Topic:"Rate Design" in M11630

Program Components - The Residential Demand Response program component aims to help facilitate a more flexible residential load that provides residential customers with economic incentives and more visibility and control of their loads. E1...

AI summary The Residential and BNI Demand Response programs aim to enhance load flexibility through economic incentives and customer control. E1 is evaluating pathways like battery control, CPP rates, EV charging, and direct load control for residential customers, while BNI customers may see battery control, curtailment, and direct load management. These initiatives seek to improve grid efficiency and customer engagement.

E1 filed the following reports with the NSUARB: - o E1 Reply to stakeholder comments on the 2022 Rate and Bill Impact Analysis Report; - o a data sharing agreement that will govern the use of E1 customer data for the purpose of facilitatin...

AI summary E1 submitted multiple reports to NSUARB, including rate analysis, data sharing agreements, financial statements, and DSM evaluations. Activities also included participation in NS Power's IRP process, technical conferences, and planning for future DSM resource plans, alongside ongoing evaluation implementation.

ATTACHMENT 1: 2023 RATE CLASS RESULTS

AI summary Attachment 1 presents the 2023 Rate Class Results from a Nova Scotia regulatory proceeding, detailing utility rate classifications and associated data. Key entities include regulatory bodies, energy efficiency programs, and legislative frameworks relevant to rate design and utility oversight.

Attachment 1: 2023 Rate Class Results

AI summary Attachment 1 details the 2023 Rate Class Results analyzed by the NSUARB, focusing on regulatory proceedings involving demand-side management (DSM) programs and Efficiency Nova Scotia (ENS). The document outlines key rate class outcomes and associated stakeholder inputs.

2023 Rate Class Expenditures E1 reports on planned and actual DSM expenditures by rate class to aid in cost recovery allocations.[34](#page-48-0) Annual mid-course planned expenditures per rate class are established using E1's mid-course a...

AI summary E1 reports on planned and actual DSM expenditures by rate class in 2023, showing 85% of mid-course planned expenditures were achieved. Variations in spending across rate classes are attributed to different program activities and customer participation. A 2015 NSUARB Order directed NS Power to file its proposed accounting treatment and cost recovery for DSM programs.

1 Table 1: 2023 Planned and Actual DSM Expenditures by Rate Class 2023 Expenditures by Rate Class Rate Class 2023 Plan as Approved ($ million) 2023 Mid-Course Planned Expenditures ($ million) Actual 2023 Expenditures ($million) 2023 Expend...

AI summary The table shows the planned and actual 2023 expenditures by rate class for the DSM program. Expenditures varied across rate classes, with some exceeding planned amounts and others falling short. The data is based on the 2023-2025 DSM Resource Plan Compliance filing approved by the NSUARB.

1 2023 Rate Class Results by Program - 2 Tables 2 7 provide a breakdown of 2023 net incremental energy and net peak demand savings, - 3 expenditures, and participation achieved by rate class within the energy efficiency programs.

AI summary The document presents 2023 results from energy efficiency programs, detailing net incremental energy savings, peak demand reductions, expenditures, and participation rates by rate class. Tables 2 and 7 are referenced as primary sources for quantitative breakdowns of program performance metrics.

1 Table 3: 2023 Existing Residential Rate Class Results Existing Residential (2023) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Expenditures ($ million) Housing Units / Products (#) Residential/Ch...

AI summary Table 3 presents 2023 residential rate class results, including energy savings, peak demand savings, expenditures, and the number of housing units or products. The data highlights the impact of various residential and industrial rate classes on energy efficiency and savings.

1 Table 7: 2023 Direct Installation Rate Class Results Direct Installation (2023) First-Year Energy Savings (GWh) Lifetime Energy Savings (GWh) Peak Demand Savings (MW) Expenditures ($ million) Products (#) Residential/Charitable (2,3,4) 1...

AI summary Table 7 presents the 2023 Direct Installation Rate Class Results, showing energy and demand savings, expenditures, and number of products installed across different rate classes. The data highlights the performance of energy efficiency programs, with significant savings in residential, small general, and general categories.

