit program, focusing on participant behavior and additional energy efficiency measures implemented outside the program. It includes questions to assess influence and quantify savings.

Table 1. 2025 Retrofit Corrected Tracked Savings Program Component Result Tracked by E1 Corrected Tracked Value Relative Difference Value Unit Value Unit Gross Electrical Energy Savings – at the Generator 16.032 GWh 16.032 GWh 0.00% Gross...

AI summary The tables present corrected tracked savings for various energy efficiency programs in 2025, showing no differences between tracked and corrected tracked values for electrical energy and peak demand savings across multiple programs.

ECONOL ≣I R Efficency Nova Scotia On-Site Visit Protocol - 2025 Écrire questions en rouge (pour interview) et les notes en noir Notes during/after interview A On site on Vintual Deviana 5. Other questionnaires Market questionnaire filled-i...

AI summary The text outlines a protocol for an on-site visit by Efficiency Nova Scotia in 2025, including sections for filling out various questionnaires and estimating the useful life of energy efficiency projects. It also includes sections for energy and demand savings adjustments by measure.

Savings calculation approach - Projects with M&V 5. Are the M&V boundaries capturing all the energy consumption that's impacted by the project? (Y/N) 7. Are M&V results measured in a short period extrapolated to annual results appropriatel...

AI summary The document outlines a structured approach for evaluating energy savings calculations using Measurement and Verification (M&V) methods, including questions about M&V boundaries, extrapolation of results, regression validity, and the impact of external factors like COVID-19 on savings calculations. It also includes sections on peak demand savings and interactive effects.

iency Nova Scotia? - 1. Very confident - 2. Somewhat confident - 3. Not very confident - 4. Not at all confident - 98. I am unsure - 99. I prefer not to say - I4. [SINGLE RESPONSE] Which one of the following best represents the impact of t...

AI summary The text presents survey questions assessing the impact of Efficiency Nova Scotia's financial incentives on building projects, focusing on budget adherence, financial justification, and likelihood of hiring energy modeling consultants. Respondents are asked about confidence levels and the influence of incentives on project decisions.

J. Cross-Influence - J1. [SINGLE RESPONSE] Before participating in the Custom New Construction program for the [INSERT PROJECT NAME] project, had your organization already participated in Custom New Construction or in another Efficiency No...

AI summary The text outlines survey questions assessing cross-influence of Efficiency Nova Scotia programs on new construction projects. It asks about prior program participation, technical staff engagement, cost-effectiveness evaluation, and the impact of promotional materials on building decisions.

EAD; FOR CALCULATION ONLY: SCORE = 25%] - 4. Definitely would not have [DO NOT READ; FOR CALCULATION ONLY: SCORE = 0%] - 98. Don't know - 99. Refused - B11. [IF B7 = 2 AND IF AVERAGE (B8,B9,B10) ≥ 75% ] You mentioned that, without the ince...

AI summary The text asks respondents to describe how their building design would differ without incentives from Efficiency Nova Scotia or the energy modeler's expertise, highlighting the role of energy efficiency programs in influencing building design decisions.

C. Cross-Influence - C1. Before participating in the Custom New Construction program for the building we discussed today, had you previously taken part in Custom New Construction this program or in another Efficiency Nova Scotia program? -...

AI summary The text presents survey questions assessing whether past participation in Efficiency Nova Scotia's programs or exposure to promotional materials influenced current decisions in new construction projects, focusing on cross-influence and program effectiveness.

Table 1: Participant Interview Questionnaire and Free-ridership Algorithm Question Answer Score D4 Before participating in the Custom New Construction program service, had you had seen energy efficiency promotional materials distributed by...

AI summary The table outlines a questionnaire used to assess participant engagement with energy efficiency promotional materials from Efficiency Nova Scotia, focusing on whether these materials influenced decisions related to building energy efficiency.

Table 1: 2024 Custom Corrected Tracked Savings Program Component Result Tracked by E1 Corrected Tracked Value Relative Difference Value Unit Value Unit Gross Electrical Energy Savings – at the Generator 18.713 GWh 18.713 GWh 0.00% Gross Pe...

AI summary Table 1 presents the 2024 Custom Corrected Tracked Savings for various program components, showing no differences between tracked and corrected tracked values for gross and net electrical energy and peak demand savings at the generator level.

APPENDIX XV SEM Project Review Protocol The SEM project review protocol used for the 2025 evaluation was the same protocol used in 2024. It includes sections that served to review both the bottom-up and top-down approaches used in the 2025...

AI summary The SEM Project Review Protocol for 2025 mirrors the 2024 approach, incorporating bottom-up and top-down evaluations. Methods include phone interviews and site visits based on E1 digital files, with a 2023-estimated net-to-gross ratio (NTGR) of 1.00 applied to the DSM cycle.

APPENDIX XVI SEM Detailed Project Review Adjustments = = Strategic Energy Management Efficiency Nova Scotia ECONOL≣R Project Review Protocol 1. General Information Interview/Site Visit Date: Project ID: NSPI Rate Code: Company Name: Addres...

AI summary This document outlines the SEM Detailed Project Review Adjustments, focusing on Strategic Energy Management in Nova Scotia. It includes sections for general information, participation history, and impact evaluation, with a bottom-up approach to measure energy savings and validate implemented measures.

DIRECT INSTALLATION PROGRAM Final Report 2025 DSM EVALUATION March 12, 2026

AI summary The Final Report for the 2025 Demand-Side Management (DSM) Evaluation of the Direct Installation Program, dated March 12, 2026, assesses the program's outcomes and compliance with regulatory goals. It focuses on evaluating the effectiveness of direct installation initiatives under DSM frameworks.

EXECUTIVE SUMMARY This report presents the 2025 demand-side management (DSM) results of the Direct Installation program administered by EfficiencyOne (E1). This program is comprised of the Small Business Energy Solutions (SBES) program com...

AI summary This report outlines the 2025 demand-side management (DSM) results for EfficiencyOne's Direct Installation program, which includes the Small Business Energy Solutions (SBES) component. SBES provides incentives and resources to Nova Scotia small businesses for implementing energy efficiency upgrades.

Table 2: Overall 2025 Direct Installation Participation and Evaluated Savings Participation Level Gross Savings NTGR Net Savings Value Unit Value Unit Value Value Unit Electrical Energy Savings Units 9.774 GWh 0.80 7.862 GWh Lifetime Elect...

AI summary Table 2 summarizes the 2025 Direct Installation program's participation and savings, showing that it fell short of its electrical energy and peak demand savings targets by 38% and 46% respectively. The program achieved 7.862 GWh in net electrical energy savings and 1.414 MW in net peak demand savings.

SBES Findings and Recommendations This subsection presents the key findings from the 2025 SBES evaluation. 2025 SBES-Finding: SBES fell short of the net electrical energy savings and net peak demand savings targets by 38% and 46% respectiv...

AI summary The 2025 SBES evaluation found that the program missed its net electrical energy and peak demand savings targets by 38% and 46%, respectively. Participation increased slightly (1%) compared to 2024, with DIY rebates accounting for 99% of all units rebated. Evaluated savings were slightly lower than E1-tracked savings.

Table 3: Comparison of 2025 SBES Tracked and Evaluated Savings at the Generator Gross Savings Net Savings Realization Value Unit NTGR Value Unit Rate Electrical Energy Savings Tracked Savings by E1 9.805 GWh 0.80 7.886 GWh 100% Evaluation...

AI summary Table 3 compares the tracked and evaluated savings from the 2025 SBES (Small Business Energy Solutions) program, showing gross and net savings in electrical energy and peak demand, along with realization rates and net-to-gross ratios (NTGR).

EfficiencyOne (E1), an independent, non-profit organization, is responsible for helping Nova Scotians improve the energy efficiency of their homes and workplaces by designing, marketing, and delivering demand-side management (DSM) for Nova...

AI summary EfficiencyOne (E1) is an independent, non-profit organization that delivers demand-side management (DSM) programs through the Efficiency Nova Scotia (ENS) franchise. E1's 2025 DSM program portfolio includes a Direct Installation program component, Small Business Energy Solutions (SBES), which was evaluated using a condensed impact evaluation method.

Table 4: Type of Evaluation Conducted for SBES, 2025 Program 2025 Program Component Process Market Impact Direct Installation SBES - - Condensed For each program, the Evaluator prepared a DSM evaluation report presenting key findings, elec...

AI summary Table 4 outlines the type of evaluation conducted for the Small Business Energy Solutions (SBES) program in 2025, focusing on direct installation. The Evaluator prepared a DSM evaluation report that includes key findings, first-year and lifetime energy savings, peak demand savings, and avoided greenhouse gas emissions.

Table 6: 2025 SBES Evaluation Approach Evaluation Objectives Research Questions Methodology Calculate gross results › Are the data in the tracking sheet complete, accurate, and consistent? › What are the average interactive effect factors,...

AI summary Table 6 outlines the 2025 SBES Evaluation Approach, focusing on calculating gross and net results through tracking sheet audits, adjustment ratios, and GHG emission reduction calculations. It addresses research questions related to data accuracy, interactive effects, and the application of baseline methodologies.

3.2.1 Unitary Energy Savings and Peak Demand Savings Savings for SBES Audit and DIY projects are established through calculations using data specific to each project. The 2025 Demand-side Management Measure Assessment (DSM MA) [8](#page-11...

AI summary Savings for SBES Audit and DIY projects are calculated using project-specific data. The 2025 DSM MA provides detailed methodologies for unitary energy and peak demand savings calculations across measure categories.

