LEPN license map Producing fields

Transcription

1 LEPN license map Producing fields Heimdal area: Bergen Vale Heimdal, Atla, Skirne, Vale Heimdal Stavanger Sleipner Sleipner area: Sleipner Vest Utgard Sleipner Øst Gungne

2 License Partners - Statoil 62,0% (O) - LEPN 15,0% - ExxonMobil 13,0% - Total 10,0% License Terms - Expires License Key Dates - Production start August Cease production Abandonment 2032 Sleipner fields PL046/PL029 Sleipner Fields infrastructure History The Sleipner area embraces the gas and condensate fields Sleipner Øst, Gungne and Sleipner Vest. The Sleipner installations are also processing hydrocarbons from the tie-in fields Sigyn, Volve, Gudrun and from 2017 also rich gas from Gina Krog. Sleipner consists of the following installations: Sleipner A - Processing, drilling and Living quarter platform Sleipner R - Riser platform for gas export and condensate export Sleipner T - Processing and CO2 removal platform Sleipner B - Unmanned production platform Sleipner has since 1996 performed removal of CO2 from produced gas, and injected and stored more than 16 million tonnes of CO2 in the Utsira formation. Start-up of the processing of Utgard well stream to Sleipner is planned in ca Sleipner delivers dry gas into Gassled pipeline infrastructure (Area D) and unstable condensate to Kårstø for further processing and export. Sleipner R is also a gas hub for gas from Kollsnes (Zeepipe II) and from Nyhamna (Langeled) for further transport to Draupner, Zeebrugge and Easington.

3 Heimdal PL036BS License Partners - Statoil 29,443% (O) - Centrica 28,798% - Petoro 20,000% - Total 16,759% - LEPN 5,00% Development Concept - Gas center/gas hub - Integrated drilling, production and accommodation, steel jacket - One producer pressure depletion License Terms - Expires License Key Dates - Production restarted February Field removal 2035 History Heimdal is a gas field located in the central part of the North Sea. The water depth in the area is 120 metres. The field was developed with an integrated drilling, production and accommodation facility with a steel jacket (HMP1). The Heimdal Jurassic development was approved in A PDO for Heimdal Gas Centre was approved in 1999, and included a new riser facility, connected by a bridge to HMP1. Heimdal is now mainly a processing centre for other fields. Atla, Huldra, Skirne and Vale have delivered gas to Heimdal. Valemon replaced Huldra in Originally, gas from Heimdal was transported in Statpipe via Draupner and Ekofisk to the continent. When the Heimdal Gas Centre was established, a new gas pipeline was connected to the existing gas pipeline from Frigg to St Fergus. Now gas can also be transported via Vesterled to St Fergus in the UK. A gas pipeline was laid from Heimdal to Grane for gas injection at Grane. Condensate is transported by pipeline to Brae in the UK sector and further to Cruden Bay in Scotland. Heimdal Field infrastructure

4 Vale PL036/PL249 License Partners - Centrica 50,000% (O) - LEPN 25,757% - PGNiG 24,243% Development Concept - Subsea tieback to Heimdal - One well pressure depletion License Terms - Expires License Key Dates - Production start May Field abandonment 2020 Vale Field infrastructure History Vale is a gas and condensate field located 16 kilometres north of Heimdal in the central part of the North Sea. The field has been developed with one well from a subsea template tied back to Heimdal. The water depth in the area is approximately 115 metres. The reservoir consists of Middle Jurassic sandstones in the Brent Group. The reservoir depth is approximately metres. The reservoir has low permeability. The field is produced by pressure depletion. The wellstream from Vale is routed to Heimdal for processing and export. From 2016 the wellstream from Vale is routed to the low pressure system at Heimdal in order to extend well lifetime and increase the reserves.

