Rig: Leiv Eiriksson

Name Leiv Eiriksson
Owner Ocean Rig 1 Inc.
Manager Transocean
Rig Type Semisub
Sub Type Ultradeep Water
Jackup Type --
Max Water Depth (ft) 7500
Max Drill Depth (ft) 25000
Dimensions (ft) 391.68 x 278.88 x 44.29
Leg Length (ft) --
Competitive Yes

Current Location

Country Norway
Region NWECS

Drilling Equipment

Drawworks Type National Oilwell Varco ADS 30Q
Drawworks HP 3000
Mud Pumps Type Continental Emsco FC-2200 Triplex
Top Drive National Oilwell Varco HPS-750
Hookload Capacity (lbs) 1500000

Rig Construction Details

Rig Design Trosvik
Rig Model Bingo 9000
Year Built 2001
Country of Build China (PRC)
Yard Name Dalian No 1 Production Yard (DSIC)
Group Yard Name China Shipbuilding Industry Company Limited (CSIC)

Rig Contract Details

Operating Status Operational
Operator Lundin

News

28 Jun 2017

Consent for exploration drilling using Leiv Eiriksson

Lundin is the operator of production licence 609. The licence covers block 7220/6 which is around 190 km from Bjørnøya. Drilling will begin in July 2017 and last approx. 34 days, depending on whether a discovery is made. The well is to be drilled by Leiv Eiriksson, which is a semi-submersible drilling facility of the SS Trosvik Bingo 9000 type, owned by Ocean Rig and operated by Rig Management Norway. Leiv Eiriksson was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2008.

11 May 2017

Alta Appraisal Well Spudded

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced drilling of appraisal well 7220/11-4 (Alta-4) on the Alta discovery in PL609, located on the Loppa High in the southern Barents Sea. The Alta-4 well is located approximately 2 km south of the original discovery well 7220/11-1 and is the fourth well to be drilled on the Alta discovery. The main objective of the Alta-4 well is to further appraise the Alta discovery and to provide a calibration point for the drilling of a horizontal well for a possible extended well test that is being planned for 2018. The Alta discovery is estimated to contain gross contingent resources of between 125 and 400 million barrels of oil equivalents (MMboe). The Alta-4 well will be drilled by the semi-submersible drilling rig Leiv Eiriksson and is expected to take approximately 65 days. Lundin Norway is the operator of PL609 with a 40 percent working interest.

8 May 2017

Lundin receives consent for exploration drilling in the Barents Sea

Lundin has received consent to drill an exploration well in block 7220 in the Barents Sea. Lundin is the operator for production licence 609 in the Barents Sea. We have given the company consent to drill exploration well 7220/11-4 in a prospect named Alta. Drilling is scheduled to begin in May 2017 and will last 65 days. Possible well testing will be in addition. Water depth at the site is 402 metres. The well is to be drilled by Leiv Eiriksson, which is a semi-submersible drilling facility of the BINGO 9000 type, owned and operated by Ocean Rig ASA. It was built in China in 2001 and fitted out in the USA. Leiv Eiriksson was issued with an Acknowledgement of Compliance by the PSA in July 2008.

3 May 2017

Delineation of oil and gas discovery 7120/1-3 (Gohta) in the Barents Sea – 7120/1-5

Lundin Norway AS, operator of production licence 492, is about to complete the drilling of appraisal well 7120/1-5 on the oil and gas discovery 7120/1-3 (Gohta). The well was drilled about four kilometres north of the discovery well, about three kilometres east of appraisal well 7120/1-4 S, which was drilled in 2014, and about 17 kilometres southwest of the discovery 7220/11-1 (Alta). The discovery was proven in 2013 in Permian carbonate rocks . Before well 7120/1-5 was drilled, the resource estimate for the discovery was between 10 and 21 million standard cubic metres (Sm3) of recoverable oil and between 5 and 8 billion standard cubic metres (Sm3) of recoverable gas. The objective of the well was to delineate the northern part of the discovery 7120/1-3 (Gohta) and to investigate the reservoir quality in Permian carbonate rocks and Permian-Triassic conglomerates. Well 7120/1-5 encountered about 300 metres of carbonates in the Røye formation with poor reservoir quality. Pressure gradients were not established and the forecasted Permian-Triassic conglomerates were not encountered. The well is classified as dry, with traces of hydrocarbons. The well has not been formation tested, but extensive data acquisition and sampling have been conducted. The resource estimate for the discovery will be reduced as a result of the well. An updated resource estimate will be prepared during the year based on all new data. Development of the Gohta discovery is being considered along with the 7220/11-1 (Alta) discovery. The well result will not have any impact on the operator’s plans for further delineation of the Alta discovery. This is the third exploration well in production licence 492. The licence was awarded in APA 2007. Well 7120/1-5 was drilled to a vertical depth of 2502 metres below the sea surface and was terminated in the Røye formation in Permian. Water depth is 344 metres. The well will be permanently plugged and abandoned. The well was drilled by the Leiv Eiriksson drilling facility, which will now proceed to drill appraisal well 7220/11-4 in production licence 609 in the Barents Sea, where Lundin Norway AS is the operator.

