Transocean Leader (Transocean Offshore Deepwater Drilling Inc.) (Semisub)

Rig secured for exploration and production

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11 October 2005

A charter worth almost NOK 900 million to use the Transocean Leader rig in both exploration and production drilling has been secured by Statoil. Due to come into force in September 2007, this one-year contract represents a direct extension of an existing charter with rig contractor Transocean. “Transocean Leader will secure future volumes of oil and gas for installations in the Tampen area of the North Sea,” says sector manager Øyvin Jensen. The rig has been drilling for Statoil since the summer of 2004, and is currently working in an exploration collaboration which also involves Shell and Hydro.

Source: http://www.statoil.com/en/NewsAndMedia/News/2005/Pages/RigSecuredForExplorationAndProduction.aspx


More News for Operator: Transocean Offshore Deepwater Drilling Inc.

15 Jan 2013

HRT Officially Receives Transocean Marianas

The Transocean Marianas semi-submersible drilling rig has officially been handed over to HRT for the start of its contract with the Brazilian operator in Namibia, the unit is now enroute to the country from Ghana and is expected to arrive within three weeks. The unit will undergo 21 days of maintenance before it begins to work on the Wingat prospect where it is expected to drill for up to 60 days. The unit was previously contracted by Eni in Ghana for a three year term from December 2009.

7 Feb 2013

Transocean Marianas rig arrives in Namibia ahead of HRT drilling contract

The Transocean Marianas semi-submersible drilling unit has arrived in walvis bay in Namibia ahead of its contract with HRT. The unit will undergo necessary maintenance work for a three to four week period before it is used to drill the Wingat Prospect in the Walvis Basin. The rig will be embarking upon a drilling campaign in the Walvis and Orange basins in Namibia with HRT estimating that up to 7.39BOE can be discovered with it exploration campaign.

15 Jan 2013

Continued delay of 'Songa Trym' adds to woes for Songa Offshore

Songa announced further bad news for the company with the release of its ‘December fleet report’, with the news that the upgrade work on the Songa Trym semisubmersible rig was taking longer than expected and would be delayed again with the unit now unlikely to begin its contract with Statoil in Norway until the end of January 2013, a full 4 months after the unit was originally scheduled to begin operations. The work associated with the unit is now expected to cost over US$260m (with Statoil contributing US$55m) which along with the increased costs that were associated with the work on the ‘Songa Delta’ rig have added to the financial problems of the company who earlier this month were forced to sell off the ‘Songa Eclipse’ semisubmersible rig to Seadrill in order to pay off debt.

17 Jan 2013

Sedco 714 secures contract extension with Total

Transocean has announced that the company has secured an 18 month contract extension with Total for the Sedco 714 semisubmersible rig that is currently operating in the UK. The contract extension ensures that the unit will be fully contracted until October 2015 in the region, where it has been working since 2005 continuously for Total. Midwater rig availability in the UK offshore market is extremely tight and this contract extension has allowed Total to secure continuous usage of a valuable asset.

17 Jun 2013

Ocean Rig secures contract for newbuild drillship

Ocean Rig has announced that it secured a letter of award (LOI) for its newbuild ultra-deepwater drillship the ‘Ocean Rig Skyros’, worth around US$190 million. The contract is with an as yet unnamed ‘major oil company’ for work off West Africa in the form of a firm five well drilling programme taking place over 275 days, which will help to boost the rig managers contract backlog to around US$5 billion. The ‘Ocean Rig Skyros’ is the second of four, seventh generation units that Ocean Rig have on order at Samsung’s yard in South Korea. The contract is expected to commence upon delivery of the unit from the yard, which is currently anticipated to be in October 2013.

8 Jul 2013

Transocean drillship breaks own record for deepest operational water depth

Transocean and ONGC have announced that the drillship ‘Dhirubhai Deepwater KG1’ has set a new world record for the deepest operational water depth achieved by an offshore drilling rig. The unit which beat the previous record it set in February 2013 spudded a well in 10,411 feet (3,174m) of water while working off the east coast of India. The unit which is being sublet by ONGC from Reliance Industries is due to end its four year drilling assignment with ONGC once it has completed the newly spudded well. Upon completion the unit will return to Reliance for the final remaining year of its original five year contract.

23 Jul 2013

Ocean Rig secures US$1.3 billion contract for 'Ocean Rig Skyros'

Ocean rig has announced that the company has been awarded a six year contract for the newbuild ‘Ocean Rig Skyros’ Samsung designed drillship. The new contract is expected to begin in direct continuation of the units initial five well, 275 day contract that was signed with Total E&P Angola in June 2013. The new letter of award is with an as yet unnamed major oil company for drilling operations in West Africa and is worth a total of US$1,300 million. The award of the contract means that all of Ocean Rig’s drillship units are now contracted through the entirety of 2014.

15 Oct 2013

Transocean orders newbuild drillship on award of five year contract from Chevron

Transocean has announced the award of a new five year drilling contract from Chevron with work expected to begin in the USA in Q1 2017 and a contract value of US$1.1 billion. The contract award has led Transocean to order a newbuild drillship from Daewoo Shipbuilding and Marine Engineering’s (DSME) Okpo yard in South Korea. The newbuild drillship is expected to be delivered in Q4 2016 at a total cost of US$725 million and upon delivery the unit will mobilise to the USA to begin the contract with Chevron. The newbuild drillship will be the seventh ultra-deepwater rig that Transocean currently has under construction at DSME once construction work begins and the order helps the company’s push towards redefining itself as a high-specification rig contractor.

29 Aug 2013

Millennium Offshore Services (MOS) completes purchase of jackup rig

Millennium Offshore Services (MOS) a provider of offshore jackup accommodation vessels globally has successfully completed the purchase of Transocean’s ‘Trident IV’ jackup rig which is to be renamed the ‘MOS Frontier’. MOS purchased the jackup rig for an all-in price of US$25 million and plan to turn the rig into an accommodation jackup vessel to target accommodation work in the Middle East, Asia-Pacific and North African regions. The ‘Trident IV’ jackup was put up for sale by Transocean in October 2012 and has been idle since completing a contract in Nigeria in 2008. The sale also falls in line with Transocean’s strategy to move the company further towards a purely high-specification asset rig operator.

2 Dec 2013

VNG to drill exploration well using the 'Transocean Arctic'

The Norwegian Petroleum Directorate has issued VNG Norge AS a drilling permit for well 6406/12-3 S, cf. Section 8 of the Resource Management Regulations. Wellbore 6406/12-3 S will be drilled from the Transocean Arctic drilling facility in position 64°01’52.37’’ north and 06°45’17.53’’ east after it completes drilling wildcat well 35/9-10 A for Wintershall Norge AS in production licence 418. The drilling programme for well 6406/12-3 S concerns drilling of a wildcat well in production licence 586. VNG Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Spike Exploration Holding AS (30 per cent), Faroe Petroleum Norge AS (25 per cent) and Rocksource Exploration Norway AS (15 per cent). The area in this licence consists of part of block 6406/11 and part of block 6406/12. The well will be drilled approx. 8 kilometres east of the 6406/11-1 S discovery and about 33 kilometres southwest of the Njord field. Production licence 586 was awarded on 4 February 2011 (APA 2010). This is the first well to be drilled in this licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities before the drilling activity starts.

23 Sep 2013

Statoil set to drill two wells on PL 348 using 'Songa Trym' semisub

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wells 6407/8-6 and 6407/8-6 A, cf. Section 8 of the Resource Management Regulations. Wells 6407/8-6 and 6407/8-6 A will be drilled from the Songa Trym drilling facility at position 64°21'12.70" north and 07°27'44.48" east after it completes drilling of the wildcat well 6608/10-15 for Statoil in production licence 128. The drilling programme for wells 6407/8-6 and 6407/8-6 A relates to the drilling of wildcat wells in production licence 348. Statoil is the operator with an ownership interest of 35 per cent. The other licensees are GDF Suez E&P Norge AS (20 per cent), E.ON E&P Norge AS (17.5 per cent), Core Energy AS (17.5 per cent), Faroe Petroleum Norge AS (7.5 per cent) and VNG Norge AS (2.5 per cent). The area in this licence consists of parts of blocks 6407/8 and 6407/9. The wells will be drilled about four kilometres west of the Hyme field and 16 kilometres northeast of the Njord field. Production licence 348 was awarded on 17 December 2004 (APA 2004 on the Norwegian shelf). These are the seventh and eighth wells to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

6 Sep 2013

GDF Suez to spud new exploration well on Gjoa field in Norway

The Norwegian Petroleum Directorate has granted GDF Suez E&P Norge AS a drilling permit for well 35/9-9, cf. Section 8 of the Resource Management Regulations. Well 35/9-9 will be drilled from the Transocean Barents drilling facility in position 61°24’12.79” north and 3°56’00.49” east after completing the drilling of wildcat well 6406/9-1 for A/S Norske Shell in production licence 255. The drilling program for well 35/9-9 relates to the drilling of a wildcat well in production licence 153. GDF Suez E&P Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Petoro AS (30 per cent), Wintershall Norge AS (15 per cent), A/S Norske Shell (12 per cent), RWE Dea Norge AS (8 per cent) and Statoil Petroleum AS (5 per cent). The area in this licence consists of parts of blocks 35/9 and 36/7. The well will be drilled about eight kilometres north of the Gjøa field. Production licence 153 was awarded on 8 July 1988 (12th licensing round on the Norwegian shelf). This is the tenth well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

22 Aug 2013

Wintershall to drill wildcat well on PL 418 using 'Transocean Arctic'

The Norwegian Petroleum Directorate has granted Wintershall a drilling permit for well 35/9-10 S, cf. Section 8 of the Resource Management Regulations. Well 35/9-10 S will be drilled from the Transocean Arctic drilling facility at position 61°15’07.02” north and 3°41’04.10” east for Wintershall Norge AS in production licence 418. The drilling programme for well 35/9-10 S relates to drilling of a wildcat well in production licence 418 where Wintershall is the operator with an ownership interest of 35 per cent. The other licensees are Capricorn (20 per cent), Bayerngas (20 per cent), Edison (15 per cent) and RWE Dea (10 per cent). The area in this licence consists of part of block 35/8 and part of block 35/9. The well will be drilled about 16 kilometres southwest of Gjøa and 16 kilometres east of Vega. Production licence 418 was awarded on 16 February 2007 (APA 2006). This is the third well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

14 Aug 2013

Statoil set to drill two wildcat wells with 'Transocean Leader' semisub

The Norwegian Petroleum Directorate has granted Statoil ASA a drilling permit for wellbores 34/10-54 S and 34/10-54 A, cf. Section 8 of the Resource Management Regulations. Wellbores 34/10-54 S and 34/10-54 A will be drilled from the Transocean Leader drilling facility at position 61º 07`32.70” N and 02º 18´35.5" E after completion of drilling of the wildcat well 6506/9-3 for Statoil ASA in production licence 479. The drilling program for wellbores 34/10-54 S and 34/10-54 A relates to drilling of a wildcat well in production licence 050 ES, Valemon Unit. Statoil ASA is the operator with an ownership interest of 57 per cent. The other licensees are Petero AS (30 per cent) and Centrica Resources (Norge) AS (13 per cent). The area in this permit consists of the block 34/10. Production licence 050 ES was awarded on 11 April 2012 as an addition to the third licensing round. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

12 Aug 2013

'Songa Trym' granted permission to drill Svale Nord prospect for Statoil in PL 128

The Norwegian Petroleum Directorate has granted Statoil ASA a drilling permit for wellbore 6608/10-15, cf. Section 8 of the Resource Management Regulations. Wellbore 6608/10-15 will be drilled from the drilling facility Songa Trym at position 66°05’20.8”N and 08°16’ 42.5”E, following the completion of the drilling of wildcat well 6507/3-10 for Statoil ASA in production licence 159 C. The drilling programme for wellbore 6608/10-15 concerns the drilling of a wildcat well in production licence 128. Statoil ASA is the operator with an ownership interest of 64 per cent. The other licensees are Petoro AS (24.5 per cent) and Eni Norge AS (11.5 per cent). The acreage in this licence consists of the blocks 6608/10 and 11. Production licence 128 was awarded on 28 February 1986 (Licensing round 10-B on the Norwegian shelf). The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

24 Jun 2013

Lundin Norway gains approval to drill 7120/1-3 wildcat well using 'Transocean Arctic' semisub

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7120/1-3, cf. Section 8 of the Resource Management Regulations. Well 7120/1-3 will be drilled from the Transocean Arctic drilling facility at position 71 54` 10.37" north and 20 16´ 11.59" east. The drilling program for well 7120/1-3 relates to drilling of a wildcat well in production licence 492. Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensees are Det norske oljeselskap ASA with 40 per cent and Noreco Norway ASA with 20 per cent. The production licence consists of parts of blocks 7120/1 and 7120/2. The licence was awarded in APA 2007. Wildcat well 7120/1-3 is the first exploration well in production licence 492. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

