E-12024 DSM Annual Progress Report
13 passages
Efficiency. E1 is forecasting to fall short of its fourth Plan Performance Target of 17.9 MW of available capacity. E1 expects to spend its 2023- 2025 Plan approved investment level of $173 million. - This Annual Progress Report (APR) prov...
AI summary EfficiencyOne (E1) is projected to miss its fourth Plan Performance Target of 17.9 MW available capacity. The 2023-2025 Plan allocates $173 million in approved investments. The Annual Progress Report (APR) details prior-year activities, performance discrepancies, program expenditures, savings forecasts, and rate-class allocation methodology.
Other regulatory activities included: - ongoing development of the 2026-2030 DSM Plan (in February 2025 the provincial government introduced legislation to extend E1's current DSM Plan by one year to include 2026. Assuming the legislation...
AI summary Regulatory activities include development of the 2026-2030 DSM Plan, pending legislation to extend E1's DSM Plan, 2024 DSM evaluation, NS Power project participation, and information requests on load forecasts. Key entities involve E1, provincial government, and NS Power.
ATTACHMENT 1: 2024 RATE CLASS RESULTS
AI summary Attachment 1 presents the 2024 rate class results from a Nova Scotia regulatory proceeding, involving entities such as Efficiency Nova Scotia (ENS), EfficiencyOne (E1), and the Nova Scotia Utility and Review Board (NSUARB). Key programs include the Mi'kmaw Home Energy Efficiency Project (MHEEP) and Demand Side Management (DSM).
Attachment 1: 2024 Rate Class Results
AI summary Attachment 1 presents 2024 Rate Class Results from a Nova Scotia regulatory proceeding, likely detailing utility rate structures and associated programs. Key entities include regulatory bodies and energy efficiency initiatives mentioned in contextual acronyms.
Rate Class Expenditures - E1 reports on planned and actual DSM expenditures by rate class to aid in cost recovery - allocations.[32](#page-51-0) - In an effort to provide insight into how E1 tracks and calculates its rate class results, th...
AI summary E1 reports on planned and actual Demand Side Management (DSM) expenditures by rate class to support cost recovery allocations. The document outlines E1's methodology for tracking rate class results, historical investment data, 2024 results, and 2025 forecasts.
1. RATE CLASS SPENDING ALLOCATION METHODOLOGY
AI summary The document outlines the methodology for allocating spending across different rate classes within a regulatory proceeding. It involves considerations of demand-side management, efficiency programs, and regulatory oversight by Nova Scotia's utility board.
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 E1 allocates DSM Plan funds by rate class using historical spending data, with exceptions for Custom. The methodology ties to NS Power's DCR Rider applications and references a 2015 NSUARB order and the Public Utilities Act. E1 commits to refining estimates for future DSM Plans.
1 Table 1: Historical Expenditures by Rate Class Historical Expenditures by Rate Class Plan as Actual Variances Rate Class Approved ($ million) Expenditures ($ million) 2016-2024 Actual Compared to 2016- 2024 Plan as Approved 2016-2024 Act...
AI summary Table 1 presents historical expenditures by rate class from 2016-2024, showing variances between approved plans and actual spending. E1's total expenditures fell short of the approved plan by 3%, with significant deviations in categories like Small General (37% over) and Municipal (38% under). The data reflects program performance against targets.
5 3. 2024 RESULTS BY RATE CLASS 6 2024 annual expenditures were higher than the 2024 Plan as Approved expenditures, asspending 7 increased overall. The increased investment was spread fairly evenly amongst most rate classes 8 and was fairl...
AI summary 2024 expenditures exceeded the approved plan, with increased investment across most rate classes except large general and medium industrial. Medium industrial spending rose due to higher BNI Demand Response participation (76 participants in 2024 vs. 9 in 2023), with over 50% of incentives allocated to medium industrials. Variability in spending is influenced by BNI sector project timing and participation.
5 Table 2: 2024 Planned and Actual DSM Expenditures by Rate Class 2024 Expenditures by Rate Class Rate Class 2024 Plan as Approved ($ million) 2024 Mid-Course Planned Expenditures ($ million) Actual 2024 Expenditures ($million) 2024 Expend...
AI summary Table 2 presents the 2024 planned and actual Demand Side Management (DSM) expenditures by rate class, showing that actual expenditures exceeded planned amounts in most categories, with residential and general rate classes showing the highest percentages of achievement. The data is based on the 2023-2025 DSM Resource Plan Compliance filing approved by the NSUARB in November 2022.
