Appendix 2. Key LNG Projects Datasheets

LNG Project: Ichthys

Partners: INPEX (Operator), TOTAL, Tokyo Gas, Osaka Gas, Chubu Electric Power and Toho Gas

Resource: Ichthys gas field, Browse Basin, North West Australia

Project Budget: $33 billion (press article)

Development Concept: Gas in the Ichthys field will ultimately be developed by approximately 50 subsea wells drilled from more than 10 drill centres. The raw gas production will be produced to a Central Production Facility which will provide gas-liquid separation, gas dehydration, gas export and well control. Liquids will be transferred to a FPSO for condensate dewatering and stabilisation, condensate storage and export and other utility services.

Dehydrated gas will be exported to the new LNG plant in Darwin by an 885 km long, 1.07 metre diameter pipeline. The LNG facilities will be installed at a new site in Darwin Harbour and will comprise two LNG trains

Initial Capacity: 2 trains x 4.2 MTPA

Technology: APCI C3MR

Start-up End 2016 planned

LNG Project: Prelude FLNG

Partners: Shell 67.5% (Operator), Inpex 17.5%, CPC 5%, Kogas 10%

Resource: Prelude gas field, Browse Basin, North West Australia

Project Budget: $12 billion (speculated)

Development Concept: Subsea wells in the Prelude field will produce to a Floating LNG facility (FLNG). The FLNG vessel will receive the raw gas, treat it and feed it to a LNG facility located on the deck of the vessel. LNG and associated by-products (LPG and condensate) will be stored in tanks in the hull of the vessel.

The vessel will be 488m long and 74m wide. It will be the largest floating offshore facility in the world.

Initial Capacity: 1 train x 3.6 MTPA

Technology: Shell DMR

Start-up 2016 planned

LNG Project: Gorgon LNG

Partners: Chevron (approx. 47.3%) (Operator), ExxonMobil (25%), Shell (25%), Osaka Gas (1.25%), Tokyo Gas (1%) and Chubu Electric Power (0.417%)

Resource: Gorgon, Jansz-Io gas fields, Carnarvon Basin, North West Australia

Project Budget: $52 billion (press release)

Development Concept: The Gorgon Project is developing the Gorgon and Jansz-Io gas fields, located within the Greater Gorgon area, between 130 and 220 kilometres off the northwest coast of Western Australia. The subsea gas-gathering system will be located on the ocean floor over the Gorgon gas fields west of Barrow Island in 200 to 1,350 metres of water.

The project includes the construction of a 15.6 MTPA LNG plant on Barrow Island (Class A Nature Reserve) and a domestic gas plant with the capacity to supply 300 Tera Joules of gas per day to Western Australia. Construction is limited to a 300 hectare development area.

Gorgon LNG will be off loaded via a 2.1 kilometre long loading jetty for transport to international markets. The domestic gas will be piped to the Western Australian mainland.

CO2 recovered from the gas treatment process will be injected into a saline aquifer. The CO2 injection location is on the central eastern coast of Barrow Island near the gas processing plant. This site was selected to maximise the migration distance from major geological faults and limit ground disturbance. The injection wells will be directionally drilled from discrete surface locations to minimise the area of land required for the well sites, surface facilities, pipelines and access roads. Monitoring wells will provide a sample point within the injection area.

A range of monitoring activities is planned, including:

  • Routine observation and recording of injection rates and surface pressures at the injection wells
  • Surveillance to detect the unlikely event of CO2 migrating to the surface
  • Measurement via well and/or seismic surveys to track the migration of the CO2 plume in the subsurface

Initial Capacity: 3 trains x 5.2 MTPA

Technology: APCI C3MR

Start-up 2015 planned

LNG Project: Sabine Pass LNG Terminal

Partners: Cheniere Energy Partners

Resource: Domestic gas, USA

Project Budget: $4 billion (EPC contract value for T1 and T2)

Development Concept: The Sabine Pass LNG Terminal is located on the Sabine Pass River on the border between Texas and Louisiana. It was originally designed as an LNG import terminal and commenced service in April 2008, but demand for LNG import to the USA declined significantly with the advent of shale gas.

The LNG import terminal is being converted to an export terminal by the construction of 4 LNG trains. Construction has commenced on the first two trains.

Initial Capacity: 4 trains x 4.5 MTPA

Technology: Optimized Cascade

Start-up 2015 planned