Songa Trym (Transocean Offshore Deepwater Drilling Inc.) (Semisub)

Statoil to suspend 'Songa Trym' for remainder of 2014

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06 November 2014

Statoil will suspend Songa Trym contract after the current well at the Oseberg field in the North Sea. The rig is currently performing plug and abandonment activity and is ahead of planned schedule for this scope of work. From mid November 2014, the rig will go on 75% suspension rate (USD279,000 per day) expected until the end of the year 2014. Songa Offshore plan to take the opportunity of this suspension period to accelerate some specific planned maintenance work that is more cost efficiently achieved outside operations. This is the third contract suspension enacted by Statoil in 2014, following the suspension of the COSLPioneer and Scarabeo 5 contracts.

Source: http://www.songaoffshore.com/Pages/Press-releases.aspx#


More News for Operator: Transocean Offshore Deepwater Drilling Inc.

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 FAR Ltd. The well will be drilled using the fifth generation rig, the ‘Cajun Express’, which arrived on site Saturday 12th April. FAN-1 is the first exploration well in a two well programme, offshore Senegal with the wells to be drilled back to back. The first well will be located on the North Fan prospect in 1,500m water depth. This well will be immediately followed by a second exploration well targeting a shelf edge prospect in 1,100m of water. These will be the first deep water (>1,000m) wells drilled in Senegalese waters and the first offshore wells to be drilled for over 20 years. The two exploration wells will test combined prospective resources of approximately 1.5 billion barrels of unrisked prospective resources and FAR Ltd retains a 15% working interest in the blocks. In accordance with the terms of farm out deals completed with Capricorn Senegal Limited (a 100% subsidiary of Cairn) and ConocoPhillips, FAR Ltd has successfully secured its share of funding for these two exploration wells. Based on current well cost estimates, the carry funding and cash payments that FAR Ltd has or will receive under the farm out agreements are expected to be in excess of FAR Ltd’s share of the combined well costs for the two wells.

17 Apr 2014

Karoon releases Poseidon North-1 well update

Karoon Gas Australia Ltd (Karoon) has reported an update to the Poseidon North-1 exploration well being drilled in WA-315-P in Australia. At 0600 WST on 17th April 2014, the hole was at a depth of 3,820m and preparations were being made to install the 9-5/8” casing. Since the last progress report released on the 4th April 2014, the cement casing shoe has been drilled and the 12-1/4” hole section drilled 1,361m to the current depth of 3,820m. Poseidon North-1 is the fifth well in the Browse Basin Phase 2 exploration drilling campaign. The well is targeting the Plover and Montara formations and has the potential to add significantly to the already discovered Greater Poseidon area resource. The six well Browse Basin Phase 2 exploration drilling campaign will continue through calendar year 2014 using the ‘Transocean Legend’ rig. 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 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 the Greater Poseidon trend. ConocoPhillips is the operator of the WA-315-P Browse Basin permit in which Karoon holds a 40% interest.

25 Apr 2014

'Transocean Arctic' granted approval to drill Storm prospect in PL555

The Norwegian Petroleum Directorate (NPD) has granted Lundin Norway AS a drilling permit for wellbore 33/2-1, cf. Section 8 of the Resource Management Regulations. Wellbore 33/2-1 will be drilled from the Transocean Artic drilling facility at position 61°59’30.76” north and 1°32’42.52” east, after completing drilling of wildcat well 6406/12-3 for VNG Norge in production licence 586. The drilling programme for wellbore 33/2-1 relates to drilling of the first well in production licence 555. Lundin Norway AS is the operator with an ownership interest of 60 per cent. The other licensee is Bayerngas Norge AS (40 per cent). The area in this licence consists of block 33/2. The well will be drilled about 200 kilometres west of Måløy. Production licence 555 was awarded on 19 February 2010 (APA 2009). This is the first well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

28 Apr 2014

Hurricane spuds Lancaster appraisal well

Hurricane Energy Plc (Hurricane) has announced that the Lancaster horizontal appraisal well was successfully spudded on the 26th April 2014 at 10:30BST. Hurricane have contracted Transocean’s ‘Sedco 712’ semisub drilling rig for the drilling operations, which is intended to drill and test the Lancaster basement oil discovery. Drilling activity is expected to last approximately 75 days after which further technical analysis will be undertaken.

28 Apr 2014

'Transocean Arctic' begins sidetrack drilling at Pil prospect

Rocksource ASA (Rocksource) is pleased to announce that drilling of the Pil sidetrack well, 6406/12-3 B, in PL 586 has commenced. As announced on 10th April 2014, the preliminary estimate by the Operator VNG Norge AS (VNG) for the size of the Pil discovery is between 8 and 27 million Sm3 recoverable oil equivalent (50 to 170 million barrels oil equivalent). The discovery well (6406/12-3 S) has been plugged back to the 20 inch casing shoe from where the sidetrack starts. The sidetrack is targeted down-dip of the discovery well and its main objectives are to prove the lateral extent of the Pil reservoir, narrow the volume range and test the upside within the closure. The sidetrack will be drilled using the drilling rig ‘Transocean Arctic’. Drilling is expected to take approximately 30 days. Rocksource Exploration Norway holds a 15% interest in PL 586. Partners are VNG (Operator) with 30%, Spike Exploration 30% and Faroe Petroleum 25%.

4 Jan 2011

Cairn secures rigs for 2011 Greenland Exploration

Cairn has secured two state of the art dynamically positioned drilling vessels for its 2011 dual rig exploration programme offshore Greenland. The “Leiv Eiriksson”, a fifth generation semi-submersible drilling rig and the “Ocean Rig Corcovado”, a sixth generation drillship, have been contracted to operate in the 2011 drilling season on Cairn’s offshore Greenland exploration programme. Both drilling vessels are operated by Ocean Rig. Subject to approval from the Government of Greenland, Cairn intends to drill up to four wells in 2011. Further details on the exploration programme will be provided in Cairn’s next operational update. To provide the immediate liquidity required to enable the group to agree these contracts, Cairn has entered into a stand-by secured revolving debt facility of US $900 million that will also provide funding for general corporate purposes. The facility is provided by Standard Chartered Bank, Bank of Scotland Plc, Crédit Agricole Corporate and Investment Bank, HSBC Bank PLC and Société Générale.

