North Sea

Alba Phase II,
Alba is located in block 16/26, 130 miles north-east of Aberdeen.	The Northern Alba Platform was shut down for 18 hours, during the installation of four new modules.	The Alba platform, with the new modules installed.
The Alba Phase II hook-up.	The control room on the Alba platform.	Workers from the Safe Caledonia flotel complete work on the topsides for Alba Phase II.
The Alba floating storage unit (FSU).

Alvheim
The Alvheim STP system will have 14 slots through the turret to accommodate risers and umbilicals for the initial subsea wells and for planned expansions.	The field will be developed by an FPSO converted from the multipurpose shuttle tanker (MST) Odin.	Alvheim lies on the Norwegian Continental Shelf, west of Heimdal, in production license PL 203.
Wellservicer is performing spool installation and tie-ins.	Apache is the vessel being used for pipe lay.

Åsgard,
The appraisal well on the Åsgard field, with the flare system in operation.	The Åsgard B topside modules awaiting assembly.	Rockwater installed two pipe bundles, 3.8km in length with 44in carrier pipe, during 1997.
The Åsgard A FPSO measures 278m in length and has a displacement of 184,300t.	The turret of the Åsgard A floating production vessel merges with the internal pipework.	The Åsgard B production platform is linked to the accommodation flotel Safe Britannia.
Delivery of the Åsgard hull by the Mighty Servant 3.

Balder,
A west-to-east cross section of the Balder reservoir, which is particularly complex.	Balder's subsea system consists of up to 15 subsea wells, tied back to a production vessel.	The Balder production vessel, back in 1995, prior to turret installation.
At the end of 1995, the lower turret was installed in the Balder floating production vessel in Levingston, Singapore.	The upper turret was installed in the Balder floating production vessel at the same time as the lower turret.

Banff,
Banff began production in mid-September 1996. Reserves are estimated at between 20 and 110 million barrels.	Schematic of the Banff field phase 2 development.	Schematic of the Banff early production system.
The Ramform Banff hull has a characteristic delta shape.	The weathervaning turret mooring can accommodate up to 15 risers, although Banff will use just seven.	The Ramform Banff process systems.

Beryl Field
The field was discovered in 1972 and named after Beryl Solomon, wife of Mobil Europe president Charles Solomon.	The project covers an area of around 12,000 acres in water depths ranging from 350ft to 400ft.	Beryl Field is located about 335km north-east of Aberdeen on the United Kingdom continental shelf in Block 9/13.

Blake Flank,
The Orelia was used on the infield pipelaying at the Blake channel.	Artist's impression of the Blake Flank development layout.	CSO Marionas was used for trenching and testing at the Blake field.
The produced oil, gas and water will be separated on Bleo Holm and the oil temporarily stored onboard prior to export by shuttle tanker.	All trenching and pipelay work for Blake will be carried out by the offshore support vessel Normand Pioneer.	On the FPSO, the Blake fluids are processed with those from the Talisman operated Ross field, 9.5km away.

Boulton,
The Boulton platform is located off the Lincolnshire coast.	The SeaHarvester platform was originally designed by the Atlantia Corporation, as a standardised concept to suit Gulf of Mexico conditions.	The 463t (installed weight gross) jacket for the Conoco-operated Boulton platform.
The 337t (installed weight gross) deck for the Conoco-operated Boulton platform.	Installation of the jacket, by the Stanislav Yudin, for the Boulton gas field in 1997.	Stanislav Yudin installed the Boulton platform topsides during 1997.

Brigantine,
Installation of the Brigantine BR on the barge, at Kye Engineering, in Lowestoft.	The Brigantine BR platform, ready for sailaway.	The Brigantine BR topsides.
The Brigantine BR platform, preparing for departure.	Installation of the Brigantine BG platform offshore.	The skiff platform was installed by the Maersk Endurer.