5 Skirne PL102 License Partners - Total 40,0% (O) - Petoro 30,0% - LEPN 30,0% Development Concept - Subsea tieback to Heimdal - One well pressure depletion License Terms - Expires License Key Dates - Production start March Field abandonment 2020 History Skirne, including the Byggve deposit, contains gas and condensate and is located east of Heimdal in the central part of the North Sea. The water depth in the area is about 120 metres. The field has been developed with two subsea templates tied to Heimdal by a pipeline. The Atla field was tied back to the Skirne/Byggve subsea template in The reservoir consists of Middle Jurassic sandstones in the Brent Group. The Skirne deposit lies at a depth of approximately metres and the Byggve deposit at approximately metres. The reservoir quality is good. The field is produced by pressure depletion. The wellstream from Skirne is transported in a pipeline to the Heimdal facility for processing. The gas is transported from Heimdal in Vesterled and Statpipe, and the condensate is transported to the Brae field in the UK sector. The field is now in the tail phase and is expected to produce until A disposal plan for Skirne was submitted to the authorities. Skirne Field infrastructure

6 Atla PL102C License Partners - Total 40,0% (O) - Petoro 30,0% - LEPN 20,0% - Det Norske 10,0% Atla Field infrastructure License Terms - Expires License Key Dates - Production start March Field abandonment 2020 History Atla is located in the central part of the North Sea, about 20 kilometres northeast of the Heimdal field. The water depth in the area is about 119 metres. Atla is developed with one production well from a subsea template tied back to Heimdal. The reservoir contains gas/condensate in sandstones in the Brent Group of Middle Jurassic age at a depth of about metres. The recovery strategy is pressure depletion. The wellstream is transported via the Skirne/Byggve subsea facility to Heimdal for processing and export.status Production started in The field is now in the tail phase. A disposal plan for Atla has been submitted to the authorities. The production will be shut down in the near future. It may be possible to produce the reservoir periodically after pressure buildup.

7 LEPN license map Developments Bergen FGD/Langfjellet Rind Stavanger Utgard Yme

8 Utgard PL046E&PL046F License partners - Statoil Norge AS 38,44% (O) - Statoil UK 38,00% - LEPN 17,36% - Total 6,20% License terms - Expires License plans - Project sanction August Production start up January 2020 Development concept - Two production wells - 4-slot subsea template - Tie-back to Sleipner (SLT) Field infrastructure History 15/8-1 Utgard was discovered in 1982 in the North Sea. The discovery straddles the border between the Norwegian and UK sectors, southwest of the Sleipner Vest field, 20 kilometres from the main Sleipner facilities. The water depth is about 110 metres. The reservoir consists of Middle Jurassic sandstones in the Hugin Formation. It lies at a depth of approximately metres and contains gas and condensate, possibly over a thin oil zone. The gas has a high CO2 content. The development concept is a subsea facility tied back to Sleipner, where the CO2 will be removed. After processing, liquids will be exported to Kårstø and dry gas to Gassled. A plan for development and operation (PDO) was submitted to the authorities in August 2016, with start-up of production in 2019/2020.

9 FriggGammaDelta/Langfjellet PL442/026B License partners - Det Norske 92,26% (O) - LEPN 9,74% License terms - Concept select by December PDO deadline December 2018 License plans - DG 2 3Q Project sanction 3Q Production start-up 1Q 2021 Development concept - Not decided Field infrastructure Drilling: 2016: Drilled Langfjellet well with 3 geological sidetracks 2017: Planning for appraisal and exploration wells into FriggGammaDelta and Langfjellet History Well 25/2-10 S was drilled on the Frigg Gamma structure in 1986 and proved oil and gas. The discovery is located about 20 kilometres east of the Frigg field in the North Sea. The water depth in the area is about 120 metres. The reservoir contains oil and gas in sandstones of the Eocene Frigg Formation and lies at a depth of about metres. The resources also include the Frigg Delta structure, where well 25/2-17 was drilled in 2009, resulting in an oil discovery at the same reservoir level. Several different development concepts are being evaluated, including concepts where several licensees have joint activities. Planned development: Field Hub is planned to be located at FriggGammaDelta. Evaluating PDQ-jacket or FPSO. Langfjellet development is planned to be produced through the FriggGammaDelta Hub. Evaluating Subsea Template or Unmanned Wellhead Platform The Field Hub is planned to receive and process streams from other nearby developments.

