Topic:"Rate Rider" in M12780

4.5 RATE AND BILL CONSIDERATIONS & RATE AND BILL IMPACT ANALYSIS (RBIA) FOR 2027–2031 E1's RBIA for the Preferred Plan demonstrates that participants in DSM benefit from bill savings. The reductions in energy use and demand achieved by par...

AI summary E1's Rate and Bill Impact Analysis (RBIA) for the Preferred Plan shows that DSM participants benefit from bill savings, with energy efficiency and demand response having positive effects on rates, and solar-PV having minimal impact. These findings are consistent with historical data from 2011 to 2026.

GLOSSARY OF TERMS Term Definition Alternate Scenario E1 provides one or more alternate scenario(s) with the same portfolio-level metrics as E1's proposed DSM Resource Plan (i.e., the Preferred Plan). Available Demand Response Capacity The...

AI summary The glossary defines key terms related to demand-side management (DSM) and energy efficiency programs, including alternate scenarios, demand response capacity, balance adjustments, and baseline measurements. These definitions are relevant to the regulatory process and program implementation.

ayers (forward looking) are shown below in [Figure 1.](#page-234-0) DATE FILED: March 31, 2026 Page 3 of 23 9 2 PAC net lifetime benefits of the DSM Portfolio. Discounted using WACC. 1 Key highlights of the 2026 historical RBIA include: -...

AI summary The 2026 historical Rate and Bill Impact Analysis (RBIA) highlights the impact of Demand Side Management (DSM) programs on electricity bills in Nova Scotia. Participants in DSM programs experienced average annual bill reductions ranging from 2.8% to 12.7%, while non-participants saw bill increases of 0.5% to 2.9%. Overall, ratepayers will save over $3.2 billion between 2011 and 2041 due to energy and demand reductions from DSM programs.

4 [Table 1](#page-243-1) highlights results in more detail by individual rate class for the 2027–2031 forward looking RBIA. 6 Table 1: Rate and Bill Impacts by Rate Class as a Result of 2027-2031 DSM Preferred Plan Activities Preferred Pla...

AI summary Table 1 presents the rate and bill impacts by rate class resulting from the 2027–2031 DSM Preferred Plan activities. The data shows the average rate impact, average bill impact for participants and non-participants, and total class average bill impact across various rate classes.

5 8. CONCLUSION - 6 Highlights from the 2027–2031 DSM Preferred Plan RBIA analysis include: - Over the 20 years of the study period, participants in DSM programs see average annual bill 8 reductions ranging from a low of 0.04 percent (aver...

AI summary The RBIA analysis for the 2027–2031 DSM Preferred Plan highlights that Nova Scotian ratepayers will save $0.4 billion over 20 years due to energy and demand reductions. The analysis shows varying bill impacts for participants and non-participants, with maximizing customer participation helping to mitigate rate impacts. The RBIA excludes non-rate-related benefits such as reduced greenhouse gas emissions and local economic investment.

DATE FILED: March 31, 2026 Page 8 of 8 Attachment 4: Results by Rate Class 2026 Historical Line# Rate and Bill Impacts of DSM on the Residential Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2...

AI summary The document presents historical data on the rate and bill impacts of Demand Side Management (DSM) on the residential class from 2011 to 2055. It includes metrics such as net incremental energy savings, total annual energy savings, DSM expenditures, and participant activity over time.

DATE FILED: March 31, 2026 Page 1 of 8 Line# Rate and Bill Impacts of DSM on the Small General Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2...

AI summary The document presents a table analyzing the rate and bill impacts of Demand Side Management (DSM) on the Small General Class from 2011 to 2055. It details energy savings, expenditures, participant numbers, and energy savings per participant over time, highlighting trends and changes in DSM effectiveness and participation.

DATE FILED: March 31, 2026 Page 2 of 8 Line# Rate and Bill Impacts of DSM on the General Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 20...

AI summary The table presents the rate and bill impacts of Demand Side Management (DSM) on the General Class over time, including energy savings, expenditures, and participant numbers. It highlights trends in energy savings and participant engagement from 2011 to 2055.

DATE FILED: March 31, 2026 Page 4 of 8 Line# Rate and Bill Impacts of DSM on the Small Industrial Class 1 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 203...

AI summary The document presents a detailed table showing the rate and bill impacts of Demand Side Management (DSM) on the small industrial class over several years, including energy savings, expenditures, number of participants, and average energy savings per participant. The data spans from 2011 to 2055 and includes metrics such as net incremental and total annual energy savings in gigawatt-hours, DSM expenditures in millions of dollars, and participant numbers.

