E-1Application
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Annual avoided costs of energy and capacity and annual avoided $CO_2e$ emissions were provided by NS Power, from the 2020 IRP using the Base level of DSM for Scenario 2.0C. Avoided costs of transmission and distribution were provided by NS...
AI summary The Settlement Plan, based on the 2020 IRP and updated with 2021 data, outlines energy and capacity savings, CO2e reductions, and cost-effectiveness ratios. It includes details on avoided costs, lifetime benefits, and a 10-year program life for Demand Response (DR) and Energy Efficiency (EE) initiatives.
PAYBACK PERIODS ARE REASONABLE DSM is a long-term investment with lasting benefits and considerable lifetime savings, yet the Settlement Plan also contributes to short-term and immediate ratepayer benefits. In the short-term, the Settlemen...
AI summary The Settlement Plan for DSM is a long-term investment with immediate and cumulative benefits, achieving 412.7 GWh of energy savings by 2025 and full payback by 2027. The investment of $173 million is expected to be offset by $114 million in avoided utility costs, with full payback no later than 2029 for any single rate class. This approach is in the best interest of ratepayers by leveraging lower current investment costs and mitigating long-term inflation impacts.
8.3.1 HISTORICAL RBIA E1's 2021 Historical RBIA indicates that ratepayers are already positioned to accrue aggregate bill savings in excess of $1.5 billion between 2011 and 2038 as a result of past DSM activities between 2011 and 2022. [Fi...
AI summary E1's 2021 Historical RBIA shows that ratepayers could save over $1.5 billion in aggregate bill savings between 2011 and 2038 due to past Demand Side Management (DSM) activities from 2011 to 2022. Figure 7 illustrates the average rate and bill impacts of DSM by rate class based on historical data.
8.3.2 2023-2025 RBIA Investment at the Settlement Plan level would result in average rate impacts that range between -0.1% and 1.0% by rate class, averaged over the lifetime of measures [(Figure 8)](#page-55-0). These figures are calculate...
AI summary The 2023-2025 RBIA discusses the impact of DSM activities on average rates and customer bills. Investment at the Settlement Plan level would lead to average rate impacts ranging from -0.1% to 1.0% by rate class, with average participants experiencing bill reductions between 1.2% and 7.9%.
1.2.1 OVERVIEW The Settlement Plan delivers demand side resources to Nova Scotia ratepayers in support of achieving NS Power's long-term electricity strategy as provided in the IRP. The Settlement Plan offers a portfolio of DSM services th...
AI summary The Settlement Plan provides demand side management (DSM) services to Nova Scotia ratepayers as part of NS Power's long-term electricity strategy. It focuses on cost-effectiveness, accessibility, and affordability, with a shift toward peak demand reduction and capacity-focused initiatives like demand response. The plan aims to lower energy costs, support the local economy, and improve grid flexibility.
GUIDING PRINCIPLES Transparency – E1 will provide stakeholders and customers with information and insight into the analyses supporting plan development and results and demonstrate how received comments were considered. Accessibility & Equi...
AI summary The document outlines guiding principles for E1, emphasizing transparency, accessibility, equity, and affordability. These principles are supported by tools such as the Integrated Resource Plan, Rate and Bill Impact Analysis, and cost effectiveness testing. Strategic themes, which inform the portfolio design and initiatives for the next plan cycle, are also highlighted.
14 Table 3: Balanced Plan Aspects Addressed in the Settlement Plan Balanced Plan Aspects 2023-2025 Settlement Plan Access to programs by all market sectors and rate classes by addressing barriers to participation • low-income investment –...
AI summary The Settlement Plan includes measures to increase access to energy efficiency and demand-side management programs for all market sectors, with a focus on low-income and residential customers. It also outlines rate impacts, including a RBIA performed on DSM model results and projected avoided costs exceeding initial investments by 2027.
9.7.2 PERFORMANCE TARGETS & THRESHOLDS - Performance Target[s46](#page-44-0) apply to the period of the NSUARB-approved Supply Agreement with NS Power, rather than annually; and - E1 is deemed to be in substantial compliance with the NSUAR...
AI summary Performance targets under the NSUARB-approved Supply Agreement with NS Power apply over the agreement period, not annually. E1 is considered in substantial compliance if it achieves 90% or more of cumulative annual energy and system-peak demand savings targets. If below 90%, the NSUARB may take discretionary action.