Britannia,
Britannia's reserves are being developed through a single drilling, production and accommodation platform.	The drilling module under construction at SLP-Teesside.	Schematic of the Britannia topside, showing the modules. The seven major components comprising the platform topsides were built in Lowestoft and Teesside.
The heaviest unit, the integrated deck weighing 11,000t, makes maximum use of the lift capability of one of the largest semisubmersible crane vessels available.	The SAGE terminal at St Fergus.

Bruce Phase II,
The original Bruce platforms were a Process, Utilities and Quarters (PUQ) platform and a drilling platform, linked by a 47m bridge.	Installation of the Bruce phase II topsides.	View of the Bruce complex, before the installation of the Bruce phase II jacket.
The 3,200t steel jacket was installed in mid-1998, shortly followed by the 2,750t topsides.	Phase II of the developments was previously known as the Western Area Development (WAD).	Phase II of the development was begun in order to develop the Western part of the Bruce field.

Buzzard Field
The Buzzard field was discovered in June 2001 using the semi-submersible Ocean Nomad.	The field will be developed by three bridge-linked platforms supporting the wellhead facilities (W), production facilities (P) and a third platform supporting living quarters and utilities (UQ).	The Buzzard field is located in the Outer Moray Firth, central North Sea, 100km northeast of Aberdeen.
Field schematic of the Buzzard field.	The reservoir has a low gas/oil ratio and will require pressure maintenance through water injection from the onset of production.

Caister Murdoch Phase 3,
Schematic of the CMS3 layout.	Seismic graphic of the K prospect.	The Murdoch platform, with the compression platform installed in CMS2.
The installation of the compression facilities.	CAD information will be useful for the installation of the new compression module.	The Murdoch platform.
The compression platform jacket, installed as part of CMS2.

Captain,
Completion of the Captain platform, with the addition of the topside.	Installation of the Captain wellhead protector platform (WPP) in the field. The first of an estimated 350 million barrels of oil flowed from the field in December 1996 — both on time and within budget.	The Texaco Captain accomodation module.
The shuttle tanker, MV Aberdeen, prior to its launch in Bilbao, Northern Spain.	The FPSO Captain, prior to sailout.	The Captain FPSO after its launch from El Ferrol, north-west Spain. A Tentech 700 design, it was purposely built at Astano’s shipyard in El Ferrol.
The Captain FPSO on-station, offloading into a shuttle tanker.

Chestnut Oil Field
The Sevan Hummingbird is the second such Sevan Marine 300 unit to be built and the first cylindrical FPSO to be deployed in the North Sea.	The outfitting and assembly of the processing plant took place Keppel Verolme Shipyard in Rotterdam.	A schematic of the Chestnut oil field.

Chukchi Sea Permit, Alaska
Spread over 29 million acres, the Shell lease area stretches from Point Barrow to Cape Lisburne.	Drilling is expected to start during 2010 with the first oil due in 2022.	It is known that there are four oil fields in the Chukchi Sea but so far the amount of oil remains a mystery.

Clair Field, Shetlands
Map of the Claire field, located 75km west of Shetland.	Model of the finished platform.	Computer diagram of the completed platform for Clair field.

Cook Field,
The pipe-in-pipe fabrication base at Evanton.	The CSO Apache was used to lay the pipe.	A seismic section, through the reservoir.
Pipe from the stern of the Apache.	Sedco 711, drilling on Cook.	Bundles of pipeline, ready to be joined.
Fabrication of the pipeline.

Curlew Field,
The geological cross section of the Curlew B and D reservoirs.	The Maersk Curlew FPSO is one of the first to make use of gas-fired boilers.	Maersk Curlew's deck, showing the layout of the oil- and gas-processing facilities.
Schematic of the field layout.	Maersk Curlew's riser turret.	The lowering of a 160t insert into position.

