E-1Application
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BY INCREMENTAL DSM Using the 2021 Historical RBIA, DSM induced a rate pressure that ranged from 1.8 to 4.0% across all rate classes. As the 2022 DSM investment of $41 million has already been approved, this investment is already rate-embed...
AI summary The 2021 Historical RBIA showed rate pressure from DSM ranging between 1.8% to 4.0%. The 2022 DSM investment of $41M is already rate-embedded and should not be double-counted. The 2023-2025 DSM Plan will only induce rate pressure from the incremental investment above $41M annually, which is expected to be minimal. DSM is highlighted as a long-term investment and savings mechanism with significant customer benefits.
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.
STRATEGIC THEMES The 2020 IRP Reference Plan – demand side resources are planned in support of the successful implementation of a long-term electricity strategy for delivery of safe, reliable, affordable, and clean electricity that is in t...
AI summary The 2020 Integrated Resource Plan (IRP) emphasizes demand side management (DSM) as a key strategy for achieving safe, reliable, and clean electricity while supporting climate change mitigation. The Settlement Plan aims to increase utility avoided costs for customers, based on the lowest revenue requirement identified in the IRP Reference Plan.
Table 8: 2023-2025 Settlement Plan Investment and Savings Year Investment a Lifetime Benefits b First-Year Energy Savings Lifetime Energy Savings Average Dem Peak EE Demand Savings Capacity Total Resource Cost Test (TRC) c Prog Admini Cost...
AI summary Table 8 outlines the 2023-2025 Settlement Plan Investment and Savings, detailing annual investments, energy savings, and cost-effectiveness metrics. The data includes lifetime benefits, energy savings, demand reductions, and capacity figures across three years, providing a comprehensive overview of the plan's financial and operational impact.
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.
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.
ach of the three years. This modelling approach is representative of what would occur if demand response programs do not continue beyond the years being analyzed (i.e. 2023-2025). In order for demand response benefits to occur beyond 2025,...
AI summary The text discusses the modeling approach for demand response programs, noting that benefits are limited to the years analyzed (2023-2025) unless further investment is made. It contrasts demand response with energy efficiency, where savings are more assured long-term. The NS Power Rate Model includes demand response data, and the impact of different scenarios on revenue requirements and unit costs is outlined.
updated avoided costs and incorporation of transfer tables and cost allocation summary tables in the NS Power Rate Model in the 2021 RBIA, and the integration of demand response in the 2023-2025 RBIA. The RBIA for the 2023-2025 DSM Plan es...
AI summary The 2023-2025 RBIA estimates that DSM programs will save customers $0.4 billion on electricity bills over the lifetime of the measures, after accounting for program costs and avoided utility costs. The analysis highlights net benefits of $368.8M and acknowledges that the RBIA does not capture all societal benefits, such as reduced emissions and energy poverty. The RBIA also examines the impact of DSM on different rate classes, including participants and non-participants.
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.
3.2.1 Functionalization of System Costs As indicated in the Revenue Requirement section above, NS Power has used the test year revenue requirements, already functionalized by the four areas, from the historic rate cases. In the "With DSM"...
AI summary The text discusses the functionalization of system costs, particularly in the context of the 'With DSM' and 'No DSM' scenarios. It explains how revenue requirements are adjusted for changes in load and inflation, with specific reference to the impact of the Maritime Link depreciation costs. The 'No DSM' case is derived from the 'With DSM' case by modifying revenue requirements based on load changes due to the absence of demand-side management.
3.2.2 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.
Comments The applied process is a simplification of a more elaborate cost allocation process in the COSS where energy- and demand- related non-FAM costs, are determined through application of rate base usage allocators developed separately...
AI summary The document discusses the simplification of a cost allocation process used in the Cost of Service Study (COSS), where energy- and demand-related non-FAM costs are determined using rate base usage allocators. The most recent rate setting procedure's class unit costs are carried forward for subsequent year simulations.
1 Table 5: 2025 Alternate Scenario Investment and Savings, by Program Component 2025 Investment a ($ million) Lifetime Benefits b ($ million) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak EE Demand Savings (MW) Availab...
AI summary Table 5 outlines the 2025 Alternate Scenario Investment and Savings for various energy efficiency and demand response programs in Nova Scotia. It provides data on investment amounts, lifetime benefits, energy savings, and other metrics for residential, business, and institutional programs.
