Production 100,000 boe per day
Wintershall Norge is one of the leading operators on the Norwegian Continental Shelf (NCS). In 2017, we took the next step on our journey by taking the Maria field all the way from discovery into production. Together with Brage and Vega we are now an operator of three producing fields, and by the turn of the next decade we will begin production from even more of our own operated developments.
Daily production from our own operated and partner operated fields is now around 100,000 barrels of oil equivalent (boe) putting us amongst the major producers in Norway.
The Brage field is Wintershall Norge’s first operated production field. It is located on Blocks 30/6, 31/4, and 31/7, east of Oseberg in the northern part of the North Sea, 125 kilometers west of Bergen. The water depth is 137 metres. The first oil on Brage was produced as early as 1993 and the field was then operated by Hydro. Equinor Energy AS was operator from 2009 until Wintershall took over in October 2013.
Brage is a fully integrated platform with living quarter, auxiliary equipment module, process modules, drilling modules, well and manifold areas. The cabin capacity is 130 people.
Brage has been developed with a fixed integrated production, drilling and accommodation facility with a steel jacket. The main drainage strategy is water injection for the Statfjord, Fensfjord and Brent formations. Produced water is injected in Statfjord and Utsira water in Fensfjord and Brent. Gas lift is utilised in most wells, independent of formation. Brage has no storage capacity and the oil is therefore exported via the Oseberg Transport System (OTS) to the Sture terminal. The gas is exported via a pipeline to Kårstø.
Gas + Oil
The Maria field has been an essential part of Wintershall Norge’s plan to become one of the leading operators on the Norwegian Continental Shelf. The field is located in the Norwegian Sea, on the Halten Terrace in blocks 6407/1 and 6406/3. The field was discovered in 2010 and has an estimated recoverable volume of around 180 million barrels of oil equivalent, of which the majority is oil.
Wintershall and the partners Petoro and Spirit Energy started production on the Maria field in December 2017, only 2 years and 3 months after the approval by Norwegian authorities in September 2015. The field has been developed as a subsea tie-back connected to four host installations. The Maria well stream goes to the Kristin platform for processing, while supply of water for injection into the reservoir comes from the Heidrun platform. Lift gas is provided from Åsgard B via the Tyrihans D subsea template. Processed oil is sent to the Åsgard field for storage and offloading to shuttle tankers. Gas is exported via the Åsgard Transport System to Kårstø.
Gas + Oil
The Gjøa field lies in Blocks 35/9 and 36/7, 60 kilometres west of Florø, in the Norwegian North Sea. The field was discovered in 1989 by Hydro. Neptune Energy Norge AS (formerly ENGIE) took over the operations when the field started to produce oil in 2010. The development comprises four subsea templates tied to a semi-submersible production and processing facility. The topside weight of the platform is 22000t and the hull dry weight is 15000t.
The Gjøa field is a complex gas field with a thin (10-15 metres) oil rim. The main reservoir units of the Gjøa field are the Fensfjord and Sognefjord formations of the Viking group. The field is produced by pressure depletion. Hydrocarbon recovery is optimised by first producing the oil before production of the gas cap begins.
The Gjøa facility is the first floating platform to get its electricity from the mainland. Gjøa is situated in a dynamic area with some recent discoveries and is currently being evaluated as host for additional discoveries.
The Vega field consists of three seabed templates, Vega North, Vega Central and Vega South. Vega North and Central are located in Block 35/8 and covered by Production Licenses 248 and 248B. Vega South is located in Block 35/11 and covered by Production License 090C.
Vega is located in the Northern part of the North Sea, 28 kilometres west of the Gjøa facility, 80 kilometres west of Florø. Vega North and Vega Central were discovered in 1980 and 1982 respectively by Gulf Exploration. Mobil discovered Vega South in 1987. Wintershall Norge took over the operatorship of the Vega field from Equinor Energy AS in March 2015.
Vega North and Central are gas condensate fields. The Vega South field is a gas condensate field overlain by an oil zone and produces by pressure depletion with the underlying gas reservoir, providing natural gas lift for the shallower oil zone.
The Edvard Grieg field is located in the Utsira High area of the North Sea, around 180 km west of Stavanger. The field, discovered in 2007, came on-stream in November 2015. The field, which is primarily oil, has been developed with a standalone platform, including processing and living quarters on a steel jacket construction.
Total reserves for Edvard Grieg are estimated at 187 million boe. The platform has been designed as a regional hub to receive and process hydrocarbons from current and future developments and discoveries in the area. The oil is transported via the Grane pipeline to the Sture terminal on the west coast of Norway, while gas is transported via a separate pipeline system to St. Fergus in Scotland.
The Ivar Aasen field is situated west of the Johan Sverdrup field in the North Sea and was discovered in 2008. The field came on-stream on 24 December 2016.
Ivar Aasen is comprised of resources from five North Sea licenses, PL 001B, 028B, 242, 338 and 547. The unitised field, including Wintershall’s Asha discovery, will be developed in two phases, where the deposits from the Ivar Aasen and West Cable reservoirs will be extracted via a manned production platform.
The selected development solution provides a pipeline link connecting the field with the nearby Edvard Grieg production platform for final processing and export of the extracted volumes. Edvard Grieg also provides lift gas and power for the Ivar Aasen production.
The Knarr field, including Knarr West, in the northern North Sea is expected to yield about 75-80 million barrels of recoverable oil equivalent. The field, formerly known as Jordbær, is in block 34/3, in an extension of the Tampen Spur area, around 45 kilometres north east of the Snorre field. The field came on-stream in March 2015
Discovered in 2008, the field has been developed at a water depth of about 400 meters with two facilities on the sea bed and a floating production storage and offloading vessel (FPSO). The FPSO has a production capacity of 63,000 barrels per day.
Knarr is operated by A/S Norske Shell with 45 %. Idemitsu Petroleum Norge AS holds 25 %, while DEA Norge AS holds 10 % and Wintershall Norge AS holds 20 % in the field.
Gas + Oil
The Veslefrikk field lies 30 kilometres north of Oseberg in the Northern part of the North Sea (block 30/3 and 30/6) at a water depth of 185 metres. The dual facility field, serviced from a fixed steel wellhead facility and a semi-submersible facility, has been producing since 1989.
An oil pipeline is connected to the Oseberg Transport System (OTS) for transport to the Sture terminal. Veslefrikk is in tail production phase.