E-1Application and Evidence
56 passages
EfficiencyOne IN THE MATTER OF The Public Utilities Act , RSNS 1989, c 380, as amended - and – IN THE MATTER OF An Application by EfficiencyOne for Approval of the 2026 DSM Extension for Demand-Side Management Activities between Efficiency...
AI summary EfficiencyOne seeks approval for the 2026 DSM Extension and amendment to the 2023-2025 Purchase Agreement with Nova Scotia Power Inc. under the Public Utilities Act. The application is filed by EfficiencyOne as the holder of the Efficiency Nova Scotia Franchise.
NOVA SCOTIA ENERGY BOARD IN THE MATTER OF The Public Utilities Act , RSNS 1989, c 380, as amended - and – IN THE MATTER OF An Application by EfficiencyOne for Approval of the 2026 DSM Extension for Demand-Side Management Activities, and fo...
AI summary EfficiencyOne seeks approval for a 2026 DSM extension and a 2023-2025 amendment to its DSM purchase agreement with Nova Scotia Power Inc., under the Public Utilities Act. The application involves Demand-Side Management activities and regulatory oversight by the Nova Scotia Energy Board.
1.7 EXISTING BOARD APPROVED COST-EFFECTIVENESS TEST - E1 has applied the current NSUARB-approved cost-effectiveness test to the 2026 DSM Extension as the - 2023-2025 DSM Plan the Total Resource Cost (TRC). This test compares inputs (costs...
AI summary The NSUARB-approved Total Resource Cost (TRC) test was applied to the 2026 DSM Extension, yielding a cost-effectiveness ratio of 1.6, exceeding the 1.0 threshold under the Public Utilities Act (PUA). E1 plans to propose a new benefit-cost analysis framework for the 2027-2031 DSM Plan to the Energy Board in Q2 2025.
1.8 DSMAG ENGAGEMENT - The DSMAG consultation timeline in relation to the 2026 DSM Extension has been condensed as a result - of the legislation being first introduced in February 2025 and brought into force March 26, 2025. Despite - this...
AI summary The DSMAG consultation timeline for the 2026 DSM Extension was condensed due to the Public Utilities Act (PUA) being introduced in February 2025 and enacted in March 2025. E1 engaged DSMAG through meetings in March/April 2025 and a technical briefing on April 22, 2025, and plans continued engagement during the application process.
2. BACKGROUND TO 2026 DSM EXTENSION
AI summary The section outlines the background for extending Demand-Side Management (DSM) programs to 2026, involving regulatory considerations by the Nova Scotia Utility and Review Board (NSUARB) under the Public Utilities Act (PUA).
2.1 DEVELOPMENTS IN LAW AND POLICY - Nova Scotia's electricity sector is in an era of significant change. Driven by ambitious federal and provincial - environmental goals, NS Power is phasing out its coal fleet by 2030, with a target to ac...
AI summary Nova Scotia's electricity sector is undergoing significant changes, driven by environmental goals. The province created the Clean Electricity Solutions Task Force, which recommended the creation of an independent energy system operator and a standalone energy regulator. These recommendations were implemented through the Energy Reform (2024) Act, which amended several existing statutes, including the Public Utilities Act.
(4) For greater certainty, the next demand-side management purchase agreement begins on January 1, 2027, and the franchise holder must file the new five-year agreement for Board approval in sufficient time to allow for the Board to approve...
AI summary The document outlines the extension of the demand-side management (DSM) purchase agreement to begin on January 1, 2027, requiring the franchise holder to file a new five-year agreement for Board approval. It also highlights the importance of stakeholder engagement in the development of the 2027-2031 DSM Plan, which will consider the new mandate of the Energy Board and the Energy Reform (2024) Act . The legislative amendment to the Public Utilities Act (PUA) aims to align energy regulation with climate change goals for the first time in Nova Scotia.
2.4 APPLICATION FOR NEW COST-EFFECTIVENESS TEST E1 is always seeking to maximize value for ratepayers in its DSM planning. As a vital input for DSM planning, how this value is measured is of critical importance. In Q2 of 2025, E1 will be f...
