1,105-MW South Field Energy project wins backing from Ohio board staff

The Ohio Power Siting Board staff filed on May 20 a report that generally recommended approval, with certain routine conditions attached, of an application by South Field Energy LLC for a certificate on an 1,105-MW, gas-fired power project.

South Field Energy falls within the corporate structure of Advanced Power AG, an international developer of independent power generation projects. The company proposes to develop, build, and operate a $925 million natural gas-fired combined-cycle facility with a capacity of 1,105 MW in Yellow Creek Township, Columbiana County, Ohio.

The proposed location for the facility consists of 150-acre parcel located in Yellow Creek Township, Columbiana County, at the northwest corner of the intersection between Forbes Road and Hibbetts-Mill Road. 

The facility would utilize two 320-MW combustion turbine generators. The applicant is considering the General Electric 7HA.02 model, the report noted. The combustion turbines would include evaporative coolers as an inlet air cooling system, which utilizes water to increase the density of the turbine inlet air and increases performance on hot summer days. The facility would be capable of year-round operation but actual hours of operation would depend upon energy needs in the region and would incorporate downtime for planned and unplanned maintenance events.

The facility would also include two three-pressure-level heat recovery steam generators (HRSG) with auxiliary duct burners. The facility would also include two reheat condensing steam turbine generators—each with an output of 246 MW. Each steam turbine generator would be connected to a HRSG. For faster facility startup, an auxiliary steam boiler would be used to generate steam.

The heat rate for the combined cycle power plant would be approximately 6,340 British thermal units per kilowatt-hour. The sum of the two combustion turbines (320 MW) and two steam turbine generators (246 MW) yields a gross power output of 1,132 MW. Some of this power would be used to operate equipment on-site. The nominal net output of the facility is 1,105 MW.

A standby/backup diesel generator would be used to safely shut the facility down in the event of a power delivery disruption and then power essential services.

The primary fuel for the facility would be natural gas, with the capability to use ultra-low sulfur distillate (ULSD) as a back-up fuel.

In order to minimize emissions of nitrogen oxides (NOx), the combustion turbines would include dry low NOx (DLN) burners. Selective catalytic reduction (SCR) systems installed in the HRSG exhausts would further reduce NOx concentrations during operation of the facility. The applicant would use good combustion practices and an oxidation catalyst to control emissions to best available control technology levels for control of carbon monoxide (CO). This would also minimize volatile organic compounds pollution. Particulate matter and sulfur dioxide (SO2) emissions would be controlled through the use of low-sulfur, pipeline quality natural gas fuel. When running on back-up fuel, the use of ULSD will minimize SO2 emissions.

The facility would use two 440-foot long mechanical draft wet cooling towers for steam condensing and other plant cooling needs. The majority of water consumption would be for makeup water to the cooling towers. The cooling towers provide heat rejection through airflow and evaporation of the circulating cooling water.

The power generated by the combustion and steam turbine generators would be stepped up from the turbines’ native voltage of 18 kV to 345 kV with generator step-up transformers. The step-up transformers would connect to a 345-kV transmission line approximately 3.9 miles in length. Two auxiliary transformers would also provide power for the facility back fed from the electric grid as needed.

South Field Energy would construct a new 345-kV transmission line to deliver electricity generated by the facility to a new point of interconnect 345 kV switchyard, which would be constructed adjacent to FirstEnergy’s Highland-Sammis 345 kV electric transmission line.

The facility would be fueled with natural gas supplies from a nearby Dominion Transmission Inc. pipeline. A preheating system, knockout drum, and filters/separator would be installed in order to assure the natural gas meets necessary quality requirements prior to combustion. The facility may require gas compression and, if necessary, a gas compressor would be located on the facility site.

The applicant would also be able to use ULSD as a secondary/backup fuel source. It would have a 3,000,000-gallon ULSD tank on-site that would be able to provide a significant number of hours of operation of the facility. ULSD fuel would be delivered to the facility by truck. The applicant will submit to the board separately, at a later date, a proposal for a natural gas transmission pipeline that would connect the existing Dominion pipeline to the facility.

The applicant proposes to commence construction in January 2017 and begin commercial operation by January 2020, the report said.

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.