West Alpha (North Atlantic Drilling AS) (Semisub)

Rosneft spuds Kara Sea well

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09 August 2014

Rosneft and ExxonMobil joint venture company Karmorneftegaz began drilling at Universitetskaya-1, the Russian Federation's northernmost well using the ‘West Alpha’ rig. The signal to begin drilling was given by Russian President Vladimir Putin in a video link to the Kara Sea with the head of Rosneft Igor Sechin and the head of ExxonMobil Russia Glenn Waller. Special representative of President of the Russian Federation on international cooperation in the Arctic and Antarctic Artur Chilingarov and North Atlantic Drilling representative Jan Tore Theimann also took part in the ceremony. “The start of exploratory drilling in the Kara Sea is the most important event of the year for the global oil and gas industry. As a result of this work we hope to discover a new Kara Sea oil-bearing province. Developing of the Arctic shelf has a huge multiplicative effect on the whole Russian economy” – said Igor Sechin. The ‘West Alpha’ rig was provided by the Norwegian company North Atlantic Drilling which signed long-term agreements with Rosneft on 30th July 2014 for the offshore drilling. ‘West Alpha’ was transported via the Barents, Pechora and Kara Seas and installed on the drilling site of the East Prinovozemelskiy-1 Licence Area in the Kara Sea. The drilling rig made the way of over 1,900 nautical miles to reach its destination. The rig is 30,700 tons in deadweight, 70 m long, 66 m wide, the derrick hangs 108.5 meters over the main deck, and it drafts during drilling for 21.5 m. The rig is held on the drilling site by an 8-anchor positioning system, which provides advanced stability for the rig. Most of the platform is outside the reach of waves, which are no impediment for the rig's operation. The drilling will continue for two months.

Source: http://www.rosneft.com/news/today/09082014.html


More News for Operator: North Atlantic Drilling AS

1 Jul 2013

North Atlantic Drilling completes sale and leaseback of newbuild jackup

North Atlantic Drilling (NADL) today announced that the company has completed the sale and leaseback of the company’s newbuild ‘West Linus’ jackup rig in deal struck with Ship Finance International Limited, another company owned by NADL’s majority shareholder John Fredriksen. The total deal is worth US$600 million, with the ‘West Linus’ being chartered by NADL for an initial 15 year term beginning from the delivery of the unit from the yard. NADL will also have the option to buy the unit back for a set price of US$380 million after the first five years of operation. The unit will continue to be recognised as an asset of NADL’s balance sheet instead of Ship Finance’s.

8 Nov 2013

Faroe Petroleum sublets 'West Navigator' drillship to drill Novus prospect

The Norwegian Petroleum Directorate has granted Faroe Petroleum Norge AS a drilling permit for well 6507/10-2 S, cf. Section 8 of the Resource Management Regulations. Well 6507/10-2 S will be drilled from the West Navigator drilling facility at position 65°12'48.46'' north and 7°16'59.03'' east. The drilling programme for well 6507/10-2 S concerns drilling of a wildcat well in production licence 645. Faroe Petroleum Norge AS is the operator with an ownership interest of 50 per cent. The other licensees are Centrica Resources (Norge) AS (40 per cent), Skagen44 AS (5 per cent) and Concedo ASA (5 per cent). The area in this licence consists of parts of blocks 6507/7 and 6507/10. The well will be drilled approx. 14 kilometres south of Heidrun. Production licence 645 was awarded on 3 February 2012 (APA 2011). This is the first well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by the authorities prior to commencing the drilling activity.

28 Jan 2014

Faroe Petroleum close to completing Novus well in Norwegian Sea

Faroe Petroleum Norge AS, operator of production licence 645, is about to complete drilling of wildcat well 6507/10-2 S. The well was drilled about 13 kilometres south of the Heidrun platform. The primary exploration target for the well was to prove petroleum in Middle Jurassic reservoir rocks (Garn and Ile formations). The secondary exploration target was to prove petroleum in Lower Jurassic reservoir rocks (Tilje formation). An approx. 12.5-metre oil column and approx. 12-metre gas column were encountered in the Garn formation, with thicker reservoir rocks and better reservoir quality than expected. The lower part of the Garn formation is aquiferous. Preliminary estimation of the size of the discovery is between 1 and 2.5 million Sm3 of recoverable oil equivalents. The other exploration targets in the Ile and Tilje formations are aquiferous. Further delineation of the discovery will be considered. The well was not formation tested, but extensive data acquisition and sampling have been carried out. This is the first exploration well in production licence 645. The licence was awarded in APA 2011. The well was drilled to a vertical depth of 2957 metres below the sea surface, and was terminated in the Åre formation in the Lower Jurassic. Water depth is 298 metres. The well will now be permanently plugged and abandoned. Well 6507/10-2 S was drilled by West Navigator which will continue working on contract for Norske Shell AS on the Ormen Lange field.

30 Nov 2007

NOIL Energy ASA: delineation of oil discovery in the North Sea

Det norske oljeselskap ASA (`DETNOR`) announces that the Ragnarock well 16/2-4 is at TD of 2000 m below sea level. Det norske oljeselskap`s affiliate, NOIL Energy ASA, holds a 30% interest in the 265 license. The current evaluation indicates considerable hydrocarbon volumes with a high uncertainty in recovery factor. A series of mini-DST well tests were conducted, which confirmed limited flow potential in the chalk reservoir. Oil and gas were also proven in low permeable crystalline basement. The main purpose of the well was to prove the extent of the moveable hydrocarbons and evaluate productivity within the chalk reservoir. More detailed evaluations are necessary to confirm the potential of Ragnarock and if commercial volumes can be produced. This well is located 35 km east of the Gudrun Field and was drilled with the West Epsilon jack-up rig. The water depth in the area is 113 metres. The partners in PL 265 are StatoilHydro ASA (30% and operator), NOIL Energy ASA (30%), Petoro AS (30%), and Talisman Energy Norge AS (10%).

14 Nov 2008

Well spudding on Fulla

Drilling operations at the Fulla Field started 12 November. The field is operated by StatoilHydro, and Det norske has a 15 percent interest in the license. Fulla is located in licenses 035 and 362, and the drilling operations are carried out by the semi-submersible rig West Alpha. The recoverable volumes are estimated at 63 MBOE (P50), while Det norske`s share is 11 MBOE. Oil, gas, and condensate are expected.The drilling operation is expected to last about 80 days. The water depth on Fulla is 114 meters. The nearest installation is Heimdal, located 36 kilometers away. The well, 30/11-7, has a reservoir of late Jurassic age in the Brent formation.

5 Feb 2009

Discovery at Fulla

StatoilHydro has made a gas and condensate discovery in North Sea license 035b on the Fulla prospect with well 30/11-7. Det norske oljeselskap ASA has an ownership stake of 15 percent in the license. The well is located about 40 kilometers north of the Heimdal Field. The well encountered gas and condensate in Middle Jurassic reservoir rocks of the lower Brent Group. Testing and extensive data sampling has been carried out. Proven volumes are estimated between one and three million standard cubic metres of oil equivalents (6 to 19 million boe). An appraisal well is being planned drilled in the spring to help decide the size of the discovery. It is positive that hydrocarbons have been proven in this area, Det norske Vice President for reserves and area development Odd Ragnar Heum noted. The well was drilled to a vertical depth of 4067 meters below the seabed and ended in rocks of Lower Jurassic age. Water depth in the area is 111 meters. The well, which was drilled on a cost sharing basis between license 035b and 362, is currently being temporarily plugged and abandoned. Det norske holds a 15 percent stake also in license 362.

24 Feb 2009

Well spudding on Ragnarrock

Drilling operations at the Ragnarrock field in Production License 265 started February 22nd 2009. The well 16/2-5 is in proximity to the recent discoveries at the Ragnarrock field in the wells 16/2-3 and -4. The drilling operation is carried out wih the jack-up West Epsilon. StatoilHydro is operator and Det norske holds a 20 percent interest in the license. The result of the drilling will be anounced by NPD.