5 Jun 2013

Statoil targets new exploration well north of Asgard field

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 6506/9-3, cf. Section 8 of the Resource Management Regulations. Well 6506/9-3 will be drilled from the Transocean Leader drilling facility in position 65°15'4.99" north and 6°54'15.66" east after completion of the drilling of production well 31/2-K-13 BY2H for Statoil Petroleum AS in production licence 054 in the Troll field. The drilling program for well 6506/9-3 concerns the drilling of a wildcat well in production licence 479. Statoil Petroleum AS is the operator with an ownership interest of 40.95 per. The other licensees are Eni Norge AS with 19.6 per cent, Petoro AS with 14.95 per cent, Exxon Mobile E&P Norway AS with 14.7 per cent and Total E&P Norge AS med 9.8 per cent. The area in this licence consists of parts of blocks 6506/9 and 6506/12. The well will be drilled about seven kilometres north of Åsgard in the Norwegian Sea. Production licence 479 was awarded on 29 February 2008 in APA 2007 on the Norwegian shelf. This is the first well drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

9 Dec 2013

Det norske oljeselskap ASA receives consent to drill Barents Sea wildcat well 7222/11-2 A

The Norwegian Petroleum Directorate has granted Det norske oljeselskap ASA a drilling permit for well 7222/11-2 A, cf. Section 8 of the Resource Management Regulations. Well 7222/11-2 will be drilled from the Transocean Barents drilling facility at position 72° 06` 23.17" north and 22° 36´ 47.74" east. The drilling programme for well 7222/11-2 relates to the drilling of a wildcat well in production licence 659. Det norske oljeselskap ASA is the operator with a 30 per cent ownership interest. The other licensees are Petoro AS with 30 per cent, Lundin Norway AS with 20 per cent, Tullow Oil Norge AS with 10 per cent, Rocksource Exploration Norway AS with 5 per cent and Ithaca Petroleum Norge AS with 5 per cent. The production licence includes parts of the blocks 7121/3, 7122/1, 7122/2, 7221/10, 7221/12, 7222/11 and 7222/12. The production licence was awarded in APA 2011. Wildcat well 7222/11-2 is the first exploration well in production licence 659. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

22 May 2013

Statoil prepared to drill Falk appraisal using 'Songa Trym'

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 6608/11-8, cf. Section 8 of the Resource Management Regulations. Well 6608/11-8 will be drilled from the Songa Trym drilling facility at position 66° 07' 39.83" north and 8° 20' 12.39" east. The drilling programme for well 6608/11-8 relates to drilling of an appraisal well in production licence 128. Statoil Petroleum AS is the operator with an ownership interest of 63.95 per cent. The licensees are Petoro AS with 24.55 per cent and Eni Norge AS with 11.50 per cent. The production licence consists of blocks 6608/10 and 6608/11. The production licence was awarded in licensing round 10-B in 1986. The drilling permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

13 May 2013

'Transocean Winner' set to be used by RWE Dea Norge AS to drill Cliffhanger South Prospect

The Norwegian Petroleum Directorate has granted RWE Dea Norge AS a drilling permit for well 6608/2-1 S, cf. Section 8 of the Resource Management Regulations. Well 6608/2-1 S will be drilled from the Transocean Winner drilling facility at position 66° 58' 6.99" north and 8° 23' 38.11" east. The drilling programme for well 6608/2-1 S relates to drilling of a wildcat well in production licence 330. RWE Dea Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Marathon Oil Norge AS with 30 per cent and Lundin Norway AS with 30 per cent. The production licence consists of blocks 6608/1 and 6608/2. The production licence was awarded in the 18th licensing round in 2004. Wildcat well 6608/2-1 S is the first exploration well in production licence 330. The permit is contingent upon the operator securing all other permits and consents required by other authorities before the drilling activity starts.

22 Apr 2013

'Songa Trym' set to drill wildcat well 25/11-27 for Statoil

The Norwegian Petroleum Directorate (NPD) has granted Statoil Petroleum AS a drilling permit for well 25/11-27, cf. Section 8 of the Resource Management Regulations. Well 25/11-27 will be drilled from the Songa Trym drilling facility at position 58°14’15.78” north and 2°32’51.25” east after completing the drilling of wildcat well 16/8-3 S for Statoil in production licence 360. The drilling programme for well 25/11-27 relates to drilling of a wildcat well in production licence 169 B2. Statoil Petroleum AS is the operator with an ownership interest of 47.5 per cent. The other licensees are Petoro AS with 30 per cent, ConocoPhillips Skandinavia AS with 12.5 per cent and ExxonMobil E&P Norway AS with 10 per cent. The area in this licence consists of part of block 25/11. The well will be drilled about 4 kilometres southwest of well 25/8-4 in the central part of the North Sea. Production licence 169 B2 was awarded on 1 March 2000 (supplement to the 13th round). This is the first well to be drilled within the area of the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

11 Nov 2013

'Transocean Barents' drills dry well on Gjoa field for GDF Suez

GDF SUEZ E&P Norge, operator of production licence 153, has completed the drilling of wildcat well 35/9-9. The well was drilled about 8 km west of the Gjøa field in the North Sea. The well is dry. The primary exploration target for the well was to prove petroleum in reservoir rocks in the Upper Jurassic (the Viking group). The secondary exploration target was to prove petroleum in reservoir rocks from the Middle Jurassic Age (the Brent group). The well encountered reservoir rocks in the Viking and Brent group with reservoir quality as expected. The well is classified as dry, with traces of petroleum. Data acquisition and sampling have been carried out. This is the ninth exploration well in production licence 153. The licence was awarded in the 12th licensing round in 1988. 35/9-9 was drilled to a vertical depth of 3298 metres below the sea surface, and was terminated in Triassic rocks. Water depth at the site is 360 metres. The well will now be permanently plugged and abandoned. Well 35/9-9 was drilled by the Transocean Barents drilling facility, which will now proceed to production licence 551 in the North Sea to drill wildcat well 31/3-4, where Tullow Oil Norge AS is the operator.

11 Nov 2013

Statoil completes double oil strike with 6407/8-6 and 6407/8-6 A wells

Statoil Petroleum AS, operator of production licence 348 B, is in the process of completing the drilling of wildcat wells 6407/8-6 and 6407/8-6 A. The wells proved oil. The wells were drilled about 4 kilometres west of the Hyme field and 15 kilometres northeast of the Njord field in the Norwegian Sea. The objective of well 6407/8-6 was to prove petroleum in Lower Jurassic reservoir rocks (the Åre formation). The well encountered the Åre formation, with reservoir rocks and reservoir quality that were poorer than expected; the reservoir is aquiferous. However, a 40-metre gross oil column was encountered in the Ile formation (Middle Jurassic) and an approx. 130-metre gross oil column in the Tilje formation (Lower Jurassic). In addition, a 21-metre gross oil column was encountered in reservoir rocks from the Triassic (most likely “Grey Beds”), further dating will clarify this. The primary exploration target for well 6407/8-6 A was to prove petroleum in Lower Jurassic reservoir rocks (the Tilje formation). The secondary exploration target was to prove petroleum in Middle and Lower Jurassic reservoir rocks (the Ile and Åre formations). A 43-metre gross oil column was encountered in the Tilje formation with reservoir quality as expected, as well as a 75-metre gross oil column in the Ile formation with reservoir quality as expected. In addition, a six-metre gross oil column was encountered in the Melke formation (Middle to Upper Jurassic). No petroleum was proven in “Grey Beds”. Preliminary estimates place the size of the discovery between 9 and 16 million Sm3 recoverable oil equivalents. The well was not formation-tested, but extensive data acquisition and sampling have been carried out. The licensees in production licence 348 B will consider tying the discovery to the Njord field, either directly or via the Hyme field. These wells are the first exploration wells in production licence 348 B. The licence was awarded in APA 2010. Wells 6407/8-6 and 6407/8-6 A were drilled to respective vertical depths of 3420 and 3537 metres below the sea surface, and both were terminated in the Upper Triassic (“Grey Beds”). Water depth at the site is 282 metres. The wells will now be permanently plugged and abandoned. Wells 6407/8-6 and 6407/8-6 A were drilled by the Songa Trym drilling facility, which will now proceed to production licence 248 in the North Sea to drill wildcat well 35/11-16, where Statoil Petroleum AS is the operator.

14 Oct 2013

'Transocean Winner' drills dry well for RWE DEA Norge AS on PL 330 in Norway

RWE DEA Norge AS, operator of production licence 330, has completed the drilling of wildcat well 6608/2-1 S. The well was drilled about 60 kilometres east of the Aasta Hansteen field in the Norwegian Sea. The well's primary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (the Fangst group). The secondary exploration target was to prove petroleum in reservoir rocks from the Late Cretaceous (the Shetland group) and the Early Jurassic (the Båt group). The well did not reach the Fangst and Båt groups and no reservoir development was proven in the Shetland group. The well will be classified as dry. Data acquisition and sampling have been carried out. This is the first exploration well in production licence 330. The production licence was awarded in the 18th licensing round in 2004. The well was drilled to a vertical depth of 5574 metres below the sea surface and was terminated in rocks from the Early Cretaceous. Water depth at the site is 303 metres. The well will now be permanently plugged and abandoned. Well 6608/2-1 S was drilled with the Transocean Winner drilling facility, which will now proceed to production licence 203 in the North Sea to complete production wells on the Alvheim field, where Marathon Oil Norge AS is the operator.

2 Oct 2013

'Transocean Arctic' finds oil whilst drilling 7120/1-3 wildcat well for Lundin Norway AS

Lundin Norway AS, operator of production licence 492, has completed drilling of wildcat well 7120/1-3. The well was drilled about 35 kilometres northwest of the Snøhvit field. The primary exploration target for the well was to prove petroleum in Middle and Early Triassic sandstone rocks (Snadd formation) and in Permian limestone (Røye formation). The secondary exploration target was to prove petroleum in Middle Triassic reservoir rocks (Kobbe formation). In the primary exploration target, the well encountered a gross oil column of about 75 metres and a gross gas column of about 25 metres in limestone rocks in the Røye formation. The reservoir quality was better than expected. The reservoir rocks encountered in the Snadd formation are of expected reservoir quality, but the formation was aquiferous. Preliminary calculations of the size of the discovery are between 10 and 23 million standard cubic metres (Sm3) of recoverable oil and between 8 and 15 billion standard cubic metres of recoverable gas. The results confirm for the first time recoverable oil and gas in a Permian play in the Norwegian part of the Barents Sea. Further delineation of the discovery is planned. A successful formation test has been carried out in the Røye formation. The maximum production rate was 683 Sm3 oil and 222300 Sm3 associated gas per flow day through a 44/64 inch nozzle opening. The gas/oil ratio is 190 Sm3/Sm3. This is the first successful test in Permian limestone rocks on the Norwegian shelf. The well is the first exploration well in production licence 492. The licence was awarded in APA 2007. The well was drilled to a vertical depth of 2515 metres below the sea surface, and was terminated in the Røye formation in Permian. Water depth is 342 metres. The well will now be permanently plugged and abandoned. Well 7120/1-3 was drilled by the Transocean Arctic drilling facility which will now proceed to production licence 418 in the North Sea to drill appraisal well 35/9-10 S where Wintershall Norge AS is the operator.

11 Sep 2013

'Songa Trym' semisub discovers oil for Statoil at Norne field in PL 128

Statoil Petroleum AS, operator of production licence 128, is about to complete drilling of wildcat well 6608/10-15. The well proved oil. The well was drilled about nine kilometres northeast of the Norne field in the Norwegian Sea. The primary exploration target was to prove petroleum in Early Jurassic reservoir rocks (the Åre formation). The secondary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (the Melke formation). The well encountered a 45-metre oil column in the Åre formation and a 45-metre oil column in the Melke formation with reservoir thickness and properties in both levels as expected. Preliminary calculations of the size of the discovery are between one and three million standard cubic metres (Sm3) of recoverable oil. The well was not formation-tested, but data acquisition and sampling have been carried out. Tie-in of the discovery to the Norne field will be considered. This is the 26th exploration well in production licence 128. The licence was awarded in licensing round 10-B in 1986. The well was drilled to a vertical depth of 2005 metres below the sea surface and was terminated in the Åre formation from the Early Jurassic. Water depth is 375 metres. The well will now be permanently plugged and abandoned. Well 6608/10-15 was drilled by the Songa Trym drilling facility, which will now proceed to production licence 348 in the Norwegian Sea to drill wildcat well 6407/8-6 where Statoil Petroleum AS is the operator.