AI summary E1 seeks approval for a new benefit-cost analysis test to enhance DSM planning, ensuring value for ratepayers. The test, to be filed in Q2 2025 with the Energy Board, will inform future DSM activities and the 2027-2031 DSM Plan. Timely resolution is emphasized for logistical planning benefits.
3. MODELLING FOR 2026 DSM EXTENSION
AI summary This section discusses the modelling for the 2026 extension of Demand-Side Management (DSM) programs in Nova Scotia. Key entities involved include the Nova Scotia Utility and Review Board (NSUARB) and the DSM Cost Recovery Rider (DCRR). The analysis involves regulatory considerations under the Public Utilities Act (PUA) and collaboration with the Independent Energy System Operator (IESO).
3.1 OVERVIEW In support of the 2026 DSM Extension Application, E1 has conducted a fulsome modelling process. An overarching objective of E1 in its modelling process for the 2026 DSM Extension was to adopt learnings drawn from the actual re...
AI summary E1's 2026 DSM Extension Application uses 2023-2025 data and 2025 forecasts to inform targets, noting no alternate scenarios were modelled. The NSUARB required alternative scenarios in past applications, with future submissions needing DSM budget scenarios and NSPI rate impact analysis.
[emphasis added ] E1 supports this requirement as an important part of DSM planning and has adhered to it for each subsequent DSM Plan application. However, in this extension application, the investment amount is statutorily mandated. As s...
AI summary E1 supports DSM planning requirements but argues the Board directive is inapplicable to the 2026 DSM Extension application due to statutorily mandated investment amounts. E1 plans to develop an alternative scenario for the 2027-2031 DSM Plan through stakeholder consultation. A 2016-2018 DSM Plan decision (M06733) is referenced.
3.2 UPDATES TO AVOIDED COST CALCULATION In its decision approving the 2023-2025 DSM Plan, the NSUARB (as it then was) made note of the fact that updates to NS Power Integrated Resource Planning process will have an impact on the avoided co...
AI summary The NSUARB directed E1 to update avoided cost calculations for DSM plans using the latest IRP data, noting climate goals are not fully addressed in current IRP versions. E1 incorporated 2022 IRP results, embedding carbon costs into energy avoided costs for the 2026 DSM Extension. The DSMAG will address climate-related updates for future plans, while the More Access to Energy Act mandates IESO's IRP process.
16 4. 2026 DSM PROGRAMS
AI summary The document outlines the 2026 Demand-Side Management (DSM) Programs under regulatory review by the Nova Scotia Utility and Review Board (NSUARB). Key entities include the DSM Cost Recovery Rider (DCRR) and the Public Utilities Act (PUA), with involvement from the Independent Energy System Operator (IESO) and the Integrated Resource Plan (IRP).
4.3 PROGRAMS AND INVESTMENT FOR THE 2026 DSM EXTENSION - [Table 5,](#page-28-0) below, summarizes the programs and corresponding investment amounts for the 2026 DSM - Extension. DATE FILED: April 30, 2025 Page 22 of 25 13 14 15 16 17 18
AI summary Section 4.3 outlines programs and investment amounts for the 2026 DSM extension, referencing Table 5. The document is part of a regulatory proceeding involving Nova Scotia's utility sector, focusing on demand-side management initiatives and associated financial commitments.
7. CONCLUSION - The 2026 DSM Extension Application is a filing brought about through recently enacted legislative - amendments to the Public Utilities Act which; - (1) extends the demand-side management purchase agreement approved by the B...
AI summary The 2026 DSM Extension Application seeks to extend the existing DSM Plan until 2026 under new PUA amendments, proposing energy and demand savings targets. The extension aligns with legislative intent, maintains program continuity, and meets cost-effectiveness criteria with a TRC of 1.6. E1 requests Board approval for the extension.
1. INTRODUCTION On March 26, 2025, the Nova Scotia government passed legislation to extend EfficiencyOne's (E1) current approved 2023-2025 DSM Plan by an additional year with a prescribed investment level of $63,750,000 for the 2026 one-ye...
AI summary The Nova Scotia government passed legislation extending E1's 2023-2025 DSM Plan by one year to 2026 with a prescribed investment of $63.75 million. The extension includes targets for energy savings, demand savings, and demand response capacity, and requires E1 to submit these targets for approval. The 2026 DSM Extension passes the Total Resource Cost test for cost effectiveness.