13 May 2009

Encouraging gas discovery in Ragnarrock Graben

Det norske oljeselskap (DETNOR) has made an encouraging gas discovery in exploration well 16/2-5 in PL 265 on the Ragnarrock Graben prospect. Preliminary analyses indicate that the gas discovery in Graben could be connected to the previous gas discovery made in basement in well 16/2-4. If this is correct, the chances are good that the necessary volumes for a viable development are present. A full scale production test was carried out in the gas zone with maximum production of 120 000 scm per day, or 750 boepd, plus some condensate. The reservoir is however complex and consist of conglomerate from the pre Cretaceous. The production could thus vary considerably in different parts of the reservoir. An additional well is planned drilled in PL 265 and may offer additional information about the gas potential and flow rates in the basement. The information gathered so far indicates that there are considerable amounts of gas present in the license (Basement north and Graben). However, the reservoirs are challenging and more geological and technical work is necessary in order to mature an economical viable development. Det norske see the results from the well as positive for further development of the resources in PL 265. The gas discovery in 16/2-5 increases the probability that gas is present also in the southern part of basement (Basement south). This is the fourth exploration well in Production License 265. The well was drilled to a vertical depth of 2,324 meters below sea level and into the basement. The water depth is 109 meter. Well 16/2-5 was drilled with the drilling facility West Epsilon, which will now sail to the Sleipner Field in PL 025 in the North Sea.

5 Apr 2001

West Epsilon leaving Sleipner

The work of moving the drilling rig West Epsilon from Sleipner West in the North Sea to the Elf operated Frøy field in the Frigg area has begun. Statoil will sublease the rig, which has finished drilling the production wells on Sleipner West. The contract with Elf is for 280 days. There then remains about one year of the hire contract with rig owner Smedvig. West Epsilon has been specially adapted to operate on the well head platform Sleipner B on the Sleipner West field. Before the rig leaves the field, the derrick will be skidded back from Sleipner B on to West Epsilon. The rig will then be jacked down to sea level. The legs will be released from the seabed before the rig is towed ashore by two tugs. Both operations set strict requirements to weather conditions. On land, the rig will be prepared for the assignment on the Frøy field, which has a similar well head platform to Sleipner West. Statoil will carry out an turnaround on both Sleipner West and Sleipner East when West Epsilon is moved. The turnaround came into effect on Saturday 31 March. According to installation manager Einar Holmemo on Sleipner A, it will last eight days on Sleipner East (the A platform) and nine days on Sleipner West (T and B platforms). One of the major tasks is to replace the flare nozzles on the flare booms on Sleipner A and Sleipner T with new nozzles.

10 May 2001

Drilling on Gudrun

The West Alpha drilling rig has started drilling an exploration and appraisal well on the Gudrun field in the North Sea. “The purpose is to prove sufficient amounts of oil, gas and condensate to develop the Gudrun find,” says Lars Jan Jaarvik, exploration manager for the Troll/Sleipner area. The find has been localised in block 15/3, about 45 kilometres north of the Sleipner East field. Gudrun was found through two exploration wells drilled in 1975 and 1979, when oil, gas and condensate were proven. The reservoir turned out to be complicated with high pressure and high temperature, and the reserves were not sufficiently quantified. Well 15/3-7 is a project in cooperation between the licensees in production licences 025 and 187. Statoil is the operator in PL 025, and is also operator for the drilling. BP has joined as a new partner in PL 025 and it is also the operator in PL 187. The well is to be drilled to a total depth of 4,800 metres. Middle and Upper Jurassic sandstone intervals will be assessed. The operations are planned to be completed at the beginning of August. Statoil has a 46.8 per cent share in PL 025, BP has 25 per cent, TotalFinaElf has 18.2 per cent and Norsk Hydro has 10 per cent.

28 Aug 2001

Find in Gudrun well

Statoil has proven hydrocarbons in an exploration and appraisal well in the Gudrun structure in the Sleipner area of the North Sea. Well 15/3-7 was drilled in the eastern section of the structure. Hydrocarbons were encountered in Middle and Upper Jurassic sandstone intervals. The well was not production tested, but core samples were retrieved and extensive information was collected. “The results of the drilling will now be evaluated in terms of the potential reserves in Gudrun and in the rest of block 15/3,” reports Kjersti Seim, acting exploration manager for the area. Gudrun was found through two exploration wells drilled in 1975 and 1979, when oil, gas and condensate were proven. The reservoir turned out to be complicated with high pressure and high temperature, and the reserves were not sufficiently quantified. Well 15/3-7 has been a cooperation project between the licensees in production licences 025 and 187. BP is operator in 187 and Statoil in 025. Statoil has also been operator for the drilling. The licensees in licence 025 are Statoil with 46.8 per cent, BP (25 per cent), TotalFinaElf (18.2 per cent) and Norsk Hydro (10 per cent). The allocation in licence 187 is BP (25 per cent), Statoil (65 per cent) and Norsk Hydro (10 per cent).

23 Jun 2003

Spudded on Ellida

The first wildcat on Statoil’s Ellida – or Grip High – prospect in the Norwegian Sea was spudded in about 1,200 metres of water on 20 June by the West Navigator drill ship. Located in block 6405/7, allocated in May 2002 as part of Norway’s 17th offshore licensing round, it lies 60 kilometres north of Norsk Hydro’s Ormen Lange development. “We’re looking for gas in this well,” explains Kent Høgseth, exploration manager for the deepwater part of the Norwegian Sea. He adds that the wildcat is being drilled in a little-explored part of the continental shelf, and that the prospects of making a find are therefore a little uncertain. The well is expected to take 2.5 months to complete. Operator Statoil has a 30 per cent interest in production licence 281, with ConocoPhillips holding 10 per cent and Norske Shell, BP and Petoro 20 per cent apiece.

8 Dec 2004

Discovery on UKCS

ChevronTexaco has reported a significant oil and gas discovery in the Rosebank/Lochnagar structure on the UK continental shelf (UKCS), where Statoil holds a 30 per cent interest. Located on the Atlantic Margin, close to the boundary between the UKCS and the Faroese sector, this strike was made with well 213/27-1Z in 1,100 metres of water. Drilling was carried out by the West Navigator in the Faroe-Shetland Channel to a total measured depth of 3,607 metres, and completed on 30 August. No testing was done. ChevronTexaco and its partners plan to drill additional wells to appraise the size of this discovery. "We are very optimistic about the significance of this discovery to Statoil," reports Gregory Himes, vice president for global exploration for the former Soviet Union and Europe, in the International Exploration & Production business area. "We hope this discovery will lead to further exploration success in the UK and Faroes." Rosebank/Lochnagar lies in licence P1026, which embraces blocks 213/26 and 213/27. Statoil took a decision to farm into this licence in January 2004. Prior to drilling the discovery, the partnership applied for and was awarded interests in the five blocks surrounding the prospect during the 22nd round. Statoil has a 30 per cent interest in all five blocks. In addition to operator ChevronTexaco, with 40 per cent, and Statoil, partners in the licence are OMV with 20 per cent and Dong with 10 per cent.

12 Sep 2004

Hydro extends rig contract on Troll

West Venture was hired in 2000 to drill production wells on the Troll field. The development of advanced drilling and well technology has contributed to Troll Oil now being the highest oil producer on the Norwegian continental shelf, with a daily production level of around 400,000 barrels. Today Hydro produces oil from 101 wells on the Troll field, 28 of which are three-branch wells. These help have lower drilling costs and allow greater recovery of the oil reserves. Hydro is planning to have two drilling rigs in activity on Troll Oil in the near future to keep up high production and value creation from the field.

30 Apr 2004

Linerle wildcat spudded

A first exploration well has been spudded by Statoil on its Linerle prospect close to the Norne field in the Norwegian Sea today, 30 April. Located within block 6608/11 in production licence 128, this wildcat lies roughly 20 kilometres north-east of Norne. “The Linerle prospect has a potential to contain oil,” says Knut Chr Grindstad, exploration manager for the Halten/Nordland cluster. “It belongs to a sequence which also includes the Svale and Falk structures, where recoverable oil deposits have already been proven.” Being drilled from the West Navigator drill ship, the well is expected to take about 20 days to complete.