DSM PLANNING MODELS THAT USE AVOIDED COST INPUTS - A. Energy Efficiency Process Model: The following five categories of avoided costs will be used to calculate the benefits of the energy efficiency portfolio for the 2023-2025 DSM Plan and...
AI summary The document outlines the use of avoided cost inputs in three planning models for the 2023-2025 DSM Plan: the Energy Efficiency Process Model, the Demand Response DRSim Model, and the Rate and Bill Impact Analysis (RBIA). Each model specifies categories of avoided costs used for calculating benefits and conducting cost-effectiveness testing.
C. Rate and Bill Impact Analysis E1 will also use the Fitted Series PRM adjusted stream (AVC 2.0C NPV 2023) of avoided costs of capacity as calculated by NS Power for the IRP Reference Plan (scenario 2.0C) and provided to the DSMAG on Augu...
AI summary E1 will use the Fitted Series PRM adjusted stream of avoided costs of capacity as calculated by NS Power for the IRP Reference Plan (scenario 2.0C) and provided to the DSMAG on August 20, 2021 for the E1 RBIA. These values are outlined in Table 3.
1. EXECUTIVE SUMMARY EfficiencyOne (E1) delivers energy efficiency (EE) programs that offer benefits to customers and the electric utility. While cost-effective energy efficiency is a key resource option for delivering clean, affordable, r...
AI summary EfficiencyOne (E1) delivers energy efficiency programs that benefit customers and the electric utility. While energy efficiency is a key resource, concerns about rate impacts can hinder investment. DSM programs typically reduce customer bills, but may cause rate increases for non-participants, raising equity concerns. E1's Rate and Bill Impact Analysis (RBIA) assesses the long-term rate and bill effects of DSM activities from 2023-2025, projecting impacts until 2039.
2. INTRODUCTION E1 files an historical RBIA to provide insight into the rate and bill impacts resulting from DSM activities that have been carried out since 2011, as well as those that have been approved by the Nova Scotia Utility and Revi...
AI summary E1 files a historical RBIA to analyze the rate and bill impacts of DSM activities from 2011 to 2022, comparing a no-DSM scenario with one that includes program investments. A forward-looking RBIA is also filed with the DSM Resource Plan Applications to assess the impacts of proposed DSM investments on rates and bills, aiding in cost-effectiveness evaluations.
4.1 SETTLEMENT PLAN AND ALTERNATE SCENARIO - The 2023-2025 DSM Plan includes both a Settlement Plan and an Alternate Scenario, which contain - different investment levels and savings over the three years of DSM delivery. A RBIA was perform...
AI summary The 2023-2025 DSM Plan includes a Settlement Plan and an Alternate Scenario with varying investment levels and savings. A Rate Base Impact Analysis (RBIA) was conducted for both using identical Excel models, with differences in DSM costs, savings, and participation estimates for the 2023-2025 period.
4.2 SCENARIOS - E1's RBIA models both compare two scenarios: a DSM scenario and a no-DSM scenario. The DSM scenario - includes the estimated utility costs and resulting energy and system-peak demand reductions of DSM - programs that are pr...
AI summary E1's RBIA models compare a DSM scenario with a no-DSM scenario to assess the impact of DSM programs from 2023 to 2025 on rates and bills. The rate impact represents the difference between the two scenarios in the same year, not the change from one year to the next. A one-percent rate impact in all years would indicate initial rate increases to recover DSM costs, followed by no further changes.
4.6 CALCULATING RATE IMPACTS - Using the RBIA approach implemented for the first time in the 2020 RBIA, rate impacts are now calculated - in NS Power's Rate Model (Attachment 6 for the Settlement Plan and Attachment 7 for the Alternate The...
AI summary This section discusses the methodology used in calculating rate impacts through the Rate Base Impact Analysis (RBIA) approach, including updates to the number of Municipal Electric Utilities (MEUs) and the integration of Demand Side Management (DSM) into NS Power's Rate Model. The RBIA isolates the effects of DSM on rates by comparing scenarios with and without DSM.
4.7.2 NON-PARTICIPANT CONSUMPTION AND BILL IMPACTS - In the DSM scenario, non-participants in DSM programs are assumed to use the same amount of energy as - they do in the no-DSM scenario. Their bill impacts are therefore driven only by ch...
