Building Johan Sverdrup
The Johan Sverdrup field is located 155 km west of Stavanger. The field was discovered in 2010 with the discovery on the Avaldsnes prospect in PL501 by Lundin Norway followed by the discovery of Aldous in PL265 by Statoil in 2011. The discovery of Johan Sverdrup was a direct result of the Edvard Grieg discovery made by Lundin Norway in 2007, as the Johan Sverdrup play concept was modelled on the same basis as that for Edvard Grieg.
The Plan of Development and Operation (PDO) for the giant Johan Sverdrup field was submitted to the Norwegian Ministry of Petroleum and Energy (the Ministry) in February 2015. Following Norwegian Parliament approval in June 2015, the PDO for Phase 1 was given final approval by the Ministry in August 2015.
Reserves and production
Following the execution of the Johan Sverdrup unit operating agreement and the approval of the PDO, Lundin Petroleum has booked net 2P reserves of 551 MMboe for the full field development, based on Lundin Petroleum’s 22.60 percent working interest. The gross 1P and 3P reserves for the full field development are estimated to be 2.0 and 3.0 billion boe respectively. These volumes expressed in boe include oil, gas and natural gas liquids and comprise approximately 95 percent oil. The reserves have been independently audited by ERC Equipoise Ltd.
The oil and gas production capacity for the full field is expected to be 660,000 barrels of oil per day. This makes Johan Sverdrup one of the five largest fields ever discovered on the Norwegian continental shelf. When the full field plateau production is reached, Johan Sverdrup is likely to represent around 25 percent of all Norwegian oil and gas production.
The Johan Sverdrup field will be developed in several phases and with multiple fixed platform installations. Phase 1 of the development consists of four bridge linked platforms as well as three subsea installations. The gross capital expenditures for Phase 1 is estimated at NOK 97 billion (nominal) which includes oil and gas export pipelines, development wells as well as power supply from shore.
Phase 1 is scheduled to start production in late 2019 with a forecast gross production level of up to 440,000 barrels of oil per day.
Phase 2 of the Johan Sverdrup development is expected to commence production in 2022. The current estimated full field capital costs, including Phase 1 costs, are in the range of NOK 137 to NOK 152 billion (real 2016).
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.
Lundin Petroleum has a 22.60 percent working interest in the Johan Sverdrup field. Statoil is operator with 40.0267 percent and the remaining partners are Maersk Oil with 8.44 percent, Petoro with 17.36 percent and Det norske oljeselskap with 11.5733 percent working interest.
Johan Sverdrup field Phase 1 layout
|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.|
|»||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.|
|»||Phase 1 gross production levels of up to 440,000 bopd|
|»||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.|
|»||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.|
|»||The platform deck consists of 48 slots, well intervention deck and manifolds.|
|»||Predrilling is performed by a semi-submersible drilling rig through a predrilling template.|
|»||The estimated weight is 15,000 tonnes dry weight. Size: 40 metres x 83 metres.|
|»||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.|
|»||Water injection and oil export pumps are also localised here.|
|»||The platform has a converter module (DC/AC) for power from shore.|
|»||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.|
|»||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.|
|»||The platform deck consists of the living quarter itself, with 450 cabins, control room and utility/control system.|
|»||The helideck and lifeboats are also localised here.|
|»||The size is 85 x 28 metres, and it is supported by a four-leg steel jacket.|
|»||The weight is approximately 16,500 tonnes.|
|»||The oil will be transported to the Mongstad terminal in the county of Hordaland by a 274 km long, 36-inch diameter pipeline.|
|»||The project includes landing and alignment and modifications to the Mongstad terminal.|
|»||The gas will be transported to Kårstø in the county of Rogaland for processing and further transport.|
|»||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).|
|»||The tie-back point is located approximately 10 km west of Karmøy.|
|»||The field contains reserves estimated at between 2.0 and 3.0 billion barrels of oil equivalents for the entire field.|
|»||The reservoir spans more than 200 square kilometres.|
|»||The reservoir is at a depth of approximately 1800 – 1900 metres beneath the seabed.|
|»||The reservoir properties are very good and characterised by good flow properties. Normal pressure and normal temperature (hydrostatic).|
|»||Requires pressure support from water injection. The oil in the field is of a quality known as «medium oil» at 28 API.|
The key to the Johan Sverdrup discovery
It took 40 years of trial and error from a range of oil companies before Lundin Norway finally found the key to unlock the petroleum reserves at the Utsira High area.
Johan Sverdrup Drilling Platform
The largest drilling platform in Norway; 22,000 tonnes and 146 metres. The Aibel built platform has now been towed to Haugesund where it will remain for hook-up and preparation work until installation on the Johan Sverdrup field next summer.