- 3 E1's RBIA model presents results by rate class for the following NS Power customer classes: - 4 Residential (rate codes 2, 3, 4, 5, 6, 9 and 16); - 5 Small General (rate code 10); - 6 General (rate code 11); - 7 Large General (rate cod...

AI summary The document outlines the customer rate classes analyzed in E1's RBIA model, including residential, small general, general, large general, small industrial, medium industrial, and large industrial classes. It also notes that certain rate classes are excluded from the analysis, and E1 does not offer programs for them. The RBIA model does not differentiate between current NS Power customers and future Renewable-to-Retail customers.

s of the measure from the customer's perspective absent program intervention. - (f) Not confirmed. Please refer to part (d) (i) of this IR response. DATE FILED: May 28, 2026 E1 (IG) IR-08 Page 4 of 4 Request IR-09: Reference: Exhibit E-1,...

AI summary The text outlines a request for clarification on the Demand Cost Recovery Rider (DCRR) and its impact on ratepayers, including how E1 accounted for overspends and underspends during the 2023-2026 Plan period, and how these will be adjusted over the 2027-2030 period. It also asks for a detailed breakdown of the DCRR by customer class and year.

(a) The eligible rate classes for Smart Synergy are business, non-profit, and institutional electricity customers served under the following NS Power rate codes: 10, 11, 12, 21, 22, or 23. Other program eligibility requirements also apply,...

AI summary Smart Synergy is available to business, non-profit, and institutional customers under specific NS Power rate codes, excluding those participating in existing demand response programs. Interruptible customers are ineligible due to the Large Industrial Interruptible Rider, and E1 has not determined eligibility for these customers during the 2027–2031 DSM Plan period, though further discussions are planned.

entives are limited to incremental voluntary curtailments that are separate from, and additional to, the customer's interruptible tariff obligation. DATE FILED: May 28, 2026 E1 (IG) IR-18 Page 3 of 6 - 1 (d) Please refer to part (c) of thi...

AI summary The text outlines a response to an inquiry regarding NS Power's Large Industrial Interruptible Rider (LIIR), noting that incentives are limited to incremental voluntary curtailments separate from the customer's interruptible tariff obligation. The response refers to other sections of the document for further details.

4 Item E1 Smart Synergy / BNI Participants NS Power Large Industrial Interruptible Rider (LIIR) i) Notice period for interruptions 16 hours No set timeframe for notifications. Advisories and Alerts are issued in advance of the interruption...

AI summary The document compares the E1 Smart Synergy / BNI program and the NS Power Large Industrial Interruptible Rider (LIIR) in terms of notice periods, interruption limits, credit values, exit requirements, and interruption flexibility. Key differences include notice periods, credit values, and the optionality of participation.

age - 2 incentives when excluding these lower cost projects (e.g., compressed air leak audits) and - 3 increased future incentives to those amounts. DATE FILED: May 28, 2026 E1 (IG) IR-19 Page 8 of 8 Request IR-20: Reference: Exhibit E-1,...

AI summary The request seeks analysis of rate and bill impacts for an alternate scenario, assumptions behind lower bill impacts for industrial customers, and whether a 4% average bill impact is considered sufficient for participation in energy efficiency programs.

17 Table 1: Rate and Bill Impacts by Rate Class as a Result of 2027 - 2031 DSM Alternate Scenario Activities. Rate Class Rate Codes Average Rate Impact (%) Average Rate Impact (cents/kWh) Participant Average Bill Impact Non Participant Ave...

AI summary The table shows rate and bill impacts by rate class due to DSM activities from 2027 to 2031. E1 corrected an error in the Municipal rate class and emphasized the significance of savings in industrial customers, attributing lower percentage bill reductions to the concentration of industrial electricity use in complex processes.

- (b) E1 has reported in its Audited Financial Statements the following DSM interest earned on restricted DSM cash balances (in thousands of Canadian dollars): 2023 - $768; 2024 - $885; 2025 - $243. These statements are filed annually with...

AI summary E1 has provided details on the interest earned on restricted DSM cash balances from 2023 to 2025, noting that the 2026 figure will be available after audit. It states that surpluses from DSM Plans are typically returned in the second year of the plan period and that the surplus from the 2023–2026 DSM Plan will be applied to the 2028 DCRR application.

- i) If not confirmed, please explain how to interpret this table. - (b) Please provide a table showing the annual impact of the Preferred Plan on the DSM rate rider for each year from 2026 through 2032, inclusive. State all assumptions. -...

