Kobra East & Gekko (KEG) field is located within the production licence (PL) 203 in the Alvheim area of the central North Sea, Norway. The water depth in the area is between 120m and 130m.
The field development will help extend the Alvheim oil and gas field’s lifetime, improve production, and decrease unit costs.
The KEG field is co-owned by Aker BP (operator, 65%), ConocoPhillips Skandinavia (20%), and Lundin Energy Norway (15%).
The plan for development and operation (PDO) of the KEG field was submitted to the Norwegian Ministry of Petroleum and Energy in June 2021. The project will involve an estimated investment of Nkr8bn ($1bn). The first production from the field is expected to occur in the first quarter (Q1) of 2024.
Kobra East & Gekko field discovery and reserves
The Kobra field was discovered by the well 25/7-5 in the Hermod Formation in 1997. The Kobra structure comprises remobilised Palaeocene Hermod sands with high-quality reservoir properties. The field was developed in 2016.
Gekko was discovered by the well 25/4-3, approximately 10km south-east of Alvheim in 1974, and was later appraised in 2018 to encounter a thin 6.5m oil column beneath a large gas cap. The sandstones reservoirs are present within the Palaeocene Heimdal Formation.
The Gekko development has been combined with the development of the Kobra East development through an additional tri-lateral well.
The KEG field has estimated recoverable reserves of approximately 40 million barrels of oil equivalent (MMboe).
KEG field development details
The Kobra East and Gekko fields will be developed through the installation of subsea production systems, tied back to the existing Alvheim floating, production, storage, and offloading (FPSO) vessel situated approximately 8km away, via the existing Kneler B sub-sea manifold.
The field development will require approximately 42km of drilling from four multi-lateral wells, which will account for a major part of the project investment. The approach of drilling a multi-branch well instead of single wellbore wells in the reservoir will increase the recovery from the fields. The drilling will take place from two locations, Gekko South and Gekko North.
The produced oil will be processed and stored in the FPSO and later buoy-loaded to tankers, while the processed gas from the FPSO will be piped to St Fergus gas terminal in Scotland via the British Scottish Area Gas Evacuation (SAGE) pipeline system.
The KEG project is expected to cut the CO₂ emissions per barrel by 50% and double the oil production from the Alvheim FPSO. The fabrication and installation of the sub-sea facilities for the project will include the pipe-in-pipe-designed pipelines, umbilicals, sub-sea X-mas trees, structures and subsea control modules.
The Alvheim FPSO has a length of 252.16m in, moulded breadth of 42m and moulded depth of 23.2m. The vessel has a design capacity of 120,000 barrels per day (bpd) oil and 125 million cubic feet per day (MMcfd) of natural gas and 560,000 barrels of oil storage capacity.
The FPSO was converted from a multi-purpose shuttle tanker named MST Odin at a yard located in Haugesund in southern Norway for use on the Alvheim oil and gas field.
The vessel became operational in 2008 and achieved 55,400 barrels of oil equivalent per day (boepd) of production in 2020 with a production efficiency of 96%.
Alvheim area details
With net proven reserves of approximately 71Mmboe, the Alvheim area comprises the producing Alvheim, Skogul, Vilje, Boyla and Volund fields along with other discoveries including Gekko, Froskelar, Caterpillar, Trine and Trell. The production from the area began in 2008.
Contractors involved in Kobra East & Gekko field
Aker BP awarded contracts worth Nkr1.7bn ($193.6m) to the sub-sea alliance among Aker Solutions, Subsea 7 and Aker BP for the engineering, procurement, fabrication and installation of the subsea production system and subsea umbilicals, risers and flowlines (SURF) for the KEG project in July 2021.