28 Mar 2017

Drilling permit for well 7220/11-4 in production licence 609

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/11-4, cf. Section 8 of the Resource Management Regulations. Well 7220/11-4 will be drilled from the Leiv Eiriksson drilling facility at position 72°2' 27.56" north and 20°33' 8.1" east. The drilling programme for well 7220/11-4 relates to the drilling of an appraisal well in production licence 609. Lundin Norway AS is the operator with an ownership interest of 40 per cent, the other licensees are Idemitsu Petroleum Norge AS with 30 per cent and DEA Norge AS with 30 per cent. The area in this licence consists of the blocks/part of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The well will be drilled about two kilometres south of the discovery well 7220/11-1 in production licence 609. Production licence 609 was awarded in the 21st licensing round in 2011. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

13 Feb 2017

Oil discovery in the Filicudi prospect in the southern Barents Sea

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has made an oil and gas discovery in the main well 7219/12-1 and is presently drilling a sidetrack 7219/12-1A on the Filicudi prospect. The wells are located in PL533 approximately 40 km southwest of Johan Castberg and 30 km northwest of the Alta and Gohta discoveries on the Loppa High in the southern Barents Sea. The main objective of the well was to prove oil in Jurassic and Triassic sandstone reservoirs. The well encountered a gross 129 metres hydrocarbon column of high quality sandstone reservoir characteristics, with 63 metres of oil and 66 metres gas in the Jurassic and Triassic targets. Extensive data acquisition and sampling has been carried out including coring, logging and oil and gas sampled from the wireline tools. The sidetrack well has reached total depth and has confirmed the reservoir and hydrocarbon column. The gross resource estimate for the Filicudi discovery is between 35 and 100 million barrels of oil equivalents (MMboe). Well results indicate significant upside potential that require further appraisal drilling. Filicudi is on trend with the Johan Castberg discovery, with resources of approximately 500 MMboe, in similar reservoir intervals. Multiple additional prospects have been identified on the Filicudi trend within PL533 with total gross unrisked prospective resource potential for the trend of up to 700 MMboe. The partnership is considering the drilling of up to two additional prospects in 2017. There are two independent high graded prospects within PL533, Hufsa containing gross unrisked prospective resources of 285 MMboe and Hurri with gross unrisked prospective resources of 218 MMboe. The success at Filicudi has reduced the risk and both prospects carry a 25 percent chance of success. The semisubmersible drilling rig Leiv Eiriksson will after completion of the well on the Filicudi prospect in PL533 move to the Gohta discovery in PL492 to drill a second delineation well on this discovery. Lundin Norway is the operator of both PL533 and PL492 and holds a 35 percent and 40 percent working interest in these respective licences.

24 Jan 2017

Oil and gas discovery northwest of 7220/11-1 (Alta) in the Barents Sea - 7219/12-1 and 7219/12-1 A