3 Jun 2011

Exploration Offshore Greenland

Cairn has commenced drilling operations on two wells offshore West Greenland. The AT-7 well in the Atammik Block, approximately 160 kilometres offshore Nuuk, west Greenland and the LF-7 well in the Lady Franklin Block approximately 300 kilometres offshore Nuuk have both started operating. The Leiv Eiriksson, a fifth generation semi submersible and the Ocean Rig Corcovado, a sixth generation drillship, are to carry out the drilling programme offshore Greenland this summer. The AT-7 prospect in the Atammik Block and LF-7 prospect in the Lady Franklin Block are in water depths of 905 and 989 metres respectively. An update on the drilling operations will be provided in due course.

29 Apr 2014

VNG using 'Transocean Arctic' for Pil sidetrack

The Norwegian Petroleum Directorate has granted VNG Norge AS a drilling permit for well 6406/12-3 B and A, cf. Section 8 of the Resource Management Regulations. Well 6406/12-3 B & A will be drilled from the Transocean Arctic drilling facility at position 64°01'52.37" north and 6°45'17.46" east after completing drilling of wildcat well 6406/12-3 B and appraisal well 6406/12-3 A for VNG Norge AS in the same production licence. The drilling programme for well 6406/12-3 B relates to drilling of an appraisal well and the drilling programme for well 6406/12-3 A relates to drilling of a wildcat well, both 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 about 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). These are the second and third 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.

30 Apr 2014

Statoil makes oil discovery at F-West prospect in Norway

Statoil Petroleum AS, operator of production licence 090, is in the process of concluding drilling of wildcat well 35/11-17. The well was drilled about one kilometre south of the Fram field in the North Sea. The well’s primary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (the Brent group). The secondary target was to prove petroleum in Middle Jurassic reservoir rocks (the Fensfjord formation). The well encountered a 48-metre gross oil column in the Brent group, 10 metres of which has good reservoir quality in the Etive and Rannoch formations. A 38-metre gross oil column was encountered in the Fensfjord formation, 20 metres of which has good reservoir quality. Oil/water contact was established in both the primary and secondary exploration targets. An approx. 10-metre oil column was also encountered in Lower Jurassic reservoir rocks (the Oseberg formation) with good reservoir quality. The well was not formation tested, but extensive data acquisition and sampling have been carried out. The preliminary size of the discovery has been estimated at between one and three million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees in production licence 090 will evaluate the discovery along with nearby prospects with a view toward further development. This is the 16th exploration well in production licence 090, which was awarded in the 8th licencing round in 1984. The well was drilled to a vertical depth of 2889 metres below the sea surface, and was terminated in the Cook formation in the Lower Jurassic. Water depth is 357 metres. The well will be permanently plugged and abandoned. Well 35/11-17 was drilled by the Songa Trym drilling facility, which will move on to drill production well 35/11-A-31 in the same production licence, where Statoil Petroleum AS is the operator.

5 May 2014

Statoil receives consent to use 'Transocean Spitsbergen' to drill Apollo prospect

Statoil has received consent to carry out exploration drilling of well 7324/2-1 Apollo in production licence 615 in the Barents Sea using the ‘Transocean Spitsbergen’ mobile drilling facility. Water depth at the site is approximately 430m. Statoil plans to begin drilling at the Apollo prospect in May 2014, with a duration of around 31 days, depending on whether a discovery is made. ‘Transocean Spitsbergen’ is a semi-submersible drilling facility of the Aker H-6e type. It was built at the Aker Stord yard in 2009, is registered in the Bahamas and classified by DnV. It received Acknowledgement of Compliance (AoC) in July 2009 (under its then name of Aker Spitsbergen).

5 May 2014

Transocean to spin off UK based midwater drilling units into new company

Transocean Ltd (Transocean) announced today that it intends to pursue the creation of an entity comprising eight of its UK North Sea midwater drilling rigs. Transocean expects to establish the new entity, Caledonia Offshore Drilling Company (Caledonia), during the second half of 2014 and, at an appropriate stage, separate Caledonia from Transocean. The offshore drilling assets currently contemplated for transfer to Caledonia include the following rigs:‘Sedco 704’, ‘Sedco 711’, ‘Sedco 712’, ‘Sedco 714’, ‘Transocean John Shaw’, ‘Transocean Prospect’, ‘GSF Arctic II’I and ‘J.W. McLean’. The UK North Sea remains an important market for Transocean and the company is committed to maintaining its presence in the region. As such, various options for the separation of Caledonia are under consideration. Caledonia is expected to have a focused approach to assets and operations in the UK North Sea and it will continue to provide best-in-class service to customers. The creation of Caledonia reflects the continued execution of Transocean's asset strategy to improve the overall capability of its offshore drilling fleet by divesting non-core assets, complemented by the addition of new, high-specification offshore drilling rigs.

7 May 2014

'Cajun Express' moves to new well location

FAR Limited (FAR) has announced that Transocean’s ‘Cajun Express’ semisub rig has been moved from the FAN-1 well location to the SNE-1 well location in Senegal. The rig has been moved whilst ongoing maintenance is completed at the FAN-1 well position and as such, the unit has been moved to drill the top-hole section of the SNE-1 well. The ‘Cajun Express’ is expected to require five to seven days to drill the top-hole section of SNE-1, after which the rig will return to the FAN-1 well in order to drill to the planned total depth. The FAN-1 well has currently been drilled to 1,200m and has 20” casing cemented in the top-hole portion of the well. Cairn Energy is the primary operator of the project offshore Senegal, with FAR having farmed into the drilling of the two exploration wells.

13 Oct 2011

Signal International Announces Contract to Upgrade Semisubmersible

Signal International has been awarded a contract for the repair and upgrade of the Transocean semisubmersible rig, Henry Goodrich. The project is slated to commence early December 2011 at Signal’s east yard facility in Pascagoula, Mississippi, for a seventy-day out-of-service time frame. The scope of work includes overall repairs, upgrades and refurbishments of the rig. In addition to the removal, renewal and replacement of major equipment; Signal will also be upgrading the crew accommodations, expanding the lifeboat capacity, and renewing the coatings and piping. With prefabrication work underway, the project will enable Signal to employ an additional 300 craft personnel at the yard during peak production. Dick Marler, President and CEO of Signal International, noted the East yard recently completed the upgrade of Transocean’s Deepwater Navigator. “We’ve enjoyed a long-standing relationship with Transocean,” Marler stated, “which has been built upon our ability to meet their standards for manufacturing excellence, speed of delivery, safe performance and overall project cost.”

