Table 8.8.B. Summer Net Internal Demand, Capacity Resources, and Capacity Margins
by North American Electric Reliability Corporation Assessment Area, 2012 Actual, 2013-2017 Projected
 

Net Internal Demand (Megawatts) -- Summer
  Eastern Interconnection ERCOT Western Interconnection All Interconnections
Period FRCC NPCC Balance of Eastern Region MAPP MISO PJM SERC SPP TRE WECC Contiguous U.S.
Actual 2012 44,338 58,319 469,273 4,967 96,769 156,319 158,041 53,177 66,548 130,465 768,943
Projected 2013 42,532 59,969 447,171 5,022 91,644 144,378 152,949 53,177 65,901 129,278 744,851
Projected 2014 43,142 60,654 448,912 5,161 92,331 144,497 152,843 54,080 67,592 128,200 748,499
Projected 2015 43,812 61,428 457,865 5,270 93,017 147,568 157,287 54,722 69,679 129,553 762,336
Projected 2016 44,355 62,386 464,840 5,540 93,703 150,480 159,684 55,433 71,613 133,150 776,343
Projected 2017 44,907 62,871 470,476 5,601 94,390 152,563 161,702 56,220 72,637 135,740 786,631

 

Capacity Resources (Megawatts) -- Summer
  Eastern Interconnection ERCOT Western Interconnection All Interconnections
Period FRCC NPCC Balance of Eastern Region MAPP MISO PJM SERC SPP TRE WECC Contiguous U.S.
Actual 2012 53,475 76,525 576,314 5,981 112,085 187,305 198,140 72,802 73,219 147,527 927,060
Projected 2013 51,613 72,050 556,959 6,412 104,194 176,356 196,660 73,337 72,681 155,044 908,348
Projected 2014 51,923 76,127 558,157 6,570 104,663 177,039 197,116 72,768 75,182 172,443 933,830
Projected 2015 52,825 75,413 545,640 6,717 99,750 171,655 194,447 73,071 76,010 174,960 924,848
Projected 2016 53,613 75,443 543,786 6,797 95,712 173,523 194,830 72,924 77,220 175,673 925,736
Projected 2017 53,413 73,956 546,471 6,750 95,781 174,971 195,820 73,150 78,383 177,344 929,567

 

Capacity Margin (Percent) -- Summer
  Eastern Interconnection ERCOT Western Interconnection All Interconnections
Period FRCC NPCC Balance of Eastern Region MAPP MISO PJM SERC SPP TRE WECC Contiguous U.S.
Actual 2012 17.1% 23.8% 18.6% 17.0% 13.7% 16.5% 20.2% 27.0% 9.1% 11.6% 17.1%
Projected 2013 17.6% 16.8% 19.7% 21.7% 12.0% 18.1% 22.2% 27.5% 9.3% 16.6% 18.0%
Projected 2014 16.9% 20.3% 19.6% 21.4% 11.8% 18.4% 22.5% 25.7% 10.1% 25.7% 19.8%
Projected 2015 17.1% 18.5% 16.1% 21.5% 6.8% 14.0% 19.1% 25.1% 8.3% 26.0% 17.6%
Projected 2016 17.3% 17.3% 14.5% 18.5% 2.1% 13.3% 18.0% 24.0% 7.3% 24.2% 16.1%
Projected 2017 15.9% 15.0% 13.9% 17.0% 1.5% 12.8% 17.4% 23.1% 7.3% 23.5% 15.4%

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 Summer peak period begins on June 1 and extends through September 30.
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."