2.1 LEGISLATIVE AMENDMENTS TO THE PUBLIC UTILITIES ACT - The Nova Scotia government enacted legislation on March 26, 2025 extending E1's current 2023-2025 - DSM Plan by one year.[6](#page-38-2) For greater clarity, Bill 6, amended Chapter...
AI summary Nova Scotia extended E1's DSM Plan until 2026 via Bill 6 amending the PUA, adding Section 79J. The extension includes a $63.75M payment, requiring E1 to submit targets by 2026 and file a new five-year agreement by 2027.
- E1 provided its 2025 forecast in its 2024 Annual Progress Report, filed on March 31, 2025, and noted that energy savings and demand savings are forecast to be lower in 2025, as compared to 2024 results. E1 provided the following observat...
AI summary E1's 2025 forecast projects lower energy and demand savings compared to 2024, citing reduced participation in programs like Instant Savings and Home Energy Assessment, program closures (Appliance Retirement, Green Heat), and the Canada Greener Homes Grant's closure. Declines are attributed to baseline changes, rebate reductions, and participant preferences for higher-incentive programs.
age-59-2) - Throughout 2023 and 2024, E1 worked with the DSMAG to develop a new Nova Scotia specific - (jurisdictional-specific) BCA test with the support of a third-party expert Energy Futures Group. - Cost-effectiveness results for the 2...
AI summary E1 collaborated with the DSMAG and Energy Futures Group to develop a jurisdiction-specific BCA test for Nova Scotia. The 2026 DSM Extension cost-effectiveness results are detailed in Table 7, including portfolio-level and program-specific results. References include the amended Public Utilities Act and NSUARB Orders related to DSM Plans.
RESID EN TIAL ENERGY EFFICIEN CY PROGRAM S
AI summary The document outlines residential energy efficiency programs under Nova Scotia's regulatory framework, involving entities like NSUARB and NSP. It references DSM, DCRR, and related acronyms for cost recovery and benefit analysis, with legislative context from the PUA.
4 5.2 EXISTING RESIDENTIAL - 5 The Existing Residential program provides residential customers with access to information, technical - 6 support, and financial assistance to identify, assess and implement energy efficiency behaviours and -...
AI summary The Existing Residential program, part of the 2023-2025 Plan, will transition from seven to six components by 2026, removing Green Heat due to declining participation. The 2026 DSM Extension includes six components, such as Home Energy Assessments and Mi'kmaw initiatives, while E1 cites reduced savings as the reason for ending Green Heat.
7 Table 17: 2026 Summary of Custom Program Component Extension Investment ($M) Energy Savings (GWh) Demand Savings (MW) Participation (projects) 2026 Total 9.8 34.0 7.0 172 Program Component Changes • approved 2023-2025 Plan. • Efficiency...
AI summary Table 17 outlines the 2026 DSM Extension with $9.8M investment, 34GWh energy savings, 7MW demand savings, and 172 participating projects. The 2023-2025 Plan was approved, and the 2026 strategy includes targeted marketing, AMI data use, and engagement with professionals. Attachment 3 provides detailed measure-level data.
8.2 PERFORMANCE INDICATORS Performance indicators are a set of selected performance metrics used to indicate or monitor progress towards performance targets and DSM Plan implementation. E1 provides the status of the organization's annual p...
AI summary E1 proposes to extend the 2023-2025 DSM Plan to 2023-2026, using the same performance indicators. Amendments to the Supply Agreement are provided in Appendices C and D. Table 24 compares proposed and approved indicators for the 2023-2026 period.
Table 24: 2023-2026 Performance Indicators Approved 2023-2025 Performance Indicators 2026 2023-2026 • Annual incremental energy savings (reported by program and rate class) (GWh) ✓ ✓ • Cumulative annual energy savings (reported by program...
AI summary Table 24 outlines 2023-2026 performance indicators for energy savings, demand response, and customer satisfaction. Key metrics include annual and cumulative energy savings (GWh), system-peak demand savings (MW), ratepayer benefits, and low-income program impacts. The table emphasizes reporting by program, rate class, and equity considerations.