Dunbar Phase II,
Fabrication of the Dunbar jacket.	The LB200 laybarge was used for the Ellon-Dunbar lines.	The double-wall interpipe, running between Dubar and North Alwyn.
The subsea choke manifold on the Ellon.	The Sedco 706, used for field drilling.	Topsides of the Dunbar platform.
The Dunbar platform, moored to the Sedco 706 tender-support vessel.

Easington Catchment Area (ECA),
The modifications to the Cleeton facilities allowing for the introduction of ECA gas will be undertaken by BP and AMEC.	The Easington Catchment Area (ECA) gas development field schematic.	The Laybarge LB 200 laying the 16in pipeline between the Neptune and Cleeton fields.
MSV Norlift, laying the 10in pipeline, between the Neptune and Mercury fields.	The fields lie in water depths ranging between 29 and 46m. The Neptune field was discovered by BP in 1985, while Mercury was found by British Gas in 1983.

Eastern Trough Area Project (Etap),
The Santa Fe Monarch, performing drilling activities at the Eastern Trough Area Project (Etap).	Schematic of the Central Processing Facility structures at Etap.	Loading out of the Mungo topsides, from Methil.
Building of the SPF topsides, by AMEC, on Tyneside.	Layout schematic of the Etap fields.	The CPF jacket, under construction at Ardersier.
The polyconcorde flotel completed the Marnock hook-up.

Ekofisk II,
The Ekofisk II complex's production will be extended to the year 2050.	The Ekofisk hub is still today amongst the most important in the North Sea.	All pipelines tied to existing Ekofisk platforms will be re-routed to 2/4 J. Statpipe gas will flow via a new line to the B-11 booster platform on the Emden gas line.
The module support frame for 2/4 J's topsides 8,000t, being installed.	The second of the 2 new Ekofisk II platforms 2/4 J was installed in July 1997. The picture shows the 6,400t process module.	Abandonment and installation operations underway on the Ekofisk II project.

Elgin-Franklin,
The Elgin-Franklin wellhead platform topsides were installed, at night, in July 1999.	Drilling rigs Magellan and Galaxy 1 will continue the drilling programme through the jackets, until the topsides are lifted into place.	Santa Fe's drilling rig, Galaxy 1.
Elgin-Franklin's TPG 500 design PUQ platform was constructed in Scotland at the Barmac yard. It is similar in configuration to a traditional jack-up drilling rig, except that it is larger and there are no drilling facilities on-board.	Artist's impression of the Elgin Franklin development. The Elgin drilling platform is linked by a 100m access bridge (for piping hydrocarbons), while the Franklin platform is connected via an interfield pipeline system.	Hydrocarbon treatment on the PUQ platform.
Onshore reception facilities.	In 1995 the project partners reached agreement on a development plan comprising two wellhead platforms – one on each field – tied into a shared processing and export platform.

Erskine,
The Erskine jacket was designed by Saipem UK and built by Lewis Offshore.	The 2,720t Erskine jacket on the Saipem M-44 barge, prior to its installation in the field by the Saipem S7000 heavy-lift vessel.	The Erskine deck was installed in April 1997.
The facilities inside the topsides are adapted specially for HP/HT service.	The multiphase flow meter, made by Framo, in operation at the Erskine development.	The Erskine process module will be installed on Amoco's Lomond platform.

Ettrick Field
The Ettrick development plan includes drilling three production wells tied back to a floating production, storage and offloading vessel.	The FPSO is based on the newly built, Aframax-size FPSO hull Aoka Mizu, which is undergoing an extensive conversion programme for the project.

Frigg Field
The Frigg field is located in the North Sea.	The Frigg site is north of Stavanger.	The Frigg field is operated by Total.

Gannet,
The Sedco 704 drilling rig.	Loading of the living-quarters/helideck module onto its recess on the main topsides.	The Gannet A topsides were loaded out under the transporter bridge, at Teesside.
Installation of the subsea isolation valve.	Lifting of the Gannet A barge into position.	The Gannet A platform, on-stream.
Aerial view of Gannet A and the Sedco 704 drilling rig.

