American Electric Power (NYSE:AEP) Senior Vice President Timothy Light captured the current situation for many generators on Aug. 18 when he said “we are burning more gas and less coal.”
AEP is one of the nation’s largest electric generators with more than 38,000 MW of capacity. It is in the process of retiring more than 5,000 MW of coal-fired power. Light described the situation during the PennWell GenForum in Columbus, Ohio.
Contributing factors to coal’s demise include weak power demand, cheap natural gas from shale, the Environmental Protection Agency (EPA) mercury and air toxics (MATS) regulation as well as the recently-announced Clean Power Plan.
If natural gas has a fatal flaw it is the fact you can’t store it on site, Light said. Providing a dual-fuel backup, like oil, will raise costs, he said.
Back in the early-2000s AEP had virtually no natural gas in its Eastern footprint. Of course back in the 1970s AEP had lots of natural gas in its fleet “and the government told us we had to get off gas and on coal,” Light said.
Now it seems the opposite is happening in the form of the EPA Clean Power Plan.
AEP has a small army of people reviewing the 1,560-page rule that requires states to cut power sector carbon dioxide emissions 32% by 2030. The initial version released by EPA in June of 2014 “was simply not workable,” Light said.
Organizations big and small reflected on the EPA CO2 plan during both GenForum and the POWER-GEN/Natural Gas conference that occurred in Columbus.
Sunflower Electric Power‘s Senior Vice President and COO Kyle Nelson fears that the EPA plan could endanger the Kansas cooperative’s ability to use the coal-fired Holcomb power plant.
“We are migrating back to almost complete dependence on natural gas,” Nelson said. Nelson noted that Sunflower did recently develop a new gas plant that uses a number of 9-MW engines.
Both Light and Nelson said that the Clean Power Plan will likely increase cost for customers.
Exelon (NYSE:EXC) subsidiary Exelon Power has essentially gotten out of coal-fired generation over the years largely because of market power rules associated with independent power producers, said Exelon Power Vice President Vicky Will.
Exelon Power does hold an ownership stake in a waste coal facility, Will said. Exelon Power is responsible for Exelon Generation‘s non-nuclear fleet of hydro, renewable and natural gas assets. Exelon Power is developing new gas plants in places like Texas and Maryland.
In organized markets, Exelon is installing backup fuel ability at new gas plants, Will said.
States like Illinois could face much trouble complying with the CO2 rule should some of the nuclear plants run by corporate parent Exelon be retired, Will said.
Greater gas penetration being felt at ISO, state level
Midcontinent ISO (MISO) Executive Director External Affairs Michelle Bloodworth said that increased coal retirements are causing infrastructure ripple effects across the transmission region.
MISO manages more than 65,000 miles of electric transmission lines and 177,000 MW of installed power generation. MISO is diverse by sub-region, with natural gas comprising 28% of installed capacity in MISO North/Central and 67% in MISO South, Bloodworth said.
MISO expects to see significant additional coal retirements in 2016 when states start filing their CO2 implementation plans with EPA. This greater dependence on gas and carbon-neutral resources is expected to have an impact on economic dispatch, Bloodworth said.
Increased gas supply from both the Marcellus and Utica Shale regions are altering the MISO landscape, Bloodworth noted.
Both Bloodworth and Will noted that more coordination is needed between gas pipelines and the operators of combined-cycle gas power plants.
Public Utilities Commission of Ohio (PUCO) Asim Haque said that Ohio is looking at the EPA CO2 plan on two fronts. Ohio has signed on to a court challenge. At the same time, Ohio is trying to determine “what compliance looks like,” Haque said.
Price shocks associated with the “Polar Vortex” winter of 2014 show that over-reliance on gas can have its drawbacks, Haque said.
Despite explosive growth in employment and revenue from shale gas, Ohio was still 67% coal-fired in 2014, the PUCO vice chair said. Ohio is poised, however, to make timely decisions on new plant applications, Haque said, because PUCO offers one-stop licensing decisions.
Some companies are retrofitting coal plants to enable them to burn natural gas, with AEP doing this type of project in Kentucky and Virginia.
Speakers said during one session in Power-GEN on Aug. 19 that access to natural gas pipeline capacity is the first and most obvious issue for such conversions.
“Do you have gas available at the site,” said Zac Loehr of Burns & McDonnell.Such conversions can usually be done in six-to-24 months. While emissions will decrease with natural gas, fuel costs will increase, Loehr said.