South Field Energy applies in Ohio on 1,105-MW gas plant

South Field Energy LLC (SFE) applied Dec. 7 at the Ohio Power Siting Board for a Certificate of Environmental Compatibility and Public Need to develop, build, and operate South Field Energy, a new dual-fuel combined cycle generating facility located in Columbiana County, Ohio.

SFE is within the corporate organizational structure of Advanced Power AG (Advanced Power), an international developer of independent power generation projects. Advanced Power develops and invests in power generation and related infrastructure projects in North America and Europe.

Advanced Power is currently developing three projects, totaling 2,500 MW, in the eastern United States. In addition, since 2006, Advanced Power has developed more than 1,500 MW of generation in the United States and Europe, including Carroll County Energy, a 750-MW facility in Carroll County, Ohio.

The South Field facility will help meet energy demand in the region, particularly in light of the recent and planned retirement of existing coal-fueled generating assets located in the PJM Interconnection region (12.8 GW have retired since 2014 and 2.6 GW are pending retirement by the end of 2019), including several plants in Ohio (i.e., Burger and BL England Diesel), said the application. The facility will help meet this need by providing additional baseload and peaking capacity via its dual-fuel combined cycle technology.

The facility is designed in a 2×2 configuration. The facility will primarily fire natural gas, with the capability to fire ultra-low sulfur distillate (ULSD) as back-up. It will utilize two integrated General Electric (GE) 7HA.02 combustion turbine generators (CTGs), each with a dedicated supplementary-fired heat recovery steam generator (HRSG); two steam turbine generators (STGs); and two mechanical draft wet cooling towers. The facility will have a nominal net output of 1,105 MW (full duct burner operation with inlet air cooling at 59 degrees Fahrenheit ambient temperature).

SFE has determined that, due to the high demand for natural gas during periods of peak energy demand, a back-up fuel is required to establish a reliable supply of energy. Therefore, although natural gas will be the facility’s primary fuel, it may also utilize ULSD.

The proposed facility (which includes the power generating facility, on-site switchyard, and ancillary equipment) will be located within an approximately 150-acre property that is located entirely within Yellow Creek Township, Columbiana County, Ohio. Because the portion of the property that is south of Hibbetts Mill Road will not be utilized in any way, the 86.5-acre portion of the property that is north of Hibbetts Mill Road has been defined as the facility site and is the subject of this application. The facility site is approximately 3 miles northwest of the Village of Wellsville and approximately 0.7 mile west of State Route (SR) 45.

The existing Dominion Transmission Pipeline natural gas pipeline into which the facility will interconnect is located approximately 2 miles to the west of the facility site, while the existing FirstEnergy 345-kV electric transmission corridor to which the facility will deliver energy is approximately 3 miles to the west.

Commercial operation targeted for 2020

The facility schedule is based on commencement of commercial operation no later than 2020. In order to meet this schedule, the company is requesting issuance of the OPSB certificate by late spring 2016 to support commercial and financing activities in the third and fourth quarters of 2016 and active construction in the first quarter of 2017.

The higher heating value (HHV) facility heat rate is 6,340 British thermal units per kilowatt-hour (Btu/kWhr) (no duct burner operation, with inlet air evaporative cooling at 59°F). The facility will be permitted to operate up to 8,760 hours per year, with limited hours permitted on ULSD. Actual hours of operation will be dependent upon energy needs in the region. Availability will be on the order of 97%; however, the facility will be dispatched as needed by PJM.

Therefore, it is anticipated that the annual capacity factor will vary between 40% and 90% due to market conditions. Operations will also include downtime for planned and unplanned maintenance events.

The facility’s fuel will be natural gas supplied from the existing Dominion pipeline system at an approximate pressure of approximately 600 pounds per square inch gauge (psig). The anticipated fuel usage (HHV) per hour is 5,962 million British thermal units per hour (MMBtu/hr) at 59˚F ambient temperature without duct firing.

An approximately 16-inch diameter natural gas pipeline is proposed to connect the facility to the existing Dominion natural gas pipeline system; this pipeline will be the subject of a separate filing with the OPSB. It is anticipated that gas metering will be provided near the point of interconnection with the existing system, but if compression is required, it will be accommodated on the facility site and is included as an option in this application. ULSD will be delivered to the site via truck.

Details of the major equipment include:

  • Combustion Turbine Generators – The CTGs will be GE 7HA.02 dual fuel turbines rated to consume 3,131 MMBtu/hr, HHV, and produce approximately 320 MW at 59°F with pipeline natural gas as the primary fuel and integrated DLN burners. The CTGs will utilize inlet air evaporative coolers to maximize output and increase efficiency at ambient temperatures of 59°F or greater.
  • Heat Recovery Steam Generators – The facility will utilize two supplementary-fired HRSGs to capture the exhaust gas heat from the CTGs. Each HRSG will be equipped with duct burners to provide additional peaking generation capacity. The HRSGs will also incorporate SCR and oxidation catalysts as BACT/BAT emission control technologies.
  • Steam Turbine Generators – The facility will utilize two STGs, with reheat and the capability to generate 246 MW at 59°F with duct burners operating. The STGs will each be housed in a building.
  • Cooling Water System/Steam Condensing – The circulating water system will provide cooling for condensing the steam turbine exhaust and the facility closed-loop cooling system. The system will consist of two mechanical draft wet cooling towers constructed of fiberglass reinforced plastic or wood, and a steam surface condenser with an air ejector/vacuum system. The cooling towers will include high efficiency draft eliminators for PM reduction capable of achieving a 0.0005 percent cooling tower drift rate. Chemical treatment of the cooling tower water will be accomplished utilizing chemical feed equipment. Although the particular treatment program for this facility has not yet been determined, a typical program could include: pH control (acid or caustic); scale inhibitor; biocide; dispersant; and chlorine/hypochlorite.
  • Combustion Turbine Inlet Evaporative Coolers – The evaporative coolers provide auxiliary cooling at the combustion turbine inlets to improve unit efficiency during ambient temperatures at or above 59˚F. The evaporative coolers will utilize demineralized water sourced from the demineralized water storage tank.
  • Step up Transformers – The two CTGs and the two STGs will be connected to a transformer that will step up generator output from 18 kV to 345 kV for connection to the existing FirstEnergy transmission system (interconnecting facilities will be the subject of a separate OPSB filing).
  • Auxiliary Boiler – An auxiliary steam boiler, rated at 99 MMBtu/hr, will be used as needed to keep the HRSGs warm during periods of facility shutdown and provide steam to the STGs during start-ups.
  • Closed Cooling Water System – The closed loop auxiliary cooling water system provides cooling for auxiliary equipment. The system will utilize demineralized water with corrosion inhibitor and freeze protection or a glycol-based solution
  • Stand-by Emergency Diesel Generator – A 2,947 horsepower (hp) emergency diesel engine driven generator capable of producing 2,000 kW of electricity will be provided and designed to safely shut the facility down in the event of a forced outage. ULSD will be utilized, and stored in an approximately 500-gallon double containment tank integrated into the equipment skid.
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.