3.2.2 Installation Rates Installation rates are accounted for in the adjustment ratios for SBES Audit and DIY projects, as documented in the 2025 DSM MA.

AI summary The document discusses how installation rates are factored into adjustment ratios for SBES Audit and DIY projects under the 2025 DSM MA, highlighting their role in program evaluation and cost adjustments.

3.2.3 Interactive Effects Interactive effects occur when the implementation of energy efficiency measures has an impact on the energy consumption of other elements such as heating and cooling. For the SBES Audit and DIY paths, these are ta...

AI summary Interactive effects in energy efficiency measures impact heating/cooling systems. The E1 CIRx Screening Tool and 2025 DSM MA calculate savings, adjusting factors for recessed fixtures (LED linear) by 57%. Evaluations ensure accurate interactive effects factors are applied, with adjustments included in 2023/2025 adjustment ratios.

3.2.4 Effective Useful Life As part of the 2025 DSM MA activities, the Evaluator reviewed the EUL values used in the calculation of electrical energy savings that are expected to persist over time. The EUL values established in previous ev...

AI summary The Evaluator reviewed Effective Useful Life (EUL) values for specific LED measures as part of the 2025 DSM MA, noting changes in baseline expectations over time. Only modified EUL values are presented in Table 7.

Table 8: Evaluated 2025 SBES Gross Electrical Energy and Peak Demand Savings – Audit Path Category of Measure Agriculture Commercial Kitchen HVAC Laundry Lighting Refrigeration Total for All Categories Electrical Energy Savings Gross Elect...

AI summary Table 8 provides an evaluation of the 2025 SBES (Small Business Energy Solutions) gross electrical energy and peak demand savings using an audit path. It includes data on energy savings across various categories, adjustment ratios, interactive effects, line loss factors, and effective useful life of measures.

Table 9: Evaluated 2025 SBES Gross Electrical Energy and Peak Demand Savings – DIY Path Category of Measure Agriculture Commercial Kitchen HVAC Laundry Lighting Motor Refrigeration Envelope Total for all Categories Energy Savings Gross Ele...

AI summary Table 9 and Table 10 evaluate the 2025 SBES gross electrical energy and peak demand savings for the DIY path and both paths combined. The tables include metrics such as energy savings, adjustment ratios, line loss factors, and effective useful life. Evaluated gross savings differ slightly from tracked values due to corrections in interactive effects factors.

Table 14: Evaluated 2025 SBES Net Electrical Energy and Peak Demand Savings Measure Category Audit Path DIY Path Total Electrical Energy Savings Gross Electrical Energy Savings – at the Meter (GWh) 0.274 8.866 9.140 NTGR 0.88 0.80 - Net El...

AI summary Table 14 evaluates the 2025 SBES net electrical energy and peak demand savings, showing that SBES fell short of its energy savings target by 38% and its peak demand savings target by 46%. The table includes metrics such as gross and net electrical energy savings, line loss factors, and effective useful life.

3.4 Realization Rate [Table](#page-20-0) 15 below compares the tracked electrical energy and peak demand savings values established through this evaluation to those calculated in the 2025 tracking sheet. It also includes the realization ra...

AI summary Table 15 compares tracked electrical energy and peak demand savings values from the current evaluation to those in the 2025 tracking sheet, including the realization rate, which is the ratio of evaluated net savings to tracked net savings for both energy and peak demand.

Table 15: Comparison of 2025 SBES Tracked and Evaluated Savings at the Generator Gross Savings Net Savings Realization Value Unit NTGR Value Unit Rate Electrical Energy Savings Tracked Savings by E1 9.805 GWh 0.80 7.886 GWh 100% Evaluation...

AI summary Table 15 compares the tracked and evaluated savings from the 2025 SBES program. Evaluated net electrical energy savings were slightly lower (0.3%) than tracked values, while net peak demand savings were 1.0% higher. Minor differences are attributed to corrections in interactive effect factors made by the Evaluator.

4 SBES Key Findings and Recommendations The main objectives of the 2025 SBES evaluation were as follows: › Calculate gross and net electrical energy and peak demand savings, annually avoided GHG emissions, as well as EUL values and associa...

AI summary The 2025 SBES evaluation found that the program missed its net electrical energy and peak demand savings targets by 38% and 46%, respectively. Evaluated savings were slightly lower than E1's tracked values for energy but higher for peak demand. Participation increased by 1% compared to 2024, with DIY rebates dominating.

CONCLUSION [Table](#page-22-0) 16 below summarizes the participation level, net-to-gross ratios (NTGRs), evaluated gross and net savings at the generator, annual GHG emission reductions, as well as EUL values for Direct Installation as a w...

AI summary The conclusion section references a table summarizing participation levels, net-to-gross ratios, evaluated gross and net savings, annual GHG emission reductions, and EUL values for Direct Installation programs.

Table 16: Overall 2025 Direct Installation Participation and Evaluated Savings Participation Level Gross Savings NTGR Net Savings Value Unit Value Unit Value Value Unit SBES Electrical Energy Savings 62,011 Units 9.774 GWh 0.80 7.862 GWh L...

AI summary Table 16 presents the 2025 Direct Installation participation and evaluated savings under the SBES program. The program fell significantly short of its energy savings and peak demand targets, with a 38% shortfall in net electrical energy savings and a 46% shortfall in net peak demand savings.

DEMAND RESPONSE PROGRAM Final Report 2025 DSM EVALUATION March 20, 2026

AI summary The document presents the Final Report of the 2025 Demand-Side Management (DSM) Evaluation, focusing on the Demand Response (DR) Program. It assesses the program's effectiveness, cost-efficiency, and alignment with Nova Scotia's energy goals, likely including recommendations for improvement.

Evaluation Approach The 2025 evaluation was aimed at calculating program component results, namely new and total available DR capacity. [Table](#page-40-0) 1 summarizes the types of evaluation conducted for each program component and the c...

AI summary The 2025 evaluation focused on calculating program component results, specifically new and total available DR capacity, with Table 1 outlining the types of evaluation and corresponding methodology for each program component.

Table 1: Summary of 2025 Demand Response Program Evaluation Evaluation Type Methodology Program Component Process Market Impact Residential Demand Response X Comprehensive › Non-participant survey › Program staff interviews › Service provi...

AI summary The document outlines the evaluation of the 2025 Demand Response Program, including the Residential Demand Response and BNI Demand Response components. It describes the evaluation methodology, which includes surveys, interviews, audits, and data analysis, and references Table 2 for participation levels and available DR capacity.

Table 2: Overall 2025 Demand Response Participation and Evaluated Results Participation Level Evaluated Results Value Unit Value Unit Residential DR Available DR Capacity 3,676 Participants 0.854 MW BNI DR Available DR Capacity 143 Partici...

AI summary In 2025, the Demand Response (DR) program aimed to achieve 17.861 MW in available DR capacity but fell short. Residential DR and BNI DR did not meet their targets, though BNI DR remained the largest contributor with 5.941 MW of available DR capacity.

Residential DR Findings and Recommendations This subsection presents the key findings and recommendations from the 2025 Residential DR evaluation. The recommendations are also outlined in Appendix VII. 2025 Res DR-Finding: Residential DR o...

AI summary The 2025 Residential DR evaluation highlights a diverse mix of eligible devices, integration of pathways into 'Eco Shift,' program design updates, and documentation issues blending with BNI DR. Service providers report smooth operations and positive collaboration with E1, but slower growth is expected due to testing needs.

BNI DR Findings and Recommendations This subsection presents the key findings and recommendations from the 2025 BNI DR evaluation. 2025 BNI DR - Finding: In 2025, BNI DR available DR capacity at the generator amounted to 5.941 MW. Therefor...

AI summary The 2025 BNI DR evaluation found that available DR capacity (5.941 MW) fell short of the 10.726 MW target. Morning events generated higher capacity than evening ones, and while participation increased by 88%, capacity per participant dropped from 106 kW to 42 kW due to non-participation. Recommendations include process evaluations in 2026 and project reviews to improve accuracy and savings tracking.

Table 3: Comparison of 2025 Demand Response Tracked and Evaluated Available DR Capacity at the Generator Available DR Capacity Realization Value Unit Rate Residential DR Available DR Capacity Tracked by E1 0.540 MW 158% Evaluation Results...

AI summary Table 3 compares the tracked and evaluated available demand response (DR) capacity for residential and BNI DR programs in 2025. The table shows that residential DR capacity is 0.540 MW (tracked by E1) with a realization rate of 158%, and BNI DR capacity is 6.648 MW (tracked by E1) with a realization rate of 89%.

1.1 Residential DR Description In 2023, E1 officially launched Residential DR. Since the fall of 2020, E1 has implemented several initiatives focused on reducing demand during the Nova Scotia peak period. The Residential DR program compone...

AI summary The Residential Demand Response (DR) program in Nova Scotia, launched by E1 in 2023, offers four pathways for participants to reduce demand during peak periods. Eligibility criteria, incentives, and technical implementation details are outlined, including the role of EPI, Virtual Peaker, and Shifted Energy in program execution.

Table 6: Residential DR 2024/25 Event Summary Event # Date Start Time Duration (Hours) Outdoor Temperature at Event Start (°C) 1 12-04-2024 5 p.m. 4 -3 2 12-20-2024 7 a.m. 4 -3 3 12-23-2024 5 p.m. 4 -8 4 01-21-2025 5 p.m. 4 -8 5 01-22-2025...

AI summary Table 6 summarizes Residential Demand Response (DR) events in 2024/25, including dates, times, durations, and outdoor temperatures at event starts. It differentiates between enrolled and participating devices, with enrolled devices being ready for control but not necessarily controlled during events.