12 2024 Rate Class Results by Program - 13 [Table](#page-55-0)s 3 7 provide a breakdown of 2024 net incremental energy and net peak demand savings, - 14 expenditures, and participation achieved by rate class within the energy efficiency pr...
AI summary The document presents tables (3 and 7) detailing 2024 net incremental energy and peak demand savings, expenditures, and participation rates by rate class under energy efficiency programs. The data reflects outcomes across different customer segments within Nova Scotia's regulatory framework.
1 4. 2025 FORECAST AND 2023-2025 DSM PLAN RESULTS & FORECAST BY RATE CLASS 2 The 2025 forecast rate class allocation has been developed as described in Sectio[n](#page-52-0) 1.2, using 2022-2024 rate class spending data. 4 [Table 9 p](#pag...
AI summary The document outlines the 2025 forecast for rate class allocation using 2022-2024 spending data. Table 9 details 2023-2025 DSM plan expenditures, actuals, and variances, incorporating 2023-2024 results and 2025 forecasts. It emphasizes the Plan outlook based on historical and projected data.
Table 1 Update on Implementation of 2018-2022 Evaluation Recommendations Year Evaluation/ Verification Recommendation Text Source Status Comments Expected Period of Completion 2021 Verification We recommend that Efficiency Nova Scotia look...
AI summary In 2021, a recommendation was made to Efficiency Nova Scotia to increase the Energy Use Limit (EUL) for a program component by emphasizing certain measures or adding an optimization component. E1 agreed with the recommendation, and an update was performed in 2024, though no changes were made to the EUL. The results were to be presented in the 2024 DSM Measure Assessment Report filed with the Nova Scotia Utility and Review Board.
E-22024 DSM Programs Evaluation Reports
27 passages
Figure 4: 2024 Tracked and Evaluated Gross Electrical Energy Savings at the Generator As presented in [Table](#page-97-2) 10, gross GHG emission reductions were calculated by applying the Nova Scotiaspecific factor[11](#page-97-3) for GHG...
AI summary Figure 4 shows 2024 tracked and evaluated gross electrical energy savings at the generator. Table 10 calculates gross GHG emission reductions using a Nova Scotia-specific factor applied to ARet gross savings.
Table 10: Evaluated 2024 ARet Gross GHG Emission Reductions Total Gross Energy Savings – at the Generator (GWh) 4.195 Nova Scotia-specific GHG Emissions Factor for Electricity Production (tonne of CO2 eq/GWh) 472.2 Gross Annual GHG Emissio...
AI summary Table 10 presents the evaluated 2024 ARet gross GHG emission reductions, showing 1,981 tonnes of CO2 eq reduction based on 4.195 GWh of gross energy savings and a Nova Scotia-specific GHG emissions factor of 472.2 tonnes of CO2 eq/GWh.
The Evaluator determined the net energy and peak demand savings, that is the electrical energy and peak demand savings that can be reliably attributed to the program component, by establishing a NTGR for each appliance type. For ARet, the...
AI summary The Evaluator calculated net energy and peak demand savings for appliance retirements by establishing a NTGR for each appliance type, considering free-ridership and secondary market impacts. The methodology followed the Uniform Methods Project guidelines, accounting for gross unitary energy savings and adjusting for spillover effects.
3.3.4 Evaluated Net Savings Net savings represent the savings that can be reliably attributed to a program component. For ARet, net savings are calculated by applying the NTGR values to gross savings as illustrated in the following equatio...
AI summary Net savings are calculated by applying NTGR values to gross savings, resulting in 1,117 tonnes of CO2 eq in annual GHG emission reductions from ARet program components.
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 document defines key terms related to demand response (DR) and energy efficiency, including accuracy, adjustment ratio, available DR capacity, and baseline. These definitions are used to measure and evaluate DR program performance and savings.
The annual gross savings at the generator are presented in [Table](#page-34-0) 11 below. The gross energy savings at the generator were estimated by using different line loss factors for each participant based on their rate code. The line...
AI summary The document presents annual gross energy savings at the generator, calculated using line loss factors specific to each participant's rate code. These factors were submitted to the NSUARB as part of the 2014 Cost of Service Study Progress Update by Nova Scotia Power. The total gross electrical energy savings are 1.159 GWh annually and 19.397 GWh over the lifetime, with an average EUL of 16.7 years for AMH in 2024.
9.4 Realization Rate [Table](#page-72-0) 24 below compares the energy and peak demand savings established through this evaluation to those calculated in the 2024 tracking sheet. It also includes the realization rate, representing the ratio...