AI summary The text requests detailed tables and explanations regarding the impact of the Preferred and Alternate Plans on the DSM rate rider, including assumptions, historical and forecasted data, and an explanation for differing rate impacts on Large Industrial customers compared to other classes.

DATE FILED: May 28, 2026 E1 (IG) IR-24 Page 2 of 4 1 Response IR-24: 2 3 (a) The Rate and Bill Impact Analysis (RBIA) estimates a Large Industrial rate impact of 6.26 4 percent in 2027 and 6.02 percent in 2028. 5 i) The following context h...

AI summary The Rate and Bill Impact Analysis (RBIA) estimates a Large Industrial rate impact of 6.26% in 2027 and 6.02% in 2028. These impacts are relative to a No DSM scenario and reflect combined effects of program cost recovery, lost revenue, and avoided costs. The RBIA assumes these effects are fully incorporated into rates each year, though this may not hold outside of a General Rate Application (GRA).

BIA) for the same 2 purpose, to convert impacts between at meter and at generator. 5 14 3 i) Line losses are a direct input to the modelling software and are applied within the 4 modelling process. (b) Table 1 of this IR response provides...

AI summary The document discusses the impact of line losses on the 2026 General Rate Application (GRA) and the 2027–2031 DSM Plan. It notes that the estimated impact was calculated manually by EfficiencyOne using line loss factors from the 2014 COSS and the 2026 GRA, rather than through the Guidehouse ProCESS or DRSim model. This method is described as an approximation.

Date Filed: May 28, 2026 NSEB-17, Attachment 1, Page 46 of 46 REDACTED 1 Request IR-18: 2 Program Cost Recovery (PCR) portion of NS Power's Demand Side 3 Management Cost Recovery Rider (DCRR) by rate class. Please refer to part 4 (c) of IG...

AI summary The text discusses the Program Cost Recovery (PCR) portion of NS Power's Demand Side Management Cost Recovery Rider (DCRR) by rate class, noting that while PCR may increase electricity costs, E1's programs will help customers reduce consumption and realize bill savings. It also mentions that lighting measures in commercial projects will no longer be supported after 2028 due to higher upfront costs and the need for more financial support from E1.

re po g a mo un an ( Ap lica tio n R eb s) ult ha mb ine d w ith in mb the ed in th ab le AR by in ad dit ion th bin ed ate s t t a nts e t to p res re co nu ers am ou us pr og ram e c om , , the Bo ard O ing R . O P M wi ll ed th e B rd b...

AI summary The text discusses the integration of application rebates within the table AR and the Board's role in reviewing and approving rebate programs. It highlights the importance of accurate reporting and the challenges in ensuring transparency and consistency in rebate calculations and program performance.

percent or more by individual rate classes and providing explanations is to ensure actual cumulative spending at the end of the DSM Plan period as compared to the approved DSM Plan does not result in a substantial balance adjustment for an...

AI summary E1 is adjusting the Mandatory Cost Allocation (MCA) thresholds for the DSM Plan, lowering the program spending threshold from 25% to 20% and setting a 15% threshold for rate class spending changes. These adjustments aim to ensure accurate budgeting and avoid future balance adjustments in the DCRR. E1 has not expanded the MCA to include sector changes and has incorporated these thresholds into its reporting processes.

- 12 This attachment provides a summary of the rate and bill impacts results as taken from the 13 E1 RBIA models filed as Appendix B, Attachments 9 and 10. It is meant to be assistive in 14 the access and review of the RBIA results. - 15 A...

AI summary This text discusses the submission of Rate Base Impact Assessment (RBIA) models by EfficiencyOne (E1) as part of a regulatory proceeding. It notes that Attachments 7 and 8 were re-filed with macros removed to improve accessibility for intervenors, while Attachments 9 and 10 remain unchanged.

1 Table 1: Rate and Bill Impacts by Rate Class as a Result of 2027-2031 DSM Preferred Plan Activities (100% 2 Rate Class Cost Allocation) Rate Class Rate Codes Average Rate Impact (%) Average Rate Impact (cents/kWh) Participant Average Bil...

AI summary The table presents the rate and bill impacts by rate class as a result of the 2027-2031 DSM Preferred Plan Activities. It shows the average rate impact percentage and cents per kWh, as well as the average bill impact for participants and non-participants across various rate classes.

8 Table 2: Correction of Appendix B Table 1 - Rate and Bill Impacts by Rate Class as a Result of 2027-2031 DSM 9 Preferred Plan Activities Rate Class Rate Codes Average Rate Impact (%) Average Rate Impact (cents/kWh) Participant Average Bi...