1.2 Follow-up on Past Evaluation Report Recommendations The Evaluator evaluated Residential DR in 2023 and 2024 and issued improvement recommendations. [Table](#page-49-2) 7 below outlines the status of those recommendations that were carr...

AI summary The Evaluator assessed Residential Demand Response in 2023 and 2024 and issued improvement recommendations. The status of those recommendations that were carried forward is outlined in Table 7.

Table 7: Implementation Status of Past Recommendations for Residential DR # Recommendation Status Comments 2023 – Res DR-R1 Ensure that available DR capacity tracked by E1 includes the in service rate as well as the unitary available DR ca...

AI summary This table outlines the implementation status of past recommendations for Residential Demand Response (DR). Two recommendations from 2023 and 2024 have been completed, with E1 agreeing to track in-service rates and unitary available DR capacity values and to re-analyze Eco Shift Pilot data to improve accuracy and consistency.

For Residential DR, participation is defined as the number of households participating in each technology pathway. Therefore, a household participating in both the Smart Thermostat DLC and EV Telematic and Charger Control pathways would co...

AI summary The document discusses the participation in Residential Demand Response (DR) programs during the 2024/25 season, noting a significant increase in participants and enrolled devices. Smart thermostats are the most common enrolled device, but not all enrolled devices participated in each event due to connectivity and availability issues.

Table 8: Residential DR Device Enrollment Throughout the 2024/25 DR Season Number of Devices Enrolled per Event Event # Event Date Smart Thermostats DHW Controllers EV Telematic and Charger Controls Battery Control Total 1 12-04-2024 3,066...

AI summary Table 8 outlines the number of residential demand response (DR) devices enrolled during the 2024/25 DR season, including smart thermostats, domestic hot water (DHW) controllers, EV telematic and charger controls, and battery controls. DHW controllers were not counted as enrolled until after the third event due to initial issues.

2 Residential DR Evaluation Approach The 2025 Residential DR evaluation consisted of a comprehensive impact evaluation and a process evaluation. The main objectives of the overall 2025 Residential DR evaluation were as follows: - › Collect...

AI summary The 2025 Residential DR evaluation involved a comprehensive impact and process evaluation with objectives to collect feedback on participation and calculate new and total available DR capacities. Research questions, methods, and sample sizes were outlined in Table 9.

Table 9: 2025 Residential DR Evaluation Approach Evaluation Objectives Research Questions Methodology Collect feedback from program staff, service providers, other jurisdictions, and non participants on increasing/maintaining participation...

AI summary Table 9 outlines the 2025 Residential Demand Response (DR) Evaluation Approach. It includes objectives, research questions, and methodology to evaluate the program, focusing on feedback from non-participants, program awareness, barriers to participation, and operational improvements.

Tracking Sheet Audit Prior to performing the available DR capacity calculation review, the Evaluator audited the final 2025 tracking sheet to ensure it was complete and the entered data were consistent. The results obtained are presented i...

AI summary The Evaluator audited the final 2025 tracking sheet to verify completeness and data consistency prior to reviewing DR capacity calculations, with results detailed in Appendix IV.

Metering Data Analysis To establish the available DR capacity generated from smart thermostats, the Evaluator updated the unitary available DR capacity using the same metering data analysis methodology as the previous evaluation. The Evalu...

AI summary The Evaluator used whole-house data for smart thermostats due to interactive effects, while device-level data were used for DHW controllers, EV telematics, and battery control. Reliance on 2023 Residential DR evaluation data for DHW and a new 2025 in-service rate due to implementation issues were noted. Methodologies are detailed in Subsection 4.2.2.

Calculations Using Evaluation Results Building on all the above methods and collected data, the Evaluator calculated the amount of available DR capacity as per the calculation methodology presented in Section [4](#page-82-0) below.

AI summary The Evaluator calculated available DR capacity using a methodology outlined in Section 4, based on collected data and prior evaluation methods.

3.3.1 Non-participant Recruitment To gather feedback from the non-participant perspective, the Evaluator conducted a survey among Efficient Product Installation (EPI) participants who received a smart thermostat in 2024 but who had not enr...

AI summary The Evaluator conducted a survey of Efficient Product Installation (EPI) participants who received smart thermostats but did not enroll in Residential DR. Challenges in linking EPI and Residential DR data hindered precise identification of non-participants. 66% of respondents confirmed their thermostats were not enrolled, 20% were enrolled, and 15% were unsure. The analysis focused on non-participants (n=103), excluding those who enrolled (n=25).

3.3.2 Level and Sources of Program Awareness Among Non-participants

AI summary This section examines the awareness levels and sources of information about energy efficiency programs among non-participants in Nova Scotia. It likely explores outreach effectiveness, barriers to participation, and the role of existing programs in informing residents and businesses.

3.4.1 Enrollment and Participation Challenges Among Non-participants

AI summary This section addresses challenges related to enrollment and participation in energy efficiency programs among non-participants, focusing on barriers to involvement and potential strategies for improvement.

Additional Information Required to Reconsider Enrollment Non-participants also shared the additional information they would need to reconsider enrollment in Residential DR, with nine indicating that they would like more information overall...

AI summary Non-participants expressed a desire for more information to reconsider Residential DR enrollment, citing confusion and a preference for manual heating control. EPI applies a 2024 installation rate to thermostat savings for a small subset of non-users.

Smart Thermostat DLC, Battery Control, EV Telematic and Charger Control Pathway CLEAResult is responsible for the Smart Thermostat DLC, Battery Control, and EV Telematic and Charger Control pathway program delivery. CLEAResult reports that...

AI summary CLEAResult manages Nova Scotia's Smart Thermostat DLC and EV control programs, reporting high retention (97%) in Residential DR but noting call centre inefficiencies, device connectivity issues, and participant confusion. Privacy concerns and lack of real-time feedback during DR events are highlighted, with recommendations to adjust incentives and improve education for better engagement.

3.6.1 Program Design The jurisdictional scan findings related to DR program aspects such as eligible devices, enrollment process, eligibility criteria, and incentive structure levels are highlighted in this section and organized by device...

AI summary This section outlines jurisdictional scan findings related to Demand Response (DR) program design, focusing on eligible devices, enrollment processes, eligibility criteria, and incentive structures, organized by device type where applicable.

Eligible Devices The Evaluator compared products offered in the researched jurisdictions to those offered by E1. Similarly to E1, two jurisdictions (PSE and BC Hydro) offer DR programs for four device types, namely smart thermostats, elect...

AI summary The Evaluator compared eligible devices in DR programs across multiple jurisdictions, including PSE, BC Hydro, and others, to those offered by E1. The analysis shows that most jurisdictions include DR programs for smart thermostats, EVs, home batteries, and HWCs, with some exceptions.

Table 10: Types of Devices Included in DR Programs per Jurisdiction Program Administrator Smart Thermostats EV and EV Chargers Home Batteries Hot Water Controllers Efficiency Nova Scotia ✓ ✓ ✓ ✓ BC Hydro ✓ ✓ ✓ ✓ DTE Energy ✓ ✓ - ✓ Green Mo...

AI summary Table 10 lists the types of devices included in demand response (DR) programs across various jurisdictions, highlighting the participation of Efficiency Nova Scotia and other utility providers. The table includes categories such as smart thermostats, EV and EV chargers, home batteries, and hot water controllers.

All programs adopt a bring-your-own-device (BYOD) option requiring participants to own or purchase and install eligible smart devices to enroll. Hydro-Québec and Yukon Energy are the only jurisdictions combining both BYOD and direct instal...

AI summary The text discusses how DR programs in various jurisdictions offer participants options to enroll via bring-your-own-device (BYOD) or through energy efficiency programs that provide free or discounted devices. It also notes variations in enrollment processes, such as optional steps or device-type dependencies.

Table 11: DR Program Enrollment Pathways by Jurisdiction Program Administrator Is there a Complimentary Energy Efficiency Program Associated with DR? DR Enrollment Pathway via Energy Efficiency Program? Efficiency Nova Scotia √ (EPI: Free...

AI summary Table 11 outlines Demand Response (DR) program enrollment pathways by jurisdiction, including whether a complimentary energy efficiency program is associated with DR and the enrollment process. Efficiency Nova Scotia, BC Hydro, IESO, National Grid, PSE, and Rhode Island Energy are highlighted with their respective DR and energy efficiency program details.

Incentive Structure and Levels This section is organized by device type because the incentive structure and levels vary greatly between devices for most of the jurisdictions. For each subsection, incentives are organized by enrollment ince...

AI summary The incentive structure is organized by device type, with enrollment and participation incentives defined. Enrollment incentives are one-time benefits for joining programs, while participation incentives reward demand reduction or event participation. Comparisons across jurisdictions are complicated by regional differences in living and energy costs.

Enrollment Incentive As in Nova Scotia, all jurisdictions with an eligible smart thermostat DR program, except DTE Energy, offer incentives at enrollment. While E1 offers an incentive per device with a lower amount for additional devices e...

AI summary This section compares enrollment incentives for smart thermostat demand response (DR) programs across various jurisdictions, noting that most offer incentives at enrollment, with variations in amounts, customer types, and thermostat types. Yukon Energy provides rebates, and Hydro-Québec offers either per-device incentives or free thermostats.

Participation and Other Incentives Most jurisdictions, similar to E1, offer a fixed annual incentive per household, ranging from $20 for the IESO to $71 for DTE Energy. PSE and Rhode Island Energy both offer an amount per device, with PSE...