2 Apr 2013

Fairmount Sherpa Delivered GSF Arctic I to Las Palmas

Tug Fairmount Sherpa has safely delivered rig GSF Arctic I in Las Palmas. The rig has been towed from offshore Rio de Janeiro, Brazil, to Las Palmas de Gran Canaria, Spain. The voyage covered a distance of almost 4,000 miles across the Atlantic Ocean with an average speed of 4.1 knots, the destination offshore Las Palmas was reached. Upon arrival offshore Las Palmas de Gran Canaria Fairmount Sherpa performed anchor handling activities for the GSF Arctic I, mooring her on her eight anchors.

12 Jul 2013

Fairmount Glacier Delivered Falcon 100 to Pointe Noire

Super tug Fairmount Glacier has delivered rig Falcon 100 safely offshore Pointe Noire, Congo. The rig was towed from Rio de Janeiro via the South Atlantic Ocean over a distance of over 3,400 miles. For this job the Fairmount Glacier was mobilized from Trinidad. First the tug towed the Falcon 100 from her drilling location offshore Macae, Brazil, to offshore Rio de Janeiro. Then Fairmount Glacier assisted the rig in anchor handling activities. Also the Fairmount Glacier assisted in installing a new ‘bridle’ – the connection between rig and towing line. After arrival in Pointe Noire the Fairmount Glacier assisted in keeping the rig in position during the deployment of her anchors. Also the Fairmount Glacier took over equipment and other cargo from Falcon 100 which was discharged in the port of Pointe Noire.

3 Mar 2002

New find in Oseberg Sør area

Norsk Hydro has found oil in exploration well 30/9-20S in the Oseberg area some 130 kilometers west of Bergen, Norway. The discovery may be phased into the Oseberg Sør (South) platform. "We will now evaluate the results and see if it's possible to recover the oil in connection with the development of the J structure in the Oseberg Sør area," says Hydro director of the Oseberg business unit Øystein Michelsen. "We will present further plans next year." The oil was proven in a sandstone layer. Core samples have been taken and thorough logging and testing have been done. The well, drilled by Transocean Arctic at a sea depth of 101 meters and total well depth of 3,072 meters, is now plugged and abandoned.

22 Nov 2002

Fast forward on Dolly

A recently-completed exploration well on Statoil’s Dolly prospect in the North Sea was drilled more rapidly than usual with the aid of innovative technology. The well path passes through a Brent formation prospect – parts of which lie more than 2,500 metres below sea level – in the form of a curve. After initially descending vertically, it angles out, becomes gently horizontal and then ascends at an angle of 106 degrees. This approach is not unusual for production wells, but the Dolly wildcat is one of the first exploration wells drilled by Statoil to use the method. The group utilised a Powerdrive drilling machine developed by Anadrill Schlumberger for the operation. Computer controlled, this unit can drill longer stretches at a time and thereby reduces the time required. It has previously been deployed by Statoil on some of its North Sea fields. “Viewed purely in terms of drilling technology, it’s all the same whether you’re drilling a producer or a wildcat,” explains Bengt Beskow, exploration manager for the Tampen area in Exploration & Production Norway. “When we’re looking for supplementary oil on the fringes of mature fields, in satellites or in new areas like the Dolly prospect, however, we must try to rationalise drilling operations.” He notes that two other recent Statoil exploration wells, in the Ole and Dole structures west of Gullfaks satellite Rimfaks, utilised new methods. The Dolly wildcat was drilled from Deepsea Trym, and a project team is now working to evaluate results from the well – which encountered hydrocarbons.

22 Aug 2002

Drilling contract for Alpha North

Statoil and Transocean have entered into a new agreement for the use of the Transocean Searcher drilling rig on the Alpha North satellite in the North Sea's Sleipner West field. The contract comprises drilling and completion of three wells on the Alpha North structure, which will be tied back to the Sleipner A platform. Operations are expected to last for 270 days. The value of the contract is estimated at over NOK 200 million, excluding options. Plans call for the Transocean Searcher to start drilling work in the summer of 2003 once the rig has finished work on the Åsgard field in the Norwegian Sea. Alpha North is due to begin producing gas and condensate on 1 October 2004.

10 May 2002

First well on Angola Block 34 dry

The first exploration well drilled on Block 34 offshore Angola has been completed and no hydrocarbons were found. The N'Demba 1 exploration well - spudded March 24 and drilled at a water depth of 1,731 meters by drillship "Deepwater Discovery" - did not encounter hydrocarbons but revealed valuable data for further exploration of the block, the operator Sonangol P&P said in a statement. The consequences of the well are still under evaluation. Several other prospects have been identified within the 6,000 km2 block and the Contractor Group will now consider possible targets for well number two. Block 34 partners include operator Sonangol P&P (20 percent), Norsk Hydro (30 percent), Phillips (20 percent), Petrobras (15 percent) and Shell (15 percent). Hydro is designated Technical Assistant on Block 34. Hydro's part in the exploration of Block 34 will be funded by approximately NOK 300 million in the second quarter 2002.

12 Dec 2003

Cong well abandoned

Statoil Exploration Ireland has completed exploratory drilling in the Cong prospect off north-west Ireland without success. The exploration well has been plugged and abandoned. Drilling was carried out by the Sedco 711 semi-submersible rig on contract from Transocean. The well data will now be analysed to ascertain whether further exploration of the area would be worthwhile. The Cong prospect is located in the Slyne basin. Statoil is operator with a 49.9 per cent interest. The other licensees are Shell E&P Ireland (35.1 per cent) and Murphy Ireland Offshore (15 per cent).

13 Aug 2003

Drilling on Alpha North

Drilling began on the first production well on the Statoil-operated Alpha North satellite in the North Sea's Sleipner West field in the early hours of 13 August. A gas and condensate field, Alpha North is to be developed with three or four wells and a subsea production system. The Transocean Searcher rig will be performing the drilling, which is expected to take about a year, reports Turid Eikebu Alfsen, head of the Sleipner drilling and well completion department. "The drilling programme has been well planned and builds on earlier experiences from Sleipner West," says Ms Eikebu Alfsen. Alfa North will be tied back to the Sleipner T gas treatment platform via an 18-kilometre pipeline. The gas which is rich in carbon dioxide will be passed through the T platform’s separation plant where the carbon dioxide is removed and pumped into the Utsira aquifer via the Sleipner A platform. The gas is then exported to Europe. Sleipner West is the only field in the world with such a separation plant. Technically recoverable reserves in Alpha North are put at roughly 13 billion cubic metres of gas and about 32 million barrels of condensate. The field is due to start producing on 1 October 2004. Statoil has 49.5 per cent of Alpha North, with ExxonMobil holding 32.24 per cent, Total 9.41 per cent and Norsk Hydro 8.85 per cent.

