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Operations Johan Sverdrup

The Johan Sverdrup discovery is one of the largest oil discoveries ever made on the Norwegian shelf. The discovery extends over an area of approximately 200 km² on the Utsira High in the central part of the North Sea.

Johan Sverdrup
Example of Johan Sverdrup field topsides layout
The Johan Sverdrup discovery is located south of Grane, northeast of Sleipner and 140 kilometres west of Stavanger. The discovery extends over three production licences, PL501, PL265 and PL502.

Lundin Norway proved the Johan Sverdrup discovery with exploration well 16/2-6, drilled in 2010 on the Avaldsnes structure in PL501. The Johan Sverdrup discovery was a result of the Edvard Grieg discovery in 2007. Edvard Grieg opened up the possibility of a continuous oil-water contact on the southern part of the Utsira High, called the Haugaland High.

An extensive appraisal program is now substantially complete with 20 appraisal wells drilled and several of the wells having been side-tracked and production-tested. Two additional wells will be drilled in 2014 for further mapping and delineation of this major discovery.

Final concept selection for Phase 1 of the field development has been chosen by the Johan Sverdrup partnership and front end engineering for Phase 1 is currently ongoing. A plan of development for Phase 1 will be submitted for approval by the Norwegian government in early 2015.

The full field gross recoverable contingent resource range of 1,800 to 2,900 MMboe, announced by the pre-unit operator Statoil, makes Johan Sverdrup one of the five largest fields discovered on the Norwegian Continental Shelf and when the field has reached forecast plateau production of 550,000 to 650,000 boepd, field production is likely to represent around 25 percent of all Norwegian oil production.

Phase 1 - Field centre
Due to Johan Sverdrup’s size and lateral extension the field will be developed in several phases and with multiple fixed platform installations. Phase 1 of the development will contain the field centre of four fixed platform installations as well as additional subsea installations. The field centre will consist of one processing platform, one riser platform, one wellhead platform with drilling facilities and one living quarter platform. The platforms, which will be installed in 120 metres of water, will be installed on steel jackets and will be bridge-linked.

The first phase of the development is scheduled to start production in late 2019 and is forecast to have a gross production capacity of between 315,000 and 380,000 boepd. It is anticipated that between 40 and 50 production and injection wells will be drilled to support Phase 1 production, of which 11 to 17 wells will be drilled prior to first oil with a semi-submersible rig to facilitate Phase 1 plateau production.

The gross capital investment for Phase 1, which includes oil and gas export pipelines as well as a power supply from shore, is estimated to between NOK 100 to 120 billion, including contingencies and certain market allowances for potential future increases in market rates. The Phase 1 field centre will also facilitate certain spare capacity for future phases and potential enhanced recovery. The licence partners are continuously working to lower the level of investment for Phase 1.

Export pipeline
The Johan Sverdrup oil and gas production will be transported to shore via dedicated oil and gas pipelines. A 274 km 36”oil pipeline will be installed and connected to the Mongstad oil terminal on the west coast of Norway. A 165 km 18” gas pipeline will be installed and connected to the Kårstø gas terminal for processing and onward transportation.
Future phases
The Johan Sverdrup resources not developed as part of Phase 1 will be developed through subsequent development phases. The scope and costs of further development phases has not yet been addressed by the Johan Sverdrup partners and will form the basis of later investment decisions.

Lundin Norway is the operator of PL501 with a 40% interest, and has a 10% interest in PL265. The PL501 partners are Statoil Petroleum AS with a 40% interest and Maersk Oil Norway AS with a 20% interest. The PL265 partners are Statoil Petroleum AS, operator of PL265, with a 40% interest, Det norske oljeselskap ASA with a 20% interest and Petoro AS with a 30% interest. Lundin Norway has no interest in PL502. The PL502 partners are Statoil Petroleum AS, operator of PL502, with a 44.44% interest, Petoro AS with a 33.33% interest and Det norske oljeselskap ASA with a 22.22% interest.