AI summary This section compares energy and peak demand savings from the current evaluation with those in the 2024 tracking sheet, highlighting the realization rate, which is the ratio of evaluated net savings to tracked net savings for both energy and peak demand.
19.2.6 Evaluated Gross Savings The annual gross savings for each category of measure installed through Green Heat in 2024 are listed in [Table](#page-138-0) 46 below. The gross savings at the generator were estimated by using a line loss f...
AI summary The document discusses the evaluation of annual gross savings for measures installed through Green Heat in 2024. Line loss factors associated with each participant's rate code were used to estimate gross savings at the generator, referencing a 2014 Cost of Service Study Progress Update submitted to the Nova Scotia Utility and Review Board.
Table 52: Implementation Status of Past Recommendations for HEA # Past Recommendations Status Comments 2018 HEA-R1 Conduct a billing analysis to review overestimation ratios (ORs) when a sufficient participant sample becomes available. Com...
AI summary Table 52 outlines the implementation status of past recommendations related to the Home Energy Assessment (HEA). A billing analysis was planned for 2022 to reassess overestimation ratios (ORs), but was deferred due to insufficient data. In 2023, a new billing analysis approach was tested, leading to the replacement of ORs with adjustment ratios (ARs) for future evaluations.
23.2.7 Evaluated Gross Savings The annual gross savings for each category of measures installed through HEA in 2024 are listed in [Table](#page-163-0) 60 below. The gross savings at the generator were estimated by using residential line lo...
AI summary The annual gross savings for measures installed through Home Energy Assessments in 2024 are detailed in a table. Residential line loss factors of 1.0947 and 1.146601 were used to estimate gross savings at the generator, based on values submitted to the NSUARB in 2014.
Net savings are defined as the energy use reductions specifically attributable to HEA. Net savings were calculated by applying the NTGR value, adding unconverted D assessment spillover savings, and subtracting Green Heat and EPI savings, a...
AI summary Net savings are calculated using the NTGR value, spillover savings, and deductions for Green Heat and EPI. This resulted in 15,093 tonnes of CO2 eq in annual GHG emission reductions.
Table 71: 2024 MHEEP Adjustment Ratios Scenario Tracked Evaluated ORD Assessment ORE Assessment AR A participant who registered with a heat pump 0% (1.00) 0% (1.00) 1.24 A participant who registered without a heat pump and who did not inst...
AI summary Table 71 outlines adjustment ratios for the Mi'kmaw Home Energy Efficiency Project (MHEEP) in 2024, showing different scenarios based on heat pump registration and installation. Participants with non-electrical space heating can generate both electrical and non-electrical savings, with electrical savings calculated using total energy consumption and the proportion of electrical heating systems during the D assessment.
As presented in [Table](#page-183-1) 78, GHG emission reductions were calculated by applying the Nova Scotia-specific factor[66](#page-183-2) for GHG emissions generated by electricity production to MHEEP gross savings results.
AI summary GHG emission reductions were calculated using a Nova Scotia-specific factor applied to MHEEP gross savings results, as presented in Table 78.
4.2.4 Evaluated Gross Savings The savings achieved for each Application Rebates measure category are presented in [Table](#page-54-1) 10 below. Both energy and peak demand savings were revised by applying the adjustment ratios discussed in...
AI summary The document discusses the evaluation of gross savings for Application Rebates measure categories, including energy and peak demand savings adjusted using ratios from Subsection 4.2.1. Savings at the generator are calculated using line loss factors provided by NS Power, weighted averages from rate codes and energy savings data from the 2024 tracking sheet.
As presented in [Table](#page-55-1) 11 below, GHG emission reductions were calculated by applying the Nova Scotiaspecific facto[r](#page-55-2) 9 for GHG emissions generated by electricity production to Application Rebates gross savings.
AI summary The text discusses the calculation of GHG emission reductions using a Nova Scotia-specific factor applied to Application Rebates gross savings, as presented in a referenced table.
5.2.6 Evaluated Gross Savings The 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 factors wher...
AI summary The document discusses the calculation of energy and peak demand savings from Instant Rebates using data from the 2024-2025 DSM Measure Assessment. Savings at the generator were calculated using weighted average line loss factors based on the distribution of rate code spending for other BNI programs in 2024, with references to the 2014 Cost of Service Study Progress Update submitted to the NSUARB.
Table 23: 2024 Instant Rebates 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 5.3.3 Evaluated Net Savings
AI summary Table 23 presents the 2024 Instant Rebates NTGRs for various energy efficiency measures, including free-ridership percentages and NTGR values. Section 5.3.3 discusses the evaluated net savings related to these rebates.