Lundin Norway AS, operator of production licence 533, has completed the drilling of wildcat well 7219/12-1 and appraisal well 7219/12-1 A. The well proved oil and gas. The wells were drilled about 32 kilometres northwest of discovery well 7220/11-1 (Alta) and about 37 kilometres southwest of discovery well 7220/8-1 Johan Castberg. The primary and secondary exploration targets for wildcat well 7219/12-1 were to prove petroleum in two Early Jurassic and Late/Middle Triassic reservoir levels (Tubåen and Fruholmen formations). The primary exploration target for appraisal well 7219/12-1 A was to collect geological data in Early Jurassic/Late Triassic sandstone rocks (Nordmela and Tubåen formations). Well 7219/12-1 proved a total oil column of about 60 metres and an overlying total gas column of about 60 metres, of which 55 metres and 45 metres, respectively, were in sandstone with good reservoir properties in the Tubåen formation. Well 7219/12-1 A confirmed a mostly equivalent gas and oil column in the Nordmela and Tubåen formations with good reservoir properties. Preliminary estimations of the size of the discovery are between 5.5 and 16 million standard cubic metres (Sm3) of recoverable oil equivalents. Further delineation and production testing of the discovery will be assessed. The wells were not production tested, but extensive data acquisition and sampling have been carried out. These are the second and third exploration wells in production licence 533. The licence was awarded in the 20th licensing round in 2009. Well 7219/12-1 was drilled to a vertical depth of 2475 metres below the sea surface and was terminated in the Snadd formation in Late Triassic. Well 7219/12-1 A was drilled to a vertical depth of 1800 metres below the sea surface and terminated in the Fruholmen formation in Late Triassic. Water depth is 323 metres. The wells will now be temporarily plugged and abandoned. Wells 7219/12-1 and 7219/12-1 A were drilled by the Leiv Eiriksson drilling facility, which will now proceed to production licence 492 in the Barents Sea to drill appraisal well 7120/1-5 where Lundin Norway AS is the operator.

19 Jan 2017

Drilling permit for wellbore 7219/12-1 A in production licence 533

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for wellbore 7219/12-1 A, cf. Section 8 of the Resource Management Regulations. Wellbore 7219/12-1 A will be drilled from the Leiv Eiriksson drilling facility at position 72°12' 44.2" north and 19°46' 38.3" east. The drilling programme for wellbore 7219/12-1 A relates to the drilling of an appraisal well in production licence 533. Lundin Norway AS is the operator with an ownership interest of 35 per cent. The other licensees are Aker BP ASA with 35 per cent and DEA Norge AS with 30 per cent. The area in this licence consists of the blocks 7219/12 and 7220/10. The well will be drilled about 24 kilometres north of the discovery well 7220/10-1 in production licence 533. Production licence 533 was awarded on 15 May 2009 in the 20th licensing round. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

27 Dec 2016

Lundin receives consent for exploration drilling

Lundin Norway AS (Lundin) has received consent to drill exploration well 7120/1-5 in the Barents Sea. Lundin is the operator for production licence 492, comprising blocks 7120/1 and 7120/2 in the Barents Sea. The PSA has given Lundin consent to drill exploration well 7120/1-5 in a prospect named Gohta. The drilling location is around 185 kilometres north-west of Hammerfest. Water depth at the site is 368 metres. Drilling is scheduled to begin in late December 2016 and estimated to last 73 days. There will also be a potential well test. The well is to be drilled using the Leiv Eiriksson mobile drilling facility, which is owned and operated by Ocean Rig. The facility is a BINGO 9000 type, built in 2001. It is classified by DNV GL and registered in the Bahamas. Ocean Rig received Acknowledgement of Compliance (AoC) for Leiv Eiriksson from the PSA in July 2008.

16 Dec 2016

Drilling permit for wellbore 7120/1-5 in production licence 492

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for wellbore 7120/1-5, cf. Section 8 of the Resource Management Regulations. Wellbore 7120/1-5 will be drilled from the Leiv Eiriksson drilling facility, at position 71°56' 15.97" north and 20°14' 57.37" east. The drilling programme for wellbore 7120/1-5 relates to the drilling of an appraisal well in production licence 492. Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensee is Aker BP ASA with 60 per cent. The area in this licence consists of the blocks 7120/1 and 7120/2. The well will be drilled about four kilometres north of the 7120/1-3 discovery well in production licence 492. Production licence 492 was awarded on 29 February 2008 in APA 2007. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing the drilling activities.