5 Sep 2013

A/S Norske Shell makes small gas discovery in Norway using 'Transocean Barents' to drill 6406/9-1 wildlcat well

A/S Norske Shell, operator of production licence 255, is about to complete drilling of wildcat well 6406/9-3. The well was drilled about 15 kilometres northwest of the Njord field and 7 kilometres southeast of the 6406/9-1 Linnorm gas discovery, in the southern part of the Norwegian Sea. The primary and secondary exploration targets for the well were to prove petroleum in Middle to Lower Jurassic reservoir rocks (Ile, Tofte and Tilje formations). The well encountered the Ile, Tofte and Tilje formations with variable reservoir quality. A thin gas column was encountered in the Ile formation, but the size of the discovery is not commercially interesting. The other reservoir rocks were dense or aquiferous. The well was not formation tested, but data acquisition and sampling have been carried out. 6406/9-3 is the fifth exploration well in production licence 255. The licence was awarded in the 16th licensing round in 2000. The well was drilled to a vertical depth of 5095 metres below the sea surface, and was terminated in the Tilje formation in Lower Jurassic. Water depth is 298 metres. The well will be permanently plugged and abandoned. 6406/9-3 was drilled by the Transocean Barents drilling facility, which will now drill wildcat well 35/9-9 in production licence 153 in the North Sea, where GDF SUEZ E&P Norge AS is the operator.

19 Aug 2013

Statoil discover gas and condensate with Smorbukk North well in Norway

Statoil Petroleum AS, operator for production licence 479, is in the process of completing the drilling of wildcat well 6506/9-3. The well was drilled about 5 km north of the Åsgard field in the Norwegian Sea. The primary exploration goal for the well was to prove petroleum in reservoir rocks of the Middle Jurassic Age (Garn, Ile and Tofte formations). The secondary exploration goal was to prove petroleum in Lower Jurassic reservoir rocks (Ror, Tilje and Åre formations). The well encountered a gas/condensate column of about 40 metres in a down-to situation in the Garn formation. In addition, a thin gas/condensate column was encountered in the Ile formation. The reservoir characteristics are good in the Garn formation, while they are somewhat poorer than expected in the Ile formation. A preliminary estimate of the size of the discovery in the Garn formation is between 4 and 7.5 million Sm3 of recoverable oil equivalents. Tie-in of the discovery to the Åsgard field 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 479. The licence was awarded on 29 February 2008 in connection with APA 2007. The well was drilled to a vertical depth of 4692 metres below the sea surface and completed in the Åre formation in the Lower Jurassic. The sea depth is 302 metres. The well will be permanently plugged and abandoned. Well 6506/9-3 was drilled from the Transocean Leader drilling facility, which will be going to production licence 050ES in the North Sea to drill wildcat well 34/10-54S, where Statoil Petroleum AS is the operator.

15 Aug 2013

'Songa Trym' discovers oil whilst drilling 6507/3-10 wildcat well for Statoil

Statoil Petroleum AS, operator for production licence 159 C, is in the process of completing drilling of the wildcat well 6507/3-10. The well was drilled about 12 km south of the Norne field in the Norwegian Sea. The purpose of the well was to prove petroleum in reservoir rocks of the Middle and Early Jurassic Age (Fangst and Båt group). The well encountered a 10-metre net oil column in Middle Jurassic (the Garn formation) with reservoir characteristics as expected. In addition, oil was encountered in a 2-3 metre thin sand layer in the upper part of the Tilje formation. A preliminary estimate of the size of the discovery is under 1 million Sm3 recoverable oil. Analyses will be made of the discovery to assess its commerciality. 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 159 C, which was awarded in February 2008. The well was drilled to a vertical depth of 3430 metres below the surface of the sea and completed in the Åre formation of the Early Jurassic Age. The sea depth is 374 metres. The well will be permanently plugged and abandoned. Well 6507/3-10 was drilled from the Songa Trym drilling facility, which will be going to production licence 128 in the Norwegian Sea to drill wildcat well 6608/10-15, where Statoil Petroleum AS is the operator.

23 Dec 2013

Ocean Rig receives sixth newbuild drillship 'Ocean Rig Skyros'

Ocean Rig UDW Inc (Ocean Rig) has taken delivery of the company’s sixth newbuild ultra-deepwater drillship, the ‘Ocean Rig Skyros’. The ‘Ocean Rig Skyros’ was delivered to Ocean Rig by Samsung Heavy Industries (SHI) in South Korea and is the first seventh generation drillship to be delivered to the company, with a further three units currently under construction at SHI. The unit is currently being mobilised to Angola to begin its drilling contract with Total, which is expected to begin in Q2 2014.

3 Jan 2014

'Transocean Barents' completes dry well north of Troll field in Norway

Tullow Oil Norge AS, operator of production licence 551, is in the process of completing the drilling of wildcat well 31/3-4. The well was dry. The well was drilled approx. ten kilometres north of the Troll C facility in the North Sea. The well's primary exploration target was to prove petroleum in Late Jurassic reservoir rocks (the Sognefjord formation). Secondary exploration targets were to prove petroleum in the Paleocenic rocks (the Lista formation) and Middle/Late Jurassic reservoir rocks (the Krossfjord and Fensfjord formations and the Brent group). In both the primary and secondary exploration targets the well encountered reservoir rocks and reservoir quality as expected. Comprehensive data acquisition and sampling have been carried out. The well is the first exploration well in production licence 551. The licence was awarded in APA 2009. The well was drilled to a vertical depth of 2082 metres below sea level and was terminated in the Brent group in reservoir rocks from the Middle Jurassic. Water depth at the site is 348 metres. The well will now be permanently plugged and abandoned. Well 31/3-4 was drilled by the Transocean Barents drilling facility, which will now proceed to production licence 659 in the Barents Sea to drill wildcat well 7222/11-2, where Det norske oljeselskap ASA is the operator.

14 Jan 2014

Det Norske spuds first operated well in the Barents Sea

Det Norske has announced the spudding of the oil and gas operators first operated well in the Barents Sea began today at the Langlitinden prospect in production license 659 in Norway. The well (7222/11-2) is being drilled by the ‘Transocean Barents’ semisub unit and is looking to prove hydrocarbons in the Kobbe formation. The ‘Transocean Barents’ is being positioned using the rigs dynamic positioning system and will drill the well to a total depth of 2,901m.

15 Jan 2014

'Transocean Arctic' completes Skarfjell appraisal well

Wintershall Norge AS, operator of production licence 418, is about to complete drilling of appraisal wells 35/9-10 S and A on the 35/9-7 oil discovery (Skarfjell). The appraisal wells are being drilled in the North Sea, about 40 kilometres north of the Troll field and two kilometres southeast of the discovery well. The discovery was proven in the spring of 2012 in two Late Jurassic sandstone layers in the Heather formation. Appraisal well 35/9-10 S was drilled in the southeastern part of the "Skarfjell structure" and sidetrack 35/9-10 A near the top of the structure in the southwestern part. Before well 35/9-10 S was drilled, the resource estimate for the discovery was between 10 and 25 million standard cubic metres (Sm3) of recoverable oil. The objective of the two wells was to examine thickness, properties, fluid content and depth to the Upper Jurassic reservoir to define the extent of the discovery to the south, and clarify whether the discovery has a gas cap. Well 35/9-10 S encountered a 13-metre (gross) gas column and an oil column of 49 metres (gross) in three thin sandstones in the upper “Intra Heather” with reservoir quality as expected. Pressure data shows that this area has a lower reservoir pressure and is not in direct communication with the western and northern part of the discovery. Well 35/9-10 A encountered a 59-metre (gross) gas column in the upper "Intra Heather" sandstone with better than expected reservoir quality. Pressure data indicates that the proven gas cap is in communication with the oil zone proven in 35/9-7 and in appraisal well 35/9-8 in the northern part of the discovery. The lower "Intra Heather" sandstone is only four metres thick, contains oil and has poorer reservoir quality than expected. Preliminary calculations place the size of the discovery between 10 and 23 million Sm3 of recoverable oil and condensate, and between 8 and 15 billion Sm3 of recoverable gas. The wells were not formation-tested, but extensive data acquisition and sampling have been carried out. The licensees will assess the discovery together with other nearby discoveries for possible development solutions. This is the third exploration well in production licence 418 (link to fact page). The licence was awarded in APA 2006. Appraisal well 35/9-10 S was drilled to a vertical and measured depth of 2837 and 3595 metres below the sea surface, respectively. Appraisal well 35/9-10 A was drilled to a vertical and measured depth of 2835 and 3179 metres below the sea surface, respectively. Both wells were terminated in the Rannoch formation in the Middle Jurassic. Water depth is 365 metres. The wells will be plugged and abandoned. The wells were drilled by Transocean Arctic, which will proceed to production licence 586 in the Norwegian Sea to drill wildcat well 6406/12-3 S where VNG Norge AS is the operator.

20 Jan 2014

'Transocean Legend' continues to drill ahead at Grace-1 well in Australia

Karoon Gas Australia (Karoon) has released a progress report on the drilling of the ConocoPhillips operated Grace-1 exploration well in Australia. The well which is being drilled by the ‘Transocean Legend’ semisub has reached a depth of 4,844m with drilling continuing ahead. Drilling work was temporarily halted due to tropical cyclone Christine as the crew were evacuated from the rig however, normal operations resumed once the cyclone had passed. The Grace-1 well is the fourth exploration well being drilled by Conocophillips in its current exploration campaign and the oil and gas operator plans to drill a further two wells in 2014 using the ‘Transocean Legend’ rig.

21 Feb 2012

Jupiter-1 discovery offshore Sierra Leone

Tullow Oil plc (Tullow) announces that the Jupiter-1 exploration well in Block SL-07B-11 offshore Sierra Leone has successfully encountered hydrocarbons. This has been confirmed by the results of drilling, wireline logs and samples of reservoir fluids. The well, located over 25 kilometres west of the Mercury-1 well which discovered oil in the block, intersected 30 metres of hydrocarbon pay in the primary Upper Cretaceousobjective and did not encounter a hydrocarbon water contact. The well has been preserved for possible future re-entry, as the area is likely to require additional evaluation. Jupiter-1 was drilled by the Transocean Discoverer Spirit drillship to a total depth of 6,465 metres in a water depth of 2,199 metres. On completion of operations, the drillship will move 15km northeast to the Mercury-2 well which will target several reservoir levels including extensions of the oil accumulations discovered by the Mercury-1 well. Anadarko (55%) is Operator of offshore Block SL-07B-11 along with partners Repsol (25%) and Tullow (20%).

18 Nov 2011

Successful appraisal of the Teak discovery offshore Ghana

Kosmos Energy (NYSE: KOS) announced today that the Teak-3A appraisal well has confirmed a northern extension of the Teak discovery on the West Cape Three Points Block offshore Ghana. The Teak-3A well is located approximately 4 kilometers (2.5 miles) north of Teak-1 and was designed to test the potential structural and stratigraphic extension of reservoirs encountered in the original discovery well. Analysis of well results, including wireline logs, reservoir pressures and fluid samples indicate that the Teak-3A well encountered approximately 35 meters (115 feet) of hydrocarbons in multiple good-quality reservoirs. The analysis identified 13 meters (43 feet) of 36-39 degree API gravity and 22 meters (72 feet) of gas-condensate pay. The hydrocarbon-bearing reservoirs encountered were Campanian and Turonian in age and similar to those seen in the discovery well. Brian F. Maxted, President and Chief Executive Officer, said "The extension of the Teak discovery is a significant milestone in progressing the appraisal and delineation of this field. We have confirmed the presence of a number of hydrocarbon pools in Teak-3A and significantly extended the productive area of the discovery. While more operational work and technical studies will be necessary to fully define the field, we are very encouraged by the result, which gives further momentum for additional development of the resources discovered on our operated block. Our appraisal and delineation programs continue to generate substantial value for Kosmos, and we look forward to a number of additional near-term appraisal and exploration well results." The "Transocean Marianas" semisubmersible drilled the Teak-3A well to a total depth of 3,222 meters (10,571 feet) in 444 meters (1,457 feet) of water. Following the completion of operations at Teak-3A, the rig will be released to another operator. Kosmos anticipates drilling the Teak-4A appraisal well in the second quarter of 2012. Additional appraisal at Teak is being planned for the second half of 2012. West Cape Three Points Block Ownership Interest Kosmos Energy is the operator of the West Cape Three Points Block with a 30.875% interest. Anadarko Petroleum Corporation has a 30.875% interest, Tullow Oil plc has a 26.396% interest, Sabre Oil & Gas Holdings Limited has a 1.854% interest; and the Ghana National Petroleum Corporation has a 10% carried interest.

9 Nov 2011

Montserrado-1 makes a non-commercial oil discovery

Tullow Oil plc (Tullow) announces that the Montserrado-1 exploration well, offshore Liberia, has made a non-commercial oil discovery in Late Cretaceous reservoir sands. This result is an important exploration breakthrough, establishing a working hydrocarbon system in the Liberian basin. The well was drilled in block LB-15 to a total depth of 5,400 metres and encountered good-quality, water-bearing sands in the main objective. In a deeper secondary objective, approximately 8 metres of hydrocarbon pay was intersected and a sample of light oil was recovered. The well is being plugged and abandoned and the drillship is being mobilised to Sierra Leone to drill the Mercury-2 appraisal well and the Jupiter exploration well on block SL-07B-11. Tullow has a 25.00% working interest in the licence and is partnered by the operator, Anadarko Petroleum (47.5%) and Repsol (27.5%).

