Riverside works to expand Kentucky plant from 900 MW up to 1,700 MW

The Kentucky Department for Environmental Protection on June 13 posted to its website a June 4 Statement of Basis document on permitting that Riverside Generating Co. LLC is doing to convert its simple-cycle plant into a a combined-cycle facility.

Riverside currently operates a simple-cycle power plant on a 42.88-acre property south of Catlettsburg, Kentucky, along State Highway 23 and the Big Sandy River in Lawrence County. The plant consists of five Siemens 501 FD2 turbines which began commercial operations in 2001 (Units 1-3) and 2002 (Units 4-5). The five existing turbines have the capacity to generate 180 MW each.

Said the basis document: “On July 24, 2012, Riverside Generating Company, L.L.C. (Riverside) applied to the Division for the conversion of the simple cycle gas turbine electric generation units to combined-cycle gas turbine (CCGT) units for a new total generating capacity of approximately 1,700 MW. Riverside submitted an application for a Prevention of Significant Deterioration of Air Quality (PSD) permit. A PSD permit is required due to the potential emissions of the conversion project exceeding PSD significant emissions levels as described in section 6.0 of this document. The Best Available Control Technology (BACT) analysis, required for a PSD permit, is detailed in section 7.0 of this document.

“The Division issued a Notice of Deficiency (NOD) on September 6, 2012. Riverside submitted a response to the NOD on March 15, 2013. On November 5, 2012, a separate NOD was issued regarding the Class II Air Quality Modeling Report. Trinity Consultants submitted a response, on behalf of Riverside, March 4, 2013. On March 24, 2013, the Division issued a second NOD and a response was received June 13, 2013. Upon receipt of the requested information form the second NOD, the application was deemed complete August 2, 2013.

“Riverside is proposing to convert the existing five simple cycle units to two (2) combined cycle systems. The proposed conversion project will include the addition of five (5) heat recovery steam generators (HRSGs) and two (2) steam turbine generators (STGs) to the existing five (5) combustion turbine generators (CTGs).

“Combustion air will be drawn through inlet air filters prior to being compressed and fed to the CTG combustion sections. Natural gas fuel will be injected into the compressed air in a lean pre-mix type combustor and ignited in the can-annular combustion section. The hot combustion gases will expand through the turbine sections of the CTGs, causing them to rotate and drive the electric generators and CTG compressors. The hot combustion gases will exit the turbine sections and enter the HRSGs, where they will transfer heat into various steam superheater, evaporator and feedwater heating elements prior to exiting the stack. Steam produced in the HRSGs will be delivered to the steam turbine generator for the production of additional electricity. Steam exiting the steam turbine generator will be condensed and heat rejection accomplished via an evaporative (wet) cooling tower system.

“Natural gas-fired duct burners will be installed in the HRSGs, providing increased steam generation capability, greater operating flexibility and improved steam temperature control. The combined cycle units may be operated continuously while the duct burners will be operated intermittently.

“The combined cycle units will operate in two separate system power blocks. System (1) will have three CTGs, three duct burners, and three HSRGs to one 400 MW STG. System (2) will have two CTGs, two duct burners, and two HSRGs to one 400 MW STG. The CTGs and duct burners will operate only on natural gas. The duct burners will burn natural gas and will be designed to provide up to 660 MMBtu per hour per HRSG.

“The combined cycle unit will utilize selective catalytic reduction (SCR) to minimize emissions of NOX. The Project is defined as a CCGT electric generation facility with maximum nominal electrical generating capacity of 1,700 MW.

“The Project will require additional ancillary equipment including two (2) 40 MMBtu/hr natural gas-fired auxiliary boilers, two (2) 750 kW emergency generators, and one (1) multi-cell cooling tower. The existing ancillary equipment including the two (2) emergency generators, two (2) fuel heaters, and one (1) firewater pump engine will remain and will not be modified.”

LS Power lists the Riverside plant on its website.

An Interconnection Service Agreement dated April 4 of this year and posted to the PJM Interconnection website shows Riverside Generating pursuing this expansion project through the PJM queue system, with the new Maximum Facility Output to be 1,584 MW.

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.