Topic:"Capacity Market Participation" in M12780

NSPI's fuel costs are affected by commodity prices and generation mix, which is largely dependent on economic dispatch of the generating fleet. NSPI brings the lowest cost options on stream first after renewable energy from IPPs including...

AI summary NSPI's fuel costs are influenced by commodity prices and the generation mix, which depends on economic dispatch and includes renewable energy from IPPs and COMFIT participants. Thermal plant availability has slightly decreased but remains consistent with industry averages, supporting reliable energy supply during the transition to renewable generation.

of the engagement with DSMAG members on this topic? Would E1 need to modify the plan to take these actions? Response IR-56: (a) Part (a) of the following IR response has been provided by NS Power. NS Power manages the interruption of inter...

AI summary The response outlines how NS Power manages capacity shortfalls by interrupting interruptible customers, ensuring system reliability. It also addresses concerns about potential double counting of capacity value if BNI DR is applied to customers already providing system value. E1 plans to continue discussions with the DSMAG during the 2027–2031 Plan period.

1 developed a DR program that spends materially on DR with no new residential customers, allows existing residential participation to decline, and relies entirely on BNI customers for capacity growth. Forecasted peak load growth reinforces...

AI summary The text discusses the limited scope of E1's Preferred Plan in terms of demand response (DR) participation, highlighting concerns over declining residential DR participation and overreliance on BNI customers for capacity growth. It emphasizes the need for a stronger commitment to DR as a near-term capacity resource, given forecasted peak load growth and declining reserve margins.

urred on January 25, 2026.[57](#page-33-2) The same report states that Nova Scotia's total system peak occurs in the December through February period because of weather-sensitive load.[58](#page-33-3) The capacity context is also reflected...

AI summary The document discusses Nova Scotia Power's 2025 10-Year System Outlook, highlighting the role of variable renewable resources like wind and solar in meeting energy needs but noting their limited contribution to firm capacity compared to conventional generation. The peak system demand occurs during the winter months due to weather-sensitive load patterns.

Response IR-03: As a general comment, the Evidence was filed on June 23, 2026, three days before the IESO-NS 2026 10-Year System Outlook was released on June 26, 2026 in M12916. GEEG reviewed the 2026 Outlook, and the 2026 ELCC Study, in p...

AI summary The response discusses the filing of evidence on June 23, 2026, and references the IESO-NS 2026 10-Year System Outlook. It notes that the 2026 Outlook shows increased required capacity and load growth compared to the 2025 Outlook, with demand-side management (DSM) resources contributing significantly to the capacity jump.

39 Response IR-04: 40 41 (a) The conclusion does not depend on the precise timing of any specific generation asset 42 retirement. It rests on the more general and, in the 2026 Outlook, confirmed proposition that the 43 system faces a growi...

AI summary The response emphasizes the importance of Demand Side Management (DSM) in meeting growing firm-capacity requirements due to load growth, coal phase-out obligations, and the transition to energy-limited resources. It argues that relying on supply-side resources increases risk and cost, while DSM provides more reliable and cost-effective solutions.

Request IR-4: - On page 12 of 39, the Brattle Group states that the lack of commitment by E1 to Demand - Response programs threatens the planned load reserve margin of Nova Scotia as system - capacity for Nova Scotia gets tighter. (a) What...

AI summary The Brattle Group responds to a request regarding demand response (DR) investment levels needed to offset reserve margin pressures in Nova Scotia. They note that a specific level of investment cannot be determined without updated studies and planning inputs. They recommend treating DR as a dispatchable capacity resource and not just a customer program.

1 2 12 The IESO-NS 2026 10YSO improves the reserve margin, closer aligned with the 2025 reserve margin. The updated 2026 reserve margin is on average five percentage points higher than the initial 2026 reserve margin based on NS Power's 20...

AI summary The IESO-NS 2026 10YSO report improves the reserve margin compared to the 2025 version, with capacity levels increasing due to changes in accreditation and additions/retirements schedules. Demand response (DR) remains a key tool for managing load growth, and the maximum potential DR penetration value of 1.3% is for 2036, not 2031.

29 (a) Please confirm: 1 (i) what "optimal DSM resource acquisition levels" means 16 17 18 19 20 21 As described previously in my testimony, peak capacity needs are projected to grow, and current forecasts require more investment in DSM th...

AI summary The text discusses concerns about the need for additional capacity investment beyond the E1 Preferred Plan, potentially leading to higher costs for customers. It references the retirement timeline of Trenton 5 and Lingan 2 and the need for 450 MW of fast-acting generation by 2029/2030 to meet reserve margin targets.