AI summary In the DSM scenario, non-participants in demand-side management programs are assumed to maintain the same energy usage as in the no-DSM scenario. Their bill impacts are influenced only by rate changes under the with-DSM scenario. However, the percentage bill impacts differ from rate impacts due to fixed customer charges, which remain unaffected by DSM.
4.8.2 PARTICIPATION FOR 2023-2025 DSM PLAN YEARS - E1 has estimated 2023-2025 annual and new participation figures based on actual participation records - from 2020[6](#page-162-1) , scaling factors to account for planned savings in 2023-2...
AI summary E1 has estimated participation figures for the 2023-2025 DSM Plan years using scaling factors based on 2020 data and planned energy savings, while excluding certain programs where participation was estimated directly. This approach accounts for the impact of the coronavirus disease (COVID-19) on energy usage and avoids skewing the estimates.
4.9 DEMAND RESPONSE - This section discusses how demand response has been incorporated into the E1 RBIA model and NS Power - Rate Model. - Demand Response costs, savings, measure life, and customer incentives are first calculated and provi...
AI summary The document discusses the integration of demand response into the E1 RBIA model and NS Power Rate Model. Demand response is modeled separately from energy efficiency, allowing for multiple scenarios, such as 'no DSM,' 'energy efficiency without demand response,' and 'demand response without energy efficiency.' Demand response is assumed to have no energy savings, only demand savings, and is modeled with a one-year measure life.
5.1 OVERALL RATE IMPACTS - DSM can lower rates by avoiding different types of electricity system costs (avoided energy, capacity, - transmission and distribution, and carbon costs). DSM may also increase rates, a result of recovering - pro...
AI summary Demand Side Management (DSM) can lower rates by avoiding system costs but may also increase rates due to program costs and lost revenues. The 2023-2025 DSM Plan RBIA analyzes long-term rate impacts, showing average rate changes ranging from -0.1% to +1.0% over 2023-2039, with significant upward impacts during program cost recovery (2023-2025) and smaller impacts afterward.
- 9 Integration of demand response 11 Table 7: Average Rate Impact compared to No-DSM Scenario, 2020-2022 Preferred Plan to 2023-2025 DSM Plan 12 Results Comparison Rate Class 2020-2022 Preferred Plan RBIA Result (average rate impact over...
AI summary The text presents a comparison of average rate impacts for different rate classes under the 2020-2022 Preferred Plan and the 2023-2025 Settlement Plan. The data shows slight variations in rate impacts, with some classes experiencing a decrease in impact under the Settlement Plan.
5.2 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 (o...
AI summary The 2023-2025 DSM Settlement Plan RBIA shows that DSM programs reduce electricity bills for participants by -7.9 to -1.2 percent and benefit all ratepayers with $0.4 billion in savings. Non-participants also see slight savings, while the overall impact ranges from -4.0 to -1.0 percent. The savings are attributed to reduced consumption and revenue requirements.
5.4.4 LARGE GENERAL - As modelled, the Large General class includes Rate Code 12 only. - The average rate impact over the study period is an increase of 0.3 percent, or 0.03 cents/kWh. - Participants in the Large General class see an avera...
AI summary The Large General rate class includes Rate Code 12 and shows an average rate increase of 0.3 percent, but participants experience a 4.0 percent average bill decrease. Non-participants see a 0.2 percent bill increase, while the overall class sees a 4.0 percent bill decrease. All customers are assumed to participate in BER-IR annually, leading to 100% participation by 2023.
5.4.6 MEDIUM INDUSTRIAL - As modelled, the Medium Industrial class includes Rate Code 22 only. - The average rate impact over the study period is an increase of 0.1 percent, or 0.01 cents/kWh. - Participants in the Medium Industrial class...
AI summary The Medium Industrial rate class (Rate Code 22) experiences a 0.1 percent rate increase and a 1.2 percent average bill decrease for participants. All customers are assumed to participate in BER-IR, leading to 100% participation by 2023. Non-participants see a 0.1 percent bill increase, though they may not exist in this class.
8. CONCLUSION - Highlights from the 2023-2025 DSM Settlement Plan RBIA analysis include: - Over the 17 years of the study period, participants in DSM programs see average annual bill reductions ranging from a low of 1.2 percent (typical Me...
