Table 8.8.B. Summer Net Internal Demand, Capacity Resources, and Capacity Margins
by North American Electric Reliability Corporation Assessment Area, 2011 Actual, 2012-2016 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 2011 44,798 62,313 466,360 4,641 98,290 146,443 161,995 54,991 68,416 117,755 759,642
Projected 2012 42,430 59,757 447,282 4,693 89,673 142,782 156,671 53,462 64,605 125,050 739,123
Projected 2013 43,041 60,325 452,250 4,904 89,318 145,254 158,528 54,247 65,649 125,220 746,485
Projected 2014 43,618 60,791 457,961 5,024 90,707 146,642 160,794 54,794 68,403 126,030 756,802
Projected 2015 44,459 61,344 463,539 5,135 91,096 149,968 162,551 54,788 71,692 127,731 768,766
Projected 2016 45,242 61,865 469,353 5,406 91,556 152,491 164,532 55,368 73,957 132,695 783,111

 

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 2011 54,340 72,277 549,067 5,244 110,611 170,066 201,103 62,044 69,595 147,147 892,426
Projected 2012 51,050 74,783 534,295 5,603 103,376 174,641 187,506 63,170 71,748 142,655 874,531
Projected 2013 51,594 76,256 543,204 6,253 103,045 173,882 195,621 64,402 73,169 148,255 892,477
Projected 2014 52,104 75,839 544,820 6,277 102,717 172,679 197,999 65,148 73,180 151,500 897,443
Projected 2015 53,882 75,427 539,078 6,335 102,610 167,273 197,599 65,260 74,644 152,314 895,345
Projected 2016 53,239 73,546 542,507 6,415 102,309 167,621 201,074 65,088 76,757 153,720 899,768

 

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 2011 17.6% 13.8% 15.1% 11.5% 11.1% 13.9% 19.4% 11.4% 1.7% 20.0% 14.9%
Projected 2012 16.9% 20.1% 16.3% 16.2% 13.3% 18.2% 16.4% 15.4% 10.0% 12.3% 15.5%
Projected 2013 16.6% 20.9% 16.7% 21.6% 13.3% 16.5% 19.0% 15.8% 10.3% 15.5% 16.4%
Projected 2014 16.3% 19.8% 15.9% 20.0% 11.7% 15.1% 18.8% 15.9% 6.5% 16.8% 15.7%
Projected 2015 17.5% 18.7% 14.0% 18.9% 11.2% 10.3% 17.7% 16.0% 4.0% 16.1% 14.1%
Projected 2016 15.0% 15.9% 13.5% 15.7% 10.5% 9.0% 18.2% 14.9% 3.6% 13.7% 13.0%

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."