2022 Investigate the impact of interruptible load rates on peak demand savings and, if needed, implement changes to peak demand savings calculation methodologies for participants on interruptible loads. Evaluator will work with EOne and NS...

AI summary This section discusses the implementation of a 2022 recommendation to investigate the impact of interruptible load rates on peak demand savings and update calculation methodologies. E1 agrees with the recommendation, and the Evaluator will work with EOne and NS Power to ensure clarity in interruptible load conditions and update protocols accordingly.

4.2.6 Evaluated Gross Savings The annual gross savings for each category of measure installed through HEA in 2023 are listed in [Table](#page-18-0) 15 below. The gross savings at the generator were estimated by using residential line loss...

AI summary The annual gross savings from residential energy efficiency measures installed in 2023 are evaluated using line loss factors submitted to the NSUARB. Adjustments were made to account for delays in processing E assessment files, affecting 420 participants. The evaluation used actual data from 2023 and corrected previous estimates from 2022.

8.7 Awareness About, Motivations for, and Barriers to Purchasing ETS MSHP participants and MSHP contractors were asked whether they had heard of electric thermal storage (ETS). A total of six in ten (61%) MSHP participants and 19 out of 20...

AI summary The text discusses awareness, motivations, and barriers related to purchasing electric thermal storage (ETS) among MSHP participants and contractors. Key motivations include time-of-day rates, energy cost savings, and rebates, while barriers primarily revolve around cost and rebate differences compared to heat pumps.

9.4 Realization Rate [Table](#page-59-1) 35 below compares the energy and peak demand savings established through this evaluation to those calculated in the 2023 tracking sheet. It also includes the realization rate, representing the ratio...

AI summary This section compares energy and peak demand savings from the current evaluation with those from the 2023 tracking sheet, introducing the realization rate as the ratio of evaluated net savings to tracked net savings for both energy and peak demand.

26.2.5 Evaluated Gross Savings The modelled and non-modelled measure annual gross savings at the meter are presented in [Table](#page-146-0) 77 and [Table](#page-146-1) 78 below respectively. As presented in [Table](#page-122-0) 63 above,...

AI summary The document discusses evaluated gross savings, presenting modelled and non-modelled measure annual gross savings at the meter and generator. Line loss factors provided by NS Power are used to estimate savings at the generator, corresponding to values submitted to the NSUARB in the 2014 Cost of Service Study Progress Update.

[ASK E1 TO E7 IF EQUIPMENT = ELECTRIC THERMAL STORAGE] - E1. [ASK IF [A4=](#page-19-0)1] You mentioned earlier that your electricity rate with Nova Scotia Power is a timeof-day rate. Among the following three choices, which one best descri...

AI summary The text asks respondents about their decision-making process regarding a time-of-day rate with Nova Scotia Power and whether the Heating System Rebates influenced their decision, specifically in relation to electric thermal storage equipment.

[DO NOT ACCEPT A RANGE – ASK [E5](#page-28-1) TO [E7](#page-28-2) SEQUENCE IN ORDER/DO NOT RANDOMIZE] E5. [ASK IF [A4=](#page-19-0)1] If there were no Heating System Rebates program, what is the likelihood that you would still have applied...

AI summary This question asks about the likelihood of applying for NS Power's Time-of-Day Rate and installing equipment if the Heating System Rebates program did not exist. It explores the relationship between rebate programs and customer participation in time-of-day rate plans.

Factor [READ AND RANDOMIZE] Responses a. The program rebate Response 98 Don't Know Refused b. Information provided by Efficiency Nova Scotia Response 98 Don't Know Refused c. The bill savings available through Nova Scotia Power's time-of-d...

AI summary The text presents responses to questions about a program rebate, information provided by Efficiency Nova Scotia, and bill savings from Nova Scotia Power's time-of-day rate, with most respondents indicating they don't know or refusing to answer. It also references a section on cross-influence.

B6. And have you ever heard of Nova Scotia Power's time-of-day rate? 2023 MSHP Biomass ETS Sample Size 90 90 - - Yes, have heard of Nova Scotia Power's time-of-day rate 78% 78% - - No, have not heard of Nova Scotia Power's time-of day rate...