28 Sep 2011

Enyenra-3A well result announcement

Tullow Oil plc (Tullow) announces that the Enyenra-3A appraisal well, in the Deepwater Tano licence offshore Ghana, has successfully encountered oil in high quality sandstone reservoirs. Pressure data indicates that the Enyenra-3A well has confirmed an up-dip extension of the Enyenra oil field. Located 6.5km north of the Owo-1 discovery well and 14km north of Enyenra-2A, the well was drilled to test the up-dip extent of the Enyenra oil field. Results of drilling, wireline logs, samples of reservoir fluids and pressure data show that Enyenra-3A has intersected 17 metres of 35o API net oil. Pressure data confirms a continuous oil column of at least 365 metres and that the oil at Enyenra-3A is in static pressure communication with both the Owo-1 discovery well and the Enyenra-2A appraisal well. The Deepwater Millennium drillship drilled Enyenra-3A to a total depth of 4,031 metres in water depths of 1,102 metres. On completion of drilling operations, prior to flow testing the Enyenra field in late 2011, pressure gauges will be deployed in Enyenra-2A and Enyenra-3A to determine reservoir connectivity. The drillship will depart the Deepwater Tano block in late October having recently been replaced by the Sedco Energy drillship. The Sedco Energy will later drill the Enyenra-4A well to further appraise the downdip extent of the field. The well will be located 6.8km south of Enyenra-2A and over 20km downdip from the Enyenra-3A well and a result is expected at the end of the year. The Enyenra-5A well also is then likely to be drilled north of Enyenra-3A to test the ultimate updip extent of the field. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest). Elsewhere in West Africa, Tullow now expects to announce the result of the Montserrado-1 well offshore Liberia during October.

11 Mar 2011

Enyenra-2A appraisal well proves major light oil field

Tullow Oil plc (Tullow) announces that the Enyenra-2A appraisal well, in the Deepwater Tano licence offshore Ghana, has successfully encountered oil in excellent quality sandstone reservoirs. Good evidence of communication with Owo-1 confirms that the Owo oil discovery, now renamed Enyenra, is a major light oil field. Located over seven kilometres south and down-dip of Owo-1, the well was drilled to appraise the Upper and Lower Channels of the Enyenra oil field. Results of drilling, wireline logs, samples of reservoir fluids and pressure data show that Enyenra-2A has intersected 21 metres of net oil pay in the Upper Channel and 11 metres of net oil pay in the Lower Channel. Pressure data from the Upper Channel has also demonstrated that the oil is in communication with the Owo-1 well. Oil pressures in the Lower Channel suggest it may also be in communication with the deeper pools seen in Owo-1 and its sidetrack. The well also tested a deeper Turonian fan where five metres of gas-condensate bearing sandstones were intersected. Interpretation of the extent and thickness of this zone away from the well is ongoing. The Deepwater Millennium drillship drilled Enyenra-2A to a total depth of 4,234 metres in water depths of 1,674 metres. On completion of operations, the well will be suspended for later use. Prior to flow testing, pressure gauges will be deployed to measure reservoir connectivity. The drillship will remain in the Deepwater Tano block to complete the drilling of the Tweneboa-4 well. The next appraisal well will be Enyenra-3A located up-dip to the north of the Owo-1 discovery. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

10 Jan 2011

Tweneboa-3 appraisal well confirms Greater Tweneboa Area resource potential

Tullow Oil plc (Tullow) announces that the Tweneboa-3 appraisal well in the Deepwater Tano licence offshore Ghana has successfully encountered gas condensate in excellent quality sandstone reservoirs. Results of drilling, wireline logs and samples of reservoir fluids, together with the well's down-dip position confirms the Greater Tweneboa Area resource base potential. The well, located over six kilometres south-east of the Tweneboa-2 well and 12 kilometres south-east from the Tweneboa-1 discovery well, was planned with two deviated boreholes to test separate areas of the Tweneboa field. The first leg was drilled to calibrate the potential of an area with a very weak seismic response. Within prognosis, this leg encountered thin reservoir sands and approximately 9 metres of gas condensate pay. The well was then sidetracked 550 metres west, targeting the significant Ntomme anomaly, an area of strong seismic response. This leg successfully encountered a gross vertical reservoir interval of approximately 65 metres containing 34 metres of net gas condensate pay in two zones of high quality stacked reservoir sandstones. Work is underway to integrate seismic, pressure and hydrocarbon phase data in order to progress development options for the Tweneboa and Enyenra (Owo) fields in the Greater Tweneboa Area. Tweneboa-3 was drilled by the Deepwater Millennium drillship to a total depth of 3,906 metres in a water depth of 1,601 metres. On completion of operations, the well will be suspended for future use in the field development. The rig will remain in the Deepwater Tano block to drill the top-hole section of the Tweneboa-4 appraisal well which will then be suspended before moving to drill the high impact Enyenra-2A well which will appraise down-dip from the Owo-1 oil discovery. The significant oil discovery, made by the Owo-1 exploration well has now been named the Enyenra field. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy Ghana (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

15 Nov 2010

Oil discovery in the Mercury-1 exploration well offshore Sierra Leone

Anadarko Petroleum Corporation (NYSE: APC) today announced the Mercury-1 exploration well offshore Sierra Leone encountered approximately 135 net feet of oil pay in two Cretaceous-age fan systems. Mercury is the company's second deepwater test in the Sierra Leone-Liberian Basin and was drilled to a total depth of approximately 15,950 feet in about 5,250 feet of water. "The Mercury well demonstrates that the stratigraphic trapping systems we've identified are working, and that the petroleum system is generating high-quality oil," Anadarko Sr. Vice President, Worldwide Exploration Bob Daniels said. "In the primary objective, the Mercury well encountered approximately 114 net feet of light sweet crude oil with a gravity of between 34 and 42 degrees API, with no water contact. An additional 21 net feet of 24-degree gravity crude was encountered in a shallower secondary objective. "These results continue to build momentum in the basin and enhance our confidence in the team's seismic interpretation and geologic modeling," added Daniels. "We are preserving the wellbore for potential re-entry, DST (drillstem testing) or a down-dip sidetrack to further delineate the reservoir's areal extent, quality and deliverability. We also plan to continue working with the government of Sierra Leone and our partnership to accelerate exploration and appraisal activity in the area in 2011." The Mercury discovery is located in offshore block SL-07B-10 approximately 40 miles east-southeast of Anadarko's previously announced Venus discovery. Anadarko holds an interest in more than 4.6 million acres on five deepwater blocks offshore Sierra Leone and Liberia, and has identified more than 17 prospects and leads on 3-D seismic on this acreage. Once operations are complete at the Mercury well, the company has committed to mobilize the drillship to Ghana to accelerate the appraisal program at the Owo and Tweneboa fields, which the company anticipates sanctioning in 2011. Anadarko operates block SL-07B-10 with a 65-percent working interest. Co-owners in the block include Repsol Exploracion Sierra Leone, S.L. (25-percent working interest) and Tullow Sierra Leone B.V. (10-percent working interest).

21 Oct 2010

Onyina-1 exploration well finds water bearing reservoirs

Tullow Oil plc (Tullow) announces that the Onyina-1 exploration well in the Deepwater Tano licence offshore Ghana encountered water bearing reservoirs. The Onyina-1 well was drilled to explore a large, high-risk, Campanian prospect between the Tweneboa and Jubilee fields in the northeast of the Deepwater Tano Licence. It intersected 49 metres of good quality sandstone reservoir, on prognosis, however they were water bearing at this location. The Sedco-702 dynamically positioned semi-submersible rig drilled Onyina-1 to a total depth of 2,730 metres in water depths of 828 metres. On completion of operations, the rig will move to the Jubilee Unit to assist in the preparations for first oil later in 2010. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy Ghana (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest). Commenting today, Angus McCoss, Exploration Director, said: "The negative test of the Campanian reservoirs in the Onyina prospect enables further refinement of our exploration and relinquishment strategy offshore Ghana. Good quality Campanian reservoir sands were found as predicted, however the lack of hydrocarbons at this location highlights the high risks of charging and trapping oil in this secondary play. Our main focus remains on the lower risk primary play, the deeper more prospective Turonian reservoirs, where we have had such outstanding success with Jubilee, Tweneboa and Owo."

13 Sep 2010

Owo-1 sidetrack confirms major oil discovery

Tullow Oil plc (Tullow) announces that the Owo-1 exploration sidetrack in the Deepwater Tano licence offshore Ghana has significantly extended the column of high quality light oil discovered by the Owo-1 well. Results of drilling, wireline logs and samples of reservoir fluids confirm that Owo is a major new oil field. The Owo-1 well encountered 53 metres of net oil pay and the sidetrack, drilled 0.6 km east of the Owo discovery well, encountered an additional 16 metres of net oil pay in the lower part of the same channel system. Pressure data indicates that this oil pay is in communication with the reservoirs penetrated in the Owo-1 well and confirms at least 69 metres of total net oil pay in a substantial gross oil column of 200 metres. Beneath the Owo oil field, 13 metres of net condensate pay was also discovered, with an additional 6 metres of net gas pay logged in the deepest sand encountered. No water was encountered in any of the hydrocarbon bearing reservoirs in either well. Following completion of logging operations the well will be suspended for future use in appraisal and development. The Sedco-702 dynamically positioned semi-submersible drilled the Owo-1 sidetrack to a final depth of 3,998 metres in water depths of 1,428 metres. On completion of operations, the rig will remain in the Deepwater Tano block to drill the Onyina-1 exploration well which targets a large Campanian prospect between the Tweneboa and Jubilee fields. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy Ghana (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

16 Sep 2009

Oil discovery in the Venus-B1 exploration well offshore Sierra Leone

Anadarko Petroleum Corporation (NYSE: APC) today announced a deepwater discovery at the Venus exploration well in block SL 6/07 offshore Sierra Leone. The Venus B-1 well was drilled to a total depth of approximately 18,500 feet in about 5,900 feet of water and encountered more than 45 net feet of hydrocarbon pay. Venus is the first deepwater test in the Sierra Leone-Liberian Basin. "The Venus discovery confirms the existence of an active petroleum system in the basin and enhances the prospectivity of our vast West Africa acreage position," said Bob Daniels, Anadarko Sr. Vice President, Worldwide Exploration. "With Jubilee on the east and Venus on the west, we have established bookends spanning approximately 1,100 kilometers (700 miles) across two of the most exciting and highly prospective basins in the world. Anadarko and our partners are evaluating the initial results of the well and the forward plan for the prospect, and anticipate additional drilling in the area. We are optimistic that the continued success of our West African Cretaceous program will create substantial value for our stakeholders as well as the people of West Africa through continued investment and increased activity. Anadarko plans to drill two to five wells in the trend next year." The Venus prospect is one of Anadarko's more than 30 identified prospects and leads on its West Africa acreage position, which includes interests in almost 8 million acres across 10 blocks offshore Sierra Leone, Liberia, Côte d'Ivoire and Ghana. Anadarko operates seven of the blocks and the majority of the identified prospects with an average working interest of approximately 40 percent. The company plans to continue its West Africa drilling operations in the Cretaceous Trend by drilling the South Grand Lahou exploration well in block CI 105 offshore Cote d'Ivoire once activities are completed at the Venus discovery well. Anadarko operates the Venus well with a 40-percent working interest. Co-owners in the discovery include Woodside (25-percent working interest), Repsol (25-percent working interest) and Tullow (10-percent working interest).

23 Jan 2006

Drilling Update

Afren (AIM:AFR), the oil and gas company focused on establishing itself as the premier pan-African independent exploration and production company, announces that Chevron, the Operator of Block 1 of the Nigeria - Sao Tome and Principe Joint Development Zone ('JDZ') has confirmed that it has commenced drilling of the first exploration well on this licence on 14 January 2006. The Obo-1 well is located in approximately 1,750m of water (5,750 ft) and should be completed in approximately 60 days, assuming no technical challenges are encountered during the drilling operation. The well is being drilled by the Deepwater Discovery Drillship, which is contracted to Chevron by Transocean. The JDZ Block-1 is located approximately 190 miles (300 km) north of the city of Sao Tome and approximately 125 miles (200 km) south of the city of Port Harcourt in Nigeria. Chevron JDZ Limited has a 51% equity share in the block, ExxonMobil holds 40% equity, and Dangote Energy Equity Resources Limited holds the remaining 9% equity. Afren plc is the beneficial owner of 49% of the equity in Dangote Energy Equity Resources Limited, through its wholly owned subsidiary Energy Equity Resources A.S.

30 May 2006

Obo-1 Discovery in Block 1 of the Nigeria Sao Tome and Principe Joint Development Zone Confirmed

Afren (AIM:AFR), the oil and gas company focused on establishing itself as the premier pan-African independent exploration and production company, announces that Chevron, the Operator of Block 1 of the Nigeria Sao Tome and Principe Joint Development Zone ("JDZ"), has confirmed that it has discovered hydrocarbons in the Obo-1 well, which is the first exploration well in this area. The Obo-1 well logged a cumulative total of at least 150 feet (45 meters) of net hydrocarbon pay in multiple reservoirs and provided important reservoir rock and liquid samples. The well is located in 1,720 meters of water (5,640 feet) The JDZ Block-1 is located approximately 190 miles (300 km) north of the city of Sao Tome and approximately 125 miles (200 km) south of the city of Port Harcourt in Nigeria. Chevron JDZ Limited has a 51 percent equity share in the block, ExxonMobil holds 40 percent, and Dangote Energy Equity Resources Limited holds the remaining 9 percent. Afren plc is the beneficial owner of 49 percent of the equity in Dangote Energy Equity Resources Limited, through its wholly owned subsidiary Energy Equity Resources A.S.