Gjøa Field, North Sea Northern
Statoil's Gjøa field lies in blocks 35/9 and 36/7 of the North Sea.	The Gjøa field will be developed with a floating production platform.	Statoil awarded a three-year $427m drilling contract to Transocean Offshore covering of 13 wells, with options for a further three.
The project is made viable through tying back the Hydro-operated Vega and Vega South fields back to Gjøa.

Glitne,
The production system on the Petrojarl 1 is monitored from a sophisticated control room.	Petrojarl 1 is manned by a crew of 49. The helideck has facilities to accommodate a Sikorsky S61 helicopter at the bow.	A plan view of the Petrojarl 1.
The production system and flare on Petrojarl 1.	Petrojarl 1, a Tentech 685 turret-moored FPSO, was built in 1986 in the NKK shipyard.	The situation of the Glitne field from the Norwegian coast and other Statoil concerns.

Goldeneye Gas Platform,
Location map.	NUI platform.	Section through the reservoir.
3D map of the Goldeneye reservoir.	Artist’s impression of the jack-up over the platform.	Production schedule.
Reception facilities at St Fergus.

Goliat
The Goliat platform will be equipped with a gas turbine with heat recovery and recycling to provide the necessary process heat.	The Goliat field is located in production licence 229, in the Barents Sea.

Gullfaks,
Installing the modules on Gullfaks A.	Processing takes place on the Gullfaks A platform.	Installation of a HOST template on the Gullfaks satellite field. The Gullfaks satellites project includes the recovery of oil/condensate from Gullfaks South, Rimfaks and Gullveig.
Artist's impression of the field layout.	Monitoring takes place from the control room.	The flowline bundle.
Installation of the process equipment.

Hanze F2A,
Location map of the Hanze field.	Transportation of the Hanze GBS by the Mighty Servant 3.	Installation of the GBS.
The GBS installed.	Schematis of the tanker offloading system.	The IPD topsides were transported to Rotterdam by the Mighty Servant 1.

Harding Area Gas Project, North Sea
The original project called for a new gas processing platform, which was to be bridge-linked to the existing Harding platform.	The Harding field is located 200 miles north-east of Aberdeen in the BP-operated block 9/23b, in 110m of water.	Gas flaring in the North Sea. Currently the Harding platform uses part of the gas as fuel gas and the remainder to provide lift in the wells.
The shuttle tanker Gerd Knutsen in dry dock in Brest. Shuttle tankers collect oil from the Harding field via a submerged turret loading buoy.	LNG carrier British Trader returns to Aberdeen. The necessary offshore storage is provided within the concrete Gravity Base / storage Tank (GBT), which has a holding capacity of 580,000 barrels.	Crude from the Harding field is heavy and naphthenic, making it of lower value than some North Sea crudes and leading to the decision to export it by tanker rather than co-mingle it in a pipeline.

Jacky Oil Field
The Jacky production well after installation.	Beatrice Platforms seen from the Galaxy II in the Jacky field.	The Jacky reservoir occurs in the Beatrice A sands, a mid-Jurassic sandstone formation more than 2,000m below the surface.

Jade Oil and Gas Platform,
The Jade topsides were constructed in Hartlepool.	The Jade jacket was manufactured at Methil, by Kvaerner.	The cables in the telecomms room.
A crane cab was installed, as well as an emergency generator.	Wellhead hydraulic pipework.	The main control panel.

Janice,
The West Royal was converted from a semi-submersible accomodation vessel to an FPU especially for the Janice project.	The development of the field is being carried out by the FPU Janice A. This is based on the Aker H3.2 semisubmersible vessel, previously known as the West Royal, purchased from Smedvig by the co-venturers.	The Janice A FPU (left) with the Ramform Banff alongside (right), at Aker McNulty Limited.
Processing equipment was installed on Janice A.	The West Royal semisubmersible, undergoing conversion alongside the Northern Producer.	The converted vessel at Teesside.

