Topic:"Capacity Costs" in M10473

Table 3 Year PRM Adjusted Fitted Series – AVC - Capacity ($/kW-yr.) 2023 $26 2024 $40 2025 $54 2026 $67 2027 $80 2028 $91 2029 $102 2030 $112 2031 $122 2032 $130 2033 $138 2034 $145 2035 $152 2036 $157 2037 $162 2038 $167 2039 $170 2040 $1...

AI summary Table 3 provides projected average variable costs (AVC) for capacity from 2023 to 2046, with values increasing annually and then stabilizing. The section B introduces the Demand Response DRSim Model, indicating a focus on demand-side management and capacity planning.

- the E1 RBIA. These values are provided in [Table 2,](#page-153-0) below. Table 2: PRM Adjusted Fitted Series Avoided Cost of Capacity Values Used for This Analysis Year PRM Adjusted Fitted Series – AVC – Capacity ($/kW-year) 2023 $26 202...

AI summary The document references the E1 RBIA and presents a table outlining PRM adjusted fitted series avoided cost of capacity values from 2023 to 2040. These values are used for analysis related to transmission and distribution system-wide avoided costs calculated by Nova Scotia.

4 Table 6: Full Range of Avoided Cost Values Used for This Analysis Category Years Details Capacity ($/kW-year) 2023-2040 • Fitted series PRM adjusted stream (AVC 2.0C NPV 2023) of avoided costs of capacity, as calculated by NS Power for t...

AI summary Table 6 presents avoided cost values for capacity, transmission, distribution, energy, and carbon from 2023 to 2040. These values are derived from NS Power's calculations for the IRP Reference Plan and include inflation adjustments and carbon pricing trajectories.

1 Table 1: Full Range of Avoided Cost Values Used for This Analysis Category Years Details Capacity ($/kW-year) 2023-2040 • Fitted series PRM adjusted stream (AVC 2.0C NPV 2023) of avoided costs of capacity, as calculated by NS Power for t...

AI summary Table 1 presents the full range of avoided cost values used in the analysis, including capacity, transmission, distribution, energy, and carbon costs from 2023 to 2040. These values are based on calculations by NS Power for the IRP Reference Plan and provided to the DSMAG.

9 Q: Have you conducted a similar comparison of the difference in avoided capacity costs 10 between Scenarios 2.0C and 2.1C? A: Yes, a relative comparison of the avoided capacity costs between Scenarios 2.0C and 2.1C is presented in Figure...

AI summary The testimony discusses a comparison of avoided capacity costs between Scenarios 2.0C and 2.1C, showing that the mid-electrification scenario (2.1C) has higher capacity costs through 2037 due to increased electrification needs. The average difference over 2023-2035 is 21.48% higher for 2.1C than 2.0C, suggesting that using 2.0C as a basis may undervalue savings.

• Load Growth-Related : • A methodology which examines growth-related capital investments in relation to incremental growth-related system capacity.

AI summary The text introduces a methodology to evaluate growth-related capital investments in relation to incremental system capacity, focusing on aligning infrastructure spending with projected load growth needs.

AVOIDED T&D COSTS: DEMAND DSM - Avoided Costs are based on peak demand of the T&D system and not with general energy sales reduction. - NS has a winter peaking system, with peak demand typically occurring in January/February. - Demand Redu...

AI summary Avoided T&D costs are calculated based on peak demand reduction, not overall energy sales. Nova Scotia's winter peaking system (peak demand in January/February) means demand-side management (DSM) can defer infrastructure projects like new transmission lines and substation upgrades by reducing peak load.

Expert Testimony FORUM ON BEHALF OF MATTER Arkansas Public Service Commission Arkansas Public Service Commission General Staff Application of Oklahoma Gas & Electric Company for an order approving a temporary surcharge to recover the costs...

AI summary The text lists various regulatory proceedings from different states, including applications for surcharges, capacity approvals, and nuclear plant management programs. These proceedings involve public service commissions and environmental councils reviewing utility company requests.

10 Table 54: Summary of Benefits – Demand Response Participant Industry Benefits Environmental Strategic DSM Benefits Benefits Portfolio Benefits • financial incentives for shifting or curtailing load • access to new controls and informati...

AI summary Table 54 outlines the benefits of demand response (DR) programs, highlighting financial, environmental, and strategic advantages. The primary use case for current DR pilots is load leveling, which helps reduce peak demand. However, the modeling results suggest that the costs of delivering these programs currently outweigh their benefits, as quantified by avoided cost calculations.

Table 1 Year Equivalent Escalating Series – AVC-Energy ($/MWh) 2023 $70 2024 $71 2025 $72 2026 $74 2027 $75 2028 $77 2029 $78 2030 $80 2031 $82 $83 2032 2033 $85 2034 $87 2035 $88 2036 $90 2037 $92 2038 $94 2039 $96 2040 $97 2041 $99 2042...

AI summary Table 1 outlines projected equivalent escalating series costs for AVC-Energy from 2023 to 2046, showing a steady increase in costs over time, with extrapolation based on 2% annual inflation for the years 2046-2063. Section B introduces the Demand Response DRSim Model, suggesting a focus on demand response strategies.