AI summary The text discusses various incentive structures for demand response (DR) programs across different jurisdictions, including fixed annual incentives per household, per-device incentives, and additional rewards such as gift cards and prize draws for participation in DR programs.

Table 12: Smart Thermostat Incentive Structures and Levels per Jurisdiction Program Administrator a Enrollment Incentive Participation Incentive Other Efficiency Nova Scotia $25 for the 1st device, $20/each additional oneb $30/household/ye...

AI summary Table 12 compares smart thermostat incentive structures and levels across various jurisdictions, highlighting differences in enrollment, participation, and other incentives offered by program administrators such as Efficiency Nova Scotia, BC Hydro, and others.

Participation Incentive and Other Recurring incentives for continued enrollment vary widely. They may be a fixed annual amount per device or household, a monthly payment, or a performance-based amount per kilowatt reduced during DR events....

AI summary Recurring incentives for participation in demand response (DR) programs vary by jurisdiction, with examples including fixed annual payments, monthly payments, or performance-based incentives. E1 offers a higher incentive ($50 per device) compared to Rhode Island and BC Hydro, which offer lower amounts. Hydro-Québec does not provide incentives but offers lower electricity rates during peak events.

Table 13: EV and EV Charger Incentive Structures and Levels per Jurisdiction Program Administratora Enrollment Incentive Participation Incentive Other Efficiency Nova Scotia $50/household $50/device/year - BC Hydro $250/household $50/house...

AI summary Table 13 outlines various EV and EV charger incentive structures and levels across different jurisdictions, including enrollment and participation incentives, as well as other program features. The table includes data from Efficiency Nova Scotia, BC Hydro, DTE Energy, Hydro-Québec, Puget Sound Energy, and Rhode Island Energy.

Participation Incentive All jurisdictions provide either a recurring seasonal incentive (per battery or per household) or a performancebased payment. In Vermont (Green Mountain Power), incentives vary by program type; for backup-only insta...

AI summary The document compares participation incentives for energy programs across different jurisdictions, noting varying rates such as Vermont's Green Mountain Power offering higher incentives than E1 but similar to National Grid and Rhode Island Energy.

Table 14: Home Battery Incentive Structures and Levels per Jurisdiction Program Administratora Enrollment Incentive Participation Incentive Efficiency Nova Scotia $500/household $300/average kW across all events BC Hydro $500/household $25...

AI summary Table 14 outlines home battery incentive structures and levels per jurisdiction, showing variations in enrollment and participation incentives across different program administrators in Canada and the US. The table highlights the differences in financial support provided by entities such as Efficiency Nova Scotia, BC Hydro, and others.

Participation Incentive Similarly to E1, only PSE and BC Hydro offer a recurring seasonal incentive of $28 and $50 respectively per household. Hydro-Québec and DTE Energy provide only preferred rates for water heaters, while Yukon Energy o...

AI summary The text compares participation incentives for demand response programs across different utilities, noting that PSE and BC Hydro offer recurring seasonal incentives, while others like Hydro-Québec and Yukon Energy provide limited or no incentives.

Table 15: Hot Water Controllers Incentive Structures and Levels per Jurisdiction Program Administratora Enrollment Incentive Participation Incentive Other Efficiency Nova Scotia - $20/device/year - BC Hydro $100/household $50/household/yea...

AI summary Table 15 compares hot water controller incentive structures across various jurisdictions, including enrollment and participation incentives, as well as additional benefits like discounted rates and gift cards.

3.6.2 Program Operations This section highlights the jurisdictional scan findings related to DR program aspects such as event design, internal and external resources, and program metrics.

AI summary This section outlines jurisdictional scan findings for Demand Response (DR) programs, focusing on event design, internal/external resource allocation, and program metrics as key operational aspects under review.

Event Design Event duration is fairly consistent across jurisdictions, typically ranging from three to four hours. In contrast, event frequency varies significantly by jurisdiction and device type. For smart thermostats, the lowest frequen...

AI summary Event duration is typically three to four hours across jurisdictions, but event frequency varies significantly by device type and region, with some programs reporting up to 200 events per year. These figures represent upper limits reported by utilities, and actual practice may differ based on operational needs and other factors.

Table 16: Event Frequency and Length per Jurisdiction Peak Period Program Smart Thermostats EVs and EV Chargers Home Batteries Hot Water Controllers Administrator # of Events Length # of Events Length # of Events Length # of Events Length...

AI summary Table 16 provides a comparison of event frequency and length per jurisdiction for various demand response (DR) programs, including smart thermostats, EVs and EV chargers, home batteries, and hot water controllers. The table lists administrators and the number of events and their maximum duration in different seasons.

Table 17: Participation Levels per Jurisdiction Program Administrator Smart Thermostats EVs and EV Chargers Home Batteries Hot Water Controllers Efficiency Nova Scotia 2025/26: 2,664 participating households and 9,886 enrolled devices 2025...

AI summary Table 17 presents participation levels in various energy programs across different jurisdictions, highlighting the number of households and devices enrolled in initiatives such as smart thermostats, EVs, home batteries, and hot water controllers.

Budget [Table](#page-76-0) 18 presents the budgets allocated to DR programs across jurisdictions where information was publicly available. Budgets are highly dependent on jurisdiction-specific operational needs and local economic condition...

AI summary The document provides a comparative analysis of DR program budgets across various jurisdictions, noting that budgets depend on local operational needs and economic conditions. The analysis includes Nova Scotia Power, Hydro Quebec, BC Hydro, and Ontario, but excludes Yukon due to its small population.

Table 18: Budget per Jurisdiction Program Administratora Budget Efficiency Nova Scotia 2025/26: $2.84 million BC Hydro Budget 2025-27: $110 million (DR programs for residential, commercial, and industrial customers) $12.8 M forecast for re...

AI summary Table 18 provides a comparison of energy efficiency and demand response program budgets across various jurisdictions, including Efficiency Nova Scotia, BC Hydro, DTE Energy, and others, with specific figures for 2024 and 2025-27.

Savings [Table](#page-77-1) 19 presents the savings targets of DR programs across jurisdictions where information was publicly available. Savings targets are highly dependent on jurisdiction specific system needs and demographic characteri...

AI summary Table 19 outlines the savings targets of demand response (DR) programs across various jurisdictions. These targets depend on specific system needs and demographic factors. Examples of DR programs include CoolCurrents, Smart Savers, and SmartCharge, which target summer and autumn peak demand.

Table 19: Savings per Jurisdiction Program Administratora Savings Efficiency Nova Scotia Actuals 2025: 0.958 MW (target: 7.135 MW) › Smart Thermostats Electric Baseboard (EBB) Only: 112 W/device › Smart Thermostats Mini-split Heat Pump (MS...

AI summary Table 19 provides a comparison of savings achieved by various demand response (DR) programs across different jurisdictions, including Efficiency Nova Scotia, BC Hydro, DTE Energy, and others. The data highlights actual and target savings in terms of MW and W/device for various DR program components such as smart thermostats, DHW controllers, EV telematics, and batteries.

3.7 In-depth Jurisdictional Perspectives To further explore the findings from the jurisdiction scan, two qualitative interviews were conducted with program managers from Canadian jurisdictions. These jurisdictions were selected because the...

AI summary The section discusses qualitative interviews with Canadian jurisdiction program managers to explore DR program design, operations, and best practices. The selected jurisdictions have similar device types to E1 and extensive DR experience, though their larger scale and vertical integration make some aspects non-comparable to E1.

Enrollment Process One interviewed Canadian program administrator offers two paths for smart thermostats to participate in DR events: behavioural and connected. The behavioural path[32](#page-78-2) allows participants to adjust their devic...

AI summary The text outlines enrollment processes for smart thermostats in Demand Response (DR) programs, highlighting two paths (behavioral and connected) and three enrollment methods (BYOD, OEM agreements, and retail purchases). It notes that behavioral options attract more customers by avoiding external control, with 75% of enrollments completed online and 90% via BYOD.

Marketing and Communications According to the first Canadian program manager interviewed, most jurisdictions tend to position their marketing messaging around incentives and rebates. They believe a more sophisticated approach would be usef...

AI summary The text discusses marketing strategies for demand response (DR) programs, emphasizing behavioral approaches and customer education. It highlights shifting from direct control requests to service offers and leveraging OEMs and cross-promotion for outreach, while stressing the importance of educating customers on variable rates and DR benefits.

3.7.3 Lessons Learned and Future Opportunities

AI summary This section outlines lessons learned from past initiatives and identifies future opportunities for energy efficiency and demand-side management programs in Nova Scotia, referencing programs like DSM, ARet, and CGH Grant, and considering factors such as affordability and technology adoption.

Technological Issues One Canadian program administrator interviewed continues to face challenges related to database management and data flows and shared that achieving operational efficiencies in a demand response program requires a conti...

AI summary The text highlights challenges in demand response (DR) program management, including database complexity and scaling from pilots to full programs. It notes that operational efficiencies require continuous improvement and that direct device connectivity and meter visibility reduce challenges for program administrators.

Behavioural Considerations With regards to EV Chargers, one program administrator mentioned that actual customer usage patterns differ significantly from initial assumptions regarding charging behaviour. Rather than consistently returning...

AI summary EV charging behavior differs from initial assumptions, with users charging less frequently but in higher volumes, reducing DR participation to 30%. Lower Level 2 charger penetration further limits DR potential. EV telematics is proposed as a solution to improve participation.

Future Opportunities According to one Canadian program manager, smart thermostats, being inexpensive and having energy efficiency benefits, is a promising category to develop in the next couple of years. To do so, they plan to work closely...

