Topic:"Load Management" in M10473

Item Description Program Enrollment Assumptions • Steady state participation levels22 range from 10% to 30% of eligible customers depending on the customer segment and the type of delivery (BYOD and DI). Eligible customers are those that e...

AI summary The document outlines assumptions and parameters for a demand response program, including participation levels, event timing, unit impacts, and projected load reduction. It also discusses the BNI Curtailment Option as part of the DR Portfolio, targeting large C&I customers and projected to provide 9 MW of load reduction by 2025.

also be offered year-round to provide load reductions during other Item Description E1 will offer the BNI Curtailment option to Large C&I and Interruptible customers. • Customers agree to reduce load by a fixed contracted amount when Table...

AI summary E1 will offer the BNI Curtailment option to Large Commercial and Industrial (C&I) and Interruptible customers, allowing them to reduce load by a fixed contracted amount when needed, as outlined in Table 16.

Table 18. EV Charging Control Option Characteristics Item EV Charging Control Description This option will manage EV charging by controlling either through the EVSE or through onboard telematics at the vehicle. This option could potentiall...

AI summary Table 18 outlines the characteristics of an EV Charging Control option aimed at managing EV charging through the EVSE or onboard telematics. It includes eligibility criteria, participation assumptions, event parameters, incentives, and projected load reductions, with a focus on winter peak reduction and a participation incentive of $32/kW-yr.

Define Program Parameters and Initiate Load Control Events NS Power is assumed to undertake the following: • Define dispatch criteria (economic, reliability, emergency, operating reserves, non-wire alternatives (NWA), etc.) ©2022 Guidehous...

AI summary NS Power is expected to define dispatch criteria and program parameters for load control events, including applicable months, event hours, and minimum load curtailment. E1 is identified as a supporting entity for this function.

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

AI summary The 'COSS Data Inputs' tab contains annual test year class usage and embedded costs from the COSS and BCF COSS, as well as a forecast of annual usage by class from the most recent ten-year Load Forecast Report. It also includes annual DSM Expenditures on rate classes, which are used to determine class unit costs and revenues.

APPENDIX I BIBLIOGRAPHY Program Components Bibliographic References National Renewable Energy Laboratory, The Uniform Methods Project Chapter 23: Estimating Net Savings: Common Practices, September 2014, p. 3. Nova Scotia Utility and Revie...

AI summary This appendix lists bibliographic references for various programs and studies, including energy efficiency initiatives, load forecasting reports, and regulatory matters. It includes sources such as the Nova Scotia Utility and Review Board, Nova Scotia Power, and Emera Inc.

9.1.1 Market Share of Heat Pumps The data presented in this subsection are for all heat pumps, not just MSHPs. NS Power data indicates that, since 2013, over 90% of heat pumps installed through the NS Power on-bill financing program compon...

AI summary The text discusses the market share of heat pumps in Nova Scotia, noting that the majority of heat pumps installed through NS Power's on-bill financing program and EOne's incentives are mini-split heat pumps (MSHPs). It provides data on the number of homes with heat pumps installed annually from 2013 to 2021 and forecasts future growth rates and cumulative numbers.

B. Participant Perspectives - B1. How did you first hear about the OEM Operational Demand Savings Pilot? - B2. What motivated you to participate in the OEM Operational Demand Savings Pilot? - B3. Did you face any challenges or barriers whe...

AI summary The text outlines a series of questions posed to participants in the OEM Operational Demand Savings Pilot, focusing on their experiences, challenges, and suggestions for improvement related to the implementation and sustainability of energy-saving measures.

Unitary Peak Demand Savings Since no information could be found in the literature, the peak demand savings of DWHTs were based on Nova Scotia Power estimates in their 2019 Load Forecast Report. 148 148 Nova Scotia Power. 2019 Load Forecast...

AI summary The peak demand savings of DWHTs were estimated based on Nova Scotia Power's 2019 Load Forecast Report, which estimated an average peak contribution of 0.57 kW per tank. Due to uncertainties, the value was rounded down to 500 W, deemed conservative and acceptable.

EfficiencyOne Demand Response Roadmap BTM battery control is the least cost option and provides around 65 MW of peak demand savings in 2031. DLC (including both Bring Your Own and Direct Install options) has the next highest contribution i...

AI summary The document compares demand response (DR) options, highlighting BTM battery control as the least costly with 65 MW peak savings in 2031, followed by DLC (62 MW) and BNI Curtailment (10 MW). Other DR methods contribute less. Cost rankings and savings are analyzed for 2030-2031.