26 Sep 2003

Hydro makes new oil discovery in the North Sea

Norsk Hydro, operator of Production Licence 036 Outside (Heimdal), has completed the drilling of exploration well 25/4-9 S. The well proved a 65-metre oil column. The well was drilled to a total depth of 2270 metres below the surface of the sea, ending in tertiary rock. The oil column was proven in the Heimdal link, which was the main target. The discovery, wich is expected to contain approx. 3-5 million Sm3 oil, is now being evaluated by Hydro, the operator for the production licence. The well was drilled by the drilling installation Deepsea Delta. The well will be permanently plugged, and the drilling installation will leave the area during the course of the next few days.

21 Jul 2003

Completed well in J10 prospect

As operator of exploration and production license 195 in the North Sea, Hydro has concluded drilling exploration well 35/8-5 S in the so-called J10 prospect. The well was drilled south-west of the western Norwegian city of Florø at a sea depth of 370 meters. It was drilled to a total depth of 3,803 meters below the sea’s surface into rock from the Mid-Jurassic period. The well showed traces of hydrocarbons in rock from the Upper Jurassic period, which was the primary goal of the drilling operation, but the find is considered non-commercial. The well results are presently being evaluated by Hydro. The drill rig Deepsea Delta has concluded drilling, plugged the well and is now proceeding to the Hydro-operated Tune field to do well intervention and completion work. Hydro owns a 40 percent stake in PL 195, followed by Petoro with 35 percent and RWE DEA at 25 percent.

11 Apr 2003

Transocean to drill on Snøhvit

A letter of intent worth some NOK 700 million has been signed by Statoil and Transocean for drilling and completion work on the Snøhvit field in the Barents Sea. The contract with Transocean covers drilling and commissioning of the ten wells in phase one of the development on the Snøhvit and Albatross fields. The Polar Pioneer rig will carry out the work, which is due to start in the autumn of 2004. The work should be finished in the spring of 2006, reports Thor Bensvik, manager for drilling and well operations for Snøhvit. "Following a full round of tenders, we concluded that the Polar Pioneer rig was best suited for this job, and that Transocean had the best commercial bid," says Mr Bensvik. The letter of intent has been signed subject to the approval of the partners in the Snøhvit licence.

29 Jan 2003

Nnwa confirmation off Nigeria

An appraisal well drilled by Statoil in block 218 off Nigeria has confirmed that the gas reservoir in the Nnwa structure extends into the neighbouring block 219 operated by Shell. A successful production test was carried out in this Nnwa-2 well, which was plugged last November. The field was discovered with the Nnwa-1 wildcat in 1999, while Shell has earlier made a find with its Doro-1 well in block 219. Transocean Sedco Energy spudded Nnwa-2 last July in 1,191 metres of water. Drilled to a planned depth of 4,984 metres, the well encountered hydrocarbons in several reservoir levels. Nnwa-2 lies 180 kilometres south-west of Port Harcourt, 6.5 kilometres north-west of the Nnwa discovery well and 10.4 kilometres north-west of Doro-1. The partners in the two blocks have earlier signed a memorandum of understanding with the state-owned Nigerian National Petroleum Company (NNPC) and the national authorities. This agreement covers a feasibility study for a possible joint development of Nnwa and Doro. Being led by Statoil, this investigation is due to be completed by the end of 2003. The size of the structure makes it necessary to conduct further appraisal work in order to characterise Nnwa/Doro fully. Statoil has a 53.85 per cent interest in block 218, with ChevronTexaco as its partner.

16 May 2014

ConocoPhillips makes discovery with Poseidon North-1

ConocoPhillips has successfully hit gas with its latest exploration well in the Browse basin, off the west coast of Australia. Karoon Gas Australia (Karoon), who are ConocoPhillips joint venture partner in the well announced that the Poseidon North-1 well reached a total depth of 5,288m on the 5th may 2014 afterwhich a wireline logging programme began. Karoon released the statement that, “based on cuttings, mud gas and wireline log data, Karoon interprets that the Poseidon North-1 well intersected gas bearing sands of Jurassic age across a 20 metre gross, 12 metre net reservoir interval”. After the completion of the logging operations, plug and abandonment operations began on the 13th May 2014. Upon completion of the plugging and abandonment work the ‘Transocean Legend’ semisub will be mobilised to drill the sixth exploration well in ConocoPhillips Browse basin exploration plan, the Pharos-1 well.

15 May 2014

Transocean secures USD953 million of new drilling contracts

Transocean Ltd (Transocean) today announced that the company has secured new contracts worth approximately USD953 million, over the previous month. In its monthly fleet update summary the world’s largest drilling rig contractor announced new contracts for the ‘Dhirubhai Deepwater KG1’, ‘Paul B. Loyd, Jr’, ‘GSF Development Driller II’, ‘GSF Constellation II’ and ‘Sedco 706’ units. The largest contract secured is associated with the ‘Dhirubhai Deepwater KG1’ drillship, with Petrobras contracting the unit for a firm three year period at a dayrate of USD440,000 (USD482 million backlog). The unit is expected to begin operations in January 2015 in Brazil, following a few months of downtime in which it will undergo contract upgrade work as well as the units five year class renewal survey.

11 Mar 2004

Drilling on Norne

A letter of intent on chartering the Transocean Arctic rig to work the Norne field and two of its satellites in the Norwegian Sea has been awarded by Statoil to drilling contractor Transocean. Placed on behalf of the partners in production licence 128, the assignment is due to last for about 19 months from 1 July and will be worth NOK 700 million. Transocean Arctic’s first job will be a sidetrack on Norne itself, before moving on to drill seven-eight production and injection wells on the Svale and Stær satellites. These two fields are being developed with subsea installations tied back to the Norne production ship. The contract with Transocean is conditional on approval of the plan for development and operation of the Norne satellites by the licence partners and the Norwegian authorities.