10 Yme PL316/316B License partners - Repsol Norge 60,0% (o) - LEPN 20,0% - Kufpec Norway 10,0% - Wintershall Norway 10,0% License terms - Expires License plans Yme New Development - Project sanction 1H Production start up 3Q 2019 Development concept - Leased jack-up rig with processing facilities - Offshore loading of oil Field infrastructure History Yme is an oil field in the southeastern part of the Norwegian sector of the North Sea. The water depth is metres. Yme was originally developed with a jack-up production platform on Yme Gamma and a storage vessel. The Beta structure was developed with subsea wells. Production started in Yme contains two separate main structures, Gamma and Beta, comprising five deposits. The reservoirs are in Middle Jurassic sandstones of the Sandnes Formation, at a depth of about metres. Production ceased in 2001, when operation of the field was no longer regarded as profitable. Yme was the first oil field on the Norwegian continental shelf to be considered for redevelopment after being shutdown. The PDO for redevelopment was approved in The development concept was a new mobile offshore production unit (MOPU). Due to structural deficiencies and the vast amount of outstanding work to complete the MOPU, it was decided to remove it from the Yme field in The production unit was removed in October 2016 in accordance with the authorities disposal decision. Redevelopment of the field is under consideration under the name Yme New Development. 10

11 License partners - Total 62,13% (O) - AkerBP 30,00% - LEPN 7,87% License terms - Expires Rind PL 026 License plans - Project sanction 3Q Production start up 1Q 2021 Development concept - Two production wells - 4-slot subsea template - Tie-back to FriggGammaDelta Field infrastructure History The Rind discovery lies in about 120 m of water about 140 km offshore Norway mainland. Exploration well in 1976 (25/2-5 and appraised in Oil discovery in Upper Brent and Statfjord and gas discovery in Lower Brent..

12 PL797 - Main area Norwegian Sea - Licensing activity TFO Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Work obligations Reprocessing of 3D seismic decision Consider acquisition of existing 3D seismic or acquire 3D seismic Decision to drill Decision to concretize (BoK) Decision to Continue (BoV) Operator: LOTOS Exploration and Production Norge

13 PL442 - Licensing activity TFO Original area (km 2 ) Current area (km 2 ) Work obligations Drilling Approved Decision to continue (BoV) The expiry of initial period Date granted: Valid to date: Operator: Aker BP

14 PL316/PL316B - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Repsol Norge AS

15 PL026 - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Total E&P Norge

16 PL026B - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Aker BP

17 PL102 - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Total E&P Norge

18 PL102C - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Total E&P Norge

19 PL102D - Licensing activity TFO Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Total E&P Norge

20 PL102E - Licensing activity TFO Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Total E&P Norge

21 PL102F/PL102G - Licensing activity TFO2011 and round 9 - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Total E&P Norge

22 PL249 - Licensing activity NST99 - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Centrica Norge Resources AS

23 PL029 - Licensing activity 2-A - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: ExxonMobil Exploration and Production Norge AS

24 PL036 - Licensing activity 2-A - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Centrica Resources Norge AS

25 PL036BS - Licensing activity 2-A - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Centrica Resources Norge AS

26 PL046 - Licensing activity 2-A - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Statoil Petroleum AS

27 PL046D - Licensing activity TFO Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Statoil Petroleum AS

28 PL046E - Licensing activity TFO Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Statoil Petroleum AS

29 PL046F - Licensing activity additionally to round 3 - Original area (km 2 ) Current area (km 2 ) Date granted: Valid to date: Operator: Statoil Petroleum AS