24 May 2004

Oil find in Linerle

An oil discovery has been made by Statoil in its Linerle prospect north-east of the Norne field in the Norwegian Sea. Knut Chr Grindstad, exploration manager for the Halten/Nordland cluster in Harstad, says it is too early to say anything about the volume or type of oil in the deposit. "We've previously discovered oil in the nearby Falk structure, and Linerle underpins our strategy to realise a collective development of these parts," says Mr Grindstad. But the Falk oil has a higher density than average, and preliminary analyses indicate that the oil in Linerle is also heavier. An assessment will now be made to see whether a profitable development is feasible. "And there could be more oil in this sequence of finds in the Norne area," adds Mr Grindstad. It was recently resolved to submit a plan for development and operation of Svale and Stær, two other oil discoveries near Norne. There will however still be available capacity on the Norne production ship after this development. The West Navigator drill ship began exploratory drilling on 30 April, and this was completed on 23 May. Linerle is located in block 6608/11 in production licence 128 (the Norne licence). Statoil is operator, with Eni, Hydro, Petoro and Shell/Enterprise as partners.

15 Mar 2014

New well on Alve

An appraisal well on Alve was spudded yesterday, 14 March, by operator Statoil. This small gas and condensate discovery in the Norwegian Sea lies close to the group’s Norne field. “We’re hoping to establish that the field is considerably larger than has already been proven,” explains Knut Chr Grindstad, exploration manager for the Halten/Nordland cluster. “In our view, there’s a good chance that possible additional resources in Alve will be oil.” The partners must identify more oil or gas in the discovery if they are to achieve a profitable development, he explains. Maturing and harnessing smaller fields located close to existing infrastructure is also important for Statoil, Mr Grindstad adds. The Alve well is being drilled by the West Navigator drill ship (formerly West Navion), with six weeks assigned for the operation. Once this appraisal has been completed, the vessel is due to drill a further exploration well in the Halten/Nordland area. Statoil has a 50 per cent interest in Alve. The other owners are Shell with 40 per cent and Norsk Hydro with 10 per cent.

8 Sep 2004

Selling West Navigator stake

A letter of intent has been concluded by Statoil covering the sale of its 50 per cent interest in the West Navigator deepwater drill ship to Smedvig of Stavanger. The agreed purchase price is USD 175 million. Under the agreement, Smedvig will receive Statoil’s share of cash flow from the vessel from 1 May 2004. “Ownership of mobile drilling units is not defined as part of our core business,” says project manager Arne Wyller Christensen at Statoil. “We have accordingly evaluated the sale of our interest in West Navigator, and recent market developments have helped us to secure an acceptable price for our holding.” Current charters held for the drill ship provide it with employment until the fourth quarter of 2007. The agreement is conditional on board approval.

31 Aug 2005

Charters awarded for 10 rig-years

Three rigs owned by two drilling contractors have been chartered by Statoil on behalf of a partnership which also includes Eni Norge, Norsk Hydro and Norske Shell. Confirming earlier letters of intent, these contracts relate to Smedvig’s West Alpha unit and the Transocean Arctic and Polar Pioneer vessels owned by Transocean. The three-year charter for West Alpha starts in the first quarter of 2006, and this rig will primarily be used for exploration. It is currently drilling production wells on Statoil’s Kristin development in the Norwegian Sea. Transocean Arctic has been chartered for about four years from the second half of 2006, and will be used for exploration drilling by the partners. Currently doing field drilling for Statoil on Norne and the Norne satellites in the Norwegian Sea, it is also due to work on Statoil’s Tyrihans project in the same waters. The charter for Polar Pioneer, currently drilling production wells on Statoil’s Snøhvit field in the Barents Sea, will run for about three years from the second quarter of 2006. This rig will primarily be used for exploration work on the Norwegian continental shelf, including the Barents Sea. The collaboration between the four partners is forward-looking and a milestone for operator cooperation on the NCS, according to Arne Tillerli Statoil’s manager for the partnership. He notes that these waters are currently characterised by a tight rig market for exploration and production drilling as well as for well workovers. The partnership model also represents a crucial step towards achieving the industry’s chosen solution for broad operator cooperation. This approach is supported by the Norwegian government through the Kon-Kraft industrial collaboration. “Our rig cooperation will be highly significant for exploration on the NCS over the next two-three years,” says Tim Dodson, senior vice president for NCS exploration at Statoil. “It ensures that the four companies involved have the rig capacity they need for a large part of their drilling programmes.”

22 Aug 2005

Troll oil discovery

Hydro has proven oil deposits in the Brent formation, the deeper rock types located under the oil and gas producing layers on the Troll field in the North Sea. Hydro regards the opportunities for commercial exploitation of the Brent formation oil as encouraging, given that the find is situated close to existing installations on the Troll field. A well drilled under the oil and gas producing formations on the Troll field has proved the presence of additional oil deposits in the Brent formation. Further analyses and delineation drilling must be carried out to obtain secure data regarding the expected volume of additional reserves and recovery rate. A production test of the formation will also be carried out. The well was drilled by the West Venture rig in the area northeast for Troll C platform. The find is the fourth made this year by Hydro as a Norwegian Continental Shelf operator. Previous discoveries were on the Oseberg Sør field and on the Astero and Peon prospects. Hydro currently produces oil and gas from reservoirs in the Sognefjord and Fensfjord formations. The Brent formation, known as a petroleum-bearing reservoir rock-type in other areas of the North Sea, lies 500 meters under these formations. For example, the oil and gas reserves on the Oseberg field are situated in the Brent formation. Hydro currently produces some 260,000 barrels of oil on the Troll B and Troll C platforms. By developing advanced subsea solutions, plus innovative drilling and well technology, Hydro’s petroleum technologists have managed to exploit the extremely thin oil zone on Troll. As of today, 106 production wells have been drilled, of which 36 are multilateral. The well was drilled at a depth of 341 meters and down to 2,055 meters below sea-level. The West Venture rig will now drill a new production well on Troll Oil.

15 Jun 2006

Finds on Valemon and Morvin

Gas and condensate have been proven by Statoil on Valemon near the Kvitebjørn field in the North Sea and oil has been proven on Morvin on the Halten Bank north of the Kristin field. The finds were made during drilling of appraisal wells 34/11-5S (Valemon) and 6506/11-8 (Morvin). "Developing fields near areas where we already play a leading role is essential to us," says Tim Dodson, senior vice president for the exploration cluster in the Exploration & Production Norway (UPN) business area. "Even if it is too early to determine the size of the reserves on Valemon and Morvin, these finds support the group's high ambitions for the Norwegian continental shelf." The appraisal well on Valemon was drilled from the Statoil-operated Kvitebjørn platform. With a total length of 7,380 metres this well is the longest high pressure/high temperature (HPHT) well ever drilled by the group. "This drilling operation has been highly cost-effective as the well is later to be converted to a production well for Kvitebjørn," says Astrid Sørensen, senior vice president for the Troll/Sleipner business cluster. "Field development studies of Valemon are currently being made, however, it is too early to say anything about any development of this gas/condensate find. We will look at alternatives involving a separate development and hook-up to another infrastructure," Ms Sørensen says. The appraisal well on Morvin was drilled from the West Alpha rig. "The oil find is interesting and confirms the large potential in the Halten Bank area. Morvin will most likely be developed as a satellite to the Kristin or the Åsgard field," Mr Dodson notes. The Kvitebjørn (production licence 193) licensees are Statoil with 43.55%, Petoro 30%, Hydro 15%, Enterprise Oil Norge 6.45% and Total with 5%. The Morvin licensees (production licence 134B) are Statoil with 50%, ENI 30%, Hydro 14% and total with 6%.

24 Mar 2006

Drilling on Morvin

The West Alpha rig has started drilling an appraisal well for operator Statoil in the Morvin structure in the Norwegian Sea. The drilling operation began on 24 March and is expected to take just over four months. Kjell Martin Edin, senior geologist in the Halten/Nordland area and project manager for well 6506/11-8, reports that Morvin is an oil discovery on the Halten Terrace. Morvin lies in production licence 134b, about 10 kilometres from the Statoil-operated Kristin field. Like Kristin, Morvin is challenging owing to high pressure and high temperature in the reservoir. In 2001, Statoil drilled an exploration well on Morvin and found light crude. The well where the find was made was drilled at the top of the structure. The purpose of the new well is to appraise the extent of the find and clarify whether the resources are sufficient to justify a development. "If oil is proven in the well, it is likely that Morvin will be a subsea development phased in to Kristin or Åsgard," says Mr Edin. The well is set to be drilled to a depth of about 4,800 metres below sea level. Water depth in the area is 380 metres. Statoil has a 50 per cent interest in production licence 134b. The other licensees are Eni (30), Hydro (14) and Total (6).