EfficiencyOne Demand Response Roadmap Figure 14. Supply Curve of DR Options for Preferred Plan BTM battery control is the least cost option and provides around 65 MW of peak demand savings in 2031. DLC (including both Bring Your Own and Di...

AI summary The document outlines the EfficiencyOne Demand Response Roadmap, highlighting BTM battery control as the least costly option providing 65 MW peak savings by 2031, followed by DLC at 62 MW but higher costs, and BNI Curtailment at 10 MW. CPP savings are limited to enabling technology portions. The analysis is by Guidehouse Inc., dated March 11, 2022.

included: audit of tracking sheet, on-site visits, Measure Assessment update, participant surveys, and calculation of GHG emission reduction. The Evaluator highlighted the following 2021 EPI impacts: - achieved 7.812 GWh in net electrical...

AI summary The 2021 evaluation of the EPI program highlights 7.812 GWh in net electrical energy savings, 1.098 MW in peak demand savings, and a 94% LED lamp installation rate. Spillover effects increased to 10%, while free-ridership remained stable. Net savings were 3% higher than tracked values due to increased NTGR. The evaluator found methods appropriate and the evaluation excellent, with no new recommendations.

15. DSM Measure Assessment For 2021, Efficiency Nova Scotia tasked Econoler to develop an in-depth review of all parameters necessary to calculate the annual and lifetime gross energy and peak demand savings of most prescriptive measures a...

AI summary Efficiency Nova Scotia commissioned Econoler to assess DSM measures for calculating energy and peak demand savings, creating a reference document with methods, EUL values, and interactive effects. The work is praised for its thoroughness and recommended for all utilities.

E1 Responses to Investment Property Owners Association of Nova Scotia (IPOANS) Information Requests NON-CONFIDENTIAL - 1 to the 2023-2025 DSM Resource Plan energy efficiency portfolio as a whole, as well as hot water - 2 based direct load...

AI summary E1 responds to IPOANS information requests regarding the 2023-2025 DSM Resource Plan, highlighting that hot water-based direct load control has a lower TRC cost ratio compared to the overall energy efficiency portfolio and ETS systems. This positions direct load control as a more cost-effective option for demand-side management.

mpany, customers or developers can request a commitment letter from the Program Administrator that allows the customer two years to enroll in the daily dispatch program for a five-year 50 The Department addresses National Grid (electric)’s...

AI summary The document discusses proposals by electric Program Administrators to implement direct load control and EV load management programs, including incentives for customers to manage energy use during peak times. It also mentions ongoing evaluations of EV activities from the 2019-2021 Three-Year Plan and uncertainty about future approaches.

cess and whether it is “opt-in” or “opt-out.” The Department is concerned about the safety of children, the elderly, and medically compromised individuals residing in a household that is auto-enrolled in an air conditioning ADR program. Ac...

AI summary The Department of Public Utilities is concerned about the safety of vulnerable individuals in households auto-enrolled in air conditioning ADR programs and requires opt-in enrollment for residential and income-eligible ADR programs. The Online Marketplace allows customers to purchase energy efficiency products with rebates already applied. Program Administrators are seeking approval for a statewide EV load management offering, though details are not yet provided.

AR Electric Company, D.P.U. 20-74, at 40 (2021); Grid Modernization, D.P.U. 15-120 through D.P.U. 15-122, at 152, 159, 169 (2018). Similarly, the Department supports the deployment of an appropriate EV load management offering by the elect...

AI summary The Department supports the deployment of EV load management by Program Administrators to reduce peak demand but cannot make substantive findings due to insufficient detail in the Three-Year Plan.

l screening. The rules for benefit-cost tests are not specified. Coordination of Ratepayer-Funded Low-Income Programs with WAP Services Level of coordination is unclear from publicly available data. Last updated: April 2017 ","Rocky Mounta...

AI summary The text discusses various energy efficiency and utility programs, including a self-direct option for customers, a decoupling pilot program, and load management tracking adjustments. It also notes the lack of policies to reward successful energy efficiency programs and promote efficient transportation systems in Wyoming.

E1 Responses to Synapse Energy Economics (Synapse) Information Requests NON-CONFIDENTIAL [Evidence] Request IR-10: Please refer to p. 58, regarding the collaboration between E1 and NS Power on two pilot programs for the 2021-2022 timeframe...

AI summary E1 and NS Power collaborated on two demand response pilot programs during 2021-2022, including the Domestic Hot Water Direct Load Control Pilot, which involved installing control equipment on residential water heaters. Procurement and testing of equipment from two vendors were completed, with 202 controllers procured.