22 Nov 2016

Oil and gas discovery east of Johan Castberg in the Barents Sea - 7220/6-2 R

Lundin Norway AS, operator of production licence 609, has completed the drilling of wildcat well 7220/6-2 R. The well proved oil and gas. Well 7220/6-2 R is a deepening of well 7220/6-2, which was temporarily plugged and abandoned in November 2015. The well was drilled about 60 kilometres northeast of the oil and gas discovery 7220/11-1 (Alta) and about 20 kilometres east of 7220/8-1 Johan Castberg. The primary targets for the well were to prove petroleum in Middle Triassic sandstone rocks (Snadd formation) and in Permian to Carboniferous carbonate rocks (Ørn formation). The well encountered a total oil column of about 20 metres with an overlying gas column of about 10 metres in carbonate rocks in the Ørn formation, with good to moderate reservoir properties. In the Snadd formation, the well encountered aquiferous sandstone with moderate to good reservoir properties. Preliminary estimations of the size of the discovery range between 3 and 7 million standard cubic metres (Sm3) of recoverable oil and between 1 and 2 billion standard cubic metres of recoverable gas. The well was not production tested, but extensive data acquisition and sampling were carried out. The well is the sixth exploration well in production licence 609. The licence was awarded in the 21st licensing round in 2011. The well was drilled to a vertical depth of 1293 metres below the sea surface, and was terminated in basement rocks. Water depth is 387 metres. The well will now be permanently plugged and abandoned. Well 7220/6-2 R was drilled by the Leiv Eiriksson drilling facility, which will now proceed to production licence 533 in the Barents Sea to drill wildcat well 7219/12-1 where Lundin Norway AS is the operator.

30 Sep 2016

Deepening of appraisal well 7220/11-3 A in the Barents Sea – 7220/11-3 AR

Lundin Norway AS, operator of production licence 609, has completed drilling the deepening 7220/11-3 AR on the 7220/11-1 (Alta) oil and gas discovery. The well was drilled about four kilometres south of the 7220/11-1 discovery well. The 7220/11-1 discovery was proven in October 2014 in carbonate rocks dating from the Early Triassic to the Carboniferous. The operator’s resource estimate after drilling the discovery well was between 14 and 50 million standard cubic metres (Sm3) of recoverable oil and between 5 and 17 billion Sm3 of recoverable gas. Well 7220/11-3 AR is a deepening of the 7220/11-3 A appraisal well, which was temporarily plugged and abandoned in September 2015. 7220/11-3 A was drilled to a measured depth of 2105 metres and a vertical depth of 1962 metres below the sea surface, and was terminated in the Gipsdalen Group in the Permian. The objective of well 7220/11-3 AR was to continue exploring the reservoir properties in the Ørn and Falk Formations under the oil-water contact in the discovery. The well encountered several zones with very good reservoir properties. Two injection tests have been completed, with injection rates of 800 and 2900 Sm3 of seawater per flow day in the Falk and Ørn Formations, respectively. A production test was also carried out in the gas zone in the Lower Triassic, with a production rate of 595 000 Sm3 gas per flow day through a 64/64 inch nozzle opening. Pressure data from the 7220/11-3, 7220/11-3 A appraisal wells and deepening 7220/11-3 AR indicate communication with the 7220/11-1 discovery well. Extensive data and samples have been collected from all wells. The results from the appraisal wells are important with regard to the further work on mapping the eastern flank of the discovery. The resource estimate will be reassessed based on the new data. This is a deepening of the fifth well in production licence 609. The licence was awarded in the 21st licensing round in 2011. The 7220/11-3 AR deepening was drilled to a measured depth of 2575 metres and a vertical depth of 2389 metres below the sea surface, and was terminated in Carboniferous sandstone in the Gipsdalen Group. Water depth is 397 metres. The well was drilled by the Leiv Eiriksson drilling facility, which will now proceed to drill wildcat well 7220/6-2 R in the same production licence.

20 Sep 2016

Drilling permit for well 7219/12-1 in production licence 533

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7219/12-1, cf. Section 8 of the Resource Management Regulations. Well 7219/12-1 will be drilled from the Leiv Eiriksson drilling facility at position 72°12' 44.2" north and 19°46' 38.3" east. The drilling programme for well 7219/12-1 relates to the drilling of a wildcat well in production licence 533. Lundin Norway AS is the operator with an ownership interest of 35 per cent. The other licensees are Det norske oljeselskap ASA with 35 per cent and DEA Norge AS with 30 per cent. The area in this licence consists of blocks 7219/12 and 7220/10. The well will be drilled about 24 kilometres south of the discovery well 7220/10-1 in production licence 533. Production licence 533 was awarded on 15 May 2009 in the 20th licensing round on the Norwegian shelf. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