Jotun,
Jotun is located on the Utsira High between the Balder and Heimdal fields, approximately 200km west of Stavanger. Average water depth in the field area is 126m.	Jotun will be developed by a wellhead platform, tied back to a floating production vessel. Oil will be exported by shuttle tanker.	The wellhead platform includes an integrated deck, utility systems, wellhead systems, living quarters, a helideck and drilling facilities.
The production vessel is 233m long and 42m wide, with a production capacity of 9,000bpd and a storage capacity of 580,000 barrels.	Artist's impression of Jotun A. View as seen from the bows of the floating production vessel.	The Jotun accommodation module was loaded out in mid-1998. It can house 60 people, and includes offices and recreational rooms.

Jura Field, North Sea Northern
Fabrication commenced at Subsea 7's pipeline bundle fabrication facility at Wester site in Wick, north-east Scotland.	In October 2007 the bundle was installed at the Jura location using subsea tow technology.	The contract includes the design, fabrication and installation of the 3km long pipeline bundle system using the Controlled Depth Tow Methodology (CDTM). Cross section shown.
The towhead that will be used on the Jura field.

K5F Gas Field
Map of the K5 block.	The massive 160t subsea cover was subcontracted to engineering contractor, Isleburn.	The DSV Toisa Polaris which transported the subsea cover 400 miles to the K5F field.
The K5F project will be first worldwide implementation of an all-electrical Christmas tree.	Cameron was awarded the contract by Total E&P for the supply of the all-electric subsea production system.	The all-electric system eliminates the potential for hydraulic leaks and the issue of hydraulic-fluid disposal.

Kristin Deepwater Project,
A map of the Haltenbank area, showing the location of Kristin.	A schematic of the possible Kristin development scenario.	The rig Scarabeo 5 was used to appraise the area north of Kristin.

Leadon,
The FPSO Global Producer III, used on Leadon.	The infrastructure of the Leadon field.	Installation of the turret.
Lifting of the separator onto the vessel.	The Leadon development should come on-stream in late 2001, less than two years after the initial field discovery.	Kerr-McGee expects a peak production of approximately 50,000 barrels of oil per day, by the end of 2002.

Lukoil's Kravtsovskoye (D-6) Oil Field
The offshore ice-resistant stationary platform from which Lukoil performs production drilling at the Kravtsovskoye (D-6) field.	Lukoil has started production drilling from a stationary platform in the Baltic sea.	Drilling derrick on the Kravtsovskoye platform.
Drilling rig control room at the Kravtsovskoye field.	Power station control room on the Kravtsovskoye platform.	Rotary table of the drilling rig.
Crane operator lifting drilling equipment out of the well.

Luno Field,
The Luno field is located in the North Sea, offshore Norway.	PL 388 is operated by Lundin Petroleum, partnered with Wintershall Norge and RWE Dea Notge.	Luno field exploration proved successful, so the companies extended their discovery work to an additional area.

MacCulloch,
The MacCulloch field is in block 15/24b, 250km north-east of Aberdeen.	The field top structure diagram.	The Stena Apache pipelay ship, used on the project.
The field development schematic.	The North Sea Producer.

Magnus EOR,
Magnus map showing Swift and Magnus south.	Geological map of the Magnus field.	The control room on Magnus.
The Foinaven FPSO that produces gas for the Magnus EOR project.	The Magnus field in the North Sea.	The Schiehallion FPSO, which supplies gas to the Magnus field.

Mikkel Deepwater Project,
The Mikkel Deepwater Project lies on Halten Bank East, Norwegian Sea, and was discovered in 1987.

Mittelplate Redevelopment
The Mittelplate drilling island.	Mittelplate island has undergone major redevelopment.	Mittelplate's land station facilities.
Gas Turbines on the Mittelplate platform.	The Mittelplate drilling schematic.	Location of the island.
Sattellite image of the Mittleplate drilling platform.

