Report outlines planned power unit deactivations in PJM

In the PJM Interconnection region, 26,787.8 MW of capacity has been, or is planned to be retired between 2011 and 2019, with all but 2,924.8 MW planned to be retired by the end of 2015, said a market analysis report for PJM released May 18 by market monitor Monitoring Analytics.

The report covers the first quarter of 2015.

The AEP Zone, dominated by power plants of American Electric Power (NYSE: AEP), accounts for 6,024.0 MW, or 22.5%, of all MW planned for retirement from 2015 through 2019.

A significant change in the distribution of unit types within the PJM footprint is likely as natural gas-fired units continue to be developed and steam units continue to be retired. While only 1,992.5 MW of coal-fired steam capacity are currently in the queue, 9,343.8 MW of coal-fired steam capacity are slated for deactivation. Most of these retirements, 7,692.8 MW, are scheduled to take place by June 1, 2015, in large part due to the EPA’s Mercury and Air Toxics Standards (MATS).

In contrast, 43,479.3 MW of gas-fired capacity are in the queue, while only 1,572.0 MW of natural gas units are planned to retire. The replacement of coal steam units by units burning natural gas could significantly affect future congestion, the role of firm and interruptible gas supply, and natural gas supply infrastructure, the report said.

The planned deactivations in PJM for the last nine months of this year, as listed in the report, are:

  • Eastlake Units 1-3, ATSI Zone, 327 MW, Coal, Steam, deactivate April 15;
  • Lake Shore Unit 18, ATSI, 190 MW, Coal, Steam, April 15;
  • Lake Shore EMD, ATSI, 4 MW, Diesel, April 15;
  • Will County, ComEd, 251 MW, Coal, Steam, April 15;
  • Dale 1-4, EKPC, 195 MW, Coal, Steam, April 16;
  • Shawville 1-4, PENELEC, 597 MW, Coal, Steam, April 16;
  • Gilbert 1-4, JCPL, 98 MW, Natural gas, Combustion Turbine, May 1;
  • Glen Gardner 1-8, JCPL, 160 MW, Natural gas, Combustion Turbine, May 1;
  • Kearny 9, PSEG, 21 MW, Natural gas, Combustion Turbine, May 1;
  • Werner 1-4, JCPL, 212 MW, Light oil, Combustion Turbine, May 1;
  • Cedar 2, AECO, 21.6 MW, Kerosene, Combustion Turbine, May 1;
  • Middle Energy Center 1-3, AECO, 74.7 MW, Kerosene, Combustion Turbine, May 1;
  • Missouri Ave B, C, D, AECO, 57.9 MW, Kerosene, Combustion Turbine, May 1;
  • Essex 12, PSEG, 184 MW, Natural gas, Combustion Turbine, May 31;
  • Lake Kingman, Dominion, 115 MW, Coal, Steam, May 31;
  • Ashtabula, ATSI, 210 MW, Coal, Steam, June 1;
  • Bergen 3, PSEG, 21 MW, Natural gas, Combustion Turbine, June 1;
  • Big Sandy 2, AEP, 800 MW, Coal, Steam, June 1;
  • Burlington 8 and 11, PSEG, 205 MW, Kerosene, Combustion Turbine, June 1;
  • Clinch River 3, AEP, 230 MW, Coal, Steam, June 1;
  • Edison 1-3, PSEG, 504 MW, Natural gas, Combustion Turbine, June 1;
  • Essex 10-11, PSEG, 352 MW, Natural gas, Combustion Turbine, June 1;
  • Glen Lyn 5-6, AEP, 325 MW, Coal, Steam, June 1;
  • Hutchings 1-3 and 5-6, DAY, 271.8 MW, Coal, Steam, June 1;
  • Kammer 1-3, AEP, 600 MW, Coal, Steam, June 1;
  • Kanawha River 1-2, AEP, 400 MW, Coal, Steam, June 1;
  • Mercer 3, PSEG, 115 MW, Kerosene, Combustion Turbine, June 1;
  • Miami Fort 6, DEOK, 163 MW, Coal, Steam, June 1;
  • Muskingum River 1-5, AEP, 1,355 MW, Coal, Steam, June 1;
  • National Park 1, PSEG, 21 MW, Kerosene, Combustion Turbine, June 1;
  • Picway 5, AEP, 95 MW, Coal, Steam, June 1;
  • Riverside 4, BGE, 74 MW, Natural gas, Steam, June 1;
  • Sewaren 6, PSEG, 105 MW, Kerosene, Combustion Turbine, June 1;
  • Sporn 1-4, AEP, 580 MW, Coal, Steam, June 1; and
  • Tanners Creek 1-4, AEP, 982 MW, Coal, Steam, June 1.

The majority, 77.5% of all MW retiring during the 2011-2019 period are coal steam units. These units have an average age of 56.2 years and an average size of 166.2 MW. This indicates that on average, retirements have consisted of smaller sub-critical coal steam units and those without adequate environmental controls to remain viable beyond 2015.

Notable is that East Kentucky Power Cooperative has delayed the retirement of the Dale Units 3 and 4 for a year, until April 2016, due to grid-support needs established by PJM.

AEP plants on the list include: Big Sandy Unit 2 (Unit 1 is to be converted to natural gas); Clinch River, Glen Lyn, Kammer, Kanawha River, Muskingum River, Picway Unit 5, Sporn and Tanners Creek.

About Barry Cassell 20414 Articles
Barry Cassell is Chief Analyst for GenerationHub covering coal and emission controls issues, projects and policy. He has covered the coal and power generation industry for more than 24 years, beginning in November 2011 at GenerationHub and prior to that as editor of SNL Energy’s Coal Report. He was formerly with Coal Outlook for 15 years as the publication’s editor and contributing writer, and prior to that he was editor of Coal & Synfuels Technology and associate editor of The Energy Report. He has a bachelor’s degree from Central Michigan University.