Production & development

The Gyda field was proven in 1980 and developed by the use of an integrated steel platform at a depth of 66 meters. The oil is transported by pipeline to Teesside via Ekofisk. The gas is piped to the Ekofisk complex and on to Emden. 

In June 2017 the Norwegian authorities approved the decommission plan for the Gyda field. The decommission scope includes permanent plugging of 32 wells on the field, removal of platform and undercarriage, as well as removal of installations on the seabed. All Gyda installations should be removed by 2023.

Operator:

• Repsol Norge AS

Production start-up:

• 21. June 1990

Licensees:

• Repsol Norge AS 61% 
• INEOS E&P Norge AS 34% 
• KUFPEC Norway AS 5%

Rev was discovered in February 2001. Varg gas is exported through Rev since February 2014. The well stream is routed through a pipeline to the Armada field in the British sector.

Operator:

• Repsol Norge AS

Production start-up:

• 2008

Licensees:

• Repsol Norge AS70% 
• Petoro AS 30%

On 16th April 2018 the Rev UKCS decommissioning programme was approved by the Secretary of State. A Copy of this document along with the EIA and Comparative assessment can be found below and also on OPRED website, see link below:

https://www.gov.uk/guidance/oil-and-gas-decommissioning-of-offshore-installations-and-pipelines#table-of-approved-decommissioning-programmes

The Varg field was discovered in 1984 and is located south of the Sleipner Øst field. The Varg field is developed at a water depth of 84 meters with a wellhead platform (Varg A) and a Floating Production Storage and Offloading vessel (FPSO). The production commenced on 24th December 1998. Associated gas was re-injected into the reservoir up to 5th February 2014 when a gas export pipeline route from Varg via Rev and Armada was commissioned. Cease of Varg production occurred on 2nd June and the FPSO left the field on 30th July 2016.

The Varg field has been a tremendous success for Repsol and its partners and has produced 3 times the promised oil volumes in the POD (Plan for Operation and Development) approved by the Norwegian authorities.

In 2015 and 2016 necessary decommissioning work was executed to enable the safe sail-way of the FPSO and subsequent permanent P&A of the wells in 2017/18.The outstanding decommissioning work is to be completed summer 2018 and consists of 3 offshore campaigns in to fully remove the Varg A platform with subsequent onshore disposal in 2H 2018.

Operator:

• Repsol Norge AS

Production start-up:

• 22. december 1998

Licensees:

• Repsol Norge AS 65% 
• Petoro AS 30% 
• AkerBP ASA 5%

The Veslefrikk field was proven in 1981 and has been developed with a well-head platform (Veslefrikk A) resting on the seabed, and a semi-subersible platform with a processing facility and accomodation quarters (Veslefrikk B). The ocean depths at the installations are 175 meters.

Operator:

• Statoil Petroleum AS

Production start-up:

• 26. december 1989

Licensees:

• Petoro AS 37% 
• Repsol Norge AS 27% 
• Statoil Petroleum AS 18% 
• RWE Dea Norge AS 13.5% 
• Wintershall Norge ASA 4.5%

The Yme field was discovered in 1987 located in Block 9/2 and 9/5 in the Egersund Basin, approximately 100 km from the Norwegian coastline. The field was in production from 1996 to 2001. The main reason for abandonment was the combination of high cost and low oil prices. Current licensees were awarded the rights to block 9/2 and 9/5 (production license 316/316B) 18 June 2004. 

A Plan for Development and Operation (PDO) for Yme re-development was approved by the Norwegian Government 11 May 2007. This re-development was based on a lease of a production unit (MOPU platform). This platform, that was installed summer 2011, was never completed and the platform was left de-manned since 10 July 2012 due to the discovery of significant structural defects. The discovery of structural defects eventually led the owner of the MOPU, Single Buoy Moorings, Inc. (SBM) to declare the MOPU as scrap, and a commercial settlement was subsequently agreed between the licensees and SBM. The MOPU was removed from the field August 2016 and handed over to the platform-owner. 

On 19 December Repsol submitted a revised Plan for Development and Operation (PDO) of the Yme field to the Norwegian Ministry of Petroleum and Energy. On 23 March 2018 the revised plan was approved by the Ministry.

The revised PDO is based on re-use of existing facilities to the extent possible, a new wellhead module on top of the existing caisson and the lease of the a mobile offshore drilling- and production unit. The existing storage tank, caisson, pipelines, subsea templates and offloading system will be reused. All existing wells will be used and further wells will be drilled.The recoverable oil reserves for the Yme field are estimated at approximately 65 million barrels at 10 year’s total production. First oil from Yme is planned for the first half of 2020.

Licensees:

• Repsol Norge AS (55% working interest) 
• Lotos Exploration and Production Norge AS (20% working interest) 
• KUFPEC Norway AS (10% working interest) 
• OKEA AS (15% working interest)

Gudrun is located 50 kilometres north of Sleipner. The water depth is approximately 110 metres. Gudrun is being developed with a fixed facility with a steel jacket and first-stage processing, tied back to Sleipner A through two dedicated pipelines; one for oil and one for rich gas. On the Sleipner A facility the oil and gas is being processed and exported. Production started in April 2014.

Operator:

• Statoil Petroleum AS

Production start-up:

• April 2014

Licensees:

• Statoil Petroleum AS: 36 % 
• Repsol Norge AS: 15% 
• GDF Suez E&P Norge AS:25% 
• OMV (Norge) AS: 24%