Table 8.9.B. Winter Net Internal Demand, Capacity Resources, and Capacity Margins
by North American Electric Reliability Corporation Assessment Area, 2013 Actual, 2014-2018 Projected
 

Net Internal Demand (Megawatts) -- Winter
  Eastern Interconnection ERCOT Western Interconnection All Interconnections
Period FRCC NPCC Balance of Eastern Region MAPP MISO PJM SERC SPP TRE WECC Contiguous U.S.
Projected 2014 / 2015 42,668 45,578 400,305 5,071 99,671 135,526 124,395 35,642 52,057 110,172 650,781
Projected 2015 / 2016 43,370 44,357 407,766 5,433 102,597 137,308 125,361 37,067 52,057 110,977 658,528
Projected 2016 / 2017 44,089 44,323 411,844 5,559 103,648 138,314 126,826 37,498 52,917 111,896 665,069
Projected 2017 / 2018 44,547 44,298 415,770 5,781 104,727 139,213 127,920 38,129 53,779 112,765 671,158
Projected 2018 / 2019 45,051 44,345 419,510 5,911 105,667 139,975 129,464 38,493 54,619 113,860 677,384

 

Capacity Resources (Megawatts) -- Winter
  Eastern Interconnection ERCOT Western Interconnection All Interconnections
Period FRCC NPCC Balance of Eastern Region MAPP MISO PJM SERC SPP TRE WECC Contiguous U.S.
Projected 2014 / 2015 55,546 72,236 558,497 6,777 136,278 183,163 168,116 64,164 76,615 154,203 917,097
Projected 2015 / 2016 57,291 73,376 562,037 6,727 134,124 192,850 165,419 62,917 77,492 158,375 928,571
Projected 2016 / 2017 56,916 71,463 564,990 6,687 136,690 190,497 167,577 63,539 78,475 156,580 928,425
Projected 2017 / 2018 57,376 71,474 561,663 6,671 136,233 185,904 169,163 63,691 78,475 157,302 926,289
Projected 2018 / 2019 58,327 71,474 562,016 6,679 135,849 185,928 170,129 63,431 77,865 155,603 925,284

 

Capacity Margin (Percent) -- Winter
  Eastern Interconnection ERCOT Western Interconnection All Interconnections
Period FRCC NPCC Balance of Eastern Region MAPP MISO PJM SERC SPP TRE WECC Contiguous U.S.
Projected 2014 / 2015 23.2% 36.9% 28.3% 25.2% 26.9% 26.0% 26.0% 44.5% 32.1% 28.6% 29.0%
Projected 2015 / 2016 24.3% 39.5% 27.4% 19.2% 23.5% 28.8% 24.2% 41.1% 32.8% 29.9% 29.1%
Projected 2016 / 2017 22.5% 38.0% 27.1% 16.9% 24.2% 27.4% 24.3% 41.0% 32.6% 28.5% 28.4%
Projected 2017 / 2018 22.4% 38.0% 26.0% 13.3% 23.1% 25.1% 24.4% 40.1% 31.5% 28.3% 27.5%
Projected 2018 / 2019 22.8% 38.0% 25.4% 11.5% 22.2% 24.7% 23.9% 39.3% 29.9% 26.8% 26.8%

Notes:
NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html
Net Internal Demand represent the system demand that is planned for by the electric power industry`s reliability authority and is equal to Internal Demand less Direct Control Load Management and Interruptible Demand.
Capacity Resources: Utility and nonutility-owned generating capacity that is existing or in various stages of planning or construction, less inoperable capacity, plus planned capacity purchases from other resources, less planned capacity sales.
Capacity Margin is the amount of unused available capability of an electric power system at peak load as a percentage of capacity resources.
The Winter peak period begins October 1 and extends through May 31.
Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection.
ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN.
Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report."