18 Cost Effectiveness Screening : - 19 A. For modelling of the 2026 DSM Extension, the Total Resource Cost (TRC) test, and Program 20 Administrator Cost (PAC) test, have been provided. - 21 B. Cost effectiveness testing has been performed...
AI summary The 2026 DSM Extension uses TRC and PAC tests for cost effectiveness screening. Energy efficiency and demand response programs underwent testing, with E1 noting some avoided cost streams are non-material to models.
AVOIDED COSTS USED IN 2026 DSM EXTENSION MODELS
AI summary The document discusses the use of avoided costs in 2026 Demand-Side Management (DSM) extension models, focusing on regulatory considerations in Nova Scotia. Key entities include Nova Scotia Utility and Review Board (NSUARB), Nova Scotia Power (NSP), and related programs like DSM Cost Recovery Rider (DCRR).
3. AVOIDED COSTS OF TRANSMISSION & DISTRIBUTION (T&D)
AI summary The section discusses avoided costs related to transmission and distribution, focusing on regulatory considerations and stakeholder analyses. Key entities include Nova Scotia Utility and Review Board (NSUARB) and Demand-Side Management (DSM) programs, with emphasis on cost recovery mechanisms and benefit-cost ratios.
A. Energy Efficiency ProCESS Model - E1 understands from NS Power that the avoided costs of carbon (electric utility compliance costs) are - embedded in the avoided costs of energy that NS Power calculated for the Evergreen IRP No Atlantic...
AI summary E1 used avoided energy costs (including embedded carbon costs) from NS Power for the 2026 DSM Extension, without modeling separate carbon costs. Avoided energy costs were not included in demand response cost-effectiveness testing. The same RBIA approach as energy efficiency programs was applied for the 2026 DSM Extension.
Appendix A Attachment 2: Estimation of DSM Low-Income and Equity Impacts
AI summary Appendix A, Attachment 2 focuses on estimating the impacts of Demand-Side Management (DSM) programs on low-income populations and equity. It likely involves analysis of cost recovery, benefit/cost ratios, and regulatory considerations under the Public Utilities Act (PUA) by the Nova Scotia Utility and Review Board (NSUARB).
Filed Electronically
AI summary The document is an electronically filed submission in a Nova Scotia regulatory proceeding involving Demand-Side Management (DSM) programs, cost recovery mechanisms, and utility rate structures. Key entities include Nova Scotia Power (NSP), the Nova Scotia Utility and Review Board (NSUARB), and EfficiencyOne (E1). Topics focus on DSM cost recovery, energy efficiency, and regulatory analysis.
Filed Electronically
AI summary The document is an electronically filed submission in a Nova Scotia regulatory proceeding involving Demand-Side Management (DSM) programs, cost recovery mechanisms, and utility rate structures. Key entities include Nova Scotia Power (NSP), the Nova Scotia Utility and Review Board (NSUARB), and EfficiencyOne (E1). Topics focus on DSM cost recovery, energy efficiency, and regulatory analysis.
forward until 2041, when the modelled impacts of 2026 measures expire. These results offer a frame of reference for considering the appropriate balance of these impacts across electricity customers. The 2026 DSM Extension RBIA compares the...
AI summary The 2026 DSM Extension RBIA compares scenarios with and without DSM, analyzing rate and bill impacts on non-participants. It isolates DSM effects from utility factors, focusing on affordability and long-term trends. Key outputs include non-participant bill impacts and cost-effectiveness testing to assess overall customer benefits.
- DSM Resource Plan application.["](#page-116-0) 4 The next historical RBIA will be filed as part of the 2027-2031 DSM - Resource Plan Application, expected to be in February/March 2026. - The analysis provides the reader with a picture of...
AI summary The document discusses the 2027-2031 DSM Resource Plan Application, expected in 2026, and the role of RBIA analyses in assessing equity impacts on participating vs. non-participating ratepayers. It highlights that DSM investments may lower bills for participants but raise them for non-participants, requiring regulators to balance cost-effectiveness and equity trade-offs, as per the National Standard Practice Manual.