20 Dec 2013

FD-1 wildcat exploration well to be plugged and abandoned

The following operational update relates to Cairn’s 2013/14 exploration drilling campaign offshore Morocco where drilling operations commenced in late October 2013. The FD-1 exploration well is located in 1,500 metres (m) of water approximately 120km offshore Morocco in the Foum Draa block (Cairn 50% Working Interest (WI) and Operator). The primary target of the well was a Late Jurassic/Early Cretaceous deep-water turbidite slope fan and channel complex. The FD-1 well has reached a Total Depth of 5,255m but has not encountered clastic reservoirs, although it has penetrated the oldest stratigraphic section of any deep water exploration well along the Moroccan margin. Gas shows and gas composition ratios encountered in the well have confirmed an active thermogenic petroleum system. The well is now being plugged and abandoned. Cairn is the Operator through its wholly owned subsidiary Capricorn Exploration and Development Limited with Joint Venture partners ONHYM, San Leon Energy plc, Serica Energy plc and Longreach Oil & Gas Limited. The next well in Cairn’s planned exploration programme is in the Juby Maritime III block in Morocco (Cairn 37.5% WI, Operator) and it will target a Middle Jurassic carbonate prospect located in 100m of water where the primary objective is some 1,000m below the 1969 Cap Juby oil discovery in the Upper Jurassic. Operations will commence on Cap Juby once the FD-1 well has been successfully plugged and abandoned.

28 Oct 2013

Cairn starts drilling operations offshore Morocco

Cairn is pleased to announce it has entered into a farm-in agreement with Kosmos Energy and the Moroccan National Oil Company (ONHYM) for a 20% non-operated interest in an exploration block offshore North West Africa which is scheduled for drilling in H2 2014. The farm-in to the Cap Boujdour exploration permit enables Cairn to access frontier acreage with transformational potential and containing a range of exploration play types. In the event of success, the area has significant follow-up potential. The permit is ~50 kilometres (km) offshore Morocco, covering an area of 27,700km2 in the Aaiun Basin in water depths of 1,000 - 3,000 metres (m). The permit is covered by a regional 2D grid and 2,000 km2 3D seismic surveys. Kosmos has identified three prospects within the 3D area with the largest of these, Gargaa located at ~2,135m water depth. Under the terms of the farm-in agreement, which is subject to Morocco Government approval, Cairn will pay a promoted share of future exploration costs, towards a 3D seismic survey, an exploration well planned for 2014 and, if successful, two appraisal wells, all subject to a maximum expenditure cap. Cairn also announces that it has now commenced drilling operations on the FD-I wildcat exploration well on the F prospect offshore Morocco using the Cajun Express, a fifth generation semi-submersible drilling unit. The FD-I exploration well is located in 1,500m of water approximately 120km offshore Morocco in the Foum Draa block (Cairn 50% Working Interest (WI) and Operator). The well has a planned Total Depth of 5,500m True Vertical Depth Sub Sea (TVDSS) and operations are anticipated to take approximately 60 days. This well is the first in a planned multi-well exploration sequence and once operations are completed on FD-1 the rig will move to the Cap Juby location in Morocco to drill an exploration well targeting Middle Jurassic carbonates, subject to necessary approvals. Cairn, through its wholly owned subsidiary Capricorn Exploration and Development Limited, partners in the project with ONHYM, San Leon Energy, Serica Energy plc and Longreach Oil & Gas Ltd.

15 Apr 2013

Cairn secures rig for Frontier Exploration Campaign

Cairn is pleased to announce it has secured a long term contract with Transocean for the “Cajun Express” drilling unit. The rig, which is on an initial one-year contract, will be used on Cairn’s planned multi-well frontier exploration programme in Senegal, Morocco and potentially other areas. Subject to obtaining the necessary approvals the rig will be mobilised to begin operations for Cairn, offshore Morocco on the Foum Draa licence in H2 2013. The Cajun Express, is a deep-water, 5th Generation, dynamically positioned, semi-submersible drilling rig with shallow mooring capabilities and a 15,000 psi bop stack. The historic performance of the Cajun Express indicates it is a highly efficient rig with low operating downtime.

27 Dec 2007

Lundin Petroleum Secures Drilling Rig for PL 304 Aegis Exploration Well

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that Aker Exploration AS will acquire an interest in production licence PL 304, located on the Norwegian Continental Shelf (NCS) in the North Sea.Aker Exploration will supply the Aker Barents drilling rig to drill the Aegis prospect in PL 304. Aker Exploration will acquire a 10 percent licence interest from Lundin Petroleum and a 20 percent interest from Endeavour Energy Norge. Following the transaction, Lundin Petroleum, the PL 304 operator, will retain a 50 percent licence interest and Endeavour Energy will hold 20 percent. The transaction is subject to approval by Norwegian regulatory authorities. The Aker Barents is owned by Aker Drilling and is a sixth-generation semi-submersible drilling rig.Drilling of the PL 304 Aegis exploration well is expected to begin in late 2008.

27 Dec 2007

LUNDIN PETROLEUM SECURES DRILLING RIG FOR PL 304 AEGIS EXPLORATION WELL

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that Aker Exploration AS will acquire an interest in production licence PL 304, located on the Norwegian Continental Shelf (NCS) in the North Sea.Aker Exploration will supply the Aker Barents drilling rig to drill the Aegis prospect in PL 304. Aker Exploration will acquire a 10 percent licence interest from Lundin Petroleum and a 20 percent interest from Endeavour Energy Norge. Following the transaction, Lundin Petroleum, the PL 304 operator, will retain a 50 percent licence interest and Endeavour Energy will hold 20 percent. The transaction is subject to approval by Norwegian regulatory authorities. The Aker Barents is owned by Aker Drilling and is a sixth-generation semi-submersible drilling rig.Drilling of the PL 304 Aegis exploration well is expected to begin in late 2008.

18 Jan 2010

EXPLORATION WELL IN PL476 SPUDDED, OFFSHORE NORWAY

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of the exploration well 6507/11-10 on the Frusalen prospect has commenced. The well is located in licence PL476 in the Norwegian North Sea. PL476 is located some 10 km northeast of the Midgard part of the Åsgard Field. Well 6507/11-10 will target sandstones of Middle Jurassic age in a structural trap. The Frusalen prospect is estimated to contain gross unrisked prospective resources of 45 millions of oil equivalents (MMboe). The planned total depth is approximately 2,300 meters below mean sea level. The well will be drilled from the semi-submersible drilling rig Songa Delta. Drilling is expected to take approximately 35 days. Lundin Petroleum has a 30 percent working interest in the licence which is operated by Det Norske Oljeselskap ASA (Det Norske).

4 Feb 2010

EXPLORATION WELL IN PL359 SPUDDED, OFFSHORE NORWAY

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 16/4-5 on the Luno High prospect in the Greater Luno Area has commenced. The well in PL359 is located 9 km south of the Luno field on the southern Utsira High in the North Sea. Well 16/4-5 in PL359 will target sandstones of Jurassic and Triassic age in a combined stratigraphic-/structural trap. The Luno High prospect is estimated to contain gross unrisked prospective resources of 103 MMboe. The well will also test potential basement prospectivity similar to that encountered in well 16/1-12 (Luno South). The planned total depth is approximately 2,275 meters below mean sea level. The well will be drilled from the semi-submersible drilling rig Transocean Winner. Drilling is expected to take approximately 50 days. Lundin Petroleum is the operator and has a 40 percent working interest in the license. Partners are Statoil Petroleum AS with 30 percent and Premier Oil Norge AS with 30 percent.

31 May 2010

LUNDIN PETROLEUM EXPLORATION WELL TO TARGET THE APOLLO PROSPECT IN PL338

Lundin Petroleum AB ("Lundin Petroleum") will drill a new exploration well 16/1-14 in PL338. The well will target the Apollo structure, which is situated immediately to the south of the Draupne field in PL001B, and some 5 kms northwest of and down-dip from the Luno field located in PL338. The main objective of the Apollo well is to test what is believed to be a possible extension of the Draupne field into PL338. This discovery, which was recently successfully appraised by the Draupne field partners, is in Upper Jurassic sands at a depth of some 2,400m below sea level. Lundin Petroleum currently estimates unrisked gross prospective resources in the range of 20 to 130 MMboe for the Apollo prospect in PL338. The range of the resources quoted is dependent on the geological model used which is very sensitive to sand thickness variations towards the south into license PL338. The well will be drilled in the third quarter 2010 with the rig Transocean Winner. Lundin Petroleum is the operator of PL338 with a 50 percent interest. Partners are Wintershall Norge ASA with 30 percent and RWE DEA Norge AS with 20 percent interest. Ashley Heppenstall President & CEO commented: "The Apollo well will test an extension of a proven and tested hydrocarbon accumulation with upside potential based upon our geological model. The prospect is close to the Luno discovery and further exploration success in the area will clearly be beneficial in respect of the development of the Greater Luno Area"

21 Jul 2010

LUNDIN PETROLEUM HAS SPUDDED AVALDSNES EXPLORATION WELL, OFFSHORE NORWAY

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 16/2-6 on the Avaldsnes prospect has commenced. The well is located in Block 16/2, production licence PL501, in the central North Sea sector of the Norwegian Continental Shelf (NCS). The Avaldsnes prospect is located approximately 25 km east of the Lundin Petroleum operated Luno discovery, on the opposite side of the Utsira structural high. The target is a Lower Cretaceous/Jurassic age sandstone sequence, analogous to the Luno reservoir, within a combined stratigraphic/four-way dip closure. The gross unrisked prospective resource of the primary Avaldsnes target is estimated by the operator at approximately 130 million barrels of oil equivalent (MMboe). Lundin Petroleum is using the semi submersible drilling rig Transocean Winner to drill the prospect. Drilling is expected to take approximately 38 days, excluding testing. Lundin Norway AS is the operator with 40 percent interest. Partners are Statoil Petroleum AS with 40 percent interest and Maersk Oil Norway AS with 20 percent interest.

24 Sep 2010

LUNDIN PETROLEUM SPUDS THE APOLLO PROSPECT EXPLORATION WELL 16/1-14 ON PL338, OFFSHORE NORWAY

Lundin Petroleum AB ("Lundin Petroleum") is pleased to announce that drilling of exploration well 16/1-14 in PL338, has commenced. The well will target the Apollo structure, which is situated immediately to the south of the Draupne field in PL001B, and some 5 kms northwest of and down-dip from the Luno field located in PL338. The main objective of the Apollo well is to test a possible extension of the Draupne field into PL338. Lundin Petroleum currently estimates unrisked gross prospective resources in the range of 20 to 130 million barrels of oil equivalents (MMboe) for the Apollo prospect in PL338. The planned depth is approximately 2,500 metres below mean sea level and the well will be drilled using the semi-submersible drilling rig Transocean Winner. Drilling is expected to take approximately 50 days. Lundin Petroleum is the operator of PL338 with 50 percent interest. Partners are Wintershall Norge ASA with 30 percent and RWE Dea Norge AS with 20 percent interest.

15 Feb 2011

CATERPILLAR EXPLORATION WELL IN NORWAY IS AN OIL DISCOVERY

Lundin Petroleum AB has successfully concluded the drilling of the Caterpillar exploration well (24/9-10S) and its side track (24/9-10A) located in production licence PL340 BS approximately 31 kilometres south of the Alvheim FPSO in the Norwegian North Sea. The Caterpillar exploration well reached a total vertical depth of 2,161m in the Paleocene Lista Formation. The primary objective of the Caterpillar exploration well was to prove oil in the upper Paleocene reservoir rocks (Hermod Formation). Both the Caterpillar main exploration well as well as its sidetrack encountered respectively a 26 and 24 meter oil column in sandstone reservoir in the Hermod Formation. A comprehensive data acquisition programme was undertaken. Preliminary gross resource range for the Caterpillar discovery is estimated at between 5 to 12 million barrels of oil equivalent (MMboe). Development studies are progressing for the Bøyla (formerly Marihøne) field tieback to the Alvheim FPSO. The Caterpillar discovery located 8 kilometres to the southeast of Bøyla is likely be developed as part of the Bøyla development concept. Ashley Heppenstall President and CEO of Lundin Petroleum comments: "We are very pleased to find additional resources in the Greater Alvheim Area. The Caterpillar discovery will be developed with the Bøyla field as a tieback to the Alvheim FPSO controlled by the same partners." Lundin Petroleum holds 15 percent interest in PL340BS. Partners are Marathon Petroleum (operator) with 65 percent interest and ConocoPhillips with 20 percent. The Transocean Winner rig will now move to production license PL505 to drill the Earb south prospect where Lundin Petroleum has a working interest of 30%.