IV. Impact on Avoided Costs of Shifting to Scenario 3.1C - Q: Have you conducted an analysis of the direction and magnitude of impacts if Scenario 3.1C is - used as the basis for determining avoided costs for DSM energy and capacity? - A:...
AI summary The analysis discusses the impact on avoided costs if Scenario 3.1C is used for determining DSM energy and capacity. A high-level comparison of NPVRR for different scenarios is presented, including the shift from 2.0C to 2.1C and from 2.0C to 3.1C, with references to a regulatory decision.
Table DGH-2: NPVRR Scenario Comparisons[12](#page-87-0) 1 Base DSM 2.0C (ref) 2.1C 3.1C Increase from low to mid electrification 7.51% Increase from low to mid Electrificaiton and 2030 coal retirement 12.42% Mid DSM 2.0C (ref) 2.1C 3.1C In...
AI summary Table DGH-2 compares the present value of revenue requirements under different scenarios involving electrification levels and coal plant retirement. Shifting to medium electrification and retiring coal plants by 2030 increases revenue requirements by over 7% for 2.1C and over 11% for 3.1C. These comparisons are directional and do not replace the need for recalculating avoided costs using scenario 3.1C.
8 The observed increase in NPVRR does not mean that avoided costs would directly increase by 9 the same amounts, they could be more or less than the increase in NPVRR. Full recalculation of the avoided costs for DSM with scenario 3.1C requ...
AI summary The testimony discusses the impact of different scenarios on avoided energy costs for DSM programs, noting that Scenario 2.1C leads to higher avoided costs compared to Scenario 2.0C. The differences are illustrated through figures showing both percentage and absolute dollar increases, with the cumulative difference over a 12-year period reaching $105 million.
COMPENSATION Schedule B (Page 1 of 2) Compensation I. Net Contract Price
AI summary The document outlines the 'Net Contract Price' section under the 'Compensation' schedule, likely detailing financial terms or agreements related to compensation within a regulatory proceeding.
E-12E1(NSUARB) RIR-1 to RIR-41
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Residual Suggested ID # Original finding Original Finding Description Status Remaining gaps Recommendations risk level timeframe 3.1 Access controls While EfficiencyOne has developed various Remediated + While EfficiencyOne has EfficiencyO...
AI summary EfficiencyOne has implemented logical access controls, but there are inconsistencies, especially with third-party IT providers, leading to a high risk. The original recommendations have been addressed, but further action is needed to align with the rate of access and permissions reviews.
trators must first fund the Three-Year Plans from other revenue sources.18 The Department may also approve funding from gas and electric ratepayers through a fully reconciling funding 17 To assess cost-efficiency and, thereby, the prudence...
AI summary The Department requires Program Administrators to fund Three-Year Plans through various revenue sources, including a system benefits charge, capacity market revenues, and cap-and-trade programs. The Department also mandates cost-effectiveness reporting to assess the prudence of expenditures.
their projected budgets through the EES contained in their EERF tariffs is consistent with the Guidelines.131 Similarly, the Department finds that the gas Program Administrators’ proposal 130 NSTAR Electric incorrectly projected its SBC re...
AI summary The text discusses the alignment of projected budgets through the Energy Efficiency Surcharge (EES) within the Electric Efficiency Reconciliation Factor (EERF) and Local Distribution Adjustment Clause (LDAC) tariffs with established guidelines. It also references a prior error by NSTAR Electric in projecting SBC revenues and the requirement for electric distribution companies to revise their EERF tariffs in future rate cases.
29, 2022 NSUARB IR-17, Attachment 3, Page 235 of 343 D.P.U. 21-120 through D.P.U. 21-129 Page 222 2019-2021 Three-Year Plans Order, at 105-106. For the 2022-2024 Three-Year Plans term, the Legislature has reallocated RGGI revenues such tha...
AI summary The document discusses the reallocation of RGGI revenues and the impact on energy efficiency programs, noting that funding to offset costs to ratepayers has decreased despite increased energy efficiency budgets needed to meet GHG reduction goals. Energy efficiency costs now make up a significant portion of residential gas and electric distribution rates.
h from these policy initiatives, the Department and policy makers must remain cognizant of the cumulative effect that these programs will have on customer bills now and in the future. 140 See, e.g., 220 CMR 18.00; Model SMART Provision, D....