30 Aug 2016

Lundin receives consent for exploration drilling

Lundin Norway AS has received consent for exploration drilling in the Barents Sea. Lundin Norway AS (Lundin) is the operator for production licence 533, comprising blocks 7219/12 and 7220/10 in the Barents Sea. The PSA has given Lundin consent to drill exploration well 7219/12-1 in a prospect named Filicudi. The drilling site is 218 kilometres north-west of Hammerfest. Water depth is around 320 metres. Drilling is scheduled to begin in early September and will last 59 days, with an addition for a potential well test. The well is to be drilled using the Leiv Eiriksson mobile facility, which is owned and operated by Ocean Rig. The facility is a BINGO 9000 type, built in 2001. It is classified by DNV GL and registered in the Bahamas. Ocean Rig received Acknowledgement of Compliance for Leiv Eiriksson from the PSA in July 2008.

26 Jul 2016

Drilling permit for well 7220/6-2 R in production licence 609

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/6-2 R, cf. Section 8 of the Resource Management Regulations. Well 7220/6-2 R will be drilled from the Leiv Eiriksson drilling facility at position 72° 34' 13.1" north and 20° 58' 19.66" east. The drilling programme for well 7220/6-2 R relates to an extension of previous wildcat well 7220/6-2, drilled in 2015 in production licence 609. Lundin Norway AS is the operator with a 40 per cent ownership interest, and the licensees are Idemitsu Petroleum Norge AS with 30 per cent and DEA Norge AS with 30 per cent. The production licence consists of blocks/parts of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The production licence was awarded in the 21st licensing round in 2011. Wildcat well 7220/6-2 R will be an extension of the sixth exploration well in production licence 609. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

21 Jul 2016

Lundin Petroleum commences the 2016 southern Barents Sea drilling campaign

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced the 2016 exploration and appraisal campaign in the Loppa High area in the southern Barents Sea with the winterised Leiv Eiriksson semi-submersible drilling rig. The 2016 drilling campaign consists of three wells commencing with the re-entry of the Alta-3 appraisal well 7220/11-3A in PL609 which was successfully drilled last year on the eastern flank of the Alta discovery. The objective of the Alta-3 re-entry is to deepen the well to further assess the quality of the Permian carbonate reservoir section as well as to conduct a production test. The original Alta-3 well encountered a gross hydrocarbon column of 120 metres and all three Alta wells drilled to date have proven pressure communication. The Alta discovery is estimated to contain gross contingent resources of between 125 and 400 million barrels of oil equivalents (MMboe). Following the completion of the Alta-3 well the rig will move further north on PL609 to re-enter the suspended Neiden exploration well 7220/6-2 which was partially drilled last year. The Neiden well was suspended immediately above prognosed reservoir section in October last year due to winter restrictions for the drilling rig (Island Innovator). The Neiden prospect is estimated to contain gross unrisked prospective resources of 204 MMboe. The third well to be drilled in the 2016 campaign is an exploration well targeting the Filicudi prospect on PL533 to the northwest of the Alta discovery and south of the Statoil operated Johan Castberg discovery. The Filicudi prospect is expected to contain Jurassic sandstone reservoir analogous to the Johan Castberg discovery. The Filicudi prospect is estimated to contain gross unrisked prospective resources of 258 MMboe. Lundin Norway is the operator of both PL609 and PL533 and holds a 40 percent and 35 percent working interest in these respective licences. The Leiv Eiriksson drilling rig has been contracted for three firm well slots with an additional six optional well slots.

9 Jun 2016

Drilling permit for well 7220/11-3 AR in production licence 609

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/11-3 AR, cf. Section 8 of the Resource Management Regulations. Well 7220/11-3 AR will be drilled from the Leiv Eiriksson drilling facility at position 72°56'45,94" north and 22°19'26,18" east in production licence 609. The drilling programme for well 7220/11-3 AR relates to the deepening of appraisal well 7220/11-3 A, which was temporarily plugged and abandoned in 2015 in production licence 609. Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensees are Idemitsu Petroleum Norge AS and DEA Norge AS, each with 30 per cent. The area in this licence consists of blocks/parts of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The well will be drilled about four kilometres south of the 7220/11-1 discovery well. Production licence 609 was awarded on 13 May 2011 in the 21st licensing round on the Norwegian shelf. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activities.