12 Sep 2004

NOK 600 million contract awarded to Odfjell Drilling

As operator on behalf of several licences, Norsk Hydro Produksjon a.s has awarded Odfjell Drilling a contract for the utilization of the semisubmersible drilling unit Deepsea Delta. The contract value without options is approximately NOK 600 million. Deepsea Delta will drill an exploration well, a sidetrack in the Vale field, and will also be used for development drilling on Oseberg Vestflanken. The contract, which is scheduled to commence in the third quarter of 2004, will cover a well programme of approximately 18 months duration and may be extended with six options of six months. The contract award is subject to approval by the licence owners.

12 Feb 2004

Transocean Leader chartered

A 15-month charter worth some NOK 600 million has been awarded by Statoil to rig contractor Transocean for its Transocean Leader drilling unit. The group also has an option to extend the hire period to cover an additional well with an estimated duration of 90 days, which would add NOK 110 million to the value of charter. According to Tore Lea, head of rig management in Statoil, the whole charter period is secured against an obligatory work programme. However, the sequence of prospects to be drilled has not been finally clarified. Due to start work for the group in May, the semi-submersible is currently located in the UK. It will be modified to prepare for operation on the Norwegian continental shelf (NCS). Transocean Leader is a fourth-generation Aker H-4.2 unit, built in 1987 to work on the NCS. Statoil chartered it most recently in 1999 for use on the Statfjord satellites in the North Sea.

19 Jan 2004

Transocean Searcher to Åsgard

Rig contractor Transocean Offshore has received a letter of intent from Statoil covering a charter for the Transocean Searcher drilling and completion unit, initially worth some NOK 300 million. Due to be placed by the Åsgard licence in the Norwegian Sea, this job involves drilling three wells through the new Q subsea template on the Smørbukk South deposit. Currently working on Statoil’s Sleipner fields in the North Sea, Transocean Searcher is due to mobilise on Smørbukk South during the first half of this year.

12 Sep 2005

Brage exploration well finished

Hydro has concluded drilling its Idun exploration well on the Brage field in the North Sea. No hydrocarbons were found in the well. The well (31/4-12) was drilled north-east of the Brage field at a sea depth of about 207 meters by the drilling rig, "Deepsea Trym." The goal of the exploration well was to find additional reserves on the Brage field. The well was drilled into a prospect of sandstone from the late Jurassic period. Drilling concluded in underlying rock that is part of the so-called Fensfjord formation. The well was drilled to a total depth of 2,200 meters before it was plugged and abandoned.

12 Sep 2005

Comprehensive rig contract secures drilling capacity

Together with Statoil, Eni and Shell, Hydro has entered into a contract with Transocean and Smedvig that will boost exploration well drilling capacity on the Norwegian Continental Shelf during the coming years. The contract comprises the hire of three rigs, each for a minimum of three years - nine rig-years altogether. The three rigs are Polar Pioneer and Transocean Arctic from Transocean and Smedvig's West Alpha.T "Four companies of this size joining forces to secure the required rig capacity represents a completely new departure," explains Hydro's exploration manager Nils Telnæs. The rigs will mainly concentrate on exploratory drilling, though Transocean Arctic will also be used for production on the Statoil-operated Tyrihans field. All in all, the collaboration will include almost 40 exploration wells, and capacity has been secured for HPHT wells and for drilling in Arctic regions. Transocean Arctic will be replaced by Transocean Leader for a period, so the collaboration has also secured deep-water capacity for drilling in the Norwegian Sea. "With this contract, Hydro will be favourbly positioned to continue developing the Norwegian Continental Shelf, and we will also be able to acquire new licences and drilling assignments in connection with the imminent licencing rounds, TFO 2005 and the 19th round," states Telnæs.

21 Jan 2005

Drilling job for Skinfaks and Rimfaks

A contract worth some NOK 550 million for drilling production wells on the Skinfaks and Rimfaks fields in the North Sea has been awarded by Statoil to Transocean. Due to be performed by the Transocean Leader semi-submersible, the work embraces at least three wells and is expected to take about 225 days. In addition, the rig will be used for roughly 130 days to carry out jobs on Statoil’s nearby Gullfaks development. All these fields lie in the Tampen area. A total of eight production wells are planned on Skinfaks, which was proven in 2002 and comprises several small reservoirs, and on Rimfaks. The latter has been on stream since 2000 through a tie-in to the Gullfaks A platform. Further development of Rimfaks will improve recovery from this discovery. Scheduled to come on stream in November 2006, the present project involves a tie-back to Gullfaks C via existing infrastructure. The plan for development and operation (PDO) of Rimfaks and Skinfaks was submitted to the Norwegian authorities on 8 December 2004. The Transocean contract is conditional on acceptance by the partners and on approval of the PDO by the Ministry of Petroleum and Energy. A decision from the latter is expected in February/March.

4 Jan 2005

First Statoil well off Venezuela

The first wildcat to be drilled by operator Statoil in block 4, part of the Plataforma Deltana area of the Venezuelan continental shelf, was spudded on 1 January from the Sovereign Explorer rig. This Ballena 1-X well is the first of three which the group is committed to drilling in this region off the east coast of the Latin American country. If it proves successful, Statoil is considering drilling one to three appraisal wells before a possible field could be declared commercial. The group is the sole licensee for block 4, which was awarded in February 2003 and covers about 1,435 square kilometres with water depths of 200-800 metres. Statoil is also a partner in two other Venezuelan production licences, holding 15 per cent of the land-based Sincor heavy crude project in the Orinoco Belt and 27 per cent of the LL 652 oil field in Lake Maracaibo.

14 Dec 2005

Secures rig for exploration offshore Norway

Hydro has entered into an agreement with Transocean Offshore (North Sea) Ltd NUF to lease the drilling rig "Transocean Winner" for a three-year period. The rig will be reactivated to drill exploration wells in the Norwegian offshore sector by the fourth quarter of 2006. Hydro is an active exploration company and made six finds in Norwegian waters during 2005. Hydro presently operates five floating rigs and has both alone and together with other oil companies in Norway, secured good rig capacity to carry out planned as well as new exploration drilling operations in the Norwegian offshore sector during the coming years. ”We see significant potential for future exploration activity in the Norwegian offshore sector and want to contribute our expertise, capacity and experience to map out and develop resource potential both in mature and new areas,” says Hydro Exploration Norway chief Lars Christian Alsvik. ”With this in mind, we have applied for new shares and operatorships in the 19th concession round and TFO round (award of pre-defined areas) in 2005. This rig contract is therefore a very important part of Hydro’s strategy. It secures us additional capacity to operate a focused and long-term exploration program in Norway,” he points out.