23 Feb 2011

THE EARB EXPLORATION WELL IN PL505 HAS SPUDDED, OFFSHORE NORWAY

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 25/10-11 on the Earb South prospect has commenced. The well is located in licence PL505 in the Norwegian North Sea. The Earb South prospect is located 15 km west of the Balder Field and 35km south of the Heimdal facilities. The well will target sandstones within the Draupne Formation (Brae Formation equivalent) and the Hugin Formation. The Earb South prospect is estimated by Lundin Petroleum to contain gross unrisked prospective gas and condensate resources of 81 million barrel oil equivalents (MMBOE). The planned total depth is 4,460 metres below mean sea level. The well will be drilled with the drilling rig Transocean Winner, and the duration is expected to be 90 days excluding test. Lundin Petroleum holds 30 percent interest in PL505. Partners are Marathon Petroleum Norge AS (operator) with 50 percent interest and VNG with 20 percent.

16 May 2011

LUNDIN PETROLEUM SPUDS SKALLE EXPLORATION WELL IN BARENTS SEA

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 7120/2-3 in PL438 has commenced. The well will target the Skalle prospect, which is situated to the north of the Snøhvit field in the Barents Sea, offshore Norway. The main objective of well 7120/2-3 is to test Cretaceous and Jurassic/Triassic age sandstones of a multiple target structure. Lundin Petroleum estimates the Skalle prospect contains unrisked, gross, prospective resources of 250 million barrels of oil equivalent (MMboe). The planned total depth is 2,650 meters below mean seal level and the well will be drilled using the semi-submersible drilling rig Transocean Leader. Drilling is expected to take approximately 60 days. Lundin Petroleum is the operator of PL438 with 25 percent interest. Partners are RWE Dea Norge AS with 20 percent interest, Petoro AS with 20 percent, Spring Energy with 17.5 percent and Talisman Energy Norge with 17.5 percent interest.

19 Nov 2012

LUNDIN PETROLEUM COMPLETES THE SNURREVAD-JUKSA EXPLORATION WELL IN THE BARENTS SEA

Lundin Petroleum AB (Lundin Petroleum), through its wholly owned subsidiary Lundin Norway AS (Lundin Norway), is in the process of completing the drilling of exploration well 7120/6-3 S in PL490. The well targeted two levels in the Snurrevad-Juksa prospect situated 10 km north west of the Snøhvit field in Barents Sea, offshore northern Norway. The main objective of the well was to prove the presence of hydrocarbons in Lower Cretaceous/Upper Jurassic reservoirs. Preliminary analysis of a cored section of the reservoir indicate thin oil bearing sands in a 8 to 9 metres zone at the top of a 25 metre Lower Cretaceous sand sequence. No reservoir was found to be present in the Snurrevad target. Further geophysical and geological studies are required to clarify the potential in the Juksa target. The semi-submersible drilling rig Transocean Arctic drilled the well to a total depth of approximately 2,993 metres below mean sea level, in a water depth of 330 metres. Lundin Norway is the operator of PL490 with 50 percent interest. Partners are Spring Energy Norway AS with 30 percent interest and Norwegian Energy Company ASA and with 20 percent interest.

15 Mar 2013

JORVIK EXPLORATION WELL COMPLETED

Lundin Petroleum AB, has, through its wholly owned subsidiary Lundin Norway AS (Lundin Norway), completed the drilling of exploration well 16/1-17 in PL338. The well targeted the Jorvik prospect located in a separate basin directly east of the Edvard Grieg field. The main objective of well 16/1-17 was to prove the presence of oil-bearing sandstones and conglomerates in a basin fill sequence. Based on sampling, mobile oil is proven in tight reservoir, consisting of conglomeratic and pebbly sandstones. The well was drilled into basement and water pressure indicates a pressure regime close to the Edvard Grieg field and the Luno South discovery. Extensive data acquisition and sampling have been carried out in the well. The whole reservoir sequence including basement has been cored. The semi-submersible drilling rig Transocean Winner drilled the well to a total depth of 2,044 metres below mean sea level, in a water depth of 110 metres. Lundin Norway is the operator and has a 50 percent working interest in PL338. Partners are Wintershall Norge AS with 30 percent and OMV (Norge) AS with 20 percent interest.

6 Dec 2013

Statoil makes another high-impact natural gas discovery offshore Tanzania

Statoil and co-venturer ExxonMobil today announce its fifth discovery in Block 2 offshore Tanzania. The discovery of an additional 2-3 trillion cubic feet (Tcf)* of natural gas in place in the Mronge-1 well brings the total of in-place volumes up to 17-20 Tcf in Block 2. Mronge-1 is drilled by the drillship Discoverer Americas, and the site is located 20 kilometres north of the Zafarani discovery, and at 2,500-metre water depth. "We have initiated a new and ambitious drilling campaign offshore Tanzania following four successful discoveries during the first drilling phase. The Mronge-1 well discovered additional gas volumes and furthers the potential for a natural gas development in Tanzania. The new drilling program also allows us to fully explore the remaining exploration potential in Block 2," says Nick Maden, senior vice president for Statoil's exploration activities in the Western hemisphere. The Mronge-1 well discovered gas at two separate levels. The main accumulation is at the same stratigraphic level as proven in the Zafarani-1 well in Block 2. The Zafarani-1 discovery was made in 2012 and was a play opener for the block. The secondary accumulation was encountered in a separate, younger gas bearing reservoir, in a play which previously has not been tested in Block 2. The Mronge-1 discovery is the venture's fifth discovery in Block 2. It was preceded by three successful high-impact gas discoveries during the first drilling phase with Tangawizi-1, Zafarani-1 and Lavani-1, and a deeper discovery in a separate reservoir in Lavani-2. "These are high value resources. The attractiveness is also demonstrated by a recent asset transaction in the neighboring block. The discoveries also demonstrate how Statoil's strategy of focusing on high-impact opportunities is paying off and supports the company's ambition for international growth," Maden says. "The Tanzania government is pleased to learn about additional gas resources discovered in Block 2," says Hon. Prof. Sospeter Muhongo, Minister for Energy and Minerals in Tanzania. The Statoil-operated partnership started its new drilling campaign in Block 2 in September 2013. In addition to Mronge-1, the campaign includes drilling of several new prospects and appraisal of previous discoveries. Following Mronge-1, the partnership is scheduled to appraise the 2012 Zafarani discovery. Statoil operates the licence on Block 2 on behalf of Tanzania Petroleum Development Corporation (TPDC) and has a 65% working interest, with ExxonMobil Exploration and Production Tanzania Limited holding the remaining 35%. Statoil has been in Tanzania since 2007, when it was awarded the operatorship for Block 2.

14 Feb 2014

'Transocean Barents' to drill wildcat well in production license 607

The Norwegian Petroleum Directorate has granted GDF SUEZ E&P Norge AS a drilling permit for wellbore 7218/8-1, cf. Section 8 of the Resource Management Regulations. Wellbore 7218/8-1 will be drilled from the Transocean Barents drilling facility at position 72°20’00.70” north and 18°28’38.46” east, following completion of the drilling of wildcat well 7222/11-1 for Det norske oljeselskap in production licence 657. The drilling programme for wellbore 7218/8-1 concerns the drilling of a wildcat well in production licence 607. GDF SUEZ E&P Norge AS is the operator with an ownership interest of 60 per cent. The other licensees are Concedo ASA (20 per cent) and OMV (Norge) AS (20 per cent). The area in this licence consists of parts of the blocks 7218/8, 7218/9 and 7219/7. The well be drilled about 65 kilometres west of the Johan Castberg area. Production licence 607 was awarded on 13 May 2011 (the 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 having secured all other permits and consents required by other authorities before the drilling starts.

14 Feb 2014

NPD grants Statoil permit to drill 35/11-17 well in Norway

The Norwegian Petroleum Directorate has granted Statoil a drilling permit for wellbore 35/11-17, cf. Section 8 of the Resource Management Regulations. Wellbore 35/11-17 will be drilled from the Songa Trym drilling facility at position 61°03’31.22”N and 3°31’56.88”E following completion of the drilling of wildcat well 35/11-16 for Statoil in production licence 090B. The drilling programme for well 35/11-17 concerns drilling of a wildcat well in production licence 090, where Statoil is the operator with an ownership interest of 45 per cent. The other licensees are ExxonMobil (25 per cent), Idemitsu Petroleum (15 per cent) and GDF Suez (15 per cent). The area in this licence consists of parts of block 35/11. The well will be drilled about one kilometre southeast of Fram. Production licence 090 was awarded on 9 March 1984 in the eighth licensing round on the Norwegian shelf. This is the 16th well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

18 Jun 2008

The Trow Prospect (Well 32/2-1) Spudded in PL 369

Talisman Energy has commenced drilling operations in Production License 369 with the semi-submersible drilling rig Transocean Winner. The exploration well, located east of the Troll Field, is aiming for hydrocarbons in Jurassic sandstones (Trow prospect). Det norske estimates that Trow could hold 100 million barrels of oil equivalents, with a discovery probability of 20%. The drilling operation is expected to take about 28 days. Det norske holds a 20% interest in PL 369. Operator Talisman Energy holds 40%. Other licensees include Petro Canada Norge and Revus, with a 20% interest each.

21 Feb 2014

Langlitinden exploration well drilled in Barents Sea close to completion

Lundin Petroleum AB (Lundin Petroleum) is announcing, through its wholly owned subsidiary Lundin Norway AS (Lundin Norway), that well 7222/11-2 on the Langlitinden prospect in PL659 in the Barents Sea is being completed. Logs and samples have been acquired. Oil with very low mobility was sampled in Middle Triassic sandstones. No pressure gradient was established. The well was drilled to a total depth of 2,878 metres below mean sea level in water depth of approximately 340 metres. The well will be permanently plugged and abandoned. Det norske is the operator with 20 percent working interest with partners Lundin Norway with 20 percent, Tullow with 15 percent, Rocksource with 5 percent, Petoro with 30 percent and Atlantic Petroleum with 10 percent working interest.

26 Feb 2014

Transocean announces construction of two newbuild drillships

Transocean Ltd (Transocean) has announced that the company has contracted Sembcorp Marine’s Jurong Shipyard in Singapore for the construction of two newbuild ultra-deepwater drillships. The two newbuild drillships are to be constructed to Jurong Shipyard’s proprietary Jurong Espadon III rig design and are expected to be delivered from the yard in Q2 2017 and Q1 2018. Both units will be capable of operating in water depths up to 12,000ft whilst drilling down to maximum depths of 40,000ft and are capable of accommodating up to 220 personnel. Transocean will pay a total of US$1.24 billion for the construction of the assets including shipyard contracts, project management, owner-furnished equipment, inventory and capital spares. The two firm drillship orders come with three additional construction options, which must be exercised at various times within a 24 month period and offer similar financial terms as the currently placed firm orders.

3 Mar 2014

GDF Suez completes wildcat well 7222/11-2 in Norway

Det norske oljeselskap ASA, operator of production licence 659, has concluded the drilling of wildcat well 7222/11-2. The well was drilled about 80 kilometres northeast of the Snøhvit field in the Barents Sea and about 160 kilometres northwest of Hammerfest. The objective of the well was to prove petroleum in reservoir rocks from the Middle Triassic (Kobbe formation). The well encountered a gross oil column of about 30 metres in the Kobbe formation, of which about 20 metres in sandstone with much poorer reservoir quality than expected. Several thin layers of sandstone were also encountered deeper in the Kobbe formation, but these were tight. The poor reservoir properties made it impossible to establish gradients from the pressure measurements. Therefore, no oil/water contact was encountered. Preliminary assessments indicate that the discovery is not commercially interesting. Extensive data acquisition and sampling have been carried out. A formation test (mini-DST) was performed, but revealed very poor flow properties. This is the first exploration well in production licence 659. The licence was awarded in APA 2011. The well was drilled to a vertical depth of 2918 metres below the sea surface, and was terminated in the Klappmyss formation from the Early Triassic. The water depth is 338 metres. The well will now be permanently plugged and abandoned. Well 7222/11-2 was drilled by the Transocean Barents drilling facility, which will now proceed to production licence 607 to drill wildcat well 7218/8-1, where GDF SUEZ E&P Norge AS is the operator.

6 Oct 2005

Rosneft-BP joint venture makes second discovery in Sakhalin

CJSC “Elvary Neftegas” (Rosneft-BP joint venture) today announced the successful completion of drilling and testing of its second exploratory well in the Kaigansky–Vasuykansky exploration licence. The offshore licence block, covering over 6,000 square kilometres, lies in the south of the Sakhalin-5 acreage, north-east of Sakhalin Island. The Udachnaya well was drilled to a total depth of 2,705 meters and encountered hydrocarbons in three zones. A restricted test programme was conducted on a single zone which flowed at a rate of 1,900 barrels of oil per day through a 28/64-inch choke. This second discovery in the block was made by the Transocean Legend semi-submersible drilling rig on the Udachnaya structure located about 40 kilometers offshore, in water depths of some 100 metres. The first well in the Kaigansky-Vasuykansky exploration licence was drilled in 2004 on the Pela Lache structure some 15 kilometres to the east. It encountered significant volumes of oil and gas in a number of high-quality sandstone reservoirs. Elvary Neftegas plans to continue exploratory drilling in 2006.