3. 2026 DSM EXTENSION RBIA RESULTS - The results in this section are for the 2026 DSM Extension. All impacts are calculated relative to a scenario - where no DSM is conducted in 2026. Results are summarized in Attachment 1, and have been p...
AI summary This section presents the 2026 DSM Extension RBIA results, comparing scenarios with and without DSM implementation. Impacts are calculated relative to a no-DSM baseline, with energy efficiency and demand response analyzed separately and combined. Attachments 1 and 2 summarize results, including rate and bill impacts by rate class, and model outputs.
3.1 OVERALL RATE IMPACTS - DSM can lower rates by avoiding different types of electricity system costs (avoided energy, capacity, - transmission and distribution). DSM may also increase rates, a result of recovering program costs as well -...
AI summary The 2026 DSM Extension RBIA analyzes rate impacts of Demand-Side Management (DSM) programs, showing average rate changes ranging from +0.08% to +0.45% over 2026-2041. Initial cost recovery in 2026 causes higher impacts (+2.1% to +4.9%), but long-term effects (2027-2041) show smaller or negative impacts (-0.14% to +0.15%). These figures reflect long-term trends, not annual fluctuations.
3.3 RESULTS BY RATE CLASS This section highlights results in more detail by individual rate class for the 2026 DSM Extension.
AI summary This section details results by rate class for the 2026 DSM Extension, focusing on analysis by individual rate classes under Nova Scotia's Demand-Side Management initiatives.
4.3 PARTICIPATION
AI summary The section titled '4.3 PARTICIPATION' outlines regulatory considerations related to stakeholder involvement in Nova Scotia utility proceedings, referencing acronyms and entities involved in energy efficiency, demand response, and regulatory analysis.
elected in the in the "E1 Data Inputs" tab, the avoided costs associated with all of the planned-DSM resources are added to NS Power's revenue requirement and will populate in the Savings(Added)' tab. Alternate scenarios, including a "No-D...
AI summary NS Power's rate model includes scenarios analyzing DSM resources' avoided costs, with alternate configurations in the 'COSS DSM Simulated' tab. Savings and costs are allocated using methods from the 2023 Cost of Service Study. A new 'Total-Savings (Avoided)' tab summarizes selected DSM resource savings and associated costs, enabling scenario analysis of 75%, 100%, and 125% of estimated avoided costs.
2. RESOURCES AND SCENARIOS - The 2026 DSM Extension Analysis includes the NS Power rate model and the E1 RBIA model, filed - in Attachments 5 and 6 respectively. The analysis compares two scenarios: a DSM scenario and a - no-DSM scenario....
AI summary The 2026 DSM Extension Analysis compares DSM and no-DSM scenarios using NS Power's rate model and E1's RBIA model. It evaluates energy efficiency and demand response impacts, isolating 2026 DSM effects on rates and bills. Alternative scenarios include Energy Efficiency Only and Demand Response Only, with results summarized in Attachment 1.
2.1 ENERGY EFFICIENCY INPUTS - For 2026, first-year energy, lifetime energy and demand savings developed at the program - component level were allocated to rate classes in proportion with the actual rate class allocation - of energy and de...
AI summary The document outlines methods for allocating 2026 energy and demand savings to rate classes based on 2022-2024 program component data. Weighted-average measure lives (WAMLs) are calculated using ratios of lifetime to first-year energy savings per rate class.
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 The Nova Scotia Utility and Review Board (NSUARB) outlines a methodology to assess changes in Nova Scotia Power's (NSP) base cost rates caused by Demand-Side Management (DSM)-induced shifts in class usage and total system costs. The analysis focuses on evaluating DSM's impact on cost recovery, rate design, and system-wide cost implications.
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 document explains that the RBIA does not require detailed annual cost data for rate base calculations, as it only assesses DSM-induced changes while keeping other costs constant. This avoids the need for a full rate case analysis, focusing instead on directional and relative rate/bill changes due to DSM programs.
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 for 'With DSM' and 'No DSM' scenarios, adjusting FAM and non-FAM costs with inflation and DSM impacts. Historic cost true-ups are excluded due to minimal rate effects, lack of COSS rigor, and complexity. E1 provides avoided fuel cost data for post-2022 adjustments.
