The Angelin gas field is located 25mi (40km) off the shore of Trinidad and Tobago in 213ft (65m) of water.
A joint enterprise between BP (70%) and Repsol (30%) known as BP Trinidad & Tobago (BPTT) is the operator of the field.
Angelin lies in the eastern coast of Trinidad, where BPTT currently operates 904,000 acres.
It is BPTT’s second biggest investment in the region after Juniper, costing an estimated $800m.
The Angelin project was sanctioned by BPTT in June 2017 following the execution of a gas sales agreement with Trinidad’s National Gas Company.
Execution of the agreement was also an important step towards the development of the field, as well as future investments in the region valued at approximately $5bn-6bn, which BPTT have scheduled to take place over the next five years.
First gas production from the field is expected in the first quarter of 2019, and the area’s development is expected to boost the national gas production rate and improve gas security across the surrounding region.
Angelin is a dry gas field lying within the northern Columbus Basin, located offshore Trinidad.
The field was discovered after the drilling of the El Diablo well in 1995. Angelin was appraised in 2006 with the drilling of the La Novia well.
BP conducted an Ocean Bottom Cable (OBC) seismic campaign to further understand the geology of the field in 2012 and 2013.
The seismic campaign helped in proving the feasibility of Angelin and also led to the discovery of two major prospects known as Savannah and Macadamia.
The Angelin field is estimated to contain 1.5 trillion cubic feet of gas.
Angelin is set to be developed through a normally unmanned platform with a production capacity of 600 million standard cubic feet of gas a day (mmscfd).
Four wells are planned to be drilled, with drilling expected to commence in the third quarter of 2018. The wells are expected to be drilled to depths of 2,500m-4,000m.
One well will produce from a single reservoir, while the remaining three wells will produce from two reservoirs.
The produced gas and fluids will be transported to the Serrette platform via a 21km, 26in-diameter export pipeline, and further onto the Cassia B platform for processing.
The processed gas will be transported to BPTT’s Beachfield / Atlantic LNG facility, while the liquids will be exported to the Galeota terminal through an existing pipeline network.
Angelin’s six-slot wellhead platform will include a 992t four-legged pile jacket and a 1,323t four-deck topside.
The platform and export pipeline are scheduled to be installed using McDermott’s DLV 2000 derrick lay vessel.
The platform will feature a 26.37in riser, a 26in subsea tie-in spool to the existing subsea Wye at Serrette and one 26in subsea tie-in spool to new Wye skid.
It will also include one subsea Wye skid each at Serrette and Angelin, and one isolation skid at Serrette.
A wellhead control panel will be installed on the platform to control the operation of the Xmas tree valves.
A chemical injection unit equipped with an injection corrosion inhibitor will protect the pipelines and process equipment from corrosion.
McDermott was awarded the contract to carry out the pre-FEED, FEED and detailed engineering of the field development facilities.
The company also won the engineering, procurement, construction, installation and commissioning contract for the facilities in June 2017.
Frames Group was subcontracted by McDermott to provide a wellhead control panel and a chemical injection unit.
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