28 Dec 2006

Further North Sea exploration

Statoil has today, Thursday 28 December, commenced drilling of exploration well 16/4-4 on the North Sea Biotitt prospect. The drilling marks the start of a busy exploration programme for the West Epsilon rig which initially will drill four North Sea exploration wells for Statoil. "We've secured significant capacity in the North Sea over the next few years with the West Epsilon contract," says Tim Dodson, Statoil's senior vice president for exploration on the Norwegian continental shelf (NCS). In the summer, Statoil signed a contract with the Seadrill company for the chartering of the jack-up rig for three years. West Epsilon can only operate at water depths down to 128 metres. The rig has now begun drilling the first well on the Biotitt prospect, south west in block 16/4 in production licence 339, awarded in 2004. The prospect lies north east of the Sleipner West field. Statoil is operator with a 70% stake, while ExxonMobil has 30%. The well will be drilled to a total depth of around 2,400 metres. The water depth in the area is around 91 metres. Exploration drilling is expected to take 40 days with the aim of proving gas/condensate which can be produced by the Sleipner A platform. Following Biotitt drilling, the rig will continue exploration in the southern part of the North Sea. Well number two will be drilled on the Ermintrude prospect in block 15/6 in production licence 303, awarded in 2003. Following that, it will be moved to the Ragnarrock structure in production licence 265, awarded in 2001. "The four exploration wells that will initially be drilled are in areas that could yield valuable additional resources near existing infrastructure," says Mr Dodson. "The wells are an important part of Statoil's exploration programme on the NCS." West Epsilon will also drill in the "cellar" under the Statoil-operated Huldra field in production licence 051. "West Epsilon's activity is important for us in achieving our goal of producing one million barrels of oil equivalent on the NCS in 2015," says Mr Dodson.

19 Sep 2006

Duster on Antares

Exploration well 6406/3-7 has been completed by operator Statoil on the Antares prospect in production licence 314 in the Norwegian Sea without encountering mobile hydrocarbons. The group now plans to drill three further exploration wells in this part of the Halten Bank area, which lies south of the Åsgard field. Drilled from the West Alpha semi-submersible in 275 metres of water, the 6406/3-7 well was intended to probe for oil and gas in Jurassic sands. “We’re naturally disappointed that the well turned out to be dry, but it was important for clarifying the potential of this area,” says Tim Dodson, Statoil’s senior vice president for exploration on the Norwegian continental shelf. Drilled to a total depth of 4,502 metres below sea level, the well terminated in early Jurassic sediments. It has now been permanently plugged and abandoned. Mr Dodson says that the three other interesting projects available in the area are due to be drilled this year and in 2007. “These operations will be carried out in quick succession, and will be important for clarifying the potential of the area,” he reports. Since Antares lies in a different geological area from the new wells, it has no significance for the probability of discoveries with them or the estimated resources they might contain. Statoil has a 45% interest in PL 314, with Hydro holding 35% and ExxonMobil 20%. West Alpha is now due to spud an exploration well in PL 255, operated by Shell.

19 Jun 2006

Rig for Troll/Sleipner chartered

Statoil has signed a contract with the rig company Seadrill for the chartering of the West Epsilon jack-up rig from November 2006. The rig will be used for exploration and production drilling in the Troll/Sleipner area in the North Sea. ”This means that there will be full focus on further development of the Sleipner area," says Astrid Sørensen, senior vice president for the Troll/Sleipner business cluster. "The production from the Sleipner fields will be off plateau in a few years. Additional volumes will be developed and exploration for new volumes performed. West Epsilon marks a change of pace in the development of this part of the North Sea.” Under the contract with Seadrill Statoil gets to charter the rig for a total period of up to four years. The alternatives are two years of charter with an option to extend the contract for two years, or three years of charter, with an option for a one-year extension. The value of the contract is between NOK 1.5 and 2.0 billion, depending on what charter alternative Statoil goes for. West Epsilon is a jack-up rig that can operate in water depths of up up to 120 metres. Currently on assignment for BP the rig will be taken over by Statoil towards the end of the year.

14 Mar 2007

Finds at Sleipner

Operator Statoil has proven gas and condensate in the Biotitt prospect in the North Sea using the West Epsilon rig, which is now continuing its exploration programme in the area. The 16/4-4 wildcat in production licence 339 was drilled to a total depth of 2,360 metres below sea level. Drilling was halted in rocks of Cretaceous age with gas and condensate being proven in the Heimdal formation of Tertiary age. "We will assess whether to produce the find using the Sleipner platform," says Tim Dodson, Statoil's senior vice president for exploration in Exploration & Production Norway (EPN). "An evaluation and analysis of the gathered data will now be carried out to determine the find's resource potential. A joint development with the 16/7-2 find south of Biotitt could be an option. "Biotitt is a good start in a comprehensive exploration programme in the North Sea in the next few years," he says. The Biotitt find lies approximately 20 kilometres north-east of the North Sea's Sleipner field. The well will now be permanently plugged and abandoned. The well was drilled using the West Epsilon drilling rig in 91 metres of water. Statoil has a three-year contract with the Seadrill company for hire of the jack-up rig which can operate at depths of up to 120 metres. West Epsilon is now being moved to its next location which is the Ermintrude prospect in block 15/6 in production licence 303, 10 kilometres north of the Sleipner field. The licensees in exploration licence 339, awarded in 2004, are Statoil with a 70% share and ExxonMobil with 30%.

29 May 2007

http://www.statoil.com/en/NewsAndMedia/News/2007/Pages/PromisingNorthSeaFinds.aspx

Operator Statoil has made a promising oil discovery in the North Sea's Ermintrude prospect. Deposits are reckoned to be in the region of 50 million barrels of recoverable reserves. "Ermintrude can give valuable additional resources at the Sleipner area," says Tim Dodson, Statoil's senior vice president for exploration in Exploration & Production Norway (EPN). "The well is an important part of our exploration programme and can contribute to our ambition of producing one million boe per day from the Norwegian continental shelf (NCS) until 2015." Wildcat 15/6-9 S in block 15/6 lies 10 kilometres north of the Sleipner area in production licence (PL) 303. The well was drilled in a water depth of 114 metres to a total depth of 3,850 metres below sea level. Drilling was halted in rocks of Triassic age. The well was found to contain light oil in sandstones of mid-Jurassic age. A small gas find was also proven in sandstones of Tertiary age. "We will now drill a sidetrack well further up in the Ermintrude structure to establish if there is gas/condensate above the oil that has been discovered," says Mr Dodson. "A prospective development, and what solution is chosen, depends on what can be proven in the sidetrack." After its Ermintrude duties, the West Epsilon rig will continue its Sleipner area exploration programme. Statoil has a three-year contract with the Seadrill company for the hire of the jack-up rig. West Epsilon's exploration programme has so far yielded promising results, with operator Statoil proving gas and condensate in the Biotitt prospect in the Sleipner area earlier this spring. "Statoil has great faith in the NCS," says Mr Dodson. "Ermintrude shows that our NCS focus gives results." Statoil has a 100% interest in PL 303.

17 Sep 2007

New oil find in Sleipner area

A new oil discovery has been made by Statoil in the Ragnarrock prospect near the Sleipner area in the North Sea. "It is encouraging that Statoil has made an oil discovery in a little-explored exploration model that is close to our North Sea infrastructure," says Frode Fasteland, acting exploration manager for the North Sea. The find was made in exploration well 16/2-3 in production licence 265, which lies 35 kilometres east of the Statoil-operated Gudrun discovery. "The oil was proven in Cretaceous rocks with complex reservoir conditions," says Mr Fasteland. "Together with our partners in the licence we have therefore decided to drill the appraisal well 16/2-4 in the structure when the first well is completed." Statoil has carried out an extensive compilation of data and taken samples which will be analysed. The well was drilled to a total depth of 1,856 metres below sea level. The water depth in the area is 113 metres. The exploration well is now being permanently plugged and abandoned by the West Epsilon jack-up rig. This is the fifth exploration well drilled by West Epsilon for Statoil this year and hydrocarbons have been proven in all of the wells. The licensees are Statoil, operator, with 30%, Petoro (30%), Den norske Oljeselskap ASA ( 30%) and Talisman (10%).

