Offshore Field Production
ExxonMobil operates the Ringhorne, Balder, Jotun and Sigyn fields on the Norwegian Continental Shelf (NCS). Total daily production from these fields in 2016 was 66,500 barrels of o.e.
ExxonMobil has ownership interests in over 20 producing fields on the Norwegian Continental Shelf (NCS), which are operated by others (Statoil and Shell). ExxonMobil’s net production from these fields per day in 2016 was about 167,000 o.e. barrels.
The Balder field is developed with a floating production, storage, and offloading vessel (FPSO) and several subsea production systems. The field is located in the North Sea, approximately 190 km northwest of Stavanger. The Ringhorne platform is tied back to the Balder FPSO for processing and export. Balder exports gas to Statpipe via the production vessel, Jotun A.
Numerous upgrades to the Balder FPSO process and compression systems have been carried out during the last few years, resulting in significantly improved reliability. In 2016 the Balder FPSO processed 49,000 barrels of oil per day; 36,000 barrels from the Balder field and 13,000 barrels from the Ringhorne field.
Seismic surveys in the Balder area were carried out in 2009 and in 2012 to prepare for a drilling campaign, which commenced in the first quarter of 2013 using the semi-submersible drilling unit "West Alpha". Until now, 8 new wells have been put into production, which has boosted production significantly. The drilling program was fully completed in 2016.
ExxonMobil is the operator and has 100 percent ownership in the Balder field.
The Jotun field is developed with two installations; a wellhead platform (Jotun B), which transfers resources to production vessel Jotun A. The field is located in the North Sea, 200 km west of Stavanger.
The average production rate in 2016 was 1,100 oil equivalent barrels per day. Jotun production has been on the decline over the last few years, thus resulting in spare production capacity. In order to utilize this capacity, Balder has been connected to Jotun via a gas pipeline, while pipelines were installed between Ringhorne and Jotun thereafter, allowing parts of the Ringhorne field to produce to the Jotun FPSO, in addition to the Balder FPSO.
In 2016 Ringhorne sent an average of 6,100 barrels of oil per day to Jotun for final processing and storage prior to export. In addition 12 million standard cubic feet per day (MCFD) of gas was exported to Jotun from Balder and Ringhorne for further gas export to Statpipe.
In 2012, modifications were made to the Jotun facilities to tie-in the Jette field. Production from Jette commenced in spring 2013. Aker BP is the operator of Jette and the production has been possible through a production handling agreement with ExxonMobil.
Decommissioning activities on the Jotun B installation were initiated in 2015 and will proceed until 2019/2020. In December 2016, the production on the Jotun B installation was permanently shutdown, this includes the conclusion of production from Jette, mentioned above.
As operator of the Jotun field, ExxonMobil has 90 per cent ownership interests. Other partners are Aker BP (7 per cent) and Faroe Petroleum (3 per cent).
The Ringhorne field is located about 9 km north of the Balder FPSO and includes a platform with initial processing and water injection capabilities. Production is routed to the Balder and Jotun installations for final processing, storage and offloading.
Production commenced in February 2003. After production start-up two discoveries in the western and eastern part of the field were included. The latter became on-stream in 2006. In 2016 the Ringhorne field produced an average of 19,000 barrels of oil per day.
Weighing 11, 400 tonnes, the installation of the Ringhorne deck was the heaviest lift ever in the North Sea — and the second heaviest offshore lift ever in the world. It was performed by the crane barge Thialf on August 22nd, 2002.
Ringhorne has only 22 horizontal wells, the longest of which is 8 km long. The geology in the area is very complex, and in addition, some of the Ringhorne oil is heavy, requiring pressure support and gas lift to be produced. Ringhorne is equipped with advanced technology and automated drilling equipment. By use of computers, the drillbit can be steered with high precision, making it possible to hit small targets many kilometres away, with a deviation of only a couple of metres.
ExxonMobil is the operator and has 100 per cent ownership in the Ringhorne field, except for Ringhorne East where ExxonMobil's equity is 77.4 per cent. The other Ringhorne East partners are Statoil (14.8 per cent) and Faroe Petroleum (7.8 per cent).
The Sigyn field, which is located in the Sleipner area in the North Sea, commenced production in 2002.
The field consists of two gas/condensate producers and one oil producer that are connected to the Sleipner A platform via a subsea template. In 2016, the average production on Sigyn was 18 million standard cubic feet of gas per day and 6,000 barrels of condensate per day. In 2016, a new production well was drilled at the Sigyn field by using the semi-submersible drilling unit "West Alpha". The new well has increased Sigyn production significantly.
ExxonMobil has 40 per cent ownership, while Statoil holds the remaining 60 per cent interests. 1 July 2017, the Sigyn field operatorship was transferred from ExxonMobil to Statoil.