AI summary The 2023-2025 DSM Settlement Plan RBIA analysis highlights significant bill reductions for participants in DSM programs, with ratepayers saving $0.4 billion. The analysis also notes the evolution of the RBIA model, incorporating updated cost allocation and demand response factors to improve accuracy.
Appendix B Attachment 2: Results by Rate Class (Settlement Plan) 11 13 18 22 23 This graph shows estimated rate impacts of DSM, relative to the no-DSM scenario. This graph shows bill impacts of DSM as percentage differences relative to the...
AI summary This appendix presents visual data on the impact of demand-side management (DSM) programs on different rate classes. It includes graphs showing estimated rate impacts, bill differences between participants and non-participants, and annual program participation rates. The data is part of a settlement plan and was filed on 11 March 2022.
6. ENERGY AND DEMAND RATES - NS Power provided estimates for 2011-2022 of rates by class (including energy, demand, and customer - charges). Beyond 2022, energy and demand charges are assumed to escalate at 2.0% per year, while - customer...
AI summary NS Power has updated its rate model to include a blended energy and demand rate, assuming equal savings in both energy and demand. This differs from the previous RBIA model, which only included energy rate impacts. The new model simplifies calculations but may slightly affect individual bill impacts, though total customer bill impacts remain unchanged.
3.1 Revenue Requirement The annual revenue requirements under the "With DSM" scenario are kept consistent with the test year information from the preceding rate cases. The non-FAM costs in the years following the 2014 test year from the 20...
AI summary The document outlines the annual revenue requirements for both 'With DSM' and 'No DSM' scenarios, noting that non-FAM costs remain constant until 2022 and then increase with inflation. FAM-related costs are adjusted for load changes and inflation. The 'No DSM' scenario adds incremental load effects to the 'With DSM' revenue requirements. Historic cost true-ups are excluded due to minimal impact and complexity.
3.2.2 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 generation costs depending on unit function. Transmission costs are classified based on load factors, while distribution and retail costs remain largely static except for inflation. NS Power uses a linear equation to estimate generation cost classification for the RBIA.
FAM-related Costs The FAM-related costs are allocated to rate classes using the following two-step process: • Annual class energy usage is multiplied by the benchmark unit cost $/MWh DATE FILED: 11 March 2022 Page 7 of 16 _________________...
AI summary The FAM-related costs are allocated to rate classes using a two-step process, with benchmark unit costs derived from previous rate cases. This method does not differentiate between energy and demand-related costs, but this may be addressed in future RBIA applications due to the increasing share of demand-related costs, now at 15 percent.
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 This section discusses the method used by NS Power to determine unit revenues for different rate classes, excluding certain factors like fuel and non-fuel cost adjustments, cost deferrals, rate smoothing, and revenue-to-cost ratios. It states that excluding these factors does not significantly affect the relative changes in unit revenues between the 'With DSM' and 'No DSM' cases.
E-12-(i)NSUARB IR-17 Attachment 2_ACEEE’s Entire State Database - Excel
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s funding from utility USB programs and also provides bill assistance and low-income weatherization. Energy Share and DPHHS work with Human Resource Development Councils (HRDC) to distribute funding. Last reviewed: July 2019 ","Self-direct...
AI summary The text discusses self-direct programs in Montana, including funding from utility USB programs, bill assistance, and low-income weatherization. It also covers the denial of lost revenue adjustments by the PSC for NorthWestern Energy and MDU, as well as the rejection of NorthWestern's decoupling approach by the PSC.
ot offer energy efficiency programs at this time. The most recent budgets for energy efficiency programs and electricity and natural gas savings can be found in the State Spending and Savings Tables. Last updated: July 2018 ","All electric...
AI summary Nebraska's energy efficiency programs are managed by publicly-owned utilities, with no Energy Efficiency Resource Standard (EERS) in place. The three largest electric utilities have self-imposed energy efficiency targets and integrated resource plans. Energy efficiency programs are available for electricity customers, but not for natural gas customers. The primary and secondary cost-effectiveness tests used are the utility cost test and the ratepayer impact measure test.
efficiency programs—a Notice of Proposed Rulemaking was published in the NYS Register on April 15, 2015. A new case, 15-M-0252, was established for the utilities post-2015 energy efficiency programs. In January 2016, the PSC authorized NYS...