5 Dec 2005

Snøhvit drilling enters final phase

Drilling and well completion work on the Snøhvit development operated by Statoil in the Barents Sea is now entering its final phase. The Polar Pioneer rig moved south to the associated Albatross reservoir on 20 November in order to drill three producers. This unit has already drilled and partly completed six production wells and the carbon dioxide injection well on the actual Snøhvit field. To ensure high output towards the end of Albatross’ producing life, two of its wells will be drilled and completed with a horizontal section. These will run through the reservoir 1,430 metres beneath the seabed, and rank as the only highly-deviated wells in this phase of the development. Drill cuttings are being transported to land for deposition. “Our work so far has been successful,” reports Thor Bensvik, drilling and well manager for the Snøhvit project. “The reservoir has been penetrated at the planned depth,” adds Lars Klefstad, who heads the petroleum technology department for the field. “We’ve also gathered large volumes of data from a number of the wells, and set a Barents Sea record for core length by retrieving a continuous section 82.5 metres long.” Well placement was analysed in detail with the aid of three-dimensional seismic data and advanced reservoir models. Collection and analysis of well data are important for future reservoir management as well as for production planning. All 10 wells on Snøhvit and Albatross will be ready for production to start in 2006, but are not due to come on stream until the Hammerfest LNG plant on Melkøya is completed in 2007. This development comprises subsea production installation on the Snøhvit, Albatross and Askeladd discoveries, which lie about 140 kilometres north-west of Hammerfest.

11 Oct 2005

Rig secured for exploration and production

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.

13 May 2005

Promising oil find at Fram

A promising oil discovery has been made during exploratory drilling of the Astero prospect North of the Fram field in the North Sea. The exploratory well designated 35/11-13 was drilled to a total depth of 3266 metres with the drilling rig Deepsea Trym. The water depth in the area is 361 metres. “We have found oil and some gas in rocks dating from the late Jura period and consider the find to be promising and commercially interesting. This find will make further exploration activities in the Fram area more interesting,” says Lars Christian Alsvik, Director of Development Norway. The drilling of the Astero prospect began on March 18, and the total drilling depth was reached at the end of April. Since then Deepsea Trym has been used for production testing of the find. During testing a production rate of 3,150 barrels per day was achieved. Alsvik emphasises that a final decision has not been made to develop the Astero find. “We will evaluate development solutions in connection with the Fram field and the Troll C platform. At the moment we can’t go into detail about how large the recoverable reserves are in this instance, but the size is significant enough that we are also considering other development solutions,” he says.

26 Jan 2005

Snøhvit drilling under way

The first well on Statoil’s Snøhvit development in the Barents Sea is under way from Polar Pioneer, which is due to complete this initial 10-hole drilling phase by spring 2006. On station since 7 December, the rig has about 100 crew in activity at any one time. Drilling has progressed without unintentional discharges or serious incidents. “We’re down to the reservoir and taking cores about 2,750 metres down,” explains drilling and well manager Thor Bensvik. “The total depth is due to reach 2,900 metres.” Designated F-2H, this first well will be used to inject carbon dioxide back below ground during the production phase. Some 700,000 tonnes of this greenhouse gas is due to be separated from the wellstream every year and injected into a separate formation to avoid releasing it to the air. That represents a major environmental measure, which will release far less of the carbon dioxide produced from the field than would otherwise be the case. Polar Pioneer is designed to work in Arctic conditions and to meet strict environmental standards, not least in relation to the important fishing industry in the Barents Sea. Water-based mud without environmentally harmful chemicals is being used to drill the Snøhvit wells. And the rig crew are specially trained to comply with strict environmental standards. “We’re putting great emphasis on good planning of the work, and have the natural environment on the agenda every single day,” says Mr Bensvik. The next well is due to be spudded in early February, and will be one of nine producers covered by the first drilling phase. A total of 20 production wells plus the carbon dioxide injector are due to be drilled in three phases, with the second and third of these scheduled for 2011 and 2014 respectively.

23 Aug 2006

Appraising the Astero discovery using a new well

Hydro's promising oil discovery on the Astero prospect north of the Fram field in the North Sea is to be appraised using a new well. Drilling started on Wednesday morning, using the semi-submersible drilling rig "Transocean Winner". The drilling rig sailed from Ølen on last Thursday, and performed anchoring tests prior to reaching the Astero prospect on Sunday evening. Drilling of the well "35/11-14S" began on Wednesday morning, and is scheduled to continue for 61 days. The aim is to appraise the size of the Astero discovery, which Hydro made in May 2005, and to determine the gas-oil contact. The well will also provide information regarding reservoir quality in the field. The results from the first exploration well on Astero are said to be promising, and estimates indicate that the discovery is commercially interesting. However, as yet no development concept for the field has been decided upon.

18 Aug 2006

Gas proven on Tros

Statoil has completed drilling of an exploration well in the Trost prospect in the Norwegian Sea. Gas was proven and the find is now being evaluated with a view to production tied back to the Norne field. "We hope that the Trost find will be commercial but it is too early to tell," says Tim Dodson, senior vice president for exploration in Statoil’s Exploration & Production Norway business area. The prospect is localised roughly one kilometre west of the Norne field. Exploration well 6608/10-11S was drilled to a total depth of 3,243 metres in early Jurassic rocks. The objective was to prove hydrocarbons in Jurassic sandstones. The well has been permanently plugged and abandoned. Drilling was performed by the Transocean Arctic rig which will continue production drilling on the Norne field. Statoil is operator for production licence 128 with a 50.5% interest. The other licensees are Petoro (24.5%), Eni (11.55%) and Hydro (13.5%).