1 Feb 2008

New oil discovery on UK continental shelf

BP and its partner, Marathon Petroleum West of Shetlands Ltd, today announced a new oil discovery in Block 204/23, following drilling on the South-West Foinaven prospect, some 190 kilometres west of the Shetland Islands. The exploration well 204/23-2 was drilled using the Paul B Loyd Junior semi-submersible drilling rig. Located 11 kilometres south-west of the Foinaven Floating, Production, Storage & Offloading (FPSO) vessel, the well reached a total depth of 2,528 metres below sea level. BP, together with its partner, is now evaluating the discovery and the potential for a two well subsea development, tied back to the Foinaven FPSO. Dave Blackwood, head of BP's North Sea business, said, "Discoveries like this are key to the future of the North Sea and, combined with continuing investment in brownfield development, will make best use of the existing offshore infrastructure. BP is always looking for new opportunities to invest, particularly around our existing acreage to extend the life of the North Sea." Licence P1263, comprising parts of blocks 204/ 23 and 204/24 was awarded to BP for operatorship (72% equity) and Marathon Oil (28%) in 2005 following the successful award in the 23rd Offshore Licensing Round.

29 Jun 2001

Duster off Ireland

Statoil Exploration Ireland has completed exploratory drilling of the Sarsfield Prospect off Ireland without finding any hydrocarbons. The well has been plugged and abandoned. Initial findings indicate that the Sarsfield Prospect does not contain reserves of oil or gas. Sarsfield is located in the Porcupine Basin, about 170 kilometres west of County Kerry. Over the coming months Statoil Exploration will analyse the data from the well to determine whether further exploration will be carried out in this area. Having completed drilling, the Transocean rig Sovereign Explorer is now on its way to the Faroes. According to Egil Endresen in Statoil Exploration Ireland, these results are disappointing. "But we were always cautious with our outlook. We have obtained valuable drilling data which we will study in the coming months to ascertain if further exploratory drilling in the area is an option at some future date", says Mr Endresen. Statoil Exploration is committed to the Irish continental shelf and has interests in seven licences. The Atlantic Margin, which stretches from off western Ireland to northern Norway, is one of the most important areas in the group's international exploration operations. Statoil Exploration Ireland holds a 42 per cent interest in Sarsfield and is operator on behalf of its partners Chevron, Conoco, Enterprise Energy Ireland and Dana Petroleum.

2 Feb 2001

New find in Barents Sea

Statoil has found oil and gas in production licence 202 in the North Cape Basin, roughly 130 kilometres north-east of Norway's North Cape. The exploration well was drilled in a structure close to a salt diapir, a model not previously explored in the Barents Sea. In 288 metres of water, the well was drilled to a total depth of 2,824 metres below sea level. The find was proven in Triassic sandstone. According to Erik Henriksen, sector manager for the Barents Sea area, it is too early to comment on recoverable resources. Drill rig Transocean Arctic has taken about 100 core samples and extensive logging of the well has been carried out. Further tests are continuing and the data collected will be analysed to determine the size of the find. Statoil is assessing whether appraisal wells should be drilled. Operator Statoil has a 25 per cent share in the licence. The other licensees are the state's direct financial interest (SDFI) with 30 per cent, Amerada Hess (25 per cent) and Norsk Hydro (20 per cent).

20 Dec 2001

Searcher heading for Mikkel

Operator Statoil has awarded Transocean the contract to drill and complete wells on the Mikkel field in the Norwegian Sea. The contract, which includes the drilling and completion of three wells, is valued at around NOK 150 million, reports Kjell Herigstad, special adviser in the production services unit. The work will be carried out from the Transocean Searcher rig starting in September 2002 and is expected to take 140 days. The Mikkel field lies 37 kilometres south of the Åsgard field, where Transocean Searcher has been carrying out drilling and completion operations since 1996. Statoil is exercising its option in the Åsgard drilling contract to extend the work to include the Mikkel field.

13 Dec 2001

New oil find in Visund area

Norsk Hydro has found oil in two separate zones while drilling exploration well 34/8-12 S in the Visund South prospect in the Norwegian sector of the North Sea. "We've made two interesting finds of light oil/condensate in rock dating from between the middle and early Jurassic Age," said Hydro project manager Jan Reidar Johnsen. "Because we've found hydrocarbons in two separate zones, we're optimistic about making more discoveries in the area. Meanwhile, additional exploration and delineation drilling is needed to determine whether the area can be commercially produced." Well 34/8-12 S was drilled by the Transocean Arctic rig to 3,160 meters vertical depth and completed in rock from the Triassic Age. Visund South lies in an area between the Visund, Gullfaks and Snorre field. The well was not tested and is now plugged. The shareholders in development and production license 120 are: Norsk Hydro (operator) with 29 percent, TotalFinaElf at 11 percent, Conoco 13 percent, Petoro 16.9 percent and Statoil 30.1 percent.

21 Aug 2001

Drilling in record time on Åsgard

By using a rotary steerable drilling tool with mud motor, Transocean Winner recently drilled a well in record time on the Åsgard field in the Norwegian Sea. This is the first time on the Norwegian continental shelf, and only the second time in the world, that the PowerDrive drilling tool from Schlumberger has been used in conjunction with a mud motor. The Transocean Winner rig took just three and a half days to drill a 12¼ inch section to the top of the reservoir on the Åsgard field. Normally it would take seven and a half days to drill the 2,150-metre section. The day rate for drilling operations on the rig is around NOK 2 million. A motor was included to achieve a higher rate of penetration (ROP). When directional changes are made with the motor during conventional drilling, ROP is a quarter of that achieved with the new system. The production well was drilled on Smørbukk, which is a hard, deep, high temperature structure. "Not only do drilling operations take less time with the new system, it can also be used for more technically challenging wells," reports Rune Skotvold, lead drilling engineer in Åsgard resource development. He believes that rotary steerable drilling combined with mud motor may be the future on Åsgard, but adds that needs vary a great deal from one field to another. The system is best suited to the most demanding fields, says Mr Skotvold.

6 Apr 2001

Drilling west of Kristin

Transocean Arctic has started drilling an exploration well in the Erlend structure five kilometres west of the Kristin field on the Halten Bank. The purpose of the drilling is to prove gas and condensate in the northern part of the Erlend structure. The well is being drilled in production licence 257, which was awarded in the 16th offshore licensing round. The total depth will be around 5000 metres, and the work is estimated to take 76 days. A minor gas find was previously made in the southern part of the structure. Exploration drilling is also taking place in the M-prospect twelve kilometres north of the Kristin field. Plans call for the Scarabeo 5 rig to complete this drilling at the end of April. The licensees are considering developing the Kristin field with a production platform fully equipped with processing facilities for gas and condensate. Such a solution provides maximum flexibility with regard to linking up to other deposits in the area. Sector manager Ørjan Birkeland in Halten/Nordland exploration says that the results from these wells will have an impact on the long-term development of this part of the Halten Bank. Arrangements will be made for any finds to be hooked up to the Kristin platform. The aim is to present the plan for development and operation to the Ministry of Petroleum and Energy in June this year.

7 Mar 2001

Duster in the Barents Sea

Statoil has finished drilling an exploration well on the Delta structure south east of the Snøhvit field in the Barents Sea. The well was dry. The purpose of the drilling was to prove oil in the Jurassic sandstone of the Delta structure in block 7121/5. This would strengthen the possibilities of a profitable development of the petroleum resources in the Snøhvit area. Drilling was carried out by Transocean Arctic to a total depth of 2265 metres below sea level and terminated in rock of the Triassic period. Only traces of oil and gas in the Jurassic and Triassic sandstone layers were proven. “The result was disappointing, and the possibility of developing the petroleum resources in the Snøhvit area has been weakened,” says Erik Henriksen, exploration manager for the Barents Sea. Statoil has collected around 60 metres of core samples and the well has been logged extensively. Statoil is the operator for production licence 110 in block 7121/5, about 120 kilometres north-west of Hammerfest. Production licence 110 is one of seven licences in the coordinated Snøhvit area.

22 May 2001

Irish well spudded

The first exploration well on the Sarsfield prospect west of Ireland has been spudded by Statoil from Transocean’s Sovereign Explorer rig. Expected to take about 52 days to complete, the well lies in the Porcupine basin about 170 kilometres off County Kerry and in 650 metres of water. Doing the work on behalf of Statoil Exploration Ireland, Sovereign Explorer arrived off the Republic recently after completing an assignment in North African waters. The Sarsfield well ranks as the first to be drilled by Statoil on the Irish continental shelf since 1997. According to Egil Endresen, managing director of Statoil Exploration Ireland, the operation forms part of the group’s commitment to the Atlantic Margin. Extending from west of Ireland to northern Norway, this area is one of the most important for Statoil’s international exploration operations. Results from the well are expected in the autumn, once all the analyses have been completed. Statoil Exploration Ireland has a 38 per cent interest in Sarsfield, with Conoco, Enterprise Energy Ireland and Dana as its partners.

8 Mar 2001

Drilling off Ireland

Statoil plans to drill the first exploration well on the Sarsfield prospect on the Irish continental shelf sometime this spring. Drilling will be carried out by the rig Sovereign Explorer, which will arrive at the field in May. The Sarsfield prospect lies in the Porcupine Basin west of Ireland. Drilling will take place in licence no 8/95 at a water depth of around 650 metres. Other partners in the exploration licence include Conoco UK, Enterprise Energy Ireland and Dana Petroleum. Statoil has chosen Fenit harbour on the west coast of Ireland as the base to provide support for the rig in connection with drilling. According to Egil Endresen, head of Statoil’s exploration off Ireland, the main reason Fenit was selected was because the harbour lies near the field and is well developed. Statoil will be able to utilise the existing infrastructure at the harbour. Statoil has previously drilled one exploration well on the Connemara field in the Porcupine Basin. Results showed that it was not profitable to develop that field.

19 Feb 2001

Drilling new well in the Barents Sea

Statoil has commenced drilling a new exploration well in the Delta structure in block 7121/5 south east of the Snøhvit field in the Barents Sea. Transocean Arctic began drilling in the structure, which lies 120 km north west of Hammerfest, on 16 February. This is the same rig that recently found oil and gas for Statoil on production licence 202 in the North Cape basin. Drilling is important to clarify the oil potential in the area around Snøhvit, says Erik Henriksen, who is in charge of exploration in the Barents Sea. The purpose of the drilling is to determine whether there are hydrocarbons in sandstones from the Jurassic period. The plan is to drill to a total depth of 2184 metres, whilst the water depth at the drilling site is 345 metres. The licensees in Snøhvit intend to send a plan for development and operation (PUD) to the Ministry of Petroleum and Energy in summer 2001. An important part of this work is to evaluate alternative solutions for profitable development of the petroleum resources in the Snøhvit area, says Mr Henriksen.

12 Jul 2001

Historic first for Faroes

Statoil Faerøyene AS started drilling the Longan well off the Faroe Islands yesterday, 11 July. This is the first well ever to be drilled off the Faroes. Rolf Magne Larsen is senior vice president for international exploration. "It is an honour to be a party to the opening of a new area for oil and gas exploration," says Rolf Magne Larsen. "This is an important development for the Faroes and its people." The Longan well is located in the Atlantic Margin area, stretching from Western Ireland to Norway, where Statoil holds substantial exploration acreage. The water depth for this operation exceeds 900 metres. "We have used Statoil's extensive experience as an operator in the North Sea in our preparations for the drilling. We therefore feel confident that the operations will be efficient and have minimal impact on the environment," says Mr Larsen. Statoil Faerøyene is drilling the Longan well on licence 003, which was awarded to the company by The Ministry of Petroleum of The Faroe Islands in August 2000. The prospect is located 130 kilometres south-east of the Faroes, close to the UK continental shelf. The rig used for the Faroese drilling is the semi submersible Sovereign Explorer. Statoil Faerøyene is operator and holds 35 per cent of the licence. The other partners in the licence are Phillips Petroleum Europe Exploration (30 per cent), Enterprise Oil Exploration (20 per cent) and Veba Oil & Gas Faroes (15 per cent).

6 Mar 2014

VNG Norge AS successful with exploration drilling on the Pil prospect in Norway

VNG Norge AS’s (VNG) partner in PL 586; Rocksource ASA (Rocksource) has announced an oil and gas discovery at the Pil prospect in the Norwegian Sea. The Pil prospect well (6406/12-3 S) was drilled by the ‘Transocean Arctic’ rig and the preliminary volumetric estimates indicate recoverable resources above the estimated pre-drill range of 20-50 million barrels of oil equivalent. The 6406/12-3 S well encountered a 226 metre hydrocarbon column, 92 metres of gas and 134 metres of oil in the Rogn formation. Extensive coring and data acquisition has been performed in the reservoir section. Preliminary data indicates good reservoir properties. The well will now be drilled to the planned TD. The partnership has decided to conduct a production test, and a potential side track into the adjacent Bue prospect is under evaluation. Rocksource will provide further information to the market as operations proceed. The PL 586 licence is operated by VNG. Pil is located within tieback distance (33 km) to the producing Njord field. Rocksource, through Rocksource Exploration Norway, holds a 15 percent interest in PL 586. Partners are VNG Norge (Operator) with 30 percent, Spike Exploration 30 percent and Faroe Petroleum 25 percent.

