20 development projects
16/07/2018
The North Sea
Yme
The authorities approved an amended development plan for Yme in 2018. The plan is to use a jack-up rig with drilling and process facilities to produce the remaining reserves. Production is scheduled to start in April 2020. Repsol is the operator.
Oda
The development plan for Oda was approved in 2017. The field will be tied back to Ula, and production is scheduled to start in the third quarter of 2019. Estimates indicate that 7.5 million Sm3 o.e. can be recovered from the field. Spirit Energy is the operator.
Utgard
The authorities approved the development plan for the Utgard gas and condensate field in 2017. Estimates indicate that the field contains about 9 million Sm3 of oil. The development will be tied back to the Sleipner facilities and production is scheduled to start in the fourth quarter of 2019. Equinor is the operator.
Valhall West Flank
The plan for a further development of the west flank of Valhall was approved earlier this year. The field will be developed with a normally unmanned facility with twelve well slots, production and gas lift pipelines and umbilicals. Expected recoverable reserves are 9.6 million Sm3 of oil equivalents. Production start is planned for the fourth quarter of 2020. Aker BP is the operator.
Ekofisk Sør (2/4 VC)
The authorities approved the development plan for 2/4 VC in 2017, as an amended PDO to Ekofisk Sør. The development comprises a subsea template with four well slots and the drilling of four wells for water injection. This will contribute to increasing oil production by around 2.7 million Sm3 of oil. Conoco Phillips is the operator.
Johan Sverdrup Phase I
The development plan for Johan Sverdrup Phase I was approved in 2015. The development solution for the first stage of construction is a field centre comprising four facilities with gangway connections – living quarters, process facility, drilling facility and riser. The drilling facility has 48 well slots. Equinor is the operator.
Martin Linge
The development plan for Martin Linge was approved in 2012. The field will be developed with an integrated fixed production platform with a steel jacket and a floating storage and offloading unit. The PDO indicated start-up for the field in 2016. The project has encountered delays, and estimated production start is in 2019. Equinor is the operator.
Skogul
The development plan for Skogul was approved in 2018. The field will be developed with a subsea facility that will be tied back to the production ship (FPSO) on Alvheim via the subsea facility on Vilje Sør. Recoverable reserves are estimated at 1.6 million Sm3 of oil equivalents. Production is expected to start in early 2020. Aker BP is the operator.
Oseberg West Flank 2
The development plan was approved in 2016. The west flank of Oseberg will be developed with an unmanned wellhead platform resting on the seabed. The plan calls for production to start in the autumn of 2018. Equinor is the operator.
Snorre
The application for an amended development plan for Snorre was approved in 2018. The development comprises six new subsea templates tied back to Snorre A, modification work on Snorre A and import of injection gas from Gullfaks. The expansion will increase recovery from the field by more than 30 million Sm3 of oil. Planned production start is the first quarter of 2021. Equinor is the operator.
Gullfaks Sør area PDO exemption
In 2018, the authorities approved the application for an exemption from the requirement to submit a PDO for additional resources in the Gullfaks Sør area. The project entails incorporation of relatively small, but profitable additional resources. The estimated recoverable reserves are in the order of 0.2-1.5 million Sm3 o.e. Equinor is the operator.
The Norwegian Sea
Dvalin
The development plan for Dvalin was approved in 2017. The field will be developed with a 4-slot subsea template tied back to the Heidrun facility. The recoverable reserves are estimated at about 18 billion Sm3 of gas. Production is scheduled to start in the fourth quarter of 2020. DEA is the operator.
Aasta Hansteen
The authorities approved the development plan for the Aasta Hansteen gas field in 2013. The field will be developed with a floating field centre (Spar platform) and two subsea templates with eight well slots. The recoverable reserves are estimated at approximately 55 billion Sm3 of gas. The plan calls for production to start during the autumn of 2018. Equinor is the operator.
Njord further development
The authorities approved the development plan for the Njord project in 2017. The field was shut down in 2016 due to structural problems with the Njord A platform. Njord A and the Njord B storage ship were towed to land for upgrades. The estimated remaining recoverable reserves are 5.1 million Sm3 of oil, 13.2 billion Sm3 of gas and 4.1 million tonnes of NGL. Production is scheduled to start in the fourth quarter of 2020. Equinor is the operator.
Trestakk
The development plan for Trestakk was approved in 2017. The oil field will be developed with a subsea template with four well slots and a subsea template with one well slot. The field will be tied back to the Åsgard A ship. Recoverable reserves are estimated at 10.7 million Sm3 of oil and 1.4 billion Sm3 of gas. Planned production start is in the second quarter of 2019. Equinor is the operator.
Bauge
The authorities approved the development plan for the Bauge oil field in 2017. The field will be developed with a subsea template tied back to Hyme and Njord. The recoverable reserves are estimated at 7.9 million Sm3 of oil, 1 million tonnes of NGL and 1.9 billion Sm3 of gas. Bauge is scheduled to start production in the fourth quarter of 2020. Equinor is the operator.
Ærfugl
The development plan for the Ærfugl gas field was approved in 2018. The plan is to develop the field in two phases with a total of six subsea templates that will be tied back to a production ship on the Skarv field. Expected recoverable gas reserves are estimated at 44 million Sm3 of oil equivalents (o.e.), of which about 85 per cent are gas. According to the plan, Phase 1 will start to produce in the fourth quarter of 2020, while Phase 2 will come in 2023. Aker BP is the operator.
Fenja
The authorities approved the development plan for the Fenja oil and condensate field in 2018. The field will be developed with two subsea templates and six wells which will be tied back to Njord. Recoverable reserves are about 11 million Sm3 of oil and 3.4 billion Sm3 of gas. The plan calls for Fenja to commence production in 2021. VNG Norge is the operator.
The Barents Sea
Johan Castberg
The development plan for the Johan Castberg oil field was approved in 2018. The field will be developed with a production and storage ship (FPSO). Recoverable oil reserves are estimated at 88.7 million Sm3. Proven gas (29 Msm3 o.e.) is not included in the reserve estimate because it is used as the drive mechanism. Equinor is the operator.
Askeladd
The Askeladd gas deposit is included in the development plan for Snøhvit, which the authorities approved in 2002. Total reserves associated with the project are 20.7 billion Sm3. Askeladd is now being developed with two subsea templates, and three new production wells will be drilled that will be tied back to the existing pipeline to Melkøya. Equinor is the operator.
Updated: 16/07/2018