Njord,
The Njord PDQ platform.	Reservoir and oil column map.	Cross section of the reservoir from A to A'.
Schematic of operations.	Location of the wells.	Examples of the well trajectories.
Production and storage units.	Investments, including drilling costs.

Norne,
Fabrication of the Norne FPSO.	The Norne 6608/10 FPSO.	The Norne FPSO on location.
Turret detail on the Norne FPSO.	The Norne FPSO vessel, prior to installation of the topsides.	Four well template. The templates in each group are positioned so that the rig can enter all the slots without the need for anchor handling.

North West Hutton Field
The North West Hutton field and the platform are located 130km north-east of the Shetland Islands.	The North West Hutton platform is the only integrated oil and gas drilling, production processing and accommodation facility on the field.	The topsides of the platform included 21 modules and seven caissons weighing about 20,000t.
The jacket on which the platform rests weighs about 17,500t including the weight of the piles above the seabed.	Decommissioning works are under progress at the North West Hutton field.

Nuggets,
The Nuggets manifold was tied back to the North Alwyn complex by a 40km, 12in pipeline and a 3in MEG line.	The CSO Constructor began installation in mid-2001.	The Nuggets manifold is controlled from the Dunbar platform.
Trenching support is provided by the Normand Pioneer.	The Normand Pioneer used the multipass plough.	CSO Apache was used to lay the pipe.

Ormen Lange,
Map of the licence area showing the bathymetry.	The Scarabeo 5 rig was used to drill the well.	Diagram of slope and subsea options.
A spar with gas piped to a tie-in point.	A spar with gas piped to the shore.	Subsea completion to the shore.
Subsea completion to the platform, then to the shore.	3D map of the slope, showing the Storegga slide.

Oseberg Sør,
Map of the Oseberg accumulations, showing the location of Oseberg Sør.	The drilling rig and module on the Oseberg Sør platform.	The Oseberg Sør jacket ready for sailaway on the barge.
Roll up of the Oseberg Sør jacket.	Tow-out of the Oseberg topsides.	Installation of the Oseberg Sør topsides on the jacket.

Pierce,
Pierce lies in blocks 23/22a and 23/27, 280km east of Aberdeen.	The development of the field was based on Navion's 103,000t double-hull multi-shuttle tanker (MST) Berge Hugin.	The Berge Hugin has a 45,000b/d process facility and can inject gas at a rate of 100M ft³/day.
The key component of the Berge Hugin STP buoy and mooring system was supplied by APL.

Premier Oil Shelley field
Sevan Marine’s Sevan Voyageur FPSO was transported to Bergen Group’s Hanøytangen shipyard for rigging up and engineering.	The Sevan Voyageur, at 66m long and 60m wide, has a displacement of 50,000t.	The Shelley field is located on Blocks 22/2b and 22/3a in the central North Sea.

Prirazlomnoye Oilfield -
The Prirazlomnoye platform is located in an area which is ice-free for just 110 days a year.	The Prirazlomnoye topsides will be based on the former UK North Sea Hutton tension leg platform, upgraded for its new work at the FSUE Sevmash military shipyard.	Oil is transported from the Prirazlomnoye field to the Belokamenka floating platform, located 1,100km away.
Prirazlomnoye has reserves of 610 million barrels.	Map of Prirazimnoye.	Prirazimnoye reservoir section.
The 360,000t floating platform Belokamenka will be installed in an ice-free part of Kola Bay.	Oil from Prirazlomnoye will be transferred to Belokamenka by ice breaking shuttle tankers of up to 220,000t.

R Block Development,
By 1996, an agreement was reached to tie back subsea wells on Renee and Rubie.	The R Block is located approximately 200km north-east of Aberdeen.	The AH001 semisubmersible was used to produce the Renee/Rubie fields.
The field infrastructure layout, showing the R Block field development.	The Seaway Pelican, used for pipe and umbilical laying.	The Renee subsea facilities consist of a manifold and four subsea wellheads, enclosed by steel cages.
The Seaway Falcon was used for pipe and umbilical laying.

