AEP now wants to protect coal units at six power plants under Ohio plan

The Ohio Power/AEP Ohio unit of American Electric Power (NYSE: AEP) has gone back to the Public Utilities Commission of Ohio with a revised plan to sell power to Ohio ratepayers out of the Clifty Creek and Kyger Creek power plants.

The commission on Feb. 25 rejected an Electric Security Plan for the company as it relates to the two power plants, but did approve other parts of the plan as it relates to Kyger Creek and Clifty Creek, which are owned by Ohio Valley Electric Corp., which is co-owned by AEP and several other power generators. On May 15, AEP Ohio filed a revised version of the Kyger Creek/Clifty Creek plan with the Ohio commission.

Pablo A. Vegas, the President and Chief Operating Officer of AEP Ohio, said in May 15 testimony: “I support AEP Ohio’s overall proposal to enter into a purchase power agreement (‘Affiliated PPA’) with AEP Generation Resources (‘AEPGR’) for the generation output of several of its generating units (‘PPA Units’) and to include the contracts in the PPA Rider that was approved by the Commission in the Company’s Electric Security Plan. I also support including in the PPA Rider the Company’s net impacts of its Ohio Valley Electric Corporation (‘OVEC’) entitlement as provided by the Inter-Company Power Agreement (‘OVEC Agreement’ or ‘OVEC PPA’) between OVEC and its Sponsoring Companies as described by Company witnesses Pearce and Allen. The generating units included within the Affiliated PPA and the OVEC PPA may also be referred to collectively as the ‘PPA Rider Units.’

“The proposed PPAs will benefit AEP Ohio’s customers, protect Ohio’s economy, and bolster the reliability of Ohio’s electric supply. It will provide a necessary hedge to AEP Ohio’s customers that will protect them from the impacts of market volatility, especially during periods of extreme weather, provide Ohio generators with a predictable source of revenue to maintain operations keeping jobs and taxes in the state, and promote economic development in Ohio by providing retail price certainty that Ohio businesses desire as demonstrated by the endorsement of the Company’s OVEC PPA proposal in the ESP III case by the Ohio Energy Group, which represents the interests of some of the largest industrial customers in AEP Ohio’s service territory.

“The proposed PPAs provide these many benefits to our customers and communities including the supply of stable and reasonably-priced power for years to come, which is a fundamental need for our communities to position themselves to prosper. It also has the potential to reliably address the uncertainties of capacity and energy supply in PJM by providing our customers with a financial hedge to the volatile market pricing currently experienced that could continue for the foreseeable future.

“During the Polar Vortex of 2014, real-time energy prices in PJM cleared in excess of $1,000/MWh over several hours and as high as $1,841/MWh for one hour. While the Polar Vortex was an extreme weather event, it is not uncommon for energy prices to fluctuate significantly hour-to-hour, month-to-month, and year-to-year. The January 2014 average real-time energy price for the PJM RTO was $113/MWH, compared to an average energy price for the entire year of 2013 of just under $37/MWH. This clearly shows that the energy market is volatile and will react to abnormal weather patterns and supply disruptions. This volatility will likely get worse in the future because retiring coal-fired units are either being replaced by gas-fired units or not being replaced at all, increasing the market’s overall reliance on gas and reducing the region’s reserve margin. Gas-fired generation does not have the same advantages as coal-fired generation with respect to on-the-ground fuel storage and coal’s less volatile pricing.

“It must also be recognized that inclusion of the PPAs for AEPGR and OVEC in the PPA Rider supports continued operation of nearly 6,800 MW of generation in Ohio when the full nameplate capacity of the shared ownership units (e.g. Conesville 4, Kyger 1-5) are considered. As one of the joint owners of these units of the Affiliated PPA, AEPGR would effectively have a veto over any proposed closure of the units; so, approval of the Affiliated PPA would leverage support for continued operation of the 6,800 MW in Ohio.”

Coal units targeted at six power plants

The PPA Rider Units, all fired by coal, are:

AEPGR Units

  • Cardinal Unit 1, Ohio, 592 MW of AEP entitlement, current projected retirement year of 2033;
  • Conesville Unit 4, Ohio, 339 MW, 2033;
  • Conesville Unit 5, Ohio, 405 MW, 2036;
  • Conesville Unit 6, Ohio, 405 MW, 2038;
  • Stuart Unit 1, Ohio, 150 MW, 2033;
  • Stuart Unit 2, Ohio, 150 MW, 2033;
  • Stuart Unit 3, Ohio, 150 MW, 2033;
  • Stuart Unit 4, Ohio, 150 MW, 2033; and
  • Zimmer Unit 1, Ohio, 330 MW, 2051.

