Golden Pass LNG project to include about 300 MW of power generation

The backers of a new liquefied natural gas (LNG) export project, which would have a major power generating component, on Feb. 19 filed with the Federal Energy Regulatory Commission a copy of an October 2014 greenhouse gas air permit application for the project that had been submitted to the Texas Commission on Environmental Quality.

In July 2014, Golden Pass Products LLC (GPP) and Golden Pass Pipeline LLC (GPPL) (collectively called “Golden Pass”) filed their respective with FERC seeking necessary authorization for the proposed Golden Pass LNG Export Project. At that time, it was indicated that a needed resource report this included the greenhouse gas permit application to the TCEQ would be available at a later date. Golden Pass on Feb. 19 submitted the GHG permit application, which has been deemed administratively complete by the Texas Commission on Environmental Quality.

Golden Pass Products and Golden Pass Pipeline are proposing to site, construct, and operate LNG export facilities along with associated new compression and pipeline facilities. The facilities include:

  • Liquefaction facilities (called the “GPX Terminal”) to be constructed adjacent to Golden Pass LNG Terminal LLC’s (GPLNG) existing import terminal (“GPLNG Terminal”) located onshore along the Sabine‐Neches Waterway (SNWW) in Jefferson County, Texas; and
  • a new compressor station (MP 1 Compressor Station) to be located near the interconnection with Natural Gas Pipeline Co. of America’s (NGPL) pipeline. The compressor station will be adjacent to the existing GP Pipeline in the southwest corner of the GPLNG Terminal site in Jefferson County.

The GPX Terminal will convert natural gas to LNG, which will be stored and exported using GPLNG Terminal facilities. GPP and GPLNG will offer both LNG import and export services (not simultaneously). The proposed GPX Terminal will have an export capacity of 15.6 million tonnes per annum (MTA) of LNG. This terminal will consist of a natural gas pre‐treatment system, a liquefaction unit, and utilities and other supporting facilities.

Power will be generated utilizing high pressure (HP) steam to drive steam turbine generators (STGs). Three STGs will be located, one in each train, and use HP steam by expanding it to very low pressure steam to generate electric power. The exhaust from the STG will be condensed via a surface condenser and the condensate pumped to the recovered condensate tank. The power generation capacity of each STG is expected to be about 100 MW. The liquefaction facility internal power grid will be connected to the utility power grid (Entergy) for back‐up power demand in case of a trip of an individual STG as well as for startup power demand.

High pressure and low pressure (LP) steam are to be generated in Heat Recovery Steam Generation (HRSG) units by recovering heat from the exhaust flue gas from the gas turbines used to drive the refrigeration compressors. The HRSGs are located in the individual liquefaction trains, with two HRSGs per train, with a total of six HRSGs for the entire liquefaction plant. 

For each of the three trains, the refrigeration power for the propane and mixed refrigerant compressors are to be provided by two mechanical drive General Electric Frame 7 gas turbines, each of which is assisted by electric helper motors.

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.