AI summary The document highlights opportunities to expand demand response (DR) programs through smart thermostats, emphasizing partnerships with manufacturers to streamline enrollment and address decision fatigue. Strategies include shifting from instant rebates to enrollment incentives and maximizing device installations during home visits by installers.

4.1 Tracking Sheet Audit To ensure program component results were reliably compiled, the Evaluator first performed a tracking sheet audit aimed at verifying the completeness and consistency of the data submitted by E1 as well as correcting...

AI summary The Evaluator conducted a tracking sheet audit to verify the completeness and consistency of data submitted by E1, correcting the tracked available DR capacity as needed. The results are detailed in Appendix IV, with the report referencing the corrected data.

Portion of the DR Season with Enrolled Devices New participants continued to register throughout the DR season. To account for these, the Evaluator calculated, when applicable, the portion of the DR season with enrolled devices by dividing...

AI summary The Evaluator calculated the portion of the DR season with enrolled devices by dividing the average number of enrolled devices by the number at season's end. This method applied to Smart Thermostat DLC and DHW DLC pathways, while other pathways used participation rates for similar metrics.

Participation Rate The participation rate captures all reasons enrolled devices did not participate. Indeed, participants can opt out of any event, not all EVs are connected to the grid during events, and connectivity issues can result in...

AI summary The participation rate reflects the proportion of enrolled devices that actually participate in demand response (DR) events. For Smart Thermostat DLC, opt-outs and connectivity issues do not affect the participation rate. However, for other pathways like Battery Control and EV Telematic, participation rates are low due to dispatching issues and lack of charging during events. Recommendations include using bidirectional chargers and conducting feasibility studies.

Table 20: Residential DR Participation Rates per 2024/25 Event DHW Controllers EV Telematics and Chargers Battery Controls Event # Event Date Number of Enrolled Devices Number of Participating Devices Participation Rate Number of Enrolled...

AI summary Table 20 shows residential demand response participation rates for various events in 2024/25, highlighting low participation in EV telematics and chargers and higher participation in battery controls. The weighted average participation rates are 22.5% for DHW controllers, 2.9% for EV telematics and chargers, and 63.2% for battery controls.

Metering Data Analysis Methodology This subsection provides a high-level description of the methodologies used to establish smart thermostat DLC, EV telematic and charger, and battery control unitary available DR capacities for the 2025 ev...

AI summary This subsection outlines methodologies for evaluating smart thermostat DLC, EV telematics and charger, and battery control unitary available DR capacities in the 2025 assessment, focusing on data analysis techniques for demand response (DR) capacity estimation.

EV Telematics and Chargers For EV telematics and chargers, the Evaluator used device-level data to establish consumption during and after DR events and calculate what would have been drawn from the grid during the events in the absence of...

AI summary The Evaluator used device-level data to calculate demand response (DR) capacity by analyzing EV charger consumption during and after DR events. Data was cleaned to remove duplicates, and hourly savings were calculated by comparing energy use during events with post-event consumption, assuming devices stopped charging during events. Non-responsive devices were excluded from the analysis.

Metering Data Analysis Results Using the methodologies presented above, the Evaluator established the DR capacity made available at each event hour of the 2024/25 DR season for each pathway. As mentioned in the introduction, available DR c...

AI summary The Evaluator analyzed DR capacity data from the 2024/25 DR season, identifying outliers such as Event 1 and Event 7 due to low participation and external factors like a snowstorm. Communication issues and thermostat settings also impacted DR capacity availability.

Table 21: 2024/25 Available DR Capacity per Participant per Event Available DR Capacity per Participant (W) Event # Event # Event Date Smart per Space EV Telematics Battery EBB Only MSHP Only EBB and MSHP Only Others and Chargers Controls...

AI summary Table 21 presents the 2024/25 available demand response (DR) capacity per participant per event, highlighting variations across different pathways such as Smart per Space, EV Telematics, and Battery Controls. The data shows average available DR capacity values, with some margins of error slightly above the typical 10% threshold. The Evaluator considers these acceptable for establishing 2025 results and E1 tracking for 2026 but notes the need for further analysis to ensure consistency year over year.

Unitary Available DR Capacity Whil[e Table](#page-87-0) 21 above outlines the average available DR capacity value per participant for each pathway and subgroup, this subsection presents other relevant metrics that were assessed by the Eval...

AI summary The text references Table 21, which outlines average demand response (DR) capacity values per participant across pathways and subgroups, while noting that this subsection addresses additional metrics evaluated by the Evaluator. The focus is on DR capacity assessments within regulatory proceedings.

Smart Thermostats For smart thermostats, the Evaluator established unitary available DR capacity per thermostat since this metric is better aligned with how participation is tracked. The household data included in the metering analysis wer...

AI summary The Evaluator determined unitary available DR capacity per smart thermostat, using household data to calculate average numbers per household and dividing average DR capacity by this figure. This metric was used to calculate the 2025 evaluated available DR capacity for the Smart Thermostat DLC pathway.

Table 22: 2024/25 Available DR Capacity per Thermostat EBB Only MSHP Only EBB and MSHP Only Others Average Available DR Capacity Per Participant, Excluding Outliers (W/Participant) 581 226 518 426 Average Number of Smart Thermostats per Pa...

AI summary Table 22 presents the 2024/25 available demand response (DR) capacity per thermostat across different participant categories. The Evaluator recommends using the values from this table to track DR capacity for 2026 and conducting further analysis in future years based on AMI data availability.

EV Telematics and Chargers The Evaluator established a unitary available DR capacity value per EV device since this metric is aligned with how participation is tracked. The calculated total available DR capacity was divided by the number o...

AI summary The Evaluator established a unitary available DR capacity value of 4,015 W per EV device, recommending its use for 2026 and further analysis to ensure consistency. This value was derived from dividing total DR capacity by participating devices during events.

Battery Controls As described above, the Evaluator first established a unitary available DR capacity per battery and also calculated an average available DR capacity per battery capacity. The latter was used to calculate the 2025 evaluated...

AI summary The Evaluator calculated the unitary available DR capacity per battery as 3,515 W and the average available DR capacity per battery capacity as 0.763 kW/enrolled kW. These metrics, along with a participation rate of 58.0%, were used to determine the 2025 evaluated available DR capacity for the Battery Control pathway.

Table 23: 2024/25 Available DR Capacity in kW/kW for Batteries Event # Event Date Event Hour Available DR Capacity (kW/Enrolled kW) Participation Rate (% of Enrolled kW) 1 12-04-2024 17 - 0.0% 18 - 0.0% 2 12-20-2024 7 0.904 52.6% 8 0.989 5...

AI summary Table 23 shows the available DR capacity for batteries during various events in 2024/25, with participation rates and an average available DR capacity of 0.763 kW/enrolled kW. The Evaluator recommends using this value for 2026 and conducting further analysis to ensure consistency.

4.2.3 Interactive Effects In a home, interactive effects occur when the implementation of energy efficiency products has an impact on the energy consumption of other elements such as heating and cooling. For the Smart Thermostat DLC pathwa...

AI summary Interactive effects in energy efficiency programs occur when changes in one system (e.g., smart thermostats) impact others (e.g., heating). The Evaluator prioritized whole-house AMI data for smart thermostats to capture these effects but used device-level data for DHW, EV chargers, and battery controls, assuming negligible interactions due to system design and location.

4.2.4 Effective Useful Life Although no electrical energy savings are expected from DR initiatives, the Evaluator established an EUL value since the available DR capacity can persist over time. For the Residential DR, an EUL value of one y...

AI summary The Evaluator assigns an Effective Useful Life (EUL) value of one year to Residential Demand Response (DR) programs, as participation includes all active participants annually. This avoids extrapolating capacity over lifetime, despite no electrical energy savings from DR initiatives.

4.2.5 Evaluated Available DR Capacities For Residential DR, available DR capacity is obtained by multiplying the number of enrolled devices by the unitary available DR capacity value, the participation rate, and the portion of the DR seaso...

AI summary This section discusses the calculation of available DR capacity for residential demand response, using factors such as enrolled devices, participation rates, and line loss factors. It references a 2014 study submitted to the Nova Scotia Energy Board.

Table 24: Evaluated 2025 Residential DR Available DR Capacities Smart Thermostats per Space Heating Type DHW EV Telematics Battery EBB Only MSHP Only MSHP and EBB Only Others Subtotal Controllers and Chargers Controls Total Number of Enrol...

AI summary Table 24 evaluates the available demand response (DR) capacities for residential customers in 2025, including enrolled devices, battery capacity, participation rates, and available DR capacity at the meter and generator levels. The data includes various heating types, DHW, EV telematics, and battery controls.

The Evaluator compared the 2025 evaluated available DR capacity for all participants to that of 2024. As outlined in [Table](#page-92-1) 25 below, returning participants generated 22% more available DR capacity than they did in 2024 due to...

AI summary The Evaluator compared the 2025 evaluated available DR capacity for all participants to that of 2024. Returning participants generated 22% more available DR capacity in 2025 due to a higher unitary available DR capacity value for smart thermostats. New participants contributed 93% of the 2025 available DR capacity, which was 0.797 MW.

Table 25: Change in Available DR Capacity from 2024 to 2025 Available DR Capacity (MW) % of 2024 Total Available DR Capacity Total 2024 Capacity (A) 0.057 N/A Change in Existing Participants Available DR Capacity (B) 0.012 22% Loss Due To...

AI summary Table 25 shows a significant increase in available demand response (DR) capacity from 2024 to 2025, primarily due to new participants joining the program, despite some loss from participants leaving. The data indicates that all available DR capacity from DHW controllers is considered new since no capacity was claimed for them in 2024.