AI summary The document discusses the impact of the 2027-2031 DSM 9 Preferred Plan activities on customer bills, noting that Solar-PV participants experience bill reductions from 2028 to 2055, while non-participants see neutral to increased bill impacts. Overall, customer bills are expected to increase during 2028–2031 but decrease from 2032 onward, with the most significant effects observed in the Residential rate class.

Table 1: STANDARDIZED FILING FRAMEWORK ITEM DESCRIPTION 5.2 Program Alternatives A comparison of the program elements in the proposed DSM Resource plan to the alternate scenarios of DSM budgets. 6. ADDITIONAL ITEMS 6.1 Rate and Bill Impact...

AI summary The text outlines a standardized filing framework, including a comparison of program elements in the proposed DSM Resource plan to alternate scenarios and the inclusion of a Rate and Bill Impact Analysis (RBIA).

4.5.64.6.6 RATE AND BILL IMPACT ANALYSIS ENS E1 will file its historical Rate and Bill Impact Analysis (RBIA) by October 31st of each yearas part of each DSM Resource Plan. 33 The historical RBIA estimates the high-level, longterm impact t...

AI summary ENS E1 is required to file both historical and forward-looking Rate and Bill Impact Analysis (RBIA) as part of each DSM Resource Plan. The historical RBIA covers DSM activities up to the previous calendar year, while the forward-looking RBIA estimates the impact of proposed DSM activities.

Table 1: STANDARDIZED FILING FRAMEWORK ITEM DESCRIPTION 6.1 Rate and Bill Impact Analysis (RBIA) This includes the following: - Forward-Looking RBIA: This will consist of a detailed description of the forward-looking rate and bill impact a...

AI summary The document outlines the requirements for the Rate and Bill Impact Analysis (RBIA) as part of the DSM Resource Plan filing. It specifies the need for both forward-looking and historical RBIA, with a breakdown by rate classes and the exclusion of certain customer classes due to data limitations.

4.6.6 RATE AND BILL IMPACT ANALYSIS E1 will file its historical Rate and Bill Impact Analysis (RBIA) as part of each DSM Resource Plan. [31](#page-71-2)The historical RBIA estimates the high-level, long-term impact to rates and bills of al...

AI summary E1 will file both historical and forward-looking Rate and Bill Impact Analysis (RBIA) as part of each DSM Resource Plan. The historical RBIA estimates the impact of past DSM activities, while the forward-looking RBIA estimates the impact of proposed DSM activities on rates and bills.

4.6.5 Rate and Bill Impact Analysis Each DSM Resource Plan filing will include: - a historical RBIA summarizing the long-term impact to rates and bills of all DSM activities up to and including those of the previous calendar year; [11](#pa...

AI summary The document outlines the requirements for Rate and Bill Impact Analysis (RBIA) in each DSM Resource Plan filing, including both historical and forward-looking analyses to assess the long-term impact of DSM activities on rates and bills.

• Assumptions for Tables 1 and 2: Participation eligibility assumptions reflect those of EfficiencyOne's (E1) rate and bill impact analysis (RBIA), found in E1's 2027–2031 DSM Plan Application, Appendix B, Attachment 5. • Each participant...

AI summary The text outlines assumptions and definitions used in EfficiencyOne's (E1) rate and bill impact analysis (RBIA) for the 2027–2031 DSM Plan Application. It includes details on participant definitions, exclusions, and references to other sections of the application.

DATE FILED: May 28, 2026 E1 (Synapse) IR-76 Page 2 of 2 Request IR-77: - Please refer to Figure 3: Average Rate Impacts (2027-2046) as a Result of 2027-2031 DSM - Preferred Plan Activities on page 8 of Appendix B - Rate and Bill Impact Ana...

AI summary The response explains that the Medium Industrial rate class has negative rate impacts due to reduced peak loads from high participation in the Demand Response program, which lowers the class's share of system peak costs. However, the inclusion of Renewable to Retail loads increases overall energy consumption, spreading DSM rider costs over more kWh and leading to negative rate impacts.

17 Q. WHAT DID THE NSUARB DETERMINE REGARDING THE MCA PROCESS. - 18 A. In its decision on the 2026 DSM Extension (M12249), the Board found the existing MCA - 19 process "unbalanced" and directed E1 to revise it. The Board wrote that "the p...