Metrics Metric Results (Nov 23, 2021) Estimated demand savings per controller 0.5 kW # of test controllers installed 4 (2 in NSCC lab & 2 in E1 homes) # of customer controllers installed 98 (73 Shifted Energy & 25 Aquanta) Pre-Pilot Testin...

AI summary The document presents metrics from a pilot testing phase involving demand response controllers. It outlines results such as estimated demand savings, number of controllers installed, and details of pre-pilot and pilot testing activities, including automatic opt-outs during peak demand periods.

Observations and Learnings - Typically scheduling three events per week, with variations in day of the week and event times. Peak Shifting events have been scheduled based on system load and wind generation forecasts. - As expected, have o...

AI summary The document discusses observations from a demand response pilot program, including scheduling practices, opt-out rates, customer concerns, and technical adjustments to minimize complaints. It highlights the use of machine learning and threshold settings to manage participant comfort and data access concerns.

Application, Appendix A, Attachment 5, PDF 301. Utilities With Small Load Interruptible Services Utility Rate or Rider Connexus Energy (Minnesota) PowerNap Water Heating DTE Energy (Detroit Edison) Interruptible Water Heating Option East C...

AI summary The application discusses the speculative nature of the Battery Control Program, citing the Guidehouse study's reliance on assumptions due to a lack of battery adoption data in Nova Scotia. The study used high-level forecasts based on industry expertise and insights reports.

6.4.3 QUALITY ASSURANCE - For DR pathways the framework is expected to leverage applicable EE quality assurance activities for - pathways co-delivered with EE activities. The quality assurance framework is also expected to include test - e...

AI summary The quality assurance framework for DR pathways is expected to leverage EE quality assurance activities, and include test events, customer surveys, and inspections to ensure compliance and effectiveness.

2.1.4 Peak Period Definition and Baseline Peak Demand Projections A key element of market characterization for the DR portfolio assessment is to develop disaggregated bottom-up peak demand projections by customer class, segment and end use...

AI summary The document outlines the process for defining peak periods and developing baseline peak demand projections for the DR portfolio assessment. It uses historical load data, normalized loadshapes, end-use shares, and energy sales forecasts to estimate demand by customer class and end use, with calibration to align with peak demand distributions.

Item Description Participation Incentives • Residential Central HP: $25/new participant (one-time enrollment), o $50/participant/yr. annual participation incentive. Baseboard and MSHP: $5/new participant (one-time enrollment), o $10/yr. ex...

AI summary The document outlines participation incentives for residential and small commercial and industrial (C&I) participants in the Direct Load Control (DLC) program for water heaters, including one-time enrollment incentives and annual participation incentives. It also projects a 0.5 MW peak load reduction in 2025 and estimates cumulative costs for DLC using smart thermostats from 2023 to 2025 at around $443.3k.

The 2023-2025 DR Portfolio includes a Bring Your Own Device (BYOD) controllable water heater and Direct Install (DI) water heater switch option to residential and small C&I customers. This option is expected to provide approximately 5.5 MW...

AI summary The 2023-2025 DR Portfolio includes a Bring Your Own Device (BYOD) controllable water heater and Direct Install (DI) water heater switch option for residential and small C&I customers, expected to provide 5.5 MW of load reduction by 2025, with 80-95% of reductions from residential customers.

12 The primary utility use case for current DR pilots (i.e. the residential direct load control water heating and 13 BNI curtailment pilots) is load leveling (i.e. peak demand reduction). The benefits of this use case can be 14 characteriz...

AI summary The document discusses current demand response (DR) pilots in Nova Scotia, focusing on load leveling and peak demand reduction. It notes that current modeling suggests program costs exceed benefits. Future pilots aim to explore new use cases, including load shifting, operating reserve, congestion management, and frequency response.

Performance Targets consist of: - Cumulative annual energy savings; - Cumulative annual system-peak demand savings; Performance targets are at the portfolio (i.e. DSM Plan) level. The cumulative annual system-peak demand savings Performanc...

AI summary The performance targets outlined include cumulative annual energy and system-peak demand savings, with specific exclusions for Demand Response savings from new or available demand capacity. Targets also apply to specific affordable housing and Mi'kmaw energy efficiency programs, as well as available demand response capacity during winter peak periods.

E1 is directed as follows: - 1. To provide detailed plans and processes for each of its research initiatives prior to proceeding with significant expenditures, to be documented and fully discussed with members of the DSM Advisory Group in...

AI summary E1 is directed to enhance transparency and collaboration in its energy initiatives, including detailed documentation of research plans, cost-effectiveness testing, and stakeholder engagement with NS Power and the DSM Advisory Group. It must justify underperforming measures, report on demand response progress, and seek Board approval for new incentives under the Demand Response Program.