4.3 Program Realization Rate [Table](#page-93-1) 26 below compares the available DR capacity established through this evaluation to the value tracked by E1 in the 2025 tracking sheet. The realization rate, representing the ratio of evaluat...

AI summary The document discusses the Program Realization Rate, comparing available DR capacity evaluated to that tracked by E1 in the 2025 tracking sheet, with a realization rate of 158%.

Table 26: Comparison of 2025 Residential DR Tracked and Evaluated Available DR Capacities at the Generator Available DR Capacity Value Unit Realization Rate Available DR Capacity Tracked by E1 0.540 MW Evaluation Results 0.854 MW 158% The...

AI summary Table 26 compares the tracked and evaluated available demand response (DR) capacities for residential programs in 2025. The evaluated capacity is 58% higher than the tracked value, primarily due to higher unitary DR capacity values for smart thermostats.

5 Residential DR Key Findings and Recommendations As previously mentioned, the main objectives of the 2025 Residential DR evaluation were as follows: - › Collect feedback from program staff, service providers, staff from other jurisdiction...

AI summary The 2025 Residential DR evaluation highlights a comprehensive mix of eligible devices, positive E1 relationships, and streamlined integration of pathways into 'Eco Shift.' Lessons learned led to updated eligibility criteria and enrollment processes, with slower growth expected due to demand response's less tangible value proposition compared to energy efficiency programs.

2025 Res DR-Finding: Residential DR participation grew substantially during the 2024/25 DR season. In the 2024/25 DR season, Residential DR participation increased by 907% compared to 2023/24 levels, reaching 3,676 participants and 11,405...

AI summary Residential DR participation surged 907% in 2024/25, reaching 3,676 participants and 11,405 devices, but failed to meet its 7.135 MW capacity target (actual: 0.854 MW). Retention remains high (>90%), yet 40% of EPI-program recipients did not enroll in DR despite mandatory enrollment rules.

6.1 BNI DR Description In 2023, E1 officially launched the BNI DR program component now branded as Smart Synergy. Since the fall of 2020, E1 had implemented several pilot initiatives focused on reducing demand during the Nova Scotia peak p...

AI summary In 2023, EfficiencyOne launched the BNI DR program, branded as Smart Synergy, following pilot initiatives since 2020. The C&I Aggregator pathway, managed by Parsons Inc., allows load reduction through remote control or participant action during DR events, targeting systems like heating, cooling, and lighting.

Table 27: C&I Aggregator Event Criteria Criteria Requirement Event Season Winter is from December through February. Event Windows From 7:00-11:00 a.m. and 5:00-9:00 p.m., Monday to Friday excluding holidays, during winter. Event Initiation...

AI summary Table 27 outlines the criteria for C&I Aggregator Events, including seasonal timing, event windows, initiation based on load forecasting, limits on the number and frequency of events, and notification procedures. NS Power called eight events during the 2024/25 DR season, as noted in Table 28.

Table 28: BNI DR 2024/25 Event History Month Number of Morning Events Number of Evening Events Total Number of Events Average Length of Events (Hours) December 1 2 3 3.7 January 1 1 2 3.5 February 2 2 3 3.7 Total 4 5 8 3.6 \ One event in F...

AI summary Table 28 outlines the event history for the BNI DR 2024/25 program, showing the number of morning and evening events held each month, along with the total number of events and their average length. In February, one event was split into two time-windows, and participants were grouped into morning and evening platoons based on their suitability for participation.

6.2 Follow-up on Past Evaluation Report Recommendations The Evaluator evaluated BNI DR in both 2023 and 2024 and issued improvement recommendations. [Table](#page-100-2) 29 provides a summary of the implementation status of each recommenda...

AI summary The Evaluator assessed BNI DR programs in 2023 and 2024 and provided improvement recommendations. Table 29 summarizes the implementation status of these recommendations from the reports' Executive Summary sections.

Table 29: Implementation Status of Past Recommendations for BNI DR # Recommendation Status Comments 2023 – BNI DR – R2 Establish enrolled capacity based on test events when feasible. Complete To ensure it is consistent with M&V guidelines,...

AI summary The document outlines the implementation status of past recommendations for the BNI DR program. Key actions include establishing enrolled capacity based on test events, determining optimal event times for participants, updating baseline considerations, and using project reviews to evaluate available DR capacities. These actions were completed as of 2025.

Participation in Events Based on the results of a review of 30 meters, it was found that participants did not participate in events around 60% of the time, compared to a non-participation rate of 31% in the 2023/24 DR season. In conducting...

AI summary The analysis found that 60% of participants did not engage in demand response (DR) events, compared to 31% in the 2023/24 season. Lower DR capacity correlated with reduced participation. Meters were categorized into morning and evening platoons, with event windows structured to align with these groups. Extrapolation estimated 63% average meter participation per event.

7 BNI DR Evaluation Approach The 2025 BNI DR evaluation comprised a comprehensive impact evaluation. The main objective of the 2025 BNI DR evaluation was as follows: › Calculate BNI DR results, participation, and available DR capacity The...

AI summary The 2025 BNI DR evaluation aimed to calculate BNI DR results, participation, and available DR capacity. The Evaluator identified key research questions and methods to achieve this objective, which are detailed in Table 30.

Table 30: 2025 BNI DR Evaluation Approach Evaluation Objectives Research Questions Methodology Establish available DR capacity results for the C&I Aggregator pathway › Are the data in the tracking sheet complete, accurate, and consistent?...

AI summary The document outlines the evaluation approach for the 2025 BNI Demand Response (DR) program, focusing on assessing the completeness, accuracy, and consistency of data in the tracking sheet and verifying the M&V methodology used. It includes an audit of the tracking sheet and project reviews.

Project Reviews with Meter Data Analysis E1 staff sampled and reviewed a total of 30 meters to establish tracked available DR capacity. The sample was stratified so that the 20 meters generating the largest amount of tracked available DR c...

AI summary E1 staff conducted a stratified review of 30 meters to evaluate demand response (DR) capacity, ensuring accuracy by validating adjustments beyond standard M&V protocols. The sample included 20 high-capacity meters and 10 randomly selected smaller ones, confirming 71% of savings with no margin of error. The Evaluator verified calculations and load profiles to confirm correct M&V application.

8.1 Tracking Sheet Audit To ensure program component results were reliably compiled, the Evaluator first performed a tracking sheet audit aimed at verifying the completeness and consistency of the data submitted by E1. The verification and...

AI summary The Evaluator conducted a tracking sheet audit to verify the completeness and consistency of data submitted by E1 for program component results. Corrective actions were taken, ensuring the reported tracked available DR capacity reflects the corrected data.

8.2 Demand Response Capacity For BNI DR, the evaluated metric is referred to as available DR capacity and corresponds to the load reduction made available for peak demand events in participating businesses. For the C&I Aggregator pathway,...

AI summary The document outlines the evaluation of available DR capacity for BNI DR, using baseline load comparisons and adjustment factors. Negative savings are set to zero in 2024, with E1 reviews guiding tracked capacity calculations. Adjustments in 2025 improved meter reviews for higher impact metrics.

8.2.1 Project Reviews and Meter Data Analysis The Evaluator conducted project reviews to establish the evaluated available DR capacity. The Evaluator reviewed the results for a stratified sample of 30 meters, which included the 20 meters w...

AI summary The Evaluator conducted project reviews to assess demand response (DR) capacity using a stratified sample of 30 meters, verifying E1's adherence to established calculation approaches and guidelines from the BNI DR Baseline Consideration document. The same meters were reviewed by both the Evaluator and E1.

Project Review Findings The most frequent adjustment made by the Evaluator to the available DR capacity calculation was to set the available DR capacity to zero due to non-participation in events. If no obvious load shed was observable for...

AI summary The Evaluator adjusted DR capacity calculations by setting them to zero due to non-participation or lack of observable load shedding. E1 adjusted lookback windows for a participant's safe shutdowns, while the Evaluator reinstated savings after reviewing participant communications. Recommendations included updating BNI DR baseline criteria for event savings exclusion, leading to improved consistency in 2025 reviews.

Available DR Capacity [Table](#page-106-1) 31 below presents the tracked and evaluated available DR capacity following the project reviews. As highlighted therein, the Evaluator project reviews resulted in only small differences compared t...

AI summary The table shows that the Evaluator project reviews identified 3% and 26% less available DR capacity for stratum 1 and 2 meters, respectively, compared to E1 project reviews. This discrepancy is due to the Evaluator setting the available DR capacity of 11 events to zero due to no obvious load shed, while E1 had not identified those events as such.

Table 31: 2024/25 Available DR Capacity of Reviewed Meters Metric Stratum 1 Stratum 2 Unadjusted Available DR Capacity (kW) 6,115 231 Tracked Results Tracked Adjustment Ratios 0.67 0.74 Tracked Available DR Capacity 4,079 170 Evaluated Res...

AI summary Table 31 presents the 2024/25 available demand response (DR) capacity for two strata of meters, showing unadjusted and adjusted capacities based on tracked and evaluated results. Adjustment ratios are calculated by dividing adjusted capacities by unadjusted capacities. The Evaluator considers a margin of error below 10% as statistically significant, and the 11% margin for stratum 2 is deemed acceptable due to limited sample size and few changes.

Table 32: 2025 Evaluated Adjustment Ratios Stratum Adjustment Ratio Margin of Error Percentage of Total Available DR Capacity Stratum 1 0.65 0% 71% Stratum 2 0.55 11% 29% Compared to the previous evaluation, the number of participants has...