<<< Johan Sverdrup concept selection presentation >>>
Facts about the Johan Sverdrup field
The field centre for the Johan Sverdrup field in the first phase will consist of four installations. The installations have steel jackets and will be connected by bridges. The water depth is approximately 120 metres.
Process platform

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The process platform has all the processing capacity for the entire field centre. Separation and injection systems. Gas, oil and injection water are transported by pipeline to a riser platform.

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Designed for a capacity of 315,000 to 380,000 barrels of oil equivalents (50,000- 60,000 standard cubic metres).

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The platform deck has three modules with two separation trains for oil and gas separation, cleaning of produced water, gas treatment and utility systems. Supported by an eight-leg steel jacket, the platform deck is 100 metres long and 23 metres wide, and the weight is estimated at 23,000 tonnes.
Drilling platform

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The field centre is planned to be developed with an integrated drilling facility. This concept was selected on the basis of seabed conditions and number of wells from the field centre.

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The platform deck consists of 48 slots, well intervention deck and manifolds.

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Predrilling is performed by a semi-submersible drilling rig through a predrilling template.

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The estimated weight is 15,000 tonnes dry weight. Size: 40 metres x 83 metres.
Riser platform

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This is the centre for export of processed oil and gas, as well as the centre for incoming volumes from future tie-backs from satellite fields.The platform is designed with between 40 and 50 risers and J-tubes.

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Water injection and oil export pumps are also localised here.

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The platform has a converter module (DC/AC) for power from shore.

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In the first phase, the platform consists of three modules. Large sections of the weather decks on these modules have been designed so as to enable future installation of IOR (improved oil recovery) modules and/or handle increased production from future development phases.

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The dry weight of the platform deck is approximately 19,000 tonnes in the first phase and is ca. 125 metres long and 30 metres wide.
Living quarters

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The platform deck consists of the living quarter itself, with 450 cabins, control room and utility/control system.

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The helideck and lifeboats are also localised here.

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The size is 85 x 28 metres, and it is supported by a four-leg steel jacket.

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The weight is approximately 16,500 tonnes.
Transport solutions

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The oil will be transported to the Mongstad terminal in the county of Hordaland by a 274 km long, 36-inch diameter pipeline.

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The project includes landing and alignment and modifications to the Mongstad terminal.

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The gas will be transported to Kårstø in the county of Rogaland for processing and further transport.

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The pipeline will be 165 km long, with an 18-inch diameter. It will be tied into the Statpipe system by means of a subsea tie-back (hot tap).

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The tie-back point is located approximately 10 km west of Karmøy.
The reservoir

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The field contains volumes estimated at between 1.8 and 2.9 billion barrels of oil equivalents for the entire field.

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The reservoir spans more than 200 square kilometres.

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The reservoir is at a depth of approximately 1800 - 1900 metres beneath the seabed.

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The reservoir properties are very good and characterised by good flow properties. Normal pressure and normal temperature (hydrostatic).

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Requires pressure support from water injection. The oil in the field is of a quality known as «medium oil» at 28 API.
Wells

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Total amount of wells in Phase 1 is 40 – 50 both production and injection wells

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11 – 17 wells (both production and injection) will be pre-drilled from 2016 for speedy production

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Water injection templates are scheduled from start because pressure support is necessary from production startup. Water injection has been chosen.
Johan Sverdrup
 
   

FRANCE


» 19 licences
  - 14 production
  -  5 exploration
» Net reserves 22.5 MMboe

NORWAY


» 61 licences
  - 5 production
  - 4 development
  - 52 exploration
» Net reserves 146.6 MMboe

NETHERLANDS


» 21 licences
  -  18 production
  -  3 exploration
» Net reserves 3.4 MMboe

RUSSIA


» 1 exploration licence
 

INDONESIA


» 6 licences
  -  1 production
  -  5 exploration
» Net reserves 1.9 MMboe

MALAYSIA


» 7 exploration licences
» Net reserves 13.7 MMboe