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Highlights • Anticipated Reserve Margins for SERC Central are expected to be sufficient for the next ten-years; however, the Anticipated Reserve Margin starts approaching the reserve margin level in the later years. • Load growth is expected to be minimal across the subregion at approximately 0.38 percent. • Annual peak demand shifted slightly for the subregion from the summer season to the winter season. Projected Demands, Resources, and Reserve Margins (Summer) Demand (MW) 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 Total Internal 40,799 40,952 41,159 41,431 41,571 41,600 41,518 41,657 41,759 41,974 Demand Response 1,970 1,958 1,883 1,830 1,795 1,792 1,790 1,789 1,788 1,787 Net Internal 38,829 38,994 39,276 39,601 39,776 39,808 39,728 39,868 39,971 40,187 Resources (MW) Anticipated 47,306 47,633 48,237 48,658 47,474 46,704 46,704 46,704 46,529 46,529 Prospective 51,621 51,898 52,410 52,428 52,240 51,920 51,920 51,920 51,745 51,745 Reserve Margins (%) Anticipated 21.83% 22.15% 22.81% 22.87% 19.35% 17.32% 17.56% 17.15% 16.41% 15.78% Prospective 32.94% 33.09% 33.44% 32.39% 31.33% 30.42% 30.69% 30.23% 29.46% 28.76%
SERC Central The SERC Central subregion is a winter peaking system, which consists of the following Planning Coordinators: Associated Electric Cooperative Inc., Electric Energy Inc., Louisville Gas &
Existing On-Peak Generation (Summer) Generation Type Peak Capacity MW % Biomass 0 0.0% Coal 15,200 31.5% Natural Gas 18,857 39.1% Hydro 3,566 7.4% Nuclear 8,421 17.4% Other 0 0.0% Petroleum 0 0.0% Pumped 1,759 3.6% Solar 8 0.0% Wind 456 0.9%
Electric/Kentucky Utilities, and Tennessee Valley Authority.
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