AI summary The text discusses the need for regulators and policymakers to consider the cumulative impact of energy efficiency programs on customer bills. It references various Massachusetts Department of Public Utilities (D.P.U.) proceedings and mentions the use of revenue decoupling to recover program implementation costs through the Energy Efficiency Surcharge (EES).
through its EES. IX. FUTURE OF REVENUE DECOUPLING A. Introduction In Section IV.D.3.b., above, the Department approved the Program Administrators’ expansion of strategic electrification to drive energy and GHG emissions reductions. For the...
AI summary The Department has allowed revenue decoupling for electric and gas distribution companies since the Green Communities Act of 2008. However, the Department now finds that the Program Administrators’ strategy of strategic electrification in the Three-Year Plans eliminates the need for continued revenue decoupling by electric distribution companies.
the regional power grid (Statewide Plan, Exh. 1, App. C.1 - Electric (Rev.), Table IV.D). In order to pursue a clean energy future consistent with the Massachusetts 2050 Decarbonization Roadmap, broad electrification achieved through the P...
AI summary The Department concludes that full revenue decoupling for electric distribution companies should be discontinued to align their business models with the Commonwealth's clean energy goals, reducing their neutrality and encouraging increased clean electric load.
ree-Year Plans Order, at 140. While the Governing Board may work with the Compact to develop a cost-allocation proposal, the Department must ensure that the Compact spends its ratepayer- provided energy efficiency funds in a reasonable and...
AI summary The text discusses the role of the Compact as a municipal aggregator and Program Administrator, emphasizing its responsibility to ensure that energy efficiency funds are used reasonably and prudently. It also highlights the Compact’s obligation to make rate recovery filings and be subject to the same regulatory standards as investor-owned utilities.
Page 325 reasonable and are consistent with the achievement of all available cost-effective energy-efficiency and demand-reduction resources. The Department has reviewed the Three-Year Plans and finds that they are constructed in a manner...
AI summary The Department of Energy and Resource Development has reviewed the Three-Year Plans and found them to be consistent with GHG emissions reduction goals. It has directed Program Administrators to implement these plans while minimizing administrative costs, using competitive procurement, and ensuring sufficient funding for low-income programs.
ities between E1 and NS Power (2023-2025 DSM Plan) E1 Responses to Nova Scotia Utility and Review Board (NSUARB) Information Requests NON-CONFIDENTIAL 1 Request IR-40: 2 3 Appendix B – Attachment 1 – 2023-2025 Summary Results (Settlement a...
AI summary EfficiencyOne (E1) responded to information requests from the Nova Scotia Utility and Review Board (NSUARB) regarding the 2023-2025 Demand Side Management (DSM) Plan. E1 provided an annotated version of the Summary Results document and directed the NSUARB to the RBIA models for full formulae and calculations.
E-12-(i)NSUARB IR-17 Attachment 2_ACEEE’s Entire State Database - Excel
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customers under a straight fixed-variable rate design, which continues through today. The CPUC stopped the electric decoupling mechanisms in 1996 due to restructuring of the electric power industry. In 2001, the Legislature passed Section...
AI summary The text discusses the history and current implementation of decoupling mechanisms in California, including the resumption of decoupling in 2001 and its integration with performance incentives for energy efficiency. It also references the Energy Savings and Performance Incentive (ESPI) established by the California Public Utilities Commission.
annually) from customers to be forwarded to the Department of Health and Social Services, Division of State Service Centers, to be used to fund low-income fuel assistance and weatherization programs. The Delaware Weatherization Assistance...
AI summary The Delaware Weatherization Assistance Program aims to complete 400 homes annually and is funded by a $4 million allocation from the merger of Exelon and Delmarva Power. The program's funds are used to support energy efficiency initiatives for low-income households and must be approved by the Energy Efficiency Advisory Council and the Public Service Commission.
unds, to supplement WAP and increase the number of homes to be weatherized. Utilities and the District coordinate through the Income Qualified Efficiency Fund. More info on the IQEF is available here. In addition, a new initiative in the D...