Ross,
The Bleo Holm FPSO, sailing to the Ross field.	The Bleo Holm FPSO is a double-hulled construction, with double sides, a double bottom and a bulbous bar.	The Bleo Holm topside processing system consists of the crude oil processing plant, the water-injection plant and the gas-compression plant.
The Bleo Holm FPSO swivel stack.	The Stolt Comex tie-in facilities.	The CPT unit at Ross.

Seven Oceans / Seven Seas Pipelay and Construction Vessels
The Seven Oceans vessel on its way to the Blind Faith platform.	Seven Oceans pipelay vessel at Peterhead.	Seven Oceans taking the line onto the ship.
Seven Oceans pipelay and construction vessel in port at Leith.	Seven Oceans reeling the line onto the drum.	The bridge of the Seven Oceans pipelay vessel.
The control room of the Seven Oceans offshore construction vessel.

Shearwater,
Shearwater lies in the Central Graben area of the central North Sea.	The five high-pressure/high-temperature (HP/HT) development wells are being drilled using the jack-up, Maersk Endurer.	Artist's impression of the field development.
The latest technology is being used in a novel flare tip to reduce emissions.	The Shearwater hydrocarbon processing flow chart.	The Shearwater reservoir cross section.

Shtokman Gas Condensate Deposit
The Shtokman gas condensate deposit lies in the Barents Sea, in the north of Russia.	TLP and spar-type platforms are likely to be the most preferable choices of development.	Shtokman is likely to be developed with three wells.
Platform options for the Shtokman development.	Cross section through the Shtokman reservoir.

Sigyn Gas Field,
A location map of the Sigyn gas field.	The Sleipner A platform, which will house the reception facilities.

Siri,
The Siri platform at the hook-up and commissioning stage.	A view of the Siri hull.	Siri alongside the drilling rig Noble George Sauvageau.
A view of the Siri hull and tank.	A view of the Siri hull.	The installation of the separation module.
Siri alongside the drilling rig Noble George Sauvageau.	The Siri hull measures 50x60m and is 6.7m high.

Skarv and Idun Fields, North Sea Northern
Skarv field development schematic.	Skarv field layout.	FSPO for the development of the oil.
Map showing the location of the Skarv field.	Skarv reservoir map.	Seabed topography of the Skarv and Idun fields.

Skinfaks Development and Rimfaks Expansion Project
The Skinfaks development and Rimfaks expansion.	Map showing the location of the Skinfaks and Rimfaks developments.	The Rimfaks installation.
Skinfaks subsea equipment.	Subsea equipment being installed.	The Skinfaks installation.

Snøhvit Gas Field,
Map of the Snøhvit area.	Map showing the pipeline from Snøhvit.	Preparing for drilling on Snøhvit.
A line will take the Snøhvit wellstream to the landfill.	Artist’s impression of the Snøhvit pipeline route.	The facilities at Melkøya.
The Snøhvit barge.	The subsea facilities on Snøhvit.

Snorre,
Artists impression of the Snorre B topsides.	Artists impression of the drilling/production system.	Anchoring points of the Snorre A tethers.
Production facilities comprise a steel tension-leg platform (TLP).	The Snorre development is based on 46 oil wells - 36 will be drilled from the TLP.	The Snorre TLP in production.
The Snorre B floating production system on Norsk Hydro's field.

South Arne,
The Maersk Giant, conducting testing operations on the South Arne field.	The Castoro Sei was used to lay the 285km export pipeline.	The top of the concrete column leg of the South Arne field platform.
Construction of the South Arne storage unit and concrete leg.	Construction of the South Arne platform topsides.	A view of the internal fabrication of the South Arne platform leg support.