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 and demand categories, with DSM affecting reclassification. NS Power uses a linear equation to estimate generation cost classifications based on load factors. Transmission costs align with load factors, while distribution and retail costs remain static except for inflation. Peaking units and environmental investments are classified differently.
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 long-term unit cost trends by rate class. Historic periods show higher DSM cost impacts, while out-years show reduced differentials. Fuel-cost-heavy classes (e.g., Large Industrial) benefit more from DSM savings, whereas fixed-cost-heavy classes (e.g., Domestic) see less benefit. Differences arise from DSM spend, usage changes, and cost allocation methods.
Overview of Spreadsheet Calculations
AI summary The document outlines spreadsheet calculations related to Demand-Side Management (DSM) programs, involving the Nova Scotia Utility and Review Board (NSUARB) and EfficiencyOne (E1). Key considerations include benefit/cost ratios (TRC, PAC), regulatory frameworks (PUA), and cost recovery mechanisms (DCRR). The analysis supports NSUARB's evaluation of DSM initiatives under the Public Utilities Act.
Data Inputs
AI summary The 'Data Inputs' section lists acronyms and their expansions relevant to a Nova Scotia regulatory proceeding, including organizations, legislation, and programs involved in energy efficiency, demand-side management, and utility regulation.
"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, customer's meter, and bulk power substation. It details methods for determining avoided fuel, generation, transmission, and distribution costs, distinguishing between FAM-related and non-FAM-related calculations.
"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 outlines annual cost allocation to rate classes using NS Power's ten-year load forecast, incorporating DSM program effects. FAM costs for 2023-2035 are adjusted via a two-step process: calculating class costs using 2022 blended FAM rates, then scaling to match annual totals. The formula combines previous year costs with energy requirement changes and avoided FAM costs.
"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 for rate classes without Demand-Side Management (DSM) savings. It uses blended unit FAM costs from the 'With DSM' case, scales costs to match total annual estimates, and applies a formula incorporating energy requirement deltas and avoided FAM costs, as detailed in tables 'Before External Effect' and 'After External Effect'.
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 details a simplified cost allocation process for FAM and non-FAM costs, differentiating allocation methods based on energy requirements, system peaks, and load factors. Non-FAM costs are calculated using 'With DSM' case data, adjusted by load factors and prorated across rate classes. Inflation adjustments for 2023–2035 and unit cost calculations at the generator's gate are also outlined.
"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 illustrates differentials between 'No DSM' and 'With DSM' scenarios, highlighting how DSM costs are excluded in the 'No DSM' case. The tabs share identical data layouts except for DSM cost treatment.
Filed Electronically
AI summary The document is an electronically filed submission in a Nova Scotia regulatory proceeding involving Demand-Side Management (DSM) programs, cost recovery mechanisms, and utility rate structures. Key entities include Nova Scotia Power (NSP), the Nova Scotia Utility and Review Board (NSUARB), and EfficiencyOne (E1). Topics focus on DSM cost recovery, energy efficiency, and regulatory analysis.
Filed Electronically
AI summary The document is an electronically filed submission in a Nova Scotia regulatory proceeding involving Demand-Side Management (DSM) programs, cost recovery mechanisms, and utility rate structures. Key entities include Nova Scotia Power (NSP), the Nova Scotia Utility and Review Board (NSUARB), and EfficiencyOne (E1). Topics focus on DSM cost recovery, energy efficiency, and regulatory analysis.
2 Schedule B (Page 2 of 2)
AI summary Schedule B (Page 2 of 2) from a Nova Scotia Utility and Review Board (NSUARB) regulatory proceeding, referencing demand-side management (DSM) and the DSM Cost Recovery Rider (DCRR). Context includes programs like EfficiencyOne (E1) and legislation such as the Public Utilities Act (PUA).
Schedule B (Page 1 of 2)
AI summary Schedule B of a Nova Scotia regulatory proceeding outlines a document involving energy efficiency, demand response, and cost recovery mechanisms. Key entities include Nova Scotia Power, EfficiencyOne, and regulatory bodies like the NSUARB. Topics focus on DSM programs, benefit/cost ratios, and compliance with the Public Utilities Act.