AI summary The District of Columbia supports energy efficiency initiatives through programs like the Weatherization Assistance Program (WAP) and the Income Qualified Efficiency Fund (IQEF), which provide grants for energy improvements in low-income homes. Additionally, the District restricts large customers from self-directing energy efficiency funds or opting out of participation in such programs. PEPCO's Bill Stabilization Adjustment (BSA) was approved to implement electric revenue decoupling and support energy efficiency goals.
iciency programs. The BSA is applied on a monthly basis to the distribution charge of all customer classes except street lighting and telecommunications network customers. More info is available here. In April 2016, Washington Gas filed a...
AI summary The document discusses energy efficiency programs, the Bill Stabilization Adjustment (BSA), and the Clean and Affordable Energy Act (CAEA) of 2008 in Washington, D.C. It outlines how the BSA is applied to customer classes and details the CAEA's authorization of a Sustainable Energy Utility (SEU) contract with performance-based incentives and penalties. In 2017, DCSEU transitioned to a five-year contract for larger, longer-term energy efficiency projects.
tment of Environmental Protection, The Office of Energy, the Florida Solar Energy Center, as well as information for Florida Weatherization Assistance and Florida's Local Weatherization Agencies List. Last reviewed: June 2020 ","Florida do...
AI summary Florida does not allow large customers to self-direct energy efficiency funds or opt-out of energy efficiency programs. The state does not have decoupling or lost revenue adjustment mechanisms for utilities, though legislation in 2008 directed the Public Service Commission to analyze decoupling. Florida Statute allows financial incentives and penalties for utilities based on energy efficiency performance, but no utilities have requested the additional return on equity.
measured as the change in cumulative savings that consider both newly acquired savings as well as lost savings due to previously administered measures reaching the end of their Expected Measure Life. Some of the provisions of the Act inclu...
AI summary This text discusses the evaluation of ratepayer-funded energy efficiency programs in Illinois, including legislative mandates and regulatory orders. It outlines the shift of responsibilities from DCEO to utilities and changes to cost caps over time, as well as the cost-effectiveness tests used for evaluation.
te Approaches to Account for Health and Environmental Benefits of Energy Efficiency. Last reviewed: July 2019 ","Requirements for State and Utility Support of Low-Income Energy Efficiency Programs In December 2016, the Illinois State Legis...
AI summary The Future Energy Jobs Bill (SB 2814) in Illinois mandates electric utilities to implement low-income energy efficiency programs with specific funding requirements. The legislation also excludes these programs from the total resource cost-effectiveness (TRC) test. The Illinois Department of Commerce and Economic Opportunity administers weatherization funds through the Illinois Home Weatherization Assistance Program (IHWAP), which is supported by multiple funding sources including DOE WAP, HHS grants, and state-level charges.
er 2018 "," Primary cost-effectiveness test(s) used: total resource cost test Secondary cost-effectiveness test(s) used: utility cost test, participant cost test, ratepayer impact measure test Regulatory orders lay out the process for eval...
AI summary The document outlines the cost-effectiveness tests used in Indiana for evaluating energy efficiency programs. The primary test is the Total Resource Cost (TRC) test, with secondary tests including the Utility Cost Test (UCT), Participant Cost Test (PCT), and Ratepayer Impact Measure (RIM) test. These are governed by 170 IAC 4-8 Guidelines for Demand-Side Cost Recovery by Electric Utilities.
the electric utility's RIM test is less than one. 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 reviewed: July 2019 ","Iowa's ener...
AI summary Iowa's energy utilities are required to administer energy efficiency programs, with investor-owned utilities recovering program costs through tariff riders. The Iowa Utilities Board (IUB) approves these plans, ensuring they are cost-effective using five tests, with the societal cost test being primary. Targets for the 2019-2023 planning period include incremental electricity savings of 0.89% annually and natural gas savings between 0.10% and 0.29% of retail sales.
"Summary: For the 2019-2023 planning period, targets vary by utility, with average incremental electricity savings of 0.89% per year and natural gas savings between 0.10% and 0.29% of retail sales. For the 2019-2023 planning period IPL set...
AI summary For the 2019-2023 planning period, Iowa's rate-regulated utilities set incremental energy savings goals, with varying targets for electricity and natural gas. The primary cost-effectiveness test used is the societal cost test, and secondary tests include the utility cost test, participant cost test, and others. Evaluations of energy efficiency programs are conducted by utilities under Iowa Administrative Code.
vocating Tariff Equity v. Michigan Public Service Commission, April 10, 2012). In light of the Court’s determination, the Commission dismissed all pending cases involving electric revenue decoupling. Act 295 also authorized natural gas dec...