AI summary The text asks if respondents have heard of Nova Scotia Power's time-of-day rate, with 78% indicating they have heard of it, 20% saying they have not, and 2% unsure. The data is based on respondents who installed a mini-split heat pump.

E5. If there were no Heating System Rebates program, what is the likelihood that you would still have applied for NS Power's Time-of-Day Rate and installed a ? 2023 MSHP Biomass ETS Sample Size 5 - - 5 MEAN 2.6 - - 2.6 Base: Respondents wh...

AI summary The question explores whether the absence of the Heating System Rebates program would affect participation in NS Power's Time-of-Day Rate and installation of ETS. The table provides sample sizes and mean values for 2023 and ETS, but lacks detailed data on the impact of the rebate program.

4.2.6 Evaluation Gross Savings The energy and peak demand savings associated with Instant Rebates were calculated using the unitary savings values (including baseline wattages, the actual wattages of efficient measures, ballast factors whe...

AI summary This section discusses the calculation of energy and peak demand savings from Instant Rebates using unitary savings values from the 2020-2023 Measure Assessment. Line loss factors used in the calculation were based on the 2014 Cost of Service Study Progress Update submitted to the Nova Scotia Utility and Review Board.

3.1.5 Decarbonization and Electrification

AI summary This section introduces the topic of decarbonization and electrification, highlighting the importance of reducing greenhouse gas emissions through the transition to cleaner energy sources and the electrification of various sectors.

SEM participant quotes: "It was difficult trying to figure out the right mix of who needs to be on the team to ensure good representation from the maintenance, facilities, equipment, and production teams so that we fully understood what co...

AI summary Participants in the SEM program found initial challenges in team composition and collaboration with service providers but now see value in the program. Many are focused on decarbonization, though some do not immediately see the link between electricity efficiency and emissions reduction. Most participants have or are implementing EMIS systems, though some lack the resources to do so.

4. On-site or Virtual Review (continued) Section to be filled out with questions prior to virtual visits, and answers to be included during the call. Create new worksheet and b. If so, how has this impacted the selection of the baseline or...

AI summary The text outlines a worksheet for on-site or virtual reviews, focusing on questions related to baseline selection, non-routine adjustments, peak demand savings, and interactive effects. It includes sections for notes before and after interviews, with specific attention to Nova Scotia's peak demand period and measurement-based demand savings.

4.2.6 Evaluated Gross Savings [Table](#page-195-0) 16, [Table](#page-196-0) 17, and [Table](#page-197-0) 18 below present the evaluated total gross savings at the meter and at the generator for both SBES paths and the CDI pilot respectivel...

AI summary The text discusses evaluated gross savings at the meter and generator levels for SBES paths and the CDI pilot, noting that generator savings calculations use line loss factors submitted to the Nova Scotia Utility and Review Board (NSUARB) as part of the 2014 Cost of Service Study Progress Update.

1.1 Residential DR Description In 2023, EOne officially launched the Residential DR program. Since the fall 2020, EOne implemented several pilot initiatives focused on reducing demand during the Nova Scotia peak period. One of them was the...

AI summary In 2023, EOne launched the Residential DR program, which includes a DHW Direct Load Control pathway. NS Power calls DR events during peak periods, and Shifted's control software manages water heater load reduction. No target was set for new and total available DR capacity at the generator in 2023.

Table 5: 2023 Residential DR Evaluation Approach Evaluation Objectives Research Questions Methodology Establish available DR capacity results for the Domestic Hot Water Direct Load Control pathway › Are the data in the tracking sheet compl...

AI summary Table 5 outlines the 2023 Residential Demand Response (DR) Evaluation Approach, focusing on assessing the Domestic Hot Water Direct Load Control pathway. It includes evaluation objectives, research questions, and methodologies such as tracking sheet audits and data analysis.

3.2.1 In-service Rates For the DHW Direct Load Control pathway, the ISR corresponds to the average percentage of systems 7 that responded to DR events; it is obtained by dividing the number of online and active controllers by the total num...