10 Mar 2014

Statoil concludes dry well north of Fram field with 35/11-16 S well

Statoil Petroleum AS, operator of production licence 248 C, is in the process of concluding the drilling of wildcat well 35/11-16 S. The well was drilled about 5.5 kilometres north of the Fram field in the northern North Sea, and about 130 kilometres northwest of Bergen. The objective of the well was to prove petroleum in Upper Jurassic reservoir rocks (intra- Draupne formation sandstones). The well was drilled from production licence 248 C, with exploration target in licence 090 B. The well encountered approx. 9-metres net intra-Draupne formation sandstones with relatively good reservoir properties. Only traces of petroleum were encountered. The well is classified as dry. Data acquisition and sampling have been carried out. The well is the first exploration well in production licence 248 C, which in 2013 was carved out of production licence 248, awarded in the 1999 North Sea Awards. The well was drilled to a vertical depth of 3211 metres below sea level and was terminated in the Heather formation in the Upper Jurassic. Water depth is 367 metres. The well will now be permanently plugged and abandoned. Well 35/11-16 S was drilled by the Songa Trym drilling facility, which will now proceed to the adjacent production licence 90 to drill wildcat well 35/11-17, where Statoil Petroleum AS is the operator.

17 Mar 2014

Cairn Energy releases Morocco drilling update

Cairn Energy (Cairn) has released an operational update relating to its 2014 exploration drilling campaign in Morocco. Cairn’s JM-1 well, which was spudded in January 2014 by Transocean’s ‘Cajun Express’ semisub has reached a total depth of 3,711m and has now been plugged and abandoned without further testing. The well was drilled to evaluate the Upper Jurassic and Middle Jurassic objectives. In the Upper Jurassic section, the well has confirmed the presence of heavy oil over a gross interval of 110 metres as originally tested in the 1968 MO-2 well, some 2km from the JM-1 well. Reservoir quality and the oil gravity in the Upper Jurassic across the Cap Juby structure require further evaluation by Cairn and its joint venture partners (Office National Des Hydrocarbures et Des Mines “ONHYM” and Genel Energy). Work is ongoing to correlate the core and log data from JM-1 with other wells on Cap Juby to evaluate the extent of moveable hydrocarbons and how any further assessment should be conducted. The Middle Jurassic objective was encountered with limited primary porosity and evaluation of well logs and side wall cores continues. The next well in Cairn’s planned exploration programme is ‘FAN-1’ located in the Sangomar, Sangomar Deep and Rufisque blocks (Cairn 40% WI, Operator) offshore Senegal. This well will target multiple stacked structural and stratigraphic fan closures interpreted as trapping a variety of potentially thick, high quality clastic reservoirs.

20 Mar 2014

ConocoPhillips spuds fifth well in Australian exploration campaign

ConocoPhillips has spudded the Poseidon North-1 well, the fifth well in its Browse Basin Phase 2 exploration campaign according to its partner Karoon Gas. The Poseidon North-1 exploration well, located 6.5km north-east of the Poseidon-1 well in permit WA-315-P, is targeting the Plover and Montara formations and has the potential to add significantly to the already discovered Greater Poseidon area. The six well Brows Basin Phase 2 drilling campaign will continue to utilise the ‘Transocean Legend’ semisub rig throughout 2014. Four of the six wells have been completed so far. The well location for the last exploration well will be announced upon joint venture approval. The principal objective of the campaign is to better define the size and quality of the hydrocarbon resource within the exploration permits which contain Greater Poseidon trend. ConocoPhillips is the operator of the WA-315-P Browse Basin permit in which Karoon Gas Australia Ltd currently holds 40%.

24 Mar 2014

OMV receives consent to use the 'Transocean Barents' in Norway

OMV Norge has received consent to carry out exploration drilling of well 7324/7-2 in production licence 537 in the Barents Sea using the ‘Transocean Barents’ mobile drilling facility. Water depth at the site is 418 metres. Drilling is planned to begin in March 2014, with a duration of around 52 days, depending on whether a discovery is made. ‘Transocean Barents’ is a 6th-generation semi-submersible drilling facility of the H-6e type. The facility was built at the Aker Stord yard in Norway and was completed in 2009. ‘Transocean Barents’ is owned and operated by Transocean Norway, with head offices in Stavanger.

25 Mar 2014

Statoil receives consent to use 'Songa Trym' for pluggin work on Glitne field

Statoil has received consent to use the ‘Songa Trym’ mobile drilling facility for permanent well plugging on the Glitne field. Glitne is an abandoned oil field in blocks 15/5 and 15/6 in the North Sea, approx. 40 km north-west of Sleipner Øst. Water depth at the site is 111 metres. Expected start-up of the operation is 10 March 2014 at the earliest. ‘Songa Trym’ is a mobile facility built in Norway at Aker Værdal, and completed in 1976. The facility is owned by Songa Offshore ASA and will be operated by Odfjell Drilling AS.

2 Apr 2014

OMV receives permit for wildcat well in PL537

The Norwegian Petroleum Directorate (NPD) has granted OMV Norge AS a drilling permit for well 7324/7-2, cf. Section 8 of the Resource Management Regulations. Well 7324/7-2 will be drilled from the Transocean Barents drilling facility at position 73°29` 27.09" north and 24°14´ 2.56" east. The drilling programme for well 7324/7-2 relates to the drilling of a wildcat well in production licence 537. OMV Norge AS is the operator with a 25 per cent ownership interest and the other licensees are Idemitsu Petroleum Norge AS with 20 per cent, Petoro AS with 20 per cent, Tullow Oil Norge AS with 20 per cent and Statoil Petroleum AS with 15 per cent. The production licence consists of the blocks 7324/7 and 7324/8, and was awarded in the 20th licensing round in 2009. Wildcat well 7324/7-2 will be the third exploration well in production licence 537. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

10 Apr 2014

GDF comes up dry with Byrkje prospect drilling

GDF SUEZ E&P Norge AS, operator of production licence 607, has concluded drilling of wildcat well 7218/8-1. The well was drilled about 65 kilometres southwest of the oil and gas discovery 7220/8-1 Johan Castberg and 130 km northwest of the Snøhvit field in the Barents Sea. The well's primary exploration target was to prove petroleum in Upper Cretaceous reservoir rocks (the Kviting formation) and Lower Cretaceous (upper part of the Kolmule formation). The secondary exploration target was to prove petroleum in reservoir rocks in the lower part of the Kolmule formation. The well encountered shallow siltstone layers in the Kviting formation with elevated gas readings in a gross interval of about 35 metres. Mobile gas was detected in a sandy siltstone layer. Reservoir rocks were not encountered in the Kolmule formation. The well was classified as dry, with traces of gas. Comprehensive data acquisition and sampling have been carried out. The well is the first exploration well in production licence 607. The production licence was awarded in the 21st licensing round. The well was drilled to a vertical depth of 3000 metres below the sea surface and was terminated in Early Cretaceous rocks from the Kolmule formation. Water depth at the site is 385 metres. The well has now been permanently plugged and abandoned. Well 7218/8-1 S was drilled by the Transocean Barents drilling facility, which will now proceed to production licence 537 in the Barents Sea to drill wildcat well 7324/7-2, where OMV (Norge) AS is the operator.

10 Apr 2014

VNG makes oil and gas discovery whilst drilling in PL586

VNG Norge AS, operator of production licence 586, is in the process of completing the drilling of wildcat well 6406/12-3 S. The well has been drilled about 35 kilometres southwest of the Njord field in the Norwegian Sea. The well's primary exploration target was to prove petroleum in Upper Jurassic reservoir rocks (the Rogn and Melke formations). A 226-metre net hydrocarbon column was encountered, 135 meters of which are oil in Middle Jurassic reservoir rocks with good reservoir quality. The lower part of the Melke formation is aquiferous, with poorer reservoir properties as in the upper part. Comprehensive data acquisition and sampling have been carried out. A successful formation test was carried out in the oil zone. The maximum production rate was 1067 Sm3 of oil per flow day through a 56/64-inch nozzle. The test proved good flow properties and the gas/oil rate is 152 Sm3/Sm3. The preliminary estimation of the discovery size is between 6 and 21 million Sm3 of recoverable oil and condensate and between 2 and 6 billion Sm3 of recoverable gas. The well is the first exploration well in production licence 586. The licence was awarded in APA 2010. The well was drilled to a vertical depth of 3738 metres below sea level and terminated in the Melke formation in the Middle Jurassic. Water depth at the site is 324 metres. The well will now be permanently plugged and abandoned. Well 6406/12-3 S was drilled by Transocean Arctic, which is now moving on to drill appraisal well 6406/12-3 B on the discovery to reduce uncertainty in the resource estimate.

11 Apr 2014

Statoil makes gas and oil discovery near Valemon field in Norway

Statoil Petroleum AS, operator of the production licences in the Valemon Unit, has concluded the drilling of wildcat wells 34/10-54 S and 34/10-54 A. The wells proved oil and gas. The wells were drilled about six kilometres north of the Valemon field in the northern part of the North Sea. The primary exploration target for the wells was to prove petroleum in a separate fault block in Middle and Lower Jurassic rocks (the Brent Group). The secondary exploration target was to prove petroleum in Lower Jurassic reservoir rocks (the Cook formation and the Statfjord group). Well 34/10-54 S encountered a 74-metre gross gas column in the Tarbert and upper Ness formations in the Middle Jurassic, of which 20 metres in sandstone with poor to good reservoir quality. In the middle and lower Ness formation, a 45-metre oil column was encountered, of which 16 metres in sandstone with good reservoir quality. In the Etive formation in the Middle Jurassic, seven metres of sandstone with good reservoir quality was encountered, but this is aquiferous. In the immediately underlying reservoir rocks, in the Rannoch formation in the Middle Jurassic, a 38-metre condensate column in sandstone with poor reservoir quality was encountered. In addition, condensate was encountered in Middle Jurassic sandstone with poor reservoir quality in the Cook formation. Well 34/10-54 A encountered an approx. 100-metre gross gas column in sand of unspecified Jurassic Age and in the Brent Group, of which 40 metres in sandstone with poor reservoir quality. In the Nansen formation from the Lower Jurassic, a 38-metre gas column was encountered, of which 32 metres in sandstone with poor to good reservoir quality. In the Eiriksson formation from the Lower Jurassic, a 77-metre gas column was encountered, of which 31 metres in sandstone with poor reservoir quality. Petroleum was also encountered in Middle Jurassic and Lower Jurassic sandstone with poor reservoir quality in the Cook and Raude formations, but it is currently unclear whether this is oil, condensate or gas. No petroleum/water contact was encountered in the wells. The wells were not formation tested, but comprehensive data acquisition and sampling were carried out. Preliminary estimates of the total size of the discoveries are between 3 and 12 million Sm³ of recoverable oil equivalents. The Valemon Unit licensees will consider tying the discoveries in to the Valemon field. 34/10-54 S and 34/10-54 A were drilled to vertical depths of 4229 and 4247 metres below the sea surface, respectively, and were terminated in the Burton formation and the Statfjord group in the Lower Jurassic, respectively. Water depth at the site is 140 metres. The wells have been permanently plugged and abandoned. Wells 34/10-54 S and -54 A were drilled by the Transocean Leader drilling facility, which will now proceed to PL073 to drill production well 6407/1-A-3, where Statoil Petroleum AS is the operator.

16 Apr 2014

Hurricane Energy mobilises 'Sedco 712' for Lancaster appraisal

Hurricane Energy plc, the UK-based oil and gas company focused on hydrocarbon resources in naturally fractured basement reservoirs, is pleased to announce that it has commenced the mobilisation process for the Transocean ‘Sedco 712’ semi-submersible drilling rig. The planned operation is to drill and test the Lancaster basement oil discovery. Well management company SPD Limited has been contracted to provide well construction and project management services during the drilling campaign. The Lancaster discovery was made in 2009 and further tested in 2010. Hurricane's Competent Person's Report, prepared by RPS Energy Consultants Limited in November 2013, allocates 2C recoverable Contingent Resources of 207 MMboe to Lancaster. The discovery is located across blocks 205/21a, 205/22a and 205/26b West of Shetland on Frontier Licence P1368. All assets under the licence are controlled 100% by Hurricane.

17 Apr 2014

'Cajun Express' commences drilling offshore Senegal

Drilling has begun on the offshore exploration well, FAN-1, offshore Senegal in which FAR Ltd holds a 15% interest (Cairn Energy PLC (“Cairn”) 40%, ConocoPhillips 35%, Petrosen 10%). The FAN-1 well will test a stacked fan structure with the potential to contain approximately 900 million barrels of oil with approximately 135mmbbls net to