AI summary The text discusses the implementation of decoupling mechanisms for electric and natural gas utilities in Michigan, referencing court decisions and Commission orders. It also outlines performance incentives for energy efficiency programs, including specific percentages and timeframes for various utility companies.
he department allows for coordination of services for low-income households. The Department of Commerce Energy Assistance Program (EAP) offers a simple one-stop shop for applying to EAP, WAP, and CIP. APPRISE Incorporated recently complete...
AI summary The document discusses the Low Income Customer Incentive Program (LI CIP) in Minnesota, highlighting its performance and opportunities for improvement through collaboration. It also outlines the self-direct option for large customers, including exemption from CRM fees and the role of the Department of Commerce in managing these accounts.
m administration; the state Department of Commerce functions as the manager of self-direct accounts and is the arbiter of whether a company qualifies for self-direct and is satisfying its obligations. Commercial gas customers served by a g...
AI summary The Minnesota legislature authorized a pilot program for revenue decoupling in 2007. The Public Utilities Commission (PUC) later approved full revenue decoupling for several gas and electric utilities, including CenterPoint Energy, Minnesota Energy Resources Corp, Great Plains Natural Gas, and Xcel Energy. The PUC also set criteria for such programs.
ies simply provide notification to their utilities that they wish to opt out. Staff of the Missouri Public Service Commission perform a desk audit of all claimed savings and may perform a field audit. Last reviewed: July 2019 ","Recovery o...
AI summary The Missouri Public Service Commission allows utilities to recover lost revenues through specific mechanisms, including rider or tracker mechanisms. In 2012, Ameren Missouri and KCP&L Greater Missouri Operations Company were approved to collect annual revenue requirements for demand-side programs, fixed operating costs, and performance incentives based on verified energy savings.
gh EM&V reports as a percentage of annual demand savings targets. Utilities may also propose recovery of lost revenues as measured and verified through EM&V prior to recovery on a retrospective basis. In early 2016, the Commission approved...
AI summary The document discusses the approval of DSM programs and DSIMs for Ameren Missouri, KCP&L, and KCP&L Greater Missouri Operations Company, allowing utilities to bill customers for estimated lost revenues and recover them through EM&V. Performance incentives are tied to achieving energy and demand savings targets over a 3-year period, with recovery over a 2-year period.
g Project (NESP). Further information on health and environmental benefits is available in ACEEE’s Overview of State Approaches to Account for Health and Environmental Benefits of Energy Efficiency. Last Updated: May 2019 ","Requirements f...
AI summary Nevada established the Nevada Fund for Energy Assistance and Conservation (FEAC) through a universal energy charge, with 25% allocated to the Nevada Housing Division for low-income energy efficiency programs. Legislation in 2017 required utilities to set aside at least 5% of efficiency program expenditures for low-income customers and exempted low-income programs from cost-effectiveness screening if the overall DSM portfolio meets requirements.
, §62-17-10). The New Mexico Public Regulation Commission (PRC) sets out the rules for implementing statute. The PRC's energy efficiency rule, NMAC 17.7.2, was updated in 2014 (Case No. 13-00310-UT). The PRC mandates that electric utilitie...
AI summary New Mexico's energy efficiency targets were established by HB 305 in 2008, requiring a 5% reduction by 2014 and 10% by 2020. These targets were later amended by HB 267 in 2013, reducing the 2020 target to 8% and introducing a fixed tariff rider for funding energy efficiency and load management programs.
tion costs, lower bad-debt expense, improved customer service, effectiveness, and other appropriate factors qualifying as utility system economic benefits” [17.7.2.9 NMAC - Rp. 17.7.2.9 NMAC, 1-1-15]. Last reviewed: July 2019 ","A self-dir...
AI summary The text discusses energy efficiency programs in New Mexico, including a self-direct option for large customers, the absence of decoupling mechanisms, and the potential adoption of such mechanisms through HB 291 (2019). It also mentions the existence of a profit incentive mechanism tied to program performance and the participation of utilities in energy efficiency initiatives.
ted to low-income or hard-to-reach customers may have lower threshold cost-effectiveness results than other efficiency programs. Coordination of Ratepayer-Funded Low-Income Programs with WAP Services Beginning in 2017 ONG combined the deli...