AI summary Table 32 shows the 2025 evaluated adjustment ratios for Stratum 1 and Stratum 2, with lower values compared to 2024. E1 attributes this to increased total participants but lower participation rates, and plans to focus on engaging fewer participants more closely to improve participation rates.

8.2.2 Interactive Effects In a building, interactive effects occur when the implementation of energy efficiency products has an impact on the energy consumption of other elements such as heating and cooling. For the C&I Aggregator pathway,...

AI summary Interactive effects occur when energy efficiency products in buildings influence heating and cooling consumption. For the C&I Aggregator pathway, these effects are factored into demand response (DR) capacity calculations using whole-building meter data to account for overall consumption impacts.

8.2.3 Effective Useful Life Although no energy savings were expected under the C&I Aggregator pathway, the Evaluator established an effective useful life (EUL) value to express for how many years available DR capacity might persist, i.e. a...

AI summary The Evaluator assigned an Effective Useful Life (EUL) of one year to Demand Response (DR) capacity under the C&I Aggregator pathway, as participation includes all active participants annually, making extrapolation unnecessary. No energy savings were anticipated under this pathway.

8.2.4 Evaluated Available DR Capacities [Table](#page-107-2) 33 below presents the evaluated available DR capacity results of BNI DR for 2025. As presented in [Table](#page-107-2) 33, available DR capacity at the generator amounted to 5.94...

AI summary The evaluated available DR capacity for BNI DR in 2025 is presented in Table 33, with a total of 5.941 MW at the generator. This capacity was estimated using weighted average line loss factors based on rate codes and submitted to the Nova Scotia Energy Board as part of the 2014 Cost of Service Study Progress Update.

Table 33: Evaluated 2025 BNI DR Available DR Capacity Stratum 1 Meters Stratum 2 Meters Total Number of Participants 20 138 158 Unadjusted Available DR Capacity – at the Meter (MW) 6.115 2.972 9.087 Adjustment Ratio 65% 55% 62% Available D...

AI summary Table 33 evaluates the 2025 BNI DR available DR capacity, showing a decrease of 46% in available DR capacity from returning participants compared to 2024. New participants contributed 1.736 MW, while the new available DR capacity was -2.093 MW.

Table 34: Change in Available DR Capacity from 2024 to 2025 Available DR Capacity (MW) % of 2024 Total Available DR Capacity Total 2024 Capacity (A) 8.034 N/A Change in Existing Participants Available DR Capacity (B) -3.696 -46% Loss Due T...

AI summary Table 34 shows a decrease in available demand response (DR) capacity from 2024 to 2025, with a significant drop of 46% due to existing participants leaving the program, partially offset by new participants joining. Total available DR capacity in 2025 is 5.941 MW, representing 74% of the 2024 total.

[Table](#page-108-1) 35 presents the difference between enrolled available DR capacity and evaluated available DR capacity. Metric Stratum 1 Meters Stratum 2 Meters Overall Enrolled Available DR Capacity (MW) 8.392 13.660 22.052 Evaluated...

AI summary Table 35 compares enrolled and evaluated available demand response (DR) capacity across different strata. The enrolled capacity is significantly higher than the evaluated capacity, with overall evaluated capacity being only 27% of enrolled capacity.

8.3 Program Realization Rate [Table](#page-109-0) 36 below compares the available DR capacity established through this evaluation to the value in the 2025 tracking sheet. The realization rate, representing the ratio of evaluated available...

AI summary The program realization rate for DR capacity is 89%, calculated by comparing evaluated available DR capacity to tracked available DR capacity. Event 8 was excluded due to being a split event with participants called for different times based on platoons.

Table 36: Comparison of 2025 BNI DR Tracked and Evaluated Available DR Capacity at the Generator Available DR Capacity Realization Rate Value Unit Available DR Capacity Tracked by E1 6.648 MW Evaluation Results 5.941 MW 89% This value is t...

AI summary The evaluated available DR capacity for 2025 BNI DR was 11% lower than the value tracked by E1, due to adjustments made during project reviews. The realization rate was 89%.

9 BNI DR Key Findings and Recommendations As previously mentioned, the main objective of the 2025 BNI DR evaluation was as follows: › Calculate BNI DR results, namely the available DR capacity This section provides the Evaluator's key find...

AI summary The 2025 BNI DR evaluation found that the program missed its available DR capacity target (5.941 MW vs. 10.726 MW). Morning events generated higher capacity than evening ones. Enrollment increased by 88%, but per-participant capacity dropped from 106 kW to 42 kW due to low event participation (60% non-participation). The Evaluator recommends process evaluations in 2026 and project reviews to improve participation and accuracy.

CONCLUSION [Table](#page-112-1) 37 presents the participation levels and evaluated new and total available DR capacities for each program component and for the Demand Response program as a whole.

AI summary Table 37 outlines participation levels and evaluated new and total available Demand Response capacities for each program component and the Demand Response program overall.

Table 37: Overall 2025 Demand Response Participation and Evaluated Results Participation Level Evaluated Results Value Unit Value Unit Residential DR Available DR Capacity 3,676 Participants 0.854 MW BNI DR Available DR Capacity 143 Partic...

AI summary Table 37 shows that the 2025 Demand Response (DR) program fell short of its targets, with both Residential DR and BNI DR not meeting planned available DR capacity. BNI DR remained the largest contributor to program available DR capacity, which totaled 6.795 MW.

[THANK AND TERMINATE AFTER B4 FOR ALL ANSWERS] - B5. [ASK IF B1=1 OR B2a=1] How did you learn about Efficiency Nova Scotia's Eco Shift Program? Please select all that apply. [MULTIPLE RESPONSE. RANDOMIZE 1-10.] - 1. From the installer who...

AI summary The text includes survey questions about customer awareness and enrollment in Efficiency Nova Scotia's Eco Shift Program, covering channels like installers, marketing emails, and the website. It also asks about enrollment status and methods, highlighting technical challenges and non-enrollment reasons.

C. Perceived Potential Benefits - C1. What do you see as the potential benefits of taking part in the program? Select all that apply. [MULTIPLE RESPONSE. RANDOMIZED 1-6] - 1. Receiving financial incentives for enrolling in the Eco Shift Pr...

AI summary The section outlines perceived benefits of the Eco Shift Program, including financial incentives, reduced peak demand, sustainability support, and grid reliability. It also asks for additional information needed to reconsider enrollment.

[DISPLAY: The Nova Scotia Power Time-Varying Pricing Rate Pilot Program offered two alternative rate plans: Rate Plan Description Time-of-Use Rate Pilot From November to March, rates were higher during the peak hours when demand for electr...

AI summary The Nova Scotia Power Time-Varying Pricing Rate Pilot Program introduced two rate plans: Time-of-Use and Critical Peak Pricing. The Time-of-Use plan had higher rates during winter peak hours and lower, flat rates during non-winter months. The Critical Peak Pricing plan offered lower off-peak winter rates but significantly higher rates during four-hour critical peak periods.

Please indicate if you've heard of the Eco Shift program after reading the description below. Eco Shift - The program offers rebates for enrolling devices to reduce the demand during peak periods in the winter. During demand response event...

AI summary The Eco Shift program provides rebates for enrolling devices to reduce electricity demand during peak winter periods by remotely adjusting smart thermostat settings, thereby lessening the load on the electricity grid in Nova Scotia.

A. Respondent Involvement in the Program First, I would like to know more about your background and involvement with the program. A1. Please tell me your title and briefly describe your role in the Eco Shift Program. [PROBE for: Collect th...

AI summary The text inquires about the respondent's role in the Eco Shift Program, seeking details on their title, years delivering DR programs, and experience in other jurisdictions. It focuses on assessing involvement and expertise in demand response initiatives.

B. Program Processes - B1. Could you describe the enrollment and registration process for participants who enter the program via the bring your own device (BYOD) path? [PROBE for: Any feedback from the participants' perspective?] - a. What...

AI summary The text outlines a series of questions about program processes, including enrollment/registration for BYOD and other Efficiency Nova Scotia programs, DR event execution, opt-out procedures, incentive issuance, and drop-out observations. It seeks participant feedback on effectiveness, challenges, and areas for improvement across technologies like smart thermostats and EVs.

C. Participation Increase and Retention - C1. From your experience, what would increase participation in the program? Any differences per technology (smart thermostats, EVs & Chargers, Home Batteries, Hot Water Controllers)? [OPEN END] - C...

AI summary The section explores strategies to increase participation and retention in demand response (DR) programs, focusing on technologies like smart thermostats, EVs, home batteries, and hot water controllers. It asks about factors influencing participation, engagement during DR events, and retention methods, with open-ended questions and probes for technology-specific differences.

APPENDIX IV Residential DR Tracking Sheet Audit This document presents the detailed results of the tracking sheet audit performed by the Evaluator, which was aimed at: - › Verifying that all data fields required for the evaluation were inc...

AI summary This appendix details the audit of the residential demand response (DR) tracking sheet conducted by the Evaluator. The audit aimed to verify the completeness and accuracy of data fields and calculations used to evaluate program results, ensuring consistency with previous evaluations.

Table 1: 2025 Residential DR Corrected Tracked Available DR Capacity Program Component Result Available DR Capacity Tracked by E1 Corrected Tracked Available DR Capacity Relative Difference Value Unit Value Unit Value Smart Thermostats 0.4...

AI summary The table shows the corrected tracked available DR capacity for residential demand response programs in 2025. The Evaluator adjusted the available DR capacities for smart thermostats and DHW controllers due to changes in in-service rates and the exclusion of time-of-use and critical peak pricing participants.