AI summary The in-service rate (ISR) for the DHW Direct Load Control pathway measures the average percentage of systems responding to demand response (DR) events. The Shifted ISR was updated using 2023 data, and the overall ISR for Shifted was 81%, while Aquanta's ISR was 82%. Connectivity issues impacted the number of systems providing load reductions.

Baseline Definition Selection Baselines for DR events are often established based on an average of similar days prior to the actual event. This is the approach adopted by EOne, and the Evaluator aimed to refine this approach by considering...

AI summary The document discusses the selection of a baseline definition for Demand Response (DR) events, comparing different scenarios to determine the most accurate method. The Evaluator found that using the average load of 10 non-event days prior to the event, without adjusting for pre-event load, provided a more precise estimate with a mean percent error (MPE) of 6.1% for mornings and 2.3% for evenings.

3.2.5 Evaluated New and Total Available DR Capacity Available DR capacity is obtained by multiplying the number of installed units by the ISR and the unitary available DR capacity value as presented in the equations below. In addition, som...

AI summary The document explains how available DR capacity is calculated using installed units, ISR, and unitary values. It notes that some participants had controllers installed during the evaluation period, leading to prorated capacity. New and total available DR capacities for residential DR in 2023 were 0.023 MW and 0.058 MW respectively, estimated using the residential line loss factor submitted to the NSUARB in 2014.

Baseline Methodology Review For the Aggregator pathway, available DR capacity is established by comparing the predicted loads (baseline) to the actual loads during DR events using meter data. Baselines for DR events are often established b...

AI summary The document reviews the baseline methodology for the Aggregator pathway in Demand Response (DR), which uses a top six-of-ten baseline with a same-day adjustment factor. The Evaluator found that this method is acceptable, though adjustments were made, such as using an additive same-day adjustment instead of a scalar one. The methodology was validated through participant interviews and literature review.

7.2.3 Effective Useful Life Although no energy savings were expected under the Aggregator pathway, the Evaluator established an effective useful life (EUL) value to express for how many years available DR capacity might persist, i.e. as lo...

AI summary The document discusses the Effective Useful Life (EUL) of Demand Response (DR) capacity under the Aggregator pathway, stating that an EUL of one year should be used for both total and new DR capacity due to the lack of data on participant retention and the nature of program participation.

Table 1: 2023 Residential DR Corrected Tracked Available New and Total DR Capacity Program Component Result Value Tracked by EOne Corrected Tracked Value Relative Difference Value Unit Value Unit Value Residential DR Available New DR Capac...

AI summary The table shows discrepancies in tracked and corrected values for residential demand response (DR) capacity in 2023. EOne tracked lower new DR capacity but higher total DR capacity compared to corrected values, attributed to differences in controller types included in the calculations.

APPENDIX II Residential DR: Baseline Definition Selection Details Baselines for demand response (DR) events are often established based on an average of similar days prior to the actual event. This was the approach adopted by EOne, and the...

AI summary The document discusses the methodology for establishing baselines for residential demand response (DR) events, focusing on variations in baseline day selection, number of days considered, and adjustment factors. The Evaluator tested multiple scenarios using 15-minute interval water heater data and compared predicted and actual load during non-event days.

Unitary Peak Demand Savings For electric thermal storage, an eight-hour charging period is assumed based on the residential off-peak period in Nova Scotia Power's time of day rate. It is also assumed that the stored heat is provided equall...

AI summary The calculation for unitary peak demand savings for electric thermal storage assumes an eight-hour charging period based on Nova Scotia Power's off-peak rate. The stored heat is distributed evenly over 16 hours, and the savings are calculated using the maximum storage capacity from manufacturer specifications.

In-service Rates While all controllers remained installed, connectivity issues resulted in not all controllers generating savings when events were called, the impact of which was included through the in-service rates as listed in [Table](#...

AI summary Connectivity issues with installed controllers affected their ability to generate savings during events, with the impact accounted for through in-service rates as detailed in Table 122.