AI summary The NSUARB found the existing MCA process 'unbalanced' and directed E1 to revise it, emphasizing the need for ratepayer protection and more opportunities for review and objection to changes in E1's DSM Plans, which are now reviewed every five years.

15 Q. WHY WOULD AN ANNUALLY APPLIED RATE-CLASS COLLAR BE 16 UNWORKABLE? 17 A. Rate-class spending can vary more than 15% from year to year. In the 2016–2024 data E1 18 filed as Attachment 1 to CA IR-15, single-year variances against plan i...

AI summary An annually applied rate-class collar would be unworkable due to significant year-to-year spending variations and the risk of creating a growing gap between savings and economically optimal levels. This could lead to frequent MCA filings and undermine the purpose of five-year planning cycles.

1 passed and yields around $200 million more in PAC net benefits compared to E1's 2 Preferred Scenario. The PAC already accounts for the cost of capital at NS Power's 3 WACC of 6.65%, meaning it already prices in the time value of money an...

AI summary The document discusses the financial benefits of a proposal, noting that it yields around $200 million more in PAC net benefits compared to E1's Preferred Scenario. It also mentions that the PAC already accounts for the cost of capital at NS Power's WACC of 6.65%, which includes the time value of money and cost recovery through the DCRR.

5 Q. DID E1 PERFORM ANY RATE AND BILL ANALYSIS OF THE IRP 6 SCENARIO? 7 A. Yes. E1 provided the IRP scenario RBIA as Attachment 2 – Appendix K, Scenario 3 in 8 its response to Synapse IR-02. Similar to the Preferred Scenario, both particip...

AI summary E1 conducted a rate and bill impact analysis (RBIA) for the Integrated Resource Plan (IRP) scenario, showing bill reductions for participants and minimal impacts on non-participants. The analysis assumes a counterfactual of no demand-side management (DSM) and compares the preferred scenario to a baseline with continued DSM.

CUSTOMERS FOR THE INTERRUPTIBLE PORTION OF THEIR LOAD.[92](#page-49-0) 1 DO 2 YOU SUPPORT THIS PROPOSAL? 3 A. No. While E1 has not committed to this, but instead states it "may be appropriate" and 4 that it is "committed to further discuss...

AI summary The respondent does not support making LII customers eligible for Smart Synergy on their interruptible load, arguing that it would result in paying twice for the same demand reduction. E1 has not committed to the proposal but is open to further discussions.

8 Q. PLEASE EXPLAIN WHY ALLOWING LII CUSTOMERS INTO SMART 9 SYNERGY WOULD CONSTITUTE DOUBLE COUNTING. 10 A. LII customers already provide dispatchable load reduction under NS Power's Large 11 Industrial Interruptible Rider ("LIIR"). Under...

AI summary The response explains that allowing LII customers to participate in Smart Synergy would result in double counting, as they already receive a demand charge reduction under the LIIR. Enrolling them in Smart Synergy would provide an additional incentive for the same demand reduction, resulting in paying twice for the same benefit.

PAC benefit-cost ratios and avoided costs - Q. Please explain your concerns about the cost-effectiveness of the residential demand response programs based on the PAC test. - A. In the 2026 Extension of E1's DSM program, my colleague Jennif...

AI summary The respondent is concerned about the cost-effectiveness of E1's residential demand response program based on the Program Administrator Cost (PAC) test. E1's projections are inconsistent, with conflicting claims about when the program will achieve cost-effectiveness. The projected PAC benefit-cost ratio (BCR) for the 2027 program is expected to improve slightly compared to the 2026 extension.

Q. How do E1's Residential program delivery costs compare to other jurisdictions? - A. E1's proposed residential demand response delivery costs as a share of total - budgets appear substantially higher than similar programs in other jurisd...

AI summary E1's residential demand response delivery costs are significantly higher compared to similar programs in Rhode Island Energy and National Grid (Massachusetts), where non-incentive spending accounted for 27-29% of budgets, versus 77% and 63% for E1. This raises concerns about cost-effectiveness and reasonableness of the proposed budget.

lice Napoleon and Courtney Lane regarding PECO Energy Company's proposed Act 129 Phase IV Energy Efficiency and Conservation Plan. On behalf of the natural Resources Defense Council. January 14, 2021. Nova Scotia Utility and Review Board (...

AI summary The document outlines various testimonies and evidence provided by Alice Napoleon on behalf of several organizations, including the Natural Resources Defense Council and The Utility Reform Network, related to energy efficiency programs, regulatory proceedings, and utility proposals across multiple jurisdictions.