16 Mar 2016

Leiv Eiriksson contract to Westcon

Ocean Rig has signed a drilling contract with Lundin Norway for use of Leiv Eiriksson in the Barents Sea. After the completion of the contract with Rig Management Norway, the drilling rig has arrived at Westcon Yards in Olen. «We are very satisfied with winning this project in a demanding market situation. Westcon will prepare the rig for use in the Barents Sea. Among other things, this includes winterization and installation of third party equipment», says Malvin Eide, rig repair manager at Westcon. At the moment, the rig Polar Pioneer and Henry Goodridge are at the quays. Safe Scandinavia and Borgland Dolphin left Westcon Yards earlier this week. “We have thus good capacity and constantly looking for more projects», Eide says.

2 Mar 2016

Dry well northeast of the Garantiana discovery in the North Sea - 34/6-4

Total E&P Norge AS, operator of production licence 554, is in the process of completing the drilling of wildcat well 34/6-4. The well is dry. The well was drilled about 6 kilometres northeast of the 34/6-2 S (Garantiana) oil discovery. The purpose of the well was to prove petroleum in Lower Jurassic reservoir rocks in the the Cook formation. The well encountered about 96 metres of aquiferous sandstone in the Cook formation with poor to moderate reservoir quality. The well is classified as dry. Data acquisition has been carried out. This is the fifth exploration well in production licence 554, awarded in 2010 (APA 2009). Well 34/6-4 was drilled to a vertical depth of 4084 metres below the sea surface and was terminated in the Lower Jurassic Burton Formation. Water depth in the area is 390 metres. The well will now be permanently plugged and abandoned. Well 34/6-4 was drilled by the Leiv Eriksson drilling facility.

7 Oct 2015

Ocean Rig Announces Fleet Update

The Leiv Eiriksson is in the process of completing its current well in Norway. As of the date of this press release, there is no further program for the unit under its current contract which is expected to expire in March 2016. Currently, there are few further prospects of employment for the rig and if no employment is found the rig will be cold stacked and the Company will consider all its options including disposing or scrapping the unit.

1 Oct 2015

Maersk find at Tvillingen South is non-commercial

North Energy has announced a non-commercial gas/condensate discovery from the Tvillingen Sør exploration well in PL 510 in the Norwegian Sea. The main objective of well 6406/6-4S was to test the reservoir properties and hydrocarbon potential of the Middle to Lower Jurassic sandstones on the Tvillingen Sør horst structure. The well encountered a hydrocarbon column of up to 30 metres in Garn Formation sandstones with good reservoir quality. The deeper reservoir targets showed high reservoir quality, but were water wet. The well was not formation tested, but data acquisition and sampling were carried out. Maersk Oil Norge AS is the operator of PL 510. Well 6406/6-4S was drilled to a total depth of 4,484 metres in the Tilje Formation by the Leiv Eiriksson rig. North Energy ASA holds a 20 per cent working interest in PL 510. Maersk Oil Norge AS holds 50 per cent and Edison Norge AS holds 30 per cent.

23 Jun 2015

Tullow hits dust with Zumba well

Tullow Oil plc (“Tullow”) has announced that the Zumba exploration well (6507/11-11) in licence area PL 591 in the Norwegian Sea has not encountered hydrocarbons and will now be plugged and abandoned. The primary objective of the well was to prove hydrocarbons in the Upper Jurassic Rogn Formation with a secondary target in the Mid-Jurassic Garn Formation of the Fangst Group. The well found no reservoir development in the Rogn Formation and, while the Garn Formation had good reservoir quality, no hydrocarbons were present in either target. The well was drilled by the Leiv Eiriksson semisub rig in 270 metres of water to a total depth of 2,875 metres. Tullow Oil Norge AS is the operator of PL 591 with 40% equity. Lime Petroleum Norway AS (25%), Rocksource (20%*) and North Energy ASA (15%) hold non-operated interests.