AI summary This text outlines the development of energy efficiency programs in New York, including the establishment of a Clean Energy Fund, the transition from surcharge-based funding to rate-based recovery, and the setting of energy efficiency targets and strategies. Key events include the Notice of Proposed Rulemaking in 2015 and the issuance of a white paper in 2018.
rection program. But no COUs including EPUD are subject to Public Purpose Charge requirements. Portland General Electric and Pacific Power cover approximately 80% of the electric customers in Oregon. Participants in the three participating...
AI summary The text discusses energy efficiency programs in Oregon, including decoupling mechanisms implemented by Portland General Electric and other utilities. It highlights the role of the Oregon Department of Energy in reviewing projects and the use of energy efficiency funds. The text also outlines the historical implementation of decoupling by various utilities.
ting use-per-customer decoupling since 2003. Both make a base rate decoupling adjustment to reflect changes in use per customer over the past year on a prospective basis in the following year’s rates. Cascade Natural Gas Docket No. UG 167,...
AI summary The text discusses decoupling mechanisms in utility rate structures, referencing past regulatory orders and current practices in energy efficiency programs. It also highlights data sharing requirements and platforms like Green Button used by utilities for customer energy use data.
re are no self-direct or opt-out provisions in place. Last reviewed: June 2020 ","There is currently no policy in place that rewards successful energy efficiency programs with performance incentives. Please see the Alternative Ratemaking F...
AI summary The document discusses the absence of self-direct or opt-out provisions and performance incentives for energy efficiency programs. It references the Alternative Ratemaking Final Policy Statement and guidelines for third-party access to customer meter data, including requirements for secure web portals for energy use data.
test, ratepayer impact measure test Evaluations in Tennessee are mainly administered by the Tennessee Valley Authority. There are no specific legal requirements for these evaluations in Tennessee. According to the Database of State Efficie...
AI summary In Tennessee, evaluations for energy efficiency programs are primarily administered by the Tennessee Valley Authority (TVA), which uses the Total Resource Cost (TRC) model as its primary cost-effectiveness test and the Ratepayer Impact Measure (RIM) and Utility Cost Test (UCT) as secondary tests. TVA conducts ongoing evaluations every three to four years and has engaged third-party contractors for data collection and process improvements. Flexibility exists for low-income programs, pilots, and new technologies.
grants, such as those received from the Federal government's American Recovery Reinvestment Act (ARRA) in 2010. The funds for natural gas conservation programs are collected through a rate surcharge. The most recent budgets for energy effi...
AI summary Maine's energy efficiency programs are funded through rate surcharges and are required by statute to procure all cost-effective energy efficiency. Efficiency Maine operates under triennial plans, with the most recent covering fiscal years 2017-2019. Annual savings targets for 2020-2022 are approximately 2.3% for electricity and 0.1% for natural gas.
ility, serving roughly 80% of statewide load, proposed and was granted decoupling in its rate case in 2014 (Docket No. 2013-00168). Last reviewed: September 2020 ","Guidelines for Third Party Access In 2007, Maine's Electronic Business Tra...
AI summary Maine's energy sector has implemented decoupling in its rate case, allowing Efficiency Maine access to individual meter data through a Commission Order. Guidelines for third-party access and electronic data interchange standards have been established to support retail competition and data dissemination.
(c) defining the standard criteria that shall be satisfied by an applicant in order to notify the utility, including means of evaluation measurement and verification and confidentiality requirements.” Last Updated: December 2020 ","Virgini...
AI summary Virginia's 2020 Clean Economy Act provides performance incentives for utilities achieving energy savings goals, with additional rewards for exceeding targets. Natural gas utilities are allowed to decouple profits from sales, while electric utilities are not. A 2008 plan implemented by Virginia Gas includes an Energy Conservation Plan and a decoupling mechanism called the RNA Rider.
represented 84.6% of the qualifying load. More information on large customer self-direct programs can be found in the ACEEE report, Follow the Leaders: Improving Large Customer Self-Direct Programs. Last reviewed: July 2019 ","The proposed...
AI summary The text discusses decoupling mechanisms implemented by Avista, Puget Sound Energy, and Pacific Power and Light, which involve commitments to increase electric conservation savings and support low-income programs. It also notes that consumer-owned utilities are not subject to state regulation of retail rates and may adjust rates as needed.