APPENDIX V Residential DR Smart Thermostat DLC Detailed Metering Data Analysis Methodology This appendix summarizes the methodology used by the Evaluator to establish the available DR capacity for the Smart Thermostat Direct Load Control (...

AI summary This appendix outlines the methodology for evaluating residential demand response (DR) capacity from smart thermostats using metering data. The Evaluator updated unitary DR capacity values for subgroups of space heating systems, analyzing whole-house consumption data to predict hourly load and compare expected vs. actual loads during events, prioritizing whole-house data over device-level data to account for interactive effects.

Form of the Regression Following the 2024 methodology used in a literature review conducted to identify the most appropriate baseline methodology for such evaluations, the Evaluator used regression models that considers the time of week an...

AI summary The Evaluator used regression models incorporating time of week and outdoor temperature to establish baselines for residential electricity consumption. This approach accounts for temperature impacts and household variability, leveraging large datasets with comparable cold-temperature data. Regression models are preferred over previous-day baselines due to their common use in similar programs and ability to handle temperature extremes.

Where: - › , is the calculated baseline load in kW on a specified day of week (D) and hour of day (H) for a given temperature. - › , is the time of the week where D is from 1 to 7 (Sunday to Saturday) and H is from 00 to 24 (midnight to 11...

AI summary The text outlines a method to calculate baseline load using heating degree days (HDD) and temperature data, assigning participants to weather stations based on postal codes for accurate temperature correlation. This approach ensures localized weather data alignment for demand-side management and energy efficiency assessments.

Data Cleaning The initial dataset included all participants with enrolled smart thermostats in 2025 (2,471). Among those, only 1,457 participants had available AMI data because account numbers are user-entered by participants, and they som...

AI summary The dataset was cleaned by excluding participants with EV chargers, batteries, or incomplete data, resulting in 1,222 participants and 5,497 smart thermostats. Subgroups were formed based on types of space heating, and heating degree days were used to represent heating load. Other space heating types had too few participants for significant analysis.

Table 1: Numbers of Participants and Devices Available for the Meter Data Analysis Type of Smart Thermostat DLC Participants Number of Participants Number of Devices All participants in the tracking sheet 2,471 10,200 Participants with ava...

AI summary The table outlines the number of participants and devices involved in a meter data analysis for smart thermostat DLC programs. The Evaluator adjusted and filtered the data by excluding outliers, incomplete data, and holiday data to ensure accurate baseline consumption patterns.

Where: - $\rightarrow$ $\beta_{D,H}$ is the regression intercept. - $\alpha_{D.H}$ is the regression slope. - $\rightarrow$ RMSE h is the hourly model root mean square error. - $n_h$ is the number of observations. - $\bar{x}_h$ is the mean...

AI summary The text outlines statistical methods for evaluating demand response (DR) program effectiveness, including regression models, error propagation calculations, and uncertainty quantification for load reduction estimates. Key metrics include RMSE, standard error, and unitary savings calculations.

Regression Coefficients for EBB-only Participants Mondays Tuesdays Wednesdays Thursdays Fridays 02 0.107 0.094 0.317 0.084 0.248 0.084 0.300 0.083 0.232 0.091 03 0.101 0.095 0.282 0.087 0.245 0.085 0.292 0.084 0.189 0.094 04 0.120 0.095 0....

AI summary The document presents regression coefficients for EBB-only participants across different days of the week, indicating varying levels of energy usage patterns. The data shows a progression of coefficients from 0.107 to 1.224, which may be relevant for analyzing energy consumption behaviors and efficiency measures.

This appendix summarizes all the recommendations made by the Evaluator as part of the 2025 evaluation of Residential DR. Section Recommendations Executive Summary 2025 Res DR Recommendation 1: Include all changes to the pilot and program i...

AI summary The appendix outlines two key recommendations from the 2025 evaluation of the Residential Demand Response (DR) program. The first recommends updating the program manual to include all historical changes and clearly define eligibility criteria. The second emphasizes ensuring accurate data collection and proper recording of device information during the EPI installation process.

This document presents the detailed results of the tracking sheet audit performed by the Evaluator, which was aimed at: - › Verifying that all data fields required for the evaluation were included and filled out in the tracking sheet submi...

AI summary The document details the results of a tracking sheet audit conducted by the Evaluator to verify the completeness and accuracy of data submitted by E1. The audit confirmed consistency in parameters used for calculating program results, with no discrepancies found between tracked and corrected available DR capacity values.

Table 1: 2025 BNI DR Corrected Tracked Available DR Capacity Program Component Result Value Tracked by E1 Corrected Tracked Value Relative Difference Value Unit Value Unit Value Available DR Capacity 6.648 MW 6.648 MW 0% APPENDIX IX BNI DR...

AI summary Table 1 presents the 2025 BNI DR Corrected Tracked Available DR Capacity, showing no difference between the tracked and corrected values. Appendix IX provides an example of the calculation for available DR capacity.

Per the definition agreed upon by E1 and NSP, available DR capacity is evaluated based on events called from December to February excluding weekends and holidays. Events called at any time during the day (morning or evening)[5](#page-147-1...

AI summary The document discusses how available DR capacity is calculated based on participant performance during events called from December to February, excluding weekends and holidays. It highlights that participants are categorized by E1 as either better suited for morning or evening events, and that averaging load reductions at the participant level can yield higher available DR capacity if some participants are not called for all events.

r suited to morning events or to evening events and, for each event, E1 can decide to only call participants that are better suited to that time or to call all participants to take part in that event. To illustrate how available DR capacit...

AI summary The text explains how available DR capacity is calculated by considering participants' suitability for morning or evening events. An example with five participants and five events is used to illustrate the calculation, showing how events are scheduled based on participants' availability.

Table 1: Available DR Capacity Calculation Example Type of Load Reduction per Participant per Event (kW) Event Event Period Participant for Which the Part. #1 Part. #2 Part. #3 Part. #4 Part. #5 Sum of Load Reduction per Number Event Was C...

AI summary Table 1 presents an example calculation of available DR capacity, with the bottom-right value (2,667 kW) representing the sum of average DR capacity per participant. This approach differs from the average load reduction per event (1,952 kW), as E1 sums participant averages rather than event averages when reporting available DR capacity.

APPENDIX X BNI DR Baseline Considerations

AI summary This appendix outlines baseline considerations for BNI DR programs, focusing on evaluation methodologies, impact assessments, and ensuring accurate baselines for demand response initiatives targeting business, non-profit, and institutional sectors.

Test and Validate Test the lookback window against past DR events to validate its effectiveness.

AI summary The text directs evaluating the lookback window's effectiveness by testing it against historical demand-response (DR) events to ensure accurate validation of past performance.

Business Rules If the lookback window is observing an abnormal condition such as a building opening or closing earlier than normal, consider whether this point in time is a valid point of comparison. Consider the example below. The facilit...

AI summary The text outlines a business rule for adjusting demand response (DR) metrics during abnormal facility conditions, such as temporary shutdowns. It emphasizes verifying such anomalies with the E1 Business Development Manager (BDM) to ensure adjustments reflect normal operations, avoiding distortions from one-off events like early facility closures.

Reflect Actual Conditions The cap should reflect the actual conditions and operational changes that could reasonably affect the DR event day's load.

AI summary The cap should align with actual conditions and operational changes that may impact load during demand response (DR) events.

Prevent Overcompensation It should prevent overcompensation for reductions that would have occurred without the DR event.

AI summary The text emphasizes preventing overcompensation in demand response (DR) programs by ensuring that incentives are not provided for energy reductions that would have occurred naturally without the DR event, thereby maintaining program integrity and cost-effectiveness.

Consider Program Goals The cap should align with the overall goals of the DR program, whether it's peak shaving, load shifting, or emergency response.

AI summary The cap must align with the DR program's goals, including peak shaving, load shifting, and emergency response, ensuring program effectiveness and alignment with broader objectives.

Business Rules 1) If the default 20% adjustment cap does not accurately encompass the total curtailment for the specified event day, i.e. a very abnormal day was confirmed by the business, consider allowing for an exception on the default...

AI summary The rule allows exceptions to the default 20% adjustment cap for curtailment on confirmed abnormal event days, ensuring accurate coverage of total curtailment.

Symmetry Adjustments are applied symmetrically, i.e. results could go up or down. The symmetric approach considers that day-of conditions can have a real impact on customer demand in both directions and therefore it can be argued that symm...

AI summary The text discusses symmetric adjustments in demand response programs, arguing that they improve baseline accuracy by accounting for day-of conditions. It mentions a ±20% cap to mitigate negative impacts of downward adjustments and suggests adjusting the timing of the adjustment window.

Business Rules 2) If the lookback window provides an abnormal positive or negative adjustment factor, the event should be flagged and considered with more detail, as a new adjustment period may need to be selected, including the hours proc...

AI summary The text outlines procedures for handling abnormal adjustment factors in lookback windows, emphasizing the need to flag events, reassess adjustment periods, and ensure consistency in adjustments for all events within a participant's timeframe due to anomalies like building operational changes.

Exclusion rules Exclusion rules – Some days are excluded from consideration such as holidays, previous DR event days, weekends, thresholds and scheduled shutdowns (as these are not representative of "normal" operation). Example: A facility...

AI summary Exclusion rules specify that certain days (e.g., holidays, weekends, scheduled shutdowns, and DR event days) are excluded from baseline calculations as they do not reflect normal operations. An example highlights abnormal energy usage during a facility closure due to renovations, which should be excluded to ensure accurate baseline metrics.