15 May 2015

OMV drills duster at Bjaaland prospect

OMV (Norge) AS, operator of production licence 537, is in the process of concluding the drilling of wildcat well 7324/8-2. The well was drilled about 6 kilometres southeast of oil discovery 7324/8-1 "Wisting" in the Barents Sea and 310 km north of Hammerfest. The purpose of the well was to prove petroleum in reservoir rocks from the Middle Jurassic to Late Triassic Age (the Stø and Fruholmen formations). The secondary exploration target was to prove petroleum in reservoir rocks from the Middle to Late Triassic Age (the Snadd formation). The well encountered about 15-metre thick reservoir rocks in the Stø formation with good reservoir quality and about 55-metre thick reservoir rocks in the Fruholmen formation with medium to good reservoir quality. The well also encountered about 10-metre thick reservoir rocks in the Snadd formation with good reservoir quality. The well is dry. Data acquisition and sampling has been carried out. This is the fourth exploration well in production licence 537. The licence was awarded in the 20th licensing round in 2009. Well 7324/8-2 was drilled to a vertical depth of 815 metres below the sea surface and was terminated in the Snadd formation from the Late Triassic Age. Water depth at the site is 394 metres. The well will now be permanently plugged and abandoned. Well 7324/8-2 was drilled by the Leiv Eriksson drilling facility, which is now scheduled to drill wildcat well 6507/11-11 in production licence 591 in the Norwegian Sea, operated by Tullow Oil Norge AS.

13 May 2015

NPD approves Zumba prospect drilling

The Norwegian Petroleum Directorate (NPD) has granted Tullow Oil Norge AS a drilling permit for well 6507/11-11, cf. Section 8 of the Resource Management Regulations. Well 6507/11-11 will be drilled from the Leiv Eriksson drilling facility in position 65° 14' 16.06'' north and 7° 30' 39.31'' east completing wildcat well 7324/8-2 in production licence 537 for OMV (Norge) AS. The drilling programme for well 6507/11-11 concerns the drilling of a wildcat well in production licence 591. Tullow Oil Norge AS is the operator with an ownership share of 80 per cent. The other licensees are North Energy ASA (15 per cent) and Lime Petroleum Norway AS (5 per cent). The area in this licence consists of part of block 6507/8, part of block 6507/9 and part of block 6507/11. The well will be drilled about 14 kilometres southeast of the Heidrun field and about 220 kilometres west of the Njord field. Production licence 591 was awarded on 4 February 2011 (APA 2010). 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.

8 May 2015

Tullow set to spud Zumba prospect

Tullow Oil Norge AS (“TONAS”) has received consent for exploration drilling of well 6507/11-11. Tullow Oil Norge AS is the operator for production licence 591 in block 6507/11 in the Norwegian Sea. TONAS has applied for consent to drill exploration well 6507/11-11 in a prospect named Zumba. Drilling is scheduled to begin in May/June 2015 and estimated to last 50 days. In the event of a discovery, the activity may last a further 8 days for well testing. Water depth at the site is 272 metres.

17 Apr 2015

OMV given approval to spud Wisting prospect

The Norwegian Petroleum Directorate has granted OMV Norge AS a drilling permit for well 7324/8-2, cf. Section 8 of the Resource Management Regulations. Well 7324/8-2 will be drilled from the Leiv Eriksson drilling facility at position 73 24` 0.63" north and 24 26´ 43.60" east. The drilling programme for well 7324/8-2 relates to the drilling of a wildcat well in production licence 537. OMV Norge AS is the operator with an ownership interest of 25 per cent and the 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 blocks 7324/7 and 7324/8. The production licence was awarded in the 20th licensing round in 2009. Wildcat well 7324/8-2 is the fourth exploration well in production licence 537. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

10 Apr 2015

Total makes minor gas discovery near Skirne field

Total E&P Norge AS, operator of production licence 627, is about to complete the drilling of wildcat well 25/6-5 S. The well was drilled about 7 kilometres east of the Skirne field in the central part of the North Sea, and about 170 kilometres northwest of Stavanger. The objective of well 25/6-5 S was to prove petroleum in Middle Jurassic reservoir rocks (Hugin formation). The well encountered a 10-metre gas column in the Hugin formation with good to very good reservoir quality. The well was not formation tested, but data acquisition was carried out. Preliminary calculations of the size of the discovery are between 0.4 and 1.5 million standard cubic metres (Sm3) of recoverable oil equivalents (o.e.). The licensees will evaluate the discovery with regard to development. This is the first exploration well in production licence 627, which was awarded in APA 2011. The well was drilled to a measured and vertical depth of 2520 and 2366 metres beneath the sea surface, respectively, and was terminated in the Dunlin formation in the Lower Jurassic. Water depth is 120 metres. The well will now be permanently plugged and abandoned. Well 25/6-5 S was drilled by the Leiv Eiriksson drilling facility which will now proceed to the Barents Sea to drill wildcat well 7324/8-2 in production licence 537, where OMV (Norge) AS is the operator.

