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Oil and gas
Gjøa is predominantly a gas reservoir with remaining reserves estimated at 297 mmboe. Gas accounts for over 65% of total reserves.
The Gjøa field was discovered in 1989. Statoil was the development operator. The operatorship was transferred to Neptune when production commenced in 2010. Operational performance and production levels have been outstanding since the start of production and good reservoir management has extended the field life. Gjøa is now set to produce 100 mmboe more than was estimated when production started.
The semi-submersible Gjøa production unit, which was jointly developed with nearby Vega fields, has full processing and export capabilities. The floating production facilitiy has been designed to act as an area hub. It has a longer technical lifetime than the Gjøa/Vega fields and additional space and weight capacity. Oil is exported to the Mongstad crude oil terminal on the west coast of Norway. Gas is exported through the FLAGS pipeline to the St. Fergus Gas Terminal in Scotland.
Gjøa is the first floating production platform to be powered sustainably by onshore facilities. A 100 km submarine cable delivers hydropower-generated electricity from Mongstad. Electricity from the mainland saves 200,000 tonnes in CO2 emissions annually, equivalent to 100,000 cars.
To mitigate the decline of Gjøa’s own production, several new development projects are underway that will make use of its processing capacity. The Gjøa P1 redevelopment project is an extension of an existing reservoir in the northern part of the field. In addition, the Neptune-operated Duva discovery 14 km northeast of Gjøa and the Wintershall-operated Nova field are planned to be produced using Gjøa facilities. All three projects are expected to start production in 2021.
Neptune Energy (30%), Petoro (30%), Wintershall (20%), OKEA (12%), DEA (8%).