3.4 Recommended Direction for SBES Solar Nova Scotia recommends that the Board require EfficiencyOne to revise the proposed SBES design to reduce unit costs and move away from a default no-cost direct-install model. The Board should direct...

AI summary Solar Nova Scotia recommends that the Board require EfficiencyOne to revise the SBES design by reducing unit costs, moving away from a default no-cost direct-install model, and incorporating more diverse DSM resources to improve program effectiveness and leverage federal funding.

- For an energy equipment manufacturer, prepared materials to educate the leadership on large load pricing principles and implementations across the USA. The Brattle team also analyzed the large load tariffs and implications for the develo...

AI summary The text outlines various rate design and impact evaluation studies conducted by Brattle for energy equipment manufacturers, utilities, and other stakeholders. These studies include large load pricing principles, clean transition tariffs, tariff reviews, and analyses of rate designs for residential and non-residential customers. A specific study focuses on the operating cost of electric heat pumps and natural gas-fueled heating equipment under alternative rate designs.

SENIOR ENERGY ASSOCIATE Chicago +1.872.302.6115 [email protected] Mr. Shetty has worked with electric utilities on issues related to regulatory retail ratemaking, rate design, load forecasting, utility program screening and transmissi...

AI summary Sai Shetty is a Senior Energy Associate with experience in regulatory retail ratemaking, rate design, load forecasting, and utility program screening. He has worked on embedded and marginal cost of service studies, performance-based regulation, and analysis of DERs, DSM, and the Value of Lost Load.

- such as target pilot customer, target recruitment samples, and pilot evaluation plans. Brattle also assisted EPE with recruitment strategies for customer enrollment in the pilots. - Rate Impact Analysis for Nevada Energy. As part of Neva...

AI summary The text outlines consulting experience related to energy regulation, including rate impact analysis, cost allocation reviews, and load impact evaluations. These projects involved analyzing demand-side management plans, transmission facilities, and time-of-use rates for various utilities and regulatory bodies.

5 Request IR-02: 6 7 Reference: E-21, Page 7, lines 2–6. 8 "I recommend that E1 should file an MCA to address any material change to optimal DSM resource acquisition levels identified in the Evergreen IRP process. A material change would b...

AI summary The text outlines a request (IR-02) for clarification on the meaning and application of 'optimal DSM resource acquisition levels,' the 20% threshold for triggering an MCA, and the evidentiary requirements for Board approval of an MCA, particularly in cases involving budget increases.

41 Response IR-12: 43 By way of introduction, it is noted that IR-12 does not refer to the Evidence filed by Mr. Love. 44 Nonetheless, the following response is provided. Date Filed: July 17, 2026 CA (IG) Page 20 of 22 1 (a) GEEG has not c...

AI summary The response to IR-12 discusses issues with overlapping demand response programs, specifically Smart Synergy and the LII interruptible tariff. It highlights the risk of double compensation for the same load reduction and notes that no methodology exists to isolate incremental voluntary curtailment. California's approach is referenced as a possible model.

1 Response IR-13: 2 3 By way of introduction, it is noted that IR-13 does not refer to the Evidence filed by Mr. Love. 4 Nonetheless, the following response is provided. 5 6 (a) Confirmed. However, the premise of the question overlooks tha...

AI summary The response to IR-13 clarifies that Large Industrial Interruptible (LII) customers are not automatically excluded from Smart Synergy benefits, as they can choose non-interruptible service. The beneficiary-pays principle does not exempt LII customers from cost responsibility, as their ineligibility is to avoid double payment, not a denial of benefits. GEEG opposes carving LII customers out of cost responsibility.

Response to Request IR-4: Refer to M12780, Exhibit E-24, SNS Evidence, Section 4.1, New Controllable Load is a Demand Response Resource, page 10 of 16, 2nd paragraph of this section. (a) Please provide the support for the statement "…at th...

AI summary The response to Request IR-4 discusses the growth of controllable residential load and the capacity value of devices like heat pumps and water heaters. It highlights that while these devices are being deployed through efficiency programs, their capacity value is not secured due to limited demand response enrollment, potentially leading to higher costs for ratepayers.

Request IR-2: 2 Reference: E-23, Pages 11-13. 3 Preamble: Synapse concludes E1's Preferred Plan will deliver approximately 215 GWh 4 less in annual energy efficiency savings than the IRP assumes by 2031, and approximately 5 9 MW less in pe...