8 Feb 2006

Drilling on Snøhvit completed

The Polar Pioneer drilling rig completed drilling of the 10 Snøhvit wells in the Barents Sea on Tuesday 7 February. The drilling operations have been performed without any harmful discharges to the sea. "The drilling campaign has on the whole been a success, and the wells have been drilled with great precision in terms of reservoir drainage," says Thor Bensvik, drilling and well manager for the Snøhvit project. "We have drilled a total of 10 wells without any harmful discharges to the sea and within the original budget and schedule," he continues. Polar Pioneer started drilling on Snøhvit in December 2004. Prior to the operation, the 20-year-old rig was modified to meet the environmental requirements of the discharge permit for drilling in the Barents Sea. Compliance with the environmental requirements has been important to Statoil. The group has promoted the use and further development of new technology for this type of operation. "We have achieved the good operational and environmental results through thorough planning of the work tasks beforehand and great commitment by the entire Snøhvit team during the execution," explains Mr Bensvik. Polar Pioneer is now finishing the completion work on the wells. The rig will then clean and prepare nine of the wells for production and one well for carbon dioxide injection. This work is expected to be finished before the summer. The first phase of the Snøhvit project covers the Snøhvit and Albatross fields, which lie about 140 kilometres north-west of Hammerfest in northern Norway. The wells will come on stream when the Hammerfest LNG plant at Melkøya is completed in 2007. Statoil is operator for the development and operation of the Snøhvit project.

22 Dec 2006

Gjøa drilling contract

As development operator, Statoil has signed an agreement with Transocean Offshore for drilling of production wells at the North Sea's Gjøa field. Valid for three years, the contract is worth around USD 427 million. The deal covers drilling of 13 wells, with options for a further three. The Transocean Searcher rig will drill the wells. First drilling is planned to start in October 2008. "It's important to have the big and important contracts in place in good time in relation to the implementation," says project manager Kjetel Digre. "We are therefore particularly pleased with the signing. The deal secures us a familiar rig with good results." Earlier this autumn Statoil signed an agreement for the construction of the platform deck and supply of subsea installations to Gjøa. The next big contract will be the building of the platform jacket for the semi-submersible production platform. Plans call for the Gjøa field to produce oil and gas from 2010. Total investment is estimated at around NOK 27 billion in 2006 money. Gjøa was proven in 1989. The field lies in blocks 35/9 and 36/7, around 70 kilometres north of the Troll field and 45 kilometres off the coast of western Norway. Reserves are estimated at around 40 billion cubic metres of gas and around 83 million barrels of oil and condensate. Gaz de France takes over as operator when the field comes onstream with a 30% stake. Other licensees are Petoro with 30%, Statoil (20%), Shell (12%) and RWE Dea (8%).

11 Aug 2009

Drilling in Tornerose

Statoil has started drilling an appraisal well in the Tornerose prospect in the Barents Sea. The Polar Pioneer rig commenced drilling on Thursday 10 August. The well is being drilled to assess the extent of the petroleum reserves in the prospect. "This appraisal well is important," says Tim Dodson, senior vice president for exploration in Statoil’s Exploration & Production Norway business area. "It will enable us to prove gas which can strengthen the basis for a possible expansion of the Hammerfest LNG plant on Melkøya." Tornerose lies about 55 kilometres east of Snøhvit and 125 kilometres north-west of Hammerfest. Water depth in the area is just over 400 metres. The drilling operations are expected to take about 40 days. Statoil is operator of Tornerose with a 33.53% holding. The other licensees are Petoro (30%), Total E&P Norge (18.40%), Gaz de France Norge (12%), Amerada Hess Norge (3.26%) and RWE Dea Norge (2.81%).

1 Sep 2006

New rig agreement with Transocean

A 30-month charter worth some NOK 2.3 billion (USD 378 million), taking effect from the end of 2008, has been awarded by Statoil to rig contractor Transocean for its Transocean Leader drilling unit. Transocean Leader will be used mainly for exploration and production drilling in the Tampen and Halten/Nordland areas of the Norwegian continental shelf (NCS). "This contract will be very important in maintaining Statoil's exploration ambitions in the Norwegian Sea, and the rig will contribute to increased production drilling in the group's core areas," says Bjarte Ydstebø, vice president for rig strategy in Statoil. The semi-submsersible Transocean Leader is a fourth-generation Aker H-4.2 unit, built in 1987 to work on the NCS. It is specially-designed to operate in greater water depths than traditional rigs and is therefore very suitable for drilling in the Norwegian Sea.

18 Aug 2006

Peon drilling operation completed

Hydro has completed a re-entry operation in the Peon gas discovery on the Norwegian Continental Shelf. The operation in the discovery well 35/2-1 R was completed with the drilling rig Deepsea Trym. Evaluation based on the well construction prior to a planned production test concluded with a postponement of the testing during the operation. A program to further increase the understanding of the field is now under way, in order to seek an optimal field development solution: Additional data-acquisition and planning activities are in progress and a seismic acquisition program will be completed later this fall. The gas field located in production license 318 was discovered by Hydro in the North Sea in August 2005, about 100 kilometers west off the coast of Sogn og Fjordane county in Norway. Peon is operated by Hydro. Co-owners are Petoro and Idemitsu.

27 Mar 2006

Oil and gas find on Gudrun

Oil and gas have been proven on the Gudrun structure in the Sleipner area of the North Sea by operator Statoil. The results from appraisal well 15/3-8 confirm the estimates of Statoil that the Gudrun structure contains at least 150 million barrels of recoverable oil equivalent. Oil, gas and condensate have earlier been proven in the structure. The appraisal well was drilled to find out if there were enough hydrocarbons in Gudrun to develop the structure. "Data from the well confirms that the Gudrun discovery is substantial," says Lars Jan Jaarvik, exploration manager for Troll/Sleipner. "Statoil is now looking at various development alternatives." Gudrun can be developed with a platform or a subsea solution. Production can be transported to a Norwegian or UK installation for further processing and export. This will be clarified later in connection with the development plans. The Gudrun structure is located in production licence 025, some 40 kilometres north of the Sleipner area and 13 kilometres east of the border between the Norwegian and UK sectors of the North Sea. The well was drilled by the Transocean Leader rig in 109 metres of water to a total depth of 4,570 metres below sea level, terminating in late Jurassic sediments. The well will be permanently plugged. Oil and gas were proven in late Jurassic sands. Statoil has completed two successful productions tests, both with a maximum production rate of between 6,000 and 7,000 barrels of oil equivalent (1,000-1,200 cubic metres) per day through a 3/4 inch nozzle opening. The Transocean Leader is moving to the Skinfaks and Rimfaks fields in the North Sea to drill production wells. Statoil has a 46.8 per cent interest in production licence 025. The other licensees are Marathon with 28.2 per cent, Gaz de France with 12.5 per cent and BP with 12.5 per cent.