9 Jul 2007

More Ermintrude resources found

Operator Statoil has completed the drilling of two appraisal wells at the Ermintrude find in the North Sea. Gas, condensate and oil have been proven. Wells 15/6 A and B lie in production licence 303 seven kilometres north of the Sleipner area in the North Sea's central sector. Gas and condensate in sandstones of Jurassic age have been proven in well 15/6-9 A while oil has been proven in well 15/6-9 B in the same reservoir. "The two successful appraisal wells have increased our understanding of the promising 15/6-9 S oil find, carried out in May this year, confirming its size to be eight to 12 million standard cubic metres of recoverable oil equivalent reserves," says Frode Fasteland, acting head of Norwegian continental shelf (NCS) exploration. "Around half is gas/condensate and half is oil." According to Mr Fasteland, the results are encouraging. "This reinforces our belief that Ermintrude can add valuable additional resources to the Sleipner area and will be an important contributor to our ambition of producing one million barrels of oil equivalent per day from the NCS until 2015," he says. The wells have not been production tested, but comprehensive data gathering and sampling have been carried out. Statoil will evaluate the need for further appraisal of the find and to what extent its development can be tied back to existing fields in the vicinity. Both wells were drilled by the West Epsilon drilling rig in a water depth of 114 metres to a total depth of 3,580 and 3,870 metres respectively. Drilling was halted in rocks of the late Triassic. The wells were then permanently plugged and abandoned. Statoil has a 100% interest in production licence 303. West Epsilon will now drill appraisal well 16/2-3 in the Ragnarrock structure in production licence 265.

10 Jan 2008

New drilling campaign at Sleipner West

On behalf of the licencees of Sleipner West, StatoilHydro has elected to exercise an option to commence drilling with the drilling rig West Epsilon in the North Sea field. The option has a value of NOK 620 million, and the total value of the contract now entered into with Seadrill for Sleipner West since last summer now amounts to NOK 1.18 billion. The option to use the jack-up drilling rig West Epsilon allows StatoilHydro to drill five or six new wells at Sleipner West in the period leading up to 2010. There is strong activity on the Sleipner West field, and new seismics will be shot this year. StatoilHydro is utilising advanced seismics to reduce risk and become more effective in its drilling operations. The drilling campaign can contribute to increasing remaining reserves. The initiatives being implemented mean that production at Sleipner West is expected to continue well beyond 2020.

14 Apr 2008

New discovery on the Halten Bank

StatoilHydro has made a gas discovery in the Natalia prospect in the Norwegian Sea. According to preliminary calculations the discovery could contain around 1.5 billion cubic metres of recoverable gas. Natalia is located five kilometres north-west of the Midgard structure on the Åsgard field on the Halten Bank and adds to the many finds in this area. Exploration activities in the area have so far this year given good results, such as the Natalia, Gamma and Marulk (partner-operated) finds. Positive results in Gamma and Natalia are also important contributions in evaluating the potential of equivalent structures in the area.

23 Oct 2008

Possible tie-back of Noatun to Njord

Recoverable reserves of the Noatun discovery have been estimated to be between five and eight million standard cubic metres of oil equivalent following the drilling of an appraisal well. A tie-back to the Njord field is being considered. In September gas and condensate were confirmed at Noatun, which lies 16 kilometres north of the Njord field in the Norwegian Sea. StatoilHydro is currently concluding the drilling of a sidetrack well from the original well. The purpose of the well was to confirm the size of a gas/condensate discovery in reservoir rocks of middle to lower Jurassic age. The data gathered in connection with the sidetrack drilling have confirmed recoverable volumes of between five and eight million standard cubic metres of oil equivalent according to a preliminary estimate. The well was drilled to a vertical depth of 5050 metres below sea level and was completed in the lower Jurassic Åre formation. ”The Noatun find proves that it is still possible to make considerable finds in established exploration models in this area, also at water depths of up to 5000 metres,” says Sivert Jørgenvåg, head of exploration activities close to existing fields on the Halten Bank. ”It is encouraging that we make discoveries which can prolong the lifetime of the Njord field.” The well was drilled by the semi-submersible West Alpha drilling rig, which is proceeding to the North Sea to drill the Fulla prospect.

21 May 2008

Gas discovery in the Norwegian Sea

StatoilHydro has struck gas during exploration drilling in the Norwegian Sea north-west of Kristiansund and will drill a sidetrack well to further identify the area. StatoilHydro, the operator of production licence 348, now completes the drilling of exploration well 6407/8-4 S. The well is located 30 kilometres north-east of the Njord field and 9 kilometres north-west of the Draugen field. "The purpose of the well was to confirm the existence of hydrocarbons in mid/lower Jurassic rocks in the southern segment of the Galtvort prospect. It is very positive that we again strike hydrocarbons in these areas where finds can quickly be put on stream,” says StatoilHydro’s vice president for infrastructure-led exploration in the North, Ørjan Birkeland. The well has confirmed the existence of gas in Jurassic sandstone. The size of the discovery is so far not determined, and a sidetrack well will be drilled right after the current well has been completed. . This is the first exploration well in production licence 348, which was awarded in TFO 2004 (awards in pre-defined areas). No formation leak-off test has been conducted in the well, but extensive data acquisition and sampling have been performed in the reservoir. The exploration well was drilled to a vertical depth of 2632.3 metres below the sea surface and completed in rocks belonging to the lower Jurassic Åre formation. The well, located in 266 metres of water, will now be permanently plugged and abandoned. The well was drilled by the West Alpha drilling rig, which will now drill sidetrack well 6407/8-4 A on the Galtvort prospect. The licensees in production licence 348 are: StatoilHydro (30.0 percent), Gaz de France Norge (20.0), Norwegian Energy Company (17.5), E.ON Ruhrgas Norge (17.5), Endeavour Energy Norge (7.5) and Petoro (7.5).

12 Sep 2008

Sidetrack to be drilled at Noatun prospect

Drilling of an exploration well in the Noatun prospect 16 kilometres north of the Njord field in the Norwegian Sea has struck gas and condensate. A sidetrack is to be drilled in the well to assess whether the find is worth exploiting. The objective of exploration well 6407/7-8 was to prove gas/condensate in the middle/lower Jurassic reservoirs in the Noatun prospect. The well struck gas/condensates at the prospective Jurassic range, although the size of the find is as yet unconfirmed. The well has been formation tested using mini-DST, and extensive data and samples have been collected. A flank sidetrack will be drilled to confirm gas/water contact and the size of the find. "We are delighted to have found hydrocarbons which can contribute to the extended lifetime of the Njord field, but we need more information before we can say anything about the size of the find, and any possible extraction methods," says Sivert Jørgenvåg, exploration manager for the Halten Bank. This is the eighth exploration well drilled in production licence 107. The licence was awarded during the ninth concession round in 1985. The well was drilled to a vertical depth of 5,110 metres under the sea surface, and terminated at the Åre formation in the lower Jurassic level. Sea depth is 293 metres. The well will be permanently plugged and abandoned. The well was drilled by the semi-submersible drilling rig West Alpha, which will now continue operations in production licence 107 by drilling sidetrack 6407/7-8A. Licensees for production licence 107 are: StatoilHydro (20%), E.ON Ruhrgas (30%), ExxonMobil (20%), Gaz de France (20%), Petoro (7.5%) and Endeavour Energy (2.5%).

16 Nov 2009

Interesting North Sea find

Gas and condensate have been discovered by Statoil in the Beta West prospect, 1.5 kilometres from the main Sleipner West reservoir. Resources in the find, which lies four kilometres west of Sleipner B, are currently estimated at 37-63 million recoverable barrels of oil equivalent (six to 10 million standard cubic metres oe). “This discovery strengthens our prospects for finding more resources in the immediate vicinity of Sleipner West,” says Tom Dreyer, head of infrastructure-led exploration in the North Sea. Edvin B Ytredal, Statoil’s operations vice president for the Sleipner area, is very satisfied both with the discovery and with the opportunities it represents for Sleipner West. “Production from this field is coming of plateau, but the newly discovered resources mean that its future prospects are substantially brighter,” he says. Located in 108 metres of water, the well was drilled from the West Epsilon rig to a vertical depth of 3,760 metres beneath sea level. Hydrocarbons were encountered in a sandstone unit belonging to the Hugin formation.