AI summary The text discusses the coordination of low-income energy efficiency programs with WAP services, the opt-out policies for transportation-only gas and electric customers, and the revenue recovery mechanisms and performance-based ratemaking used by Oklahoma gas utilities, including shared benefit incentive plans.
will be cost-effective during the period?the program is offered;? f. Are included in a pilot or research project; or? g. Are required by law or are consistent with Commission policy or direction? Further information on cost-effectiveness s...
AI summary The text discusses requirements for low-income energy efficiency programs in Oregon, including legislation requiring utilities to allocate funds for public purposes, cost-effectiveness rules, and the coordination of programs with WAP services. It references specific orders and legislation related to these programs.
of State Payroll Tax Program that provides a direct ongoing revenue stream for transit districts that can demonstrate equal local matching revenues from state agency employers in their service areas. The state of Oregon passed HB 2017 in t...
AI summary Oregon implemented HB 2017, which introduced a .001 employee-wage transit tax starting July 1, 2018, funding the Statewide Transportation Improvement Fund (STIF) for public transit. Funds are distributed to qualifying entities, competitive grants, intercity services, and ODOT. The state also has a Lieu of State Payroll Tax Program for transit districts with matching revenues from state agency employers.
as also codified the use of nonwires alternatives for promoting the state's policy goals of enhancing grid reliability and resilience. CHP is defined as an eligible measure for nonwires alternatives. Technical assistance is also available,...
AI summary Rhode Island has achieved high energy savings through its energy efficiency programs, supported by legislation like the Comprehensive Energy Conservation, Efficiency and Affordability Act of 2006 and House Bill 8082. Narragansett Electric and Pascoag Utility District manage these programs, with National Grid offering technical assistance and incentives for CHP systems.
ear energy saving targets. Enacted in 2010, House Bill 8082 authorizes revenue decoupling for electric and natural gas utilities and requires utilities to submit proposals to implement these policies. The most recent budgets for energy eff...
AI summary Rhode Island's energy efficiency programs are funded through a conservation and load adjustment factor, with a minimum surcharge of 2 mills per kilowatt-hour. The Comprehensive Energy Conservation, Efficiency and Affordability Act of 2006 mandated utilities to acquire cost-effective energy efficiency and created a statewide natural gas conservation program. Program plans are reviewed annually by the Rhode Island Public Utilities Commission.
Approaches to Account for Health and Environmental Benefits of Energy Efficiency. Last Updated: January 2019 ","Requirements for State and Utility Support of Low-Income Energy Efficiency Programs The Comprehensive Energy Conservation, Effi...
AI summary The document outlines requirements for state and utility support of low-income energy efficiency programs under the Comprehensive Energy Conservation, Efficiency and Affordability Act of 2006. It discusses funding allocations for residential income-eligible programs, cost-effectiveness rules, and the coordination of ratepayer-funded programs with WAP services.
ons of Rhode Island programs, the state has relied on Massachusetts’ benefit valuation work, as they have similar program types. Coordination of Ratepayer-Funded Low-Income Programs with WAP Services The Rhode Island Department of Human Se...
AI summary Rhode Island coordinates its Low-Income Weatherization Assistance Program (WAP) with the LIHEAP program through collaboration between the Department of Human Services (DHS) and CLEAResult. A Weatherization Technical Committee was formed to share expertise and develop policies. Additionally, revenue decoupling was enacted in 2010 and implemented by National Grid in 2011.
uires utilities to submit proposals to implement these policies. In 2011, National Grid proposed a revenue decoupling mechanism that was approved by the Public Utilities Commission (Docket No. 4206). Rhode Island has had a shareholder ince...
AI summary Rhode Island has implemented various energy and transportation policies, including revenue decoupling mechanisms, shareholder incentives for energy savings, and adoption of California's Low-Emission and Zero-Emission Vehicle programs. The state also integrates transportation and land use planning and has set tailpipe emissions standards.
strial, manufacturing or retail commercial customers with 1,000,000 kWh annual usage or greater are eligible to opt-out. Self-certification only is required. Roughly 50% of eligible load is opted-out. Last Updated: July 2016 ","S.C. Code A...