As presented in [Table](#page-190-2) 12 below, GHG emission reductions were calculated by applying the Nova Scotiaspecific factor[12](#page-189-3) for GHG emissions generated by electricity production to Retrofit gross savings. [https://s2...
AI summary The document discusses the calculation of GHG emission reductions using a Nova Scotia-specific factor applied to Retrofit gross savings. It also references line loss factors and EUL values derived from specific projects and rate codes. Data sources include Nova Scotia Power and Emera Inc.'s 2023 Annual Report.
3.4 Realization Rate [Table](#page-194-0) 17 below compares the total 2024 tracked and evaluated savings for Retrofit. It also includes the realization rate, representing the ratio of evaluated net savings to tracked net savings, for both...
AI summary The section discusses the realization rate for Retrofit in 2024, comparing total tracked and evaluated savings, and explains line loss factors and effective useful life (EUL) values used for calculating energy and peak demand savings.
Net savings are defined as the energy use reductions that are specifically attributable to SBES. Program component net impacts were estimated by applying the above NTGRs to the revised gross savings by using the following equation: Net Sav...
AI summary The document defines net savings as energy use reductions attributable to the Small Business Energy Solutions (SBES) program and calculates net energy savings using the Net Total Gross Reduction (NTGR) equation. The results show 5,125 tonnes of CO2 eq in annual GHG emission reductions.
[Table](#page-198-0) 3 below presents a comparison of E1 tracked available DR capacity compared to evaluated results as well as the realization rate. Table 3: Comparison of 2024 Tracked and Evaluated Savings at the Generator Available DR C...
AI summary Table 3 compares the tracked and evaluated demand response (DR) capacity for residential and BNI DR programs in 2024. The realization rates for BNI DR are high (99% and 100%), but residential DR data is incomplete due to ongoing methodological considerations.
3.2.5 Evaluated New and Total Available DR Capacities Available DR capacity is obtained by multiplying the number of controlled thermostats by the unitary available DR capacity value as presented in the equations below. = ℎ × [Table](#page...
AI summary The document evaluates new and total available demand response (DR) capacities for residential DR in 2024, which amounted to 0.057 MW at the generator. The calculation uses the number of controlled thermostats and unitary available DR capacity values, with line loss factors submitted to the NSUARB in 2014.
7.2.4 Evaluated New and Total Available DR Capacities [Table](#page-21-0) 18 below presents the new and total available DR capacity results of BNI DR for 2024. For BNI DR, the new available DR capacity was defined as the increase in availa...
AI summary The section evaluates new and total available demand response (DR) capacities for BNI DR in 2024. New available DR capacity increased compared to the previous year, with new and total capacities at 5.669 MW and 8.034 MW, respectively. Line loss factors were used to estimate DR capacity at the generator, based on rate codes and submissions to the NSUARB from the 2014 Cost of Service Study Progress Update.
7.3 Program Realization Rate [Table](#page-23-0) 20 below compares the available DR capacity established through this evaluation to the value in the 2024 tracking sheet. The realization rates, representing the ratio of evaluated available...
AI summary The document discusses the program realization rate for demand response (DR) capacity, comparing evaluated available DR capacity to tracked available DR capacity. The realization rates are established at 99% for new DR capacity and 100% for total available DR capacity.
Presented below is the template used by the Evaluator to review projects to determine evaluated savings. PID Customer Name Agreed Curtailment (kW) Event 1 Event 2 Event 3 Event 4 Event 5 Event 6 Event 7 Event 8 Event 9 Event 10 Average Sav...
AI summary The document presents a template for evaluating energy savings from demand response (DR) projects under the BNI DR program. It includes fields for tracking customer names, curtailment agreements, savings calculations, and adjustments based on guidelines.
In-service Rates While all controllers remained installed, connectivity issues resulted in not all controllers generating savings when events were called, the impact of which was included through the in-service rates as listed in [Table](#...
AI summary Connectivity issues with installed controllers affected their ability to generate savings during events, leading to adjustments reflected in in-service rates as outlined in Table 131.
Table 369: Summary of E1's Current NTGR Approach Program Component Measures for Which FR Is Established Year of Last FR Update Current Spillover Methodology Year of Last Spillover Update Proposed Changes ARet FR determined for all measures...
AI summary This table outlines EfficiencyOne's (E1) current approach to Net-to-Gross Ratio (NTGR) for various program components, including the establishment of Free-Rider (FR) rates, spillover methodologies, and proposed changes. The table includes details for ARet, IS, and HEA, with specific FR rates, spillover methodologies, and planned updates for 2025.