30 Apr 2009

Gas condensate find at Veslefrikk

A small gas condensate discovery has been made by StatoilHydro in the Canon prospect, about 11 kilometres west of the Veslefrikk field in the North Sea. The purpose of the exploration well was to prove petroleum in a fault block between the Huldra and Oseberg fields. The well tested two reservoir levels – an upper one belonging to the Brent group and a deeper level in the Statfjord group. "The exploration well struck gas condensate in the Brent group but the reservoir was thinner than expected and the find is probably not commercial," says Tom Dreyer, StatoilHydro's vice president for infrastructure exploration in the North Sea. Deeper in the structure, the well struck sandstone belonging to the Statfjord group. Data gathered from this interval showed that the reservoir consisted of tight sand and was probably full of water. Drilled by the West Alpha semi-submersible, the well will now be permanently plugged and abandoned. The rig's charter with StatoilHydro will terminate once the well is completed. This is the second well to be tested in the Canon structure. An exploration well drilled in 2000 provided inconclusive results about the economic potential of the structure. The licensees in production licence 052 are: operator StatoilHydro (18%), Petoro (37.0%), RWE Dea Norge (13.5%), Revus Energy (4.5%) and Talisman Resources Norge (27.0%).

13 May 2009

New North Sea discovery

More oil and gas have been discovered by StatoilHydro with an exploration well drilled about 35 kilometres east of Gudrun in the North Sea and roughly 30 kilometres south of Grane. Gas and oil with associated condensate were found in rocks interpreted to be Jurassic or Triassic/Permian. An exploration well proved gas and oil about 6.5 kilometres further north in the autumn of 2007, and the latest discovery probably forms part of the same hydrocarbon system. Preliminary estimates put total recoverable gas resources in these two finds at three to 10 billion standard cubic metres (scm). More detailed studies of collected well data will be needed to evaluate the resources and determine further activity around the discovery. “This represents a new and exciting play,” comments Noralf Steinsland, StatoilHydro’s licence manager for the North Sea. “It increases opportunities for further discoveries in a mature area where we have strengthened our position through new licences and farm-ins.” The discovery well was drilled from the West Epsilon rig to a vertical depth of 2,324 metres beneath the sea surface, in waters 109 metres deep. It will now be permanently plugged and abandoned. In addition to StatoilHydro, with a 40% holding, the partners in production licence 265 are Petoro with 30%, Det Norske Oljeselskap with 20% and Talisman Energy Norway with 10%.

6 Apr 2010

Extending Seadrill rig contract

Statoil has offered Seadrill a new five-year contract for the use of the West Venture rig on the Norwegian continental shelf (NCS). The contract is worth about USD 712 million. “This contract will be important in ensuring that we are able to reach our production targets,” says Geir Slora, Statoil’s senior vice president for drilling and wells. Plans call for the contract to take effect from 1 August 2010, one year before the present contract for Statoil’s use of this rig expires. Under the terms of the new contract, the rig will be used by Statoil until August 2015. Statoil has the option up until January 2011 to extend the contract by a further one or two years at the same rig price. Rig capacity needed Statoil aims to maintain its present production level on the NCS for the next 10 years. Enhanced recovery from existing fields, quick and efficient development of new fields and an active exploration programme are the key measures for achieving this goal. To effectuate these measures, it is crucial that rig capacity is available. The new contract means that Statoil will not exercise the one-year extension option in the existing contract. “We are well pleased with the terms of the agreement and we see that the prices in the rig market are now at a more normal level,” says Anders Opedal, Statoil’s senior vice president for procurement. West Venture is a semi-submersible fifth-generation rig. It has been in operation for Statoil on the Troll field in the North Sea since it was built in 2000.

17 Mar 2010

New rig contracts signe

Statoil has awarded a contract to Dolphin AS and a letter of intent to Seadrill for two rigs which will operate on the Norwegian continental shelf (NCS). The Bideford Dolphin rig has won a three-year contract with start-up from 27 January 2011. The contract is worth about USD 421 million. Statoil has an option to extend the contract from three to four years by 1 November 2010. The value of the contract will then increase to about USD 553 million. Dolphin AS is a wholly-owned subsidiary of Fred Olsen Energy ASA. Seadrill’s West Epsilon rig has been awarded a letter of intent for a four-year contract to take effect on 29 December 2010. This contract is worth about USD 394 million. The agreement is conditional on partner approval. Statoil can extend the contract period to five or six years before 1 October 2010. There will also be an option to extend the contract for an additional two years. Both rigs are working for Statoil at present. “We have great expectations that these rigs will continue their improvement efforts in health, safety and the environment and in drilling operations,” says Geir Slora, senior vice president for drilling and wells in Exploration & Production Norway. Before the global economic problems took full effect Statoil found that the rig rates had increased too much, and they did not decrease correspondingly when the market circumstances changed. Anders Opedal, senior vice president for procurement in Projects & Procurement, says that the rig rates are now at a more sustainable level. “We see that the cost level for rig charter is better adapted to the current market situation and we look forward to continuing cooperation with the two rigs,” says Opedal. “They will play an important part in helping us reach out production targets for the NCS in the next few years.”

28 Sep 2011

All go for Gudrun drilling

The Gudrun project is reaching new milestones, with the West Epsilon rig busy drilling wells that need to be ready for production start in 2014. “The Gudrun field is characterised by high pressure and high temperature,” says Petter Kostøl, who is in charge of drilling and well operations in Stavanger. All seven production wells planned for the Gudrun field will be pre-drilled through the jacket before the topside is installed in 2013. Work commenced on the first well on 6 September. “Due to the field characteristics we have to pre-drill all wells before we start the actual production,” says Kostøl. “With this concept we have chosen a robust well strategy.” Production in 2014 The background for this strategy is not least to avoid depletion problems, which means reservoir depressurisation that would complicate further drilling. “This stepwise and repeated drilling operation leads to a more rational use of equipment and resources,” says drilling superintendent Nils Petter Norheim. “The result is improved learning and safety as well as higher efficiency.” Drilling through the jacket will continue for two years until the summer of 2013. Then the topside will be installed on the Gudrun platform, and the pre-drilled wells will be completed and prepared for production. The entire drilling programme will stretch into 2014, with plans calling for oil and gas production to start in the first quarter of 2014. In addition to the seven wells on Gudrun, an effort is currently being made to obtain approval for the drilling of a production well on the Brynhild discovery. “While the Gudrun project has been able to build on drilling experience from the Kristin, Morvin and Kvitebjørn high-pressure fields, the experience from Gudrun may be useful during the engineering and development of the Valemon field,” indicates Jan Einar Malmin, head of the Gudrun field development project. Like Gudrun, the Valemon field also has high pressure and high temperature, and production from this field is also scheduled for start-up in 2014.

3 Jan 2012

West Alpha returns to Ølensvåg

Westcon Yard has received a Letter of Intent from North Atlantic Drilling (a company partially owned by Seadrill) for work on the submersible rig West Alpha, in the third quarter of 2012. The work includes intermediate inspection and various modification works to prepare the rig for a new contract with ExxonMobil on the Balder field. West Alpha will bore two wells, a job which has an anticipated value of US$100 million, and will have an option for drilling a further four wells.

13 Oct 2011

Giant rig West Elara arrives in Ølensvåg

One of the world's largest jack-up rigs has arrived at Westcon Yard in Ølen. New rig West Elara arrived in the fjord last Wednesday loaded on cargo vessel Mighty Servant 1. It is planned that the rig will be at the yard for six weeks, informed Project Manager Rolf Eikemo. The new build has taken two months in transit from Singapore to Ølen. The rig arrived as planned last Wednesday, and by Sunday was ready for work to begin. The rig is owned by North Atlantic Drilling, that is a company which Seadrill have a 75% ownership. "Seadrill is a company that returns to the yard time and again, and with whom we have a long and close working relationship", says Rolf Eikemo. The main tasks for Westcon Yard will be completion and preparation for working in the North Sea. West Elara enters into a contact with Statoil at the end of November.

11 Feb 2011

West Alpha arrives at Westcon

West Alpha arrived at Westcon on the 7th of February; it was also in for a major yard stay in autumn 2009. The main job this time will be to install third party equipment required for the rig’s next task which is involves the drilling and completion of well 6507/3-L-4 AH on the Alve field and the intervention of well. While this work is in progress there will also be a new Gantry Crane installed in addition to various minor works. The rig is expected to remain in the yard for a period of one week.