AI summary The text discusses energy efficiency programs in South Carolina, including eligibility for opt-out by large commercial customers, lost revenue recovery mechanisms approved by the Public Service Commission, shared savings incentives for Duke Energy and Dominion Energy, and the absence of revenue decoupling authorization by the South Carolina General Assembly.
to submit a plan to reach 60% of the current energy assistance need by 2030, and 90% of the current energy assistance need by 2050. Cost-Effectiveness Rules for Low-Income Energy Efficiency Programs Washington specifies the total resource...
AI summary Washington State requires utilities to submit plans to meet increasing energy assistance needs by 2030 and 2050. The state uses the Total Resource Cost (TRC) test as the primary cost-effectiveness criterion for low-income energy efficiency programs, with a minimum TRC ratio of 0.67. Non-energy benefits are included in the TRC test, and utilities are encouraged to fund low-income conservation measures, as outlined in the Weatherization Manual. The commission revised rules in Docket UE-131723 to allow, rather than require, utilities to pursue cost-effective low-income conservation programs.
E-30E1 Compliance Filing 2023-2025 with Appendix A-D FINAL
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STRATEGIC THEMES The 2020 IRP Reference Plan – demand side resources are planned in support of the successful implementation of a long-term electricity strategy for delivery of safe, reliable, affordable, and clean electricity that is in t...
AI summary The 2020 Integrated Resource Plan (IRP) emphasizes demand-side management (DSM) as a key strategy for delivering safe, reliable, and clean electricity. It highlights the importance of E1's DSM portfolio in decarbonizing Nova Scotia's economy and outlines the evidence used to develop strategic themes, including past NSUARB decisions and stakeholder feedback. The Settlement Plan aims to reduce customer revenue requirements by leveraging DSM investments.
14 Table 6: Benefit and Cost Components in the Total Resource Cost Test Calculations for EE and DR Component Description Benefit or Cost Avoided Cost of Transmission & Distribution EE & DR – the avoided cost of transmission and distributio...
AI summary The table outlines the benefit and cost components in the Total Resource Cost (TRC) test calculations for Energy Efficiency (EE) and Demand Response (DR) programs. It highlights benefits such as avoided costs of transmission, distribution, capacity, and carbon, while noting that DR does not contribute to avoided energy or carbon costs. Program administration and incremental costs are also detailed for both EE and DR.
Table 8: 2023-2025 Settlement Plan Investment and Savings Year Investment a Lifetime Benefits b First-Year Energy Savings Lifetime Energy Savings Average Dema Peak EE Demand Savings Available DR Capacity (MW) Total Re Cost Tes esource st (...
AI summary Table 8 presents the 2023-2025 Settlement Plan Investment and Savings, outlining annual investments, energy savings, demand reductions, and related costs. The table includes metrics such as lifetime benefits, energy savings, peak demand savings, and associated costs, providing a comprehensive overview of the plan's financial and operational impact.
ver $130 million in annual electricity costs (accounting for DSM cost recovery)[1](#page-76-1) and over 775 kilotonnes of greenhouse gas emissions annually through a variety of programs and services. E1's Settlement Plan is an investment o...
AI summary The document discusses the benefits of demand side management (DSM) in Nova Scotia, highlighting over 775 kilotonnes of annual greenhouse gas emissions reductions and over $130 million in annual electricity cost savings. The $173 million Settlement Plan is outlined as a long-term investment in energy efficiency and demand response, with a 5-year payback period and significant long-term benefits to customers.
19 Table 35: 2023-2025 New Residential Performance Indicators Year Investment ($ million) First-Year Energy Savings Lifetime Energy Savings Peak Demand Savings Total Resource Cost Test (TRC) a \nincl. excl. Program Administrator Cost Test...
AI summary Table 35 outlines the 2023-2025 New Residential Performance Indicators, including investment, energy savings, peak demand savings, and cost metrics. The table shows data for 2023, with 2024 and 2025 left blank, and includes metrics like Total Resource Cost (TRC) and Program Administrator Cost (PAC) tests.
The figure below identifies the Contract Price to be paid by NSPI allocated for each year of the Term. 2023 2024 2025 Total UARB Approved Investment Amount 53,000,000 57,500,000 62,500,000 173,000,000 Refund (273,174) TBD (273,174) Net Con...
AI summary The document outlines the Contract Price to be paid by NSPI for each year of the Term, including an investment amount and a refund of a 2019 surplus. The surplus from the 2020-2022 DSM Plan will adjust the 2024 Net Contract Amount. Any surplus from the Performance Targets will be reported to and refunded by the UARB.