22 Oct 2007

Four year contract for Polar Pioneer

StatoilHydro has awarded a four-year contract to Transocean for lease of the semi-submersible rig Polar Pioneer. The contract will become effective during the first half of 2010. The exact date of commencement will depend on the completion of work under the current rig lease contract. "This is the first rig contract awarded by the new company and represents a strategically important acquisition, not least with regard to exploration in the far north of Norway and completion of production wells," says Kjell-Erik Østdahl, chief procurement officer. "Moreover, we have good previous experience with this rig. It is flexible and has a proven record in efficient operations. It is vital for StatoilHydro to secure further resources for exploration projects in the time ahead, and Polar Pioneer is regarded as suitable in this respect," says Østdahl.

23 Jul 2007

Drilling of Snøhvit well completed

Statoil has concluded the drilling of an appraisal well in the Snøhvit field in the Barents Sea. The well was drilled to map the recoverable oil reserves in the field. The appraisal well 7120/6-2 in production licence 097 was drilled to a depth of 3,120 metres below the seabed and finished in late Triassic rocks. Water depth in the area is 321 metres. The Polar Pioneer drilling rig has performed yet another successful operation in the Barents Sea. The appraisal well was drilled without any incidents or accidental discharges to the sea. The goal of the drilling was to gain further information about the thickness of the gas and oil column in the western part of Snøhvit and to find out whether the oil column is situated in a zone with reservoir properties that are sufficiently good for oil recovery. A comprehensive data compilation has been done in the well. The data will now be analysed and the result will be ready during September. The well has been temporarily plugged and will possibly be used later for injection of formation water or carbon dioxide. Statoil is operator for the development and operation of Snøhvit with a 33.53% share. The other licensees are Petoro (30.00%), Total E&P Norge (18.40%), Gaz de France (12.00%), Amerada Hess Norge (3.26%) and RWE Dea Norge (2.81%).

5 Nov 2007

Dry well in Snøhetta prospect

Drilling of the first exploration well 6609/6-1 in the Snøhetta prospect in the Norwegian Sea has been completed. No hydrocarbons were proven. StatoilHydro is operator for production licence 286 in block 6609 on the Nordland Ridge. "This wildcat was started in September and completed after the merger of Statoil and Hydro," says Geir Richardsen, exploration vice president in Exploration & Production Norway. "Collaboration between the drilling teams in the two former companies has been good and the drilling operation was carried out in a safe, efficient and environmentally-sound manner." The primary objective was to test the potential for hydrocarbons in Upper Cretaceous rocks. Secondly, the well was also to explore the prospect opportunity in the Brygge formation in Eocene rocks. Only thin layers of sandstone were found in the potential reservoir zones. This was the first well in PL 286 which was awarded in the 17th licensing round in 2002. The well was drilled to a total depth of 2,710 metres below sea level and terminated in Triassac rocks. It has now been permanently plugged and abandoned. The drilling operation was carried out by the Polar Pioneer rig in 330 metres of water. The rig will leave the area on 3 November for the Snøhvit Unit to drill well 7120/8-4, Askeladden Beta. StatoilHydro is operator for this well.

18 Jul 2007

Rosebank a success

The Rosebank appraisal well 205/1-1 in block PL 1026, west of Shetland, is a success. During a production test, the well flowed at choked rates of 6,000 barrels of oil per day. Statoil has a 30% interest in the find. "Statoil is very encouraged by the first test results from Rosebank," says Gregory T Himes, vice president in Statoil global exploration (GEX). "The partnership is making every effort to commercialise the discovery as quickly as possible." The Rosebank discovery lies in some 1,000 metres of water, around 160 kilometres north-west of the Shetland Islands. "If commercial, Rosebank will add substantially to Statoil's Atlantic Margin production," Mr Himes says. The 205/1-1 well is the second appraisal well drilled in Rosebank as part of a three-well programme conducted by the Transocean Rather drilling rig. The deviated well is located at the southern end of the Rosebank structure and was drilled to a vertical depth of 2,750 metres. The oil is very light, with a gravity of 38 degrees API (American Petroleum Institute gravity scale). North Sea oil is normally of 20-30 API quality. The rig is currently preparing to move to the third appraisal well location in the northern part of the structure to drill well 213/27-A2. "The three-well programme is designed to fully evaluate the Rosebank discovery and fast-track a development," says Mr Himes. The well programme will optimise the understanding of the size, geometry and production potential of the field. It is expected that the programme will be completed by November 2007 when analysis of the appraisal data will determine the future work programme for the discovery. Statoil’s partners in the area are operator Chevron with a 40% interest, OMV (20%) and Dong Energy (10%). The group has acquired much of the acreage surrounding Rosebank where further prospects lie. In addition, Rosebank is 15 kilometres from the UK/Faroe Islands median line, which is promising for exploration in the Faroes where Statoil is operator in four large licences. In the area to the west of Shetland, Statoil already has a 5.88% interest in the BP-operated Schiehallion field.

26 Oct 2009

Venezuelan exploration campaign completed

StatoilHydro in Venezuela has completed the third and last well of the minimum exploration programme of Block 4, Plataforma Deltana, eastern Venezuela. The campaign initiated in December 2004 found gas-bearing sands in the Cocuina and Ballena areas. The Orca well was not successful. StatoilHydro and Total, based on thorough evaluations of the results of this exploration campaign have proposed to the Venezuelan ministry of energy and petroleum to retain acreage around Cocuina in order to assess commerciality. Plataforma Deltana Block 4 is a licence awarded to Statoil by the Venezuelan government in 2003. StatoilHydro, with a 51% interest, is the operator of the licence in which Total has the remaining 49%. Statoil has been present in Venezuela since 1995, and participates in Sincor, the most successful project in the Orinoco Belt that produces, upgrades, and commercialises extra heavy crude oil.

11 Jun 2007

Oil find in North Sea

As operator of exploration and production license 090, Hydro has made a small oil find on the H-North Prospect in the North Sea. “The find on H-North can provide valuable additional resources to fields in the Fram area. The find confirms Hydro exploration successes in this area over the past few years,” says Tore Lilloe-Olsen, exploration manager in the Development Norway sector of Hydro’s Oil & Energy business area. Both the Peon and Astero finds were discovered in this area in 2005 and proven to contain recoverable oil. Development concepts for the finds are presently being worked on. Exploration well 35/11-15S with sidetrack 35/11-15ST5 were drilled to a respective total depth of 3,177 and 2,961 meters below the surface of th