OVEC Units

  • Kyger Creek Unit 1, Ohio, 40 MW, 2040;
  • Kyger Creek Unit 2, Ohio, 40 MW, 2040;
  • Kyger Creek Unit 3, Ohio, 40 MW, 2040;
  • Kyger Creek Unit 4, Ohio, 40 MW, 2040;
  • Kyger Creek Unit 5, Ohio, 40 MW, 2040;
  • Clifty Creek Unit 1, Indiana, 40 MW, 2040;
  • Clifty Creek Unit 2, Indiana, 40 MW, 2040;
  • Clifty Creek Unit 3, Indiana, 40 MW, 2040;
  • Clifty Creek Unit 4, Indiana, 40 MW, 2040;
  • Clifty Creek Unit 5, Indiana, 40 MW, 2040; and
  • Clifty Creek Unit 6, Indiana, 40 MW, 2040.

Total: 3,111 MW

All of the energy, capacity, and ancillary services associated with the PPA Rider Units will be bid into the PJM market. The net revenues and costs resulting from the PPA will be included in the PPA Rider approved in the ESP III proceeding, Vegas noted. The PPA Rider is designed to stabilize customer prices due to the relatively stable cost of owning and operating the PPA Rider Units compared to much more volatile market prices.

“The over 3,100 MW included in the Affiliated and OVEC PPAs provides the significant financial hedge that will stabilize rates as required by the Commission in the ESP III Order,” Vegas wrote. “This total represents over a third of AEP Ohio’s connected retail load and from a portfolio basis is both a significant and reasonable amount of generation to use for a hedge.”

These coal units are in good shape in terms of clean-air compliance

John M. McManus, employed by American Electric Power Service Corp. as Vice President–Environmental Services, said in May 15 testimony about the status of these coal units in terms of clean-air compliance: “All eleven of the OVEC units are equipped with over-fire air systems and, with the exception of Clifty Creek Unit 6, are also equipped with selective catalytic reduction (‘SCR’) for the reduction of nitrogen oxide (‘NOx’) emissions. For control of particulate matter, all units are equipped with electrostatic precipitators (‘ESPs’), which provide a reduction in particulate matter by more than 99%. All eleven of the units have been retrofitted with flue gas desulfurization (‘FGD’) systems for mitigation of sulfur dioxide (‘SO2’) emissions.

“For those units that are already equipped with SCR and FGD systems, compliance with the MATS Rule is anticipated as they are currently configured. This includes Clifty Creek Units 1-5, Kyger Creek Units 1-5, Cardinal Unit 1, Conesville Unit 4, Stuart Units 1-4, and Zimmer Unit 1. Through the co-benefit of the SCR and FGD systems, mercury will be converted to a soluble state as it passes through the SCR systems and then is removed via the FGD systems. Acid gases will also be removed through the FGD systems, while non-mercury trace metals will be removed through the existing ESP systems. Although SCR technology is not installed on Clifty Creek Unit 6 the facility utilizes a 90 day rolling site average and with the level of emission reductions gained through the controls on Units 1-5, no additional controls are anticipated to be necessary on Unit 6 as a result of the MATS Rule.

“[A]dditional environmental controls are necessary at Conesville Units 5 and 6 to ensure compliance with the stringent mercury limit established under the MATS Rule. Both Units 5 and 6 at the Conesville Plant have received administrative extensions under the MATS Rule from the Ohio Environmental Protection Agency, which extend the MATS compliance dates for those units by up to one year from the April 16, 2015 effective date for the rule.”

McManus noted that the U.S. Environmental Protection Agency’s CO2-reducing Clean Power Plan for existing power plants is the subject of protest by various parties, including Ohio regulators. There is also some indication that the Clean Power Plan mandates, which begin in 2020, may be delayed, he added. The EPA plan is supposed to be issued in final form this summer. AEP has added a $15/tonne CO2 emissions proxy penalty to its projections under this application, starting in 2022, to account for the Clean Power Plan and any new form it might take.

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.