The Petroleum Safety Authority Norway (PSA) granted an extension to ExxonMobil to use the Jotun A floating production storage offloading (FPSO) vessel and Jotun B wellhead platform beyond their original expected lifetimes in the North Sea.
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Jotun A FPSO. Image from Exxon. |
Production at Jotun began in 1999, with expected completion set for 2015; however, Exxon is now estimating that Jotun will be able to produce until 2021.
The extension was granted to Exxon for demonstrating oversight of technical conditions, and its plans for maintenance and follow-up, so the facilities and equipment may continue to be operated in compliance with regulatory requirements, the PSA said.
The Jotun field is located about 200km west of Stavanger, between the Balder and Heimdal fields, at 126m water depth. Jotun's reserves lie within production Blocks 25/8 and 25/7. Recoverable reserves are estimated at approximately 200 MMbbl of oil and 1.8 cu m of gas. The crude is blended with together with oil from the Elli, Elli South, Tau West, and Ringhorne Jurassic fields.
In 2013, average production was 2800 boe/d. According to Exxon, Jotun production has been on the decline over the last few years, thus resulting in spare production capacity.
To utilize Jotun’s capacity, Exxon connected Balder 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 A FPSO, in addition to the Balder FPSO.
In 2013 Ringhorne sent an average of 9700 b/d to Jotun for final processing and storage prior to export. In addition, 7 MMcf/d of gas was exported to Jotun from Balder and Ringhorne for further gas export to Statpipe, Exxon said.
ExxonMobil is the operator of the Jotun field with 45% interest. Partners include Dana (45%), Det norske (7%), and Faroe Petroleum (3%).
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