Laggan-Tormore Project, United Kingdom
Laggan and Tormore are two gas and condensate fields situated about 125km north-west of the Shetland Islands in the UK. They are located 16km apart in the North Sea. The fields are owned by Total E&P UK (80%) and Dong E&P (UK) (20%). Total is the operator.
The Laggan-Tormore project involves the development of the two fields and construction of a gas processing plant and export pipeline. The project is estimated to require an investment of £2.5bn ($3.8bn), of which Dong will contribute about £500m (approximately DKK4.3bn). It will employ about 800 workers during construction and 70 during operations.
First production is scheduled in mid-2014.
The fields are located in the west of Shetland area which contains 17% of the oil and gas reserve remnants in the UK. Laggan lies in block 206/1a and Tormore in block 205/5a, at a water depth of 600m (1,968ft).
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The Laggan field was discovered in 1986. It was licensed to Total in 1995.
The Tormore field was discovered in 2007. The discovery well (205/5a-1) recorded a test flow rate of 32mcf/d of gas at a depth of 3,936m (12,913ft). The condensate was 75 barrels per 1mcf of gas.
The total field reserves are estimated to exceed one trillion cubic feet of gas and condensates (about 230 million barrels of oil equivalent).
The two fields together are expected to produce 14 million cubic metres of gas and condensate per day at peak production rate.
The field will be developed as a long subsea tie-back to the new gas processing terminal (Shetland Gas Plant) that will be built at Sullom Voe, about 100km from the field. The development plan was approved in March 2010.
Appraisal drilling on the Laggan field was completed in 2004. Two appraisal wells were completed in 2004 and one of them (2006/4AZ) recorded a flow rate of 37.8 million cubic feet (mcf) of gas per day.
The first exploration well in the Tormore field was drilled in 2007. Appraisal drilling was carried out between 2008 and 2010.
The development drilling, expected to start in 2012, will be carried out in two phases. The first phase, scheduled to begin upon the completion of subsea template installation in 2012, will include drilling of seven production wells - four on Laggan and three on Tormore. Six of the seven wells drilled will be new whereas the seventh well is an existing exploration well on Tormore, which will be re-entered.
The second phase will involve drilling of one more well, the eighth, which will help to study the dynamic response of the field reservoirs.
The West Phoenix, a semi-submersible rig operated by Seadrill, will be used for offshore drilling.
The subsea infrastructure will include eight subsea wells and two subsea production systems (one for Laggan and one for Tormore). The production systems will comprise two six-slot production manifold templates. Fabrication of the manifold templates will begin in September 2011.
Heerema Marine is responsible for the transportation and installation of the production systems. Heerema will use its heavy lift vessel Thialf for transportation and installation.
Two flowlines, each of 18in diameter and 143km length, will be built to transfer gas from the subsea production system to the Shetland Gas Plant (SGP).
Another pipeline of 243km length and 30in diameter, called the Shetland Islands Regional Gas Export Pipeline (SIRGE), will be built to export the processed gas further for final processing and sale. The SIRGE line will have a capacity of 665mcf/d of gas.
The entire pipeline network will require an estimated 200,000t of high-grade steel. The inner walls of the pipes will be protected by a three-layer polypropylene anticorrosion coating, internal flow efficiency coating and concrete weight coating.
The produced gas will be first sent to the Shetland Gas Plant through the two flowlines. The associated liquid hydrocarbons will be exported to the Sullom Voe terminal.
The treated gas from the plant will be exported to the Frigg UK pipeline in the North Sea through the SIRGE line. It will then be transported to the St Fergus Gas Terminal for final processing.
The gas will be separated from the liquids using a three-phase separator system at the SGP.
Basic engineering of the field development, including the subsea infrastructure, gas treatment plant and the export pipeline, was provided by a joint venture of Ode and Doris Engineering. The JV was contracted by Total in March 2009.
The contract to supply the field subsea production systems was awarded to FMC Technologies in April 2010.
Subsea 7 was contracted in May 2010 for providing a number of subsea infrastructure items including two control umbilicals, two piggyback rigid flowlines and other accessories. One of the umbilicals will be 127km-long, the longest single length umbilical installed by Subsea 7. The second umbilical will be 17km-long.
The flow lines will include an 8in mono ethylene glycol line and a 2in service line, extending to a length of 141km. The 8in pipe will be supplied by Valorec Mannesman and the 2in pipe will be supplied by Saltzgitter Mannesman International.
The contract is valued at more than $250m and includes installation, tie-ins and pre-commissioning of all the pipelines. Installation and pre-commissioning of the pipelines and umbilicals will begin in the second quarter of 2012. Tie-in and commissioning will begin in the second quarter of 2013.
The 18in and 30in flowline pipes will be supplied by Corus, under a £200m contract signed with Total in 2010. The installation of flowlines and onshore pipelines will be carried out by Allseas UK. The installations are scheduled to begin in 2012.
The processing plant (SGP) will be built by Petrofac's Offshore Engineering & Operations (OE&O) unit.