AI summary The document requests clarification from Synapse regarding the assumptions in the IRP's DSM savings, whether a RBIA was conducted to close the energy efficiency savings gap, and the methodology for allocating incremental investment. It also asks why NSPI's EE contributions were excluded from the comparison in Table 1.

Response IR-5: (a) Synapse did not conduct a RBIA for the Round 2 SE results. However, E1 conducted a RBIA for the Round 2 SE results and provided this RBIA in response to Synapse IR-02 as Attachment 2, Appendix K: RBIA Round 2 – Scenario...

AI summary Synapse did not conduct a Rate and Bill Impact Analysis (RBIA) for the Round 2 SE results, but E1 did and provided it as Attachment 2, Appendix K. A snapshot of the disaggregated average rate impacts by rate class is presented in the table and figure.

Michael Goldman Published Articles, Conference Proceedings, and Interviews Just, Reasonable, and a Little Bit Ridiculous: An Introduction to Modern Utility Policy and Regulation DISTRIBUTECH · Feb 2, 2026 Navigating modern utility policy a...

AI summary The document is a list of publications, conference proceedings, and interviews by Michael Goldman, focusing on modern utility policy, regulation, and distributed energy resources. Topics include EV programs, DERMS, energy storage, and geothermal projects.

EfficiencyOne (E1) holds the demand side management (DSM) franchise in Nova Scotia and has the exclusive right to supply Nova Scotia Power (NS Power) with reasonably available, cost-effective demand side management[.](#page-0-0) 1 NS Power...

AI summary EfficiencyOne (E1) holds the DSM franchise in Nova Scotia and has filed a five-year DSM Resource Plan for 2027–2031, proposing a total investment of $318 million. NS Power must ensure the plan is affordable and cost-effective. This proceeding establishes a five-year planning horizon, aligning with Nova Scotia's energy transformation goals.

23 Green Energy Economics Response: 24 25 Confirmed that none of the utilities listed in exhibit E-21(iv) serve the seven jurisdictions listed in 26 the "Review of EfficiencyOne First-Year Costs and Unit Cost Reasonableness" provided by AP...

AI summary The response confirms that none of the utilities listed in exhibit E-21(iv) serve the seven jurisdictions mentioned in a review of EfficiencyOne's first-year costs and unit cost reasonableness, which was provided by APEX Analytics and included in M12789 as Attachment 2 to E1 response to IG IR-10.

1 2 (a) Does this reflect current approved rates in the 2027-2028 GRA? If not, please explain. (b) Please provide a version of Exhibit E-1(ii) for the Alternate Scenario (in excel format). (c) Please provide the measure level payback analy...

AI summary The text includes a series of questions and requests related to the 2027-2028 GRA, specifically regarding approved rates, Exhibit E-1, payback analysis, and the Demand Cost Recovery Rider (DCRR). It also asks for clarification on a percentage variance in Table 2 for the Large Industrial class.

- 29 (a) Please provide: 1 (i) The complete rate-class allocation methodology, step by 18 Industrial achieved 0.0 MW of available DR capacity with participation from one customer 19 and $0.0M recorded in expenditures. 20 (a) Please confirm...

AI summary The text requests information on rate-class allocation methodology, eligibility for Smart Synergy (BNI Demand Response) in the 2027–2031 plan, and reasons for past ineligibility of interruptible customers. It also asks about potential eligibility for Large Industrial Interruptible customers and written eligibility criteria.

5 1 2 (b) Please provide a table showing the annual impact of the Preferred Plan on the DSM rate rider for each year from 2026 through 2032, inclusive. State 3 all assumptions. 4 (i) Please provide the same table for the Alternate Scenario...

AI summary The request asks for tables showing the annual impact of the Preferred Plan and Alternate Scenario on the DSM rate rider from 2026 to 2032, as well as combined historical and forecast rate impacts from 2011 to 2046. It also asks for an explanation of why Large Industrial customers will see rate increases for Demand Response despite rate decreases for other classes. The reference points to a study conducted by BBA as part of NSPI's 2014 Cost of Service Study.

Background This decision letter contains the Board's findings about a motion by various Intervenors challenging the confidentiality claimed by Nova Scotia Power Inc. (NS Power, Company, Utility) over certain portions of its general rate ap...

AI summary This decision letter addresses a motion by intervenors challenging NS Power's confidentiality claims over parts of its GRA. The Board panel reviewed objections to the redacted information, with NS Power justifying some claims based on privacy laws and the Public Utilities Act. Some claims were abandoned, while others were upheld, particularly those related to cyber security measures.

