The US Federal Energy Regulatory Commission (FERC) has granted authorization to the Alaska Gasline Development Corp. (AGDC) for its Alaska LNG Project, with conditions.
In March, AGDC had received its final environmental impact statement (EIS) from FERC, where it was concluded that the project would result in “temporary and permanent impacts on the environment, and while most impacts would not be significant or could be reduced to less than significant levels with the implementation of proposed or recommended avoidance, minimization, and mitigation measures, some impacts would be adverse and significant.” AGDC worked with local and federal agencies to address the issue brought forth in the EIS to receive the necessary authorization to move forward.
The purpose of the project is to commercialize the natural gas resources of Alaska’s North Slope by converting the existing natural gas supply to liquefied natural gas (LNG) for export and providing gas for users in Alaska, USA.
The Alaska LNG Project includes a gas treatment plant (GTP); a 1.0-mile (1.6-km)-long, 60-in. (1.5-m)-diameter Prudhoe Bay Unit Gas Transmission Line; a 62.5-mile (100.5-km)-long, 32-in. (0.8-m)-diameter Point Thomson Unit Gas Transmission Line; an 806.9-mile (1298.6-km)-long, 42-in. (1.1-m)-diameter natural gas pipeline and associated above ground facilities, including eight compressor stations and a heater station; and a 20 million metric-ton per annum liquefaction facility, including an LNG plant and marine terminal. The project would have an annual average inlet design capacity of up to 3.7 billion standard cubic feet per day and a peak capacity of 3.9 billion standard cubic feet per day.
The new liquefaction facility would be constructed on the eastern shore of Cook Inlet, in the Kenai Peninsula Borough, Alaska. The facility would include the structures, equipment, underlying access rights, and all other associated systems for final processing and liquefaction of natural gas, as well as storage and loading of LNG, including terminal facilities and auxiliary marine vessels used to support marine terminal operations. The liquefaction facility would include three liquefaction trains combining to process up to approximately 20 million metric tons per annum (MMTPA) of LNG; and two 240,000‐cubic‐meter tanks to store the LNG. Each of the three liquefaction trains would include two 50,000 hp (37,300 kW) treated gas compressors, and two CO2 compressors, totaling six of each in the facility.
The proposed design includes eight compressor stations (CS).
- Sagwon CS – Three 20,500 hp (15,293 kW) Solar Titan 130 Compressor Units
- Galbraith Lake CS – Two 30,000 hp (22,380 kW) Solar Titan 250 Compressor Units
- Coldfoot CS – Two 30,000 hp Solar Titan 250 Compressor Units
- Ray River CS – Two 30,000 hp Solar Titan 250 Compressor Units
- Minto CS – Two 30,000 hp Solar Titan 250 Compressor Units
- Healy CS – Two 30,000 hp Solar Titan 250 Compressor Units
- Honolulu Creek CS – One 30,000 hp Solar Titan 250 Compressor Unit
- Rabideux Creek CS – One 30,000 hp Solar Titan 250 Compressor Unit
Mainline facilities also include one standalone heater station, one heater station collocated with a compressor station, and six cooling stations associated with six of the compressor stations; four meter stations; 30 mainline block valves; one pig launcher facility at the GTP meter station, one pig receiver facility at the Nikiski meter station, and combined pig launcher and receiver facilities at each compressor station; and associated infrastructure facilities. Along the mainline route, there would be at least five gas interconnection points to allow for future in‐state deliveries of natural gas.