Tordis IOR Project
Layout of the Tordis improved oil recovery project.	Tordis IOR scope of supply.	The Tordis discoveries have all been developed with subsea installations tied back to the Gullfaks C platform.
The subsea separation station is equipped with two multiphase flow meters.	A Tordis subsea module with over-trawlable guard.	A protected Tordis IOR subsea module.

Triton,
The Triton fields lie in the North Sea, 190km east of Aberdeen.	The new-build double-hull tanker was built in Korea, then modified in the Sembawang shipyard, in Singapore.	Map of Triton, in relation to the surrounding fields.
The FPSO is a double-hull tanker. This will be located in block 21/30.	Field development schematic, showing the position of the FPSO over the two clusters.

Troll West,
The Troll West oil-production facilities.	The Troll C platform substructure.	The Troll B field development plan.
The Troll B semisubmersible.	The riser system on Troll B.	Troll B has been used to produce oil from the oil province and the southern part of the gas province.
The Castoro SEI unit will be used for the Troll II pipeline.

Tyrihans, Norwegian Sea,
Tyrihans is located on the Haltenbank in the Norwegian Sea, 35km southeast of the Kristin field in roughly 285m of water.	An electrically heated pipeline will link Tyrihans with the Kristin platform.	Condensate and crude will be combined with Kristin output after stabilisation and piped to the Åsgard C storage ship.
Tyrihans will be developed by a total of 12 wells connected to five subsea templates.	Plateau production for gas is expected to be about 13 million m³/d, while plateau production for liquid is expected to be 13,000m³/d.

Valhall Flank Water Injection Platform,
Plan of Valhall flank platform.	Valhall flank jacket installed.	Valhall flank topsides.
Vallhall water injection field plan.	Vallhall water injection topsides.	Water injection is expected to improve the oil recovery factor from 31% to 38%.
The platform configuration allows for drilling and maintenance of wells on the new platform and on the existing WP platform.

Victoria Field
West Phoenix, a semi-submersible rig, drilled the Victoria well to a depth of 5,664m below sea level.	The PL 211 licence, including the Victoria discovery, is located in the Norwegian Sea, 200km offshore and in water depths of 400m.	The Bella Donna prospect was drilled with semi-submersible installation West Alpha

Viking B,
The platform Viking KD in block 49/12a produces the F and Fs reservoirs.	Running in parallel with Phoenix was a project to modernise and automate the Viking B complex, with the aim of improving its safety, reliability and cost effectiveness.	Computer-generated image of the Viking Phoenix reservoir.
Two normally unmanned six-slot installations, linked to the Viking B complex, were planned so as to develop the reserves.	At Viking B, gas from the new and existing reservoirs is processed in a new purpose-built triplex module, to separate the liquids.

Visund,
Located roughly 140km west of the Sogne Fjord, Visund comprises four reservoirs. It lies in licence 120, blocks 34/7 and 34/8.	The Visund semisubmersible substructure and deck, ready for mating at UOG's yard, in Haugesund.	Mating transportation for the semisubmersible.
Mating the substructure and the topside took one week.	The semisubmersible platform measures 120m in length, 95m in width and is 48m high up to the upper deck (146m to the top of the tower).	For the platform mooring, one socket is equipped with stiffener anodes and rigging equipment.

Vixen,
The Vixen infrastructure is in block 49/17.	The jack-up rig Ensco 80 was used to drill the sidetrack well.	The CSO Wellservicer diving vessel was used to install the WHPS and the piles.
The Vixen subsea tree.	The wellhead structure during assembly. One of the piles is in the foreground.	The Apache installed the pipeline and the umbilical.

West Don Oil Field
Stratic owns a 17.25% stake in the West Don field.	The West Don oil field was discovered in 1975 by Burmah Oil.	The oil gravity of the West Don field is 34°API.
Development drilling commenced on West Don in 2008 and was complete by 2009.

Browse Projects