Recovery of executive remuneration - 64B (1) In this Section, "report" means the report required by subsection (2). - (2) Nova Scotia Power Incorporated shall submit to the Board - (a) on or before January 1, 2013; and - (b) with each appl...

AI summary This section outlines the process for submitting and reviewing reports on executive remuneration by Nova Scotia Power Incorporated to the Energy and Regulatory Boards. The Board has the authority to approve, reject, or require amendments to the report, and may determine executive employees if the report is not amended within 30 days. The regulation also restricts the recovery of certain executive remuneration from approved rates, charges, or fees.

Salary and compensation recoverable from rates, charges or fees - 3 For the purpose of subsection 64B(8) of the Act, Nova Scotia Power Incorporated may recover the following remuneration from its rates, charges or fees approved by the Boar...

AI summary The document outlines the maximum salary and compensation that Nova Scotia Power Incorporated may recover from its rates, charges, or fees, as approved by the Board, under subsection 64B(8) of the Act. This includes specific percentages for the Chief Executive Officer and other executives.

period. This is the extent to which NS Power wants to disclose details of its executive compensation. However, in its submissions, NS Power did offer a compromise providing the following disclosure: NS Power acknowledges these compensation...

AI summary NS Power proposed a compromise to disclose non-confidential aggregate compensation data from Mercer Reports to address concerns about executive compensation in the GRA. However, the Intervenors did not accept this offer, and the Board noted that NS Power claimed 'Board Confidential' treatment for the reports, which would restrict access to the Intervenors.

on by NS Power. Having reviewed all the submissions, the Board concludes that the Mercer Reports are relevant and should be available to the Intervenors who have signed a confidentiality undertaking. At the very least, as noted by Ms. Rubi...

AI summary The Board has concluded that the Mercer Reports, which detail executive compensation at NS Power, are relevant and should be made available to intervenors who have signed a confidentiality agreement. The Board supports the public interest in transparency regarding executive pay, emphasizing that ratepayers have a right to know whether compensation is justified. NS Power agrees in principle but argues that disclosure should only occur if the compensation is being recovered in rates.

c) Stantec decommissioning study – Pricing Information In Grant Thornton IR-50, the Board Counsel consultant requested copies of the latest decommissioning studies. The Stantec Report in Attachment 1 to the IR response was filed as fully c...

AI summary The Board requested decommissioning studies from NS Power. The Stantec Report was filed as fully confidential, while the Hydro Asset Study was partially confidential. NS Power agreed to re-file the Stantec Report by June 24, 2022, with only pricing information kept confidential.

rrier by marketing a beneficial rate structure to customers. - Assisted with rate design proposal. Brattle has been retained by Nova Scotia power to assist with a comprehensive evaluation of innovative rate designs and development of Compa...

AI summary Brattle has assisted Nova Scotia Power in evaluating innovative rate designs and developing a rate proposal, including load and bill impact analyses. They also reviewed rate design studies for the New Hampshire Public Utilities Commission and prepared educational materials for Rate Advisory Committee meetings.

SENIOR ENERGY ASSOCIATE Chicago +1.872.302.6115 [email protected] Mr. Shetty has worked with electric utilities on issues related to regulatory retail ratemaking, rate design, load forecasting, utility program screening and transmissi...

AI summary Sai Shetty is a Senior Energy Associate with experience in regulatory retail ratemaking, rate design, load forecasting, and utility program screening. He has worked on modernizing electric rate design and conducting embedded and marginal cost of service studies. His work also includes performance-based regulation, benefit-cost analysis for DERs and DSM, and analysis of the Value of Lost Load and Net Energy Metering.

er's self-generation profiles against utility-owned generation and understanding marginal costs incurred by the utility to serve an additional customer. - Rate Modernization for Interstate Power and Light (IPL). For IPL in Iowa, Mr. Shetty...

AI summary The text outlines Sai P. Shetty's consulting experience with various utilities, including work on rate modernization for IPL and innovative rate pilots for EPE. It highlights activities such as embedded cost of service studies, marginal cost of service studies, and the design of new rate structures.

1 (f) Given that Mr. Love considers E1's existing unit acquisition costs as 2 materially above comparable jurisdictions, please explain how directing E1 3 to acquire substantially more savings — using the same program designs 4 and deliver...

AI summary The text questions how increasing E1's savings targets using existing program designs would lower average unit costs for ratepayers, given that E1's current unit acquisition costs are higher than comparable jurisdictions. It also asks whether the marginal cost per kWh for additional IRP-scenario savings would be higher or lower than the Preferred Plan average of $0.66/kWh.