16 Mar 2015

Shango exploration well commences drilling in the Norwegian North Sea

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway and the UK, is pleased to announce the spudding of the Shango exploration well 25/6-5S (Faroe 20%). The Shango prospect in Licence PL 627 (named Skirne East by the operator Total E&P Norge AS (“Total”)) is located in the Norwegian North Sea on the northern part of the Utsira High approximately 5 kilometres from the producing Skirne field, which is also operated by Total. Shango is a structural prospect where the primary target is the Middle Jurassic Hugin formation reservoir, which has proved to be of excellent quality in the neighbouring Skirne field. Shango is located on the spill-route from the Skirne field which is producing above expectations and has been interpreted to be filled to spill. A fast-track subsea development to the Skirne field is planned if the prospect is found to contain a similar gas and condensate hydrocarbon type as found in Skirne. Skirne has been developed as a tie-back to the Statoil-operated Heimdal platform approximately 24 kilometres to the west. The Shango exploration well, located in approximately 120 metres of water, is being operated by Total (40%) using the Leif Eriksson drilling rig with partners Centrica Resources Norge AS (20%) and Det norske oljeselskap AS (20%). Results from the well will be announced when drilling operations are complete.

12 Mar 2015

OMV set to drill Bjaaland prospect

OMV Norge AS (“OMV”) is the operator for production licence 537 in block 7324/8 in the Barents Sea. OMV is to drill well 7324/8-2 Bjaaland, to investigate the find's potential. Expected start-up is April 2015 with a duration of approx. 47 days, depending on the discovery. Leiv Eiriksson is a semi-submersible drilling facility of the SS Trosvik Bingo 9000 type. The facility is owned by Ocean Rig and will be operated by Rig Management Norway. Leiv Eiriksson is registered in the Bahamas and classified by DNV GL. Leiv Eiriksson was issued with an Acknowledgement of Compliance by the PSA in July 2008.

27 Feb 2015

Total gets approval to drill 25/6-5 S well in Norway

The Norwegian Petroleum Directorate has granted Total E&P Norge AS a drilling permit for well 25/6-5 S, cf. Section 8 of the Resource Management Regulations. Well 25/6-5 S will be drilled from the Leif Eiriksson drilling facility at position 59°35’27.15” north and 02°45’39.46” east, in the central part of the North Sea. The drilling programme for well 25/6-5 S relates to drilling of a wildcat well in production licence 627. Total E&P Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Centrica Resources (Norge) AS, Det norske oljeselskap ASA and Faroe Petroleum Norge AS, each with 20 per cent. The area in this licence consists of parts of blocks 25/5, 25/6, 25/8 and 25/9. Production licence 627 was awarded on 3 February 2012 (APA 2011). This is the first exploration well to be drilled in the licence, but exploration wells have been drilled before within the area covered by this licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

26 Feb 2015

Total set to spud Skirne Ost prospect in March 2015

Total E&P Norge AS (“TEPN”) has received consent for exploration drilling of wells 25/6-5 S and 25/6-5 A. TEPN is the operator for production licence 627 in block 25/6 in the central North Sea. TEPN is to drill wells 25/6-5 S and 25/6-5 A Skirne Øst, to investigate the find's potential. Expected start-up is March 2015 with a duration of approximately 50 days, depending on whether a discovery is made. Leiv Eiriksson is a semi-submersible drilling facility of the SS Trosvik Bingo 9000 type. The facility is owned by Ocean Rig and will be operated by Rig Management Norway.

20 Feb 2015

Tvillingen South well abandoned by Maersk

North Energy ASA (“North Energy”) and its fellow licence partners in PL 510 have decided to plug and abandon the Tvillingen South exploration well (6406/6-4) in the PL 510 licence. This follows a period of difficulties in a liner setting covering the intermediate part of the well. The rig, Leiv Eiriksson, will move on to drill Total's well Skirne in PL 627. Licence partners in PL 510 will carefully evaluate new