13 Jun 2014

'West Linus' unit compliant in Norway

North Atlantic Drilling Limited’s (NADL) jack-up rig ‘West Linus’ has received the Petroleum Safety Authority Norway's Acknowledgement of Compliance (AoC). ‘West Linus’ and relevant parts of NADL Management AS’s organisation and management systems are considered to be in compliance with relevant regulatory requirements for petroleum activities. The validity of this Acknowledgement of Compliance assumes that NADL ensures that the facility and relevant parts of the company’s organisation and management systems are maintained, so to fulfil terms and conditions set out in the PSA’s decision.

30 Jul 2014

Rosneft contracts a number of rigs from NADL

North Atlantic Drilling Ltd. (NADL) has announced the signing of six binding offshore contracts with Rosneft Oil Company (Rosneft). The total revenue potential for the six contracts exclusive of mobilization is approximately USD4.25 billion. According to the agreement, any break rights expire after 100 days. The executed contracts include five year contracts for the ‘West Navigator’, the ‘West Rigel’, the ‘West Alpha’, two newbuild CJ-54 class rigs, and a 2.5 year contract for Northern Offshores ‘Energy Endeavour’ Gusto class jackup rig. These contracts commence in Russian waters from 2015 through 2017. These binding contracts are consistent with the provisions of the Investment and Cooperation Agreement between Seadrill, NADL and Rosneft announced on May 24th, 2014. The ‘West Alpha’ is already in Russia and is drilling for ExxonMobil under its partnership with Rosneft. The two CJ-54 newbuild jackups are yet to be identified, the only two units currently being built to this specification are being constructed for Malta Oil & Gas Ltd at Drydocks World in Dubai and it has not been confirmed whether or not NADL has struck a deal to buy these newbuilds.

8 Aug 2014

'West Linus' lined up to complete wells on Ekofisk

ConocoPhillips Skandinavia AS (COPSAS) has received consent to use the ‘West Linus’ jack-up drilling facility for drilling and completion of wells at Ekofisk 2/4-ZZ. The Ekofisk field was discovered in 1969 and is the oldest of the oil and gas fields in production on the Norwegian Continental Shelf. The field is situated around 280 km south-west of Stavanger. Water depth is around 73 metres. West Linus received Acknowledgement of Compliance on 25 May 2014.

8 Aug 2014

Centrica set to use 'West Navigator' to drill Ivory prospect

Centrica Resources (Norge) AS has received consent for exploration drilling using the ‘West Navigator’ mobile drilling facility to drill well 6707/10-3 S, in production licences 528 and 528 B. The well is in the Norwegian Sea, around 293 km from Brønnøysund and 20 km from the Aasta Hansteen field. Water depth at the site is approx. 280 metres. Drilling is planned to begin in August 2014, with a duration of around 78 days, depending on whether a discovery is made. ‘West Navigator’ is owned and operated by North Atlantic Norway Limited. The facility received Acknowledgement of Compliance (AoC) in September 2000.

29 Sep 2014

Rosneft announces discovery with Universitetskaya-1 well

Rosneft successfully completed the drilling of the northernmost well in the world – the Universitetskaya-1 well in the Arctic. According to the results of the drilling Rosneft has made an oil discovery at the East-Prinovozemelskiy-1 license area. The drilling was completed in record-breaking time - in one and a half month - in compliance with all the technological and ecological standards and requirements. The sea depth at the drilling site is 81 m, the depth of the straight well – 2,113 m. the well was drilled in open-water conditions – at the 74th circle of longitude, 250 km clear off the inland of the Russian Federation. As a result of the drilling formation samples were obtained, a pilot borehole was drilled (diameter 8.5 inches to a depth of 600 m) and horizontal drill samples were collected. Specialists obtained substantial amount of new geological data which will be elaborated. Upon the completion of the analysis a conclusion on the resource base of the discovered field can be made. At the moment the geological data interpretation is being conducted, the field’s development model is being elaborated. The security and fail-safety of the operations of future drilling is guaranteed by the landing of 5 columns. The Universitetskaya structure covers an area of 1,200 thousand kilometers with a 550 m high hydrocarbon trap. Its resources account to more than 1.3 billion tons of oil equivalent. A total of some 30 structures were found in three East Prinovozemelskiy areas of the Kara Sea, and the entire resource base of the three areas is estimated at 87 billion barrels or 13 billion tonnes of oil equivalent. According to experts the volume of the Kara Sea oil province resources exceeds the oil and gas resources the Gulf of Mexico, the Brazilian shelf, the shelf of Alaska and Canada, and it will be comparable to the resource base of Saudi Arabia. Prior to the start of operations in the Kara Sea the ‘West Alpha’ drilling rig was heavily upgraded, which among other things was needed to guarantee ecological safety. The rig is equipped with two groups of blowout preventers and an independent submarine locking device, which in case of minor risks will seal the well. The rig is held at the drilling site by an anchoring positioning system, consisting of 8 anchors. This guarantee an elevate rig stability. Most of the platform is out of the reach of the waves, which can disturb its operations. The rig is capable of drilling to a depth of up to 7 km.

29 Sep 2014

Centrica given approval to drill Ivory prospect

The Norwegian Petroleum Directorate (NPD) has granted Centrica Resources (Norge) AS a drilling permit for wellbore 6707/10-3, cf. Section 8 of the Resource Management Regulations. Wellbore 6707/10-3 will be drilled from the 'West Navigator' drilling facility at position 67°11'31.58 N and 7°19'34.06" east. The drilling programme for wellbore 6707/10-3 relates to drilling of a wildcat well in production licence 528 B. Centrica Resources (Norge) AS is the operator with an ownership interest of 40 per cent. The other licensees are Statoil Petroleum AS (35 per cent), Atlantic Petroleum Norge AS (15 per cent) and Rocksource Exploration Norway AS (10 per cent). The area in this licence consists of part of block 6707/10. The well will be drilled about 20 kilometres north-east of the Aasta Hansteen field. Production licence 528 B was awarded on 13 May 2011) (21st licensing round on the Norwegian shelf.). This is the first well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by the authorities before the drilling activity commences.

6 Oct 2014

Centrica spuds Ivory well in Norway

Atlantic Petroleum has announced that the Ivory well (6707/10-3 S) in PL 528B has been successfully spudded. Atlantic Petroleum Norge has a 9% working interest in PL 528B located in the Norwegian Sea. The licence is located adjacent to the Statoil-operated Aasta Hansteen field development which is due to come on stream in 2017. The Ivory well is being drilled by the ‘West Navigator’ drillship. The well is planned to drill to a total depth of around 4,200 m TVD and operations are anticipated to take 60-90 days. This will be extended in the case of discovery. The PL528 licence contains the Ivory prospect which is gas prone with Direct Hydrocarbon Indicator (DHI) support. Gross recoverable resources have been estimated to be 50- 230 mmboe for the main target. The licence also holds several other large prospects, some with DHI support. Centrica Resources (Norge) is operator of the licence with an equity interest of 40%. Other licence partners are Statoil Petroleum 35%, Rocksource Exploration Norway 10%, Atlantic Petroleum Norge 9% and Repsol Exploration Norge 6%.

2 Dec 2014

Centrica strikes gas at Ivory prospect

Atlantic Petroleum is pleased to announce that the PL528 B Ivory exploration well in the Norwegian Sea has discovered gas. The 6707/10-3S well tested the westernmost segment of the Ivory structure, one of several prospects within the license. The primary objective of the Ivory well was to prove the presence of hydrocarbons in the Kvitnos Formation sandstones. A thick, well developed deep marine fan was encountered 61 m shallower than prognosed. The well was drilled down-dip from the crest of the structure and encountered a 12 m gas-zone. In the Lysing Formation the well penetrated a water-bearing sand. Extensive data acquisition has been performed including cores, fluid samples, pressure points, wireline logs and VSP. These data will now be fully analysed. Further work is needed to evaluate the resource potential of the discovery. Given commercial, the discovery can be tied back to the Statoil-operated Aasta Hansteen field, located 20 km to the southwest, and which is due to come on stream in 2017. The exploration well was drilled to a total depth of 4,264 m below sea level by the West Navigator drill ship. The well will now be permanently plugged and abandoned.

8 Dec 2014

Centrica completes drilling of Ivory well in Norway

Centrica Resources Norge AS, operator of production licence 528 B, is about to complete drilling of wildcat well 6707/10-3 S. The well was drilled about 20 kilometres northeast of the Aasta Hansteen field in the Norwegian Sea. The primary and secondary exploration targets for the well were proving petroleum in Upper Cretaceous reservoir rocks, the Kvitnos and Lysing formations, respectively. Well 6707/10-3 S encountered a total gas column of about 12 metres in the Kvitnos formation with good reservoir properties. The entire reservoir zone, including the water zone, has a gross thickness of about 200 metres. Reservoir rocks were encountered in the secondary exploration target with a total of 25 metres thickness in the Lysing formation, which was tight and aquiferous. Preliminary calculations of the size of the discovery are between two and eight billion standard cubic metres (Sm3) of recoverable gas. The licensees will assess well results with regard to profitability. The well was not formation tested, but extensive data acquisition and sampling were carried out. This is the first exploration well in production licence 528 B. The licence was awarded in the 21st licensing round, as an addition to production licence 528. Well 6707/10-3 S was drilled to a vertical depth of 4264 metres below the sea surface, and was terminated in the Lange formation in the Lower Cretaceous. Water depth is 1421 metres. The well will now be permanently plugged and abandoned. Well 6707/10-3 S was drilled by the West Navigator drill ship.

8 Dec 2014

ExxonMobil to use 'West Alpha' on Balder field

ExxonMobil has received consent to use the West Alpha semisub drilling rig for production drilling, completion and installation of subsea equipment on the Balder field. Balder was the first oil field to be discovered on the Norwegian Continental Shelf, with Esso as the sole licensee in production licence 001. This happened as far back as 1967, more than two years before the Ekofisk field was discovered and declared viable. At the time, Balder was not assessed to be commercially interesting. Following new investigations, the Balder field was subsequently developed. Production began in 1999, still with ExxonMobil as the sole licensee and operator. The Balder field is in the central North Sea, around 213 kilometres west of Stavanger. The field has been developed using a subsea solution tied to a floating production, storage and offloading (FPSO) unit. Water depth in the area is approximately 125 metres. ExxonMobil has now received consent from the PSA to use West Alpha to drill and complete new production wells on the field. The activities also concern the installation of subsea equipment and the plugging of wells no longer in use.

19 Jan 2015

Statoil to drill on Gudrun field with 'West Epsilon'

Statoil has received consent to use West Epsilon for production drilling on the Gudrun field. Gudrun is 50 kilometres north of the Sleipner Øst and Sleipner Vest fields. Water depth is around 110 metres. Gudrun has been developed using a facility with a steel jacket and first stage processing. It is tied to Sleipner A through two pipelines, one for oil and one for rich gas. Statoil formerly received consent to use West Epsilon for drilling and completion of well 15/3 on the Gudrun field and has now received consent to drill the remaining sections of well 15/3 – A- 14. The PSA has now granted Statoil consent to use the West Epsilon mobile drilling facility for these activities. West Epsilon is operated by North Atlantic Drilling, formerly known as Seadrill Offshore AS.

13 Mar 2015

North Atlantic Drilling receives notice of termination for the West Navigator

North Atlantic Drilling Ltd. (NADL) has received a notice of termination from Rosneft of the service order for the West Navigator in connection with the Framework Agreement. The drillship was indicatively scheduled to commence operations under its five-year contract with Rosneft during the summer of 2015, which would have required earlier mobilisation. As outlined in our fourth quarter 2014 results report, NADL believes that it will be very challenging to close the transactions with Rosneft on the same terms or in the timeframe contemplated in the executed agreements, and that there were significant risks attached to the US$4.1 billion order backlog related to the drilling contracts with Rosneft. The termination of the service order for West Navigator will reduce NADL's contract backlog by US$1.0 bn. NADL will be marketing the West Navigator for alternative future opportunities, however remains in discussions with Rosneft to explore various alternatives for future co-operation.

17 Apr 2015

Rosneft and NADL delay proposed agreement by two years

On August 22nd, 2014 North Atlantic Drilling Ltd. ("NADL") announced that it had entered into a Framework Agreement between NADL, Seadrill and Rosneft Oil Company ("Rosneft"). On November 7th, 2014, the closing of the transaction was delayed until the end of May 2015. Today, all parties have mutually agreed to extend the termination date of the Framework Agreement until May 31st, 2017, whereby any party can terminate the Framework Agreement and / or any offshore drilling contracts at any time prior to May 31st, 2017 at no cost. Additionally, the parties have agreed to use reasonable efforts to renegotiate the terms and characteristics of the transactions contemplated in the Framework Agreement and the terms of the related offshore drilling contracts. During this time, NADL is permitted to market the offshore drilling rigs subject to existing drilling contracts with Rosneft and enter into binding contracts with third parties. NADL will also be permitted to delay the construction, delivery, or shipyard stay of any of those rigs. This delay follows the decision to cancel the contracts for the ‘West Navigator’ drillship and ‘Energy Endeavour’ jackup, both of which were also due to go on contract with Rosneft in Russia.

10 Jul 2015

North Atlantic Drilling secures new contract for 'West Phoenix'

North Atlantic Drilling ("NADL") has been awarded a contract extension for the semi-submersible rig West Phoenix by Total E&P UK Limited, commencing mid-March 2016 and securing work for the unit through the end of August 2016. The total revenue potential for the contract extension is approximately USD62 million. A portion of the USD62 million will be paid during the currently anticipated idle period from the beginning of September 2015 to the middle of March 2016. The Company has the ability to market the rig for alternate work during this period. As part of the agreement to extend the West Phoenix, the Company has agreed to a dayrate reduction on the current contract effective from June 1, 2015 until its expected conclusion at the end of August 2015, resulting in a reduction to the remaining revenue potential of approximately USD16 million.

14 Mar 2016

Consent to use West Epsilon for permanent well plugging

Statoil has received consent to use West Epsilon for permanent plugging of wells at Huldra 30/2-A, in production licence 051. Statoil has allocated 215 days for the activity, which will start in the second quarter of 2016. Water depth at the site is 125 metres. The PSA has now granted Statoil consent to use the West Epsilon mobile drilling facility for these activities. West Epsilon is operated by North Atlantic Drilling, formerly known as Seadrill Offshore AS. The Petroleum Safety Authority Norway issued an Acknowledgement of Compliance (AoC) for West Epsilon on 14 February 2003.

19 Jun 2008

AoC for West Phoenix

The West Phoenix mobile drilling unit operated by Seadrill Management AS has received an acknowledgement of compliance (AoC) from the Petroleum Safety Authority of Norway. This facility represents the first in a series of brand new mobile units which are due to be used on the Norwegian continental shelf.

21 Dec 2016

Audit of West Elara

The PSA has carried out an audit of North Atlantic Drilling in respect of structural safety at West Elara. West Elara is a jack-up drilling facility owned and operated by North Atlantic Drilling (NAD). The facility was issued with an Acknowledgement of Compliance (AOC) by the PSA in December 2011. The PSA has carried out an audit of the operational organisation for West Elara relating to competence within structural safety, the history of structural incidents and maritime systems, operational life assessments and routines for investigating structural incidents. The audit took place at NAD's premises in Bergen on 1 and 2 December 2016. The audit detected no non-conformities or improvement points.

3 Feb 2017

Gas discovery on the Valemon field in the North Sea – 34/11-6 S

Statoil Petroleum AS, operator of production licence 193 D, has concluded the drilling of wildcat well 34/11-6 S. The well was drilled from the Valemon facility, 160 km northwest of Bergen. The objective of the well was to prove petroleum in the Middle Jurassic (the Brent group). The well encountered two gas columns of about 80 and 35 metres in the Tarbert and Ness formations, respectively. There were 50 metres of sandstone with moderate to good reservoir quality in the Tarbert formation and 10 metres of sandstone with poor reservoir quality in the Ness formation. Preliminary estimates place the size of the discovery between 3 - 8 million standard cubic metres (Sm3) of recoverable oil equivalents. The well will be completed and will start production from the Valemon facility. Data acquisition was carried out. This is the first exploration well in production licence 193 D. Well 34/11-6 S was drilled to a vertical depth of 4337 metres below the sea surface, and was terminated in the Drake formation in the Lower to Middle Jurassic. Water depth at the site is 133 metres. Well 34/11-6 S was drilled by the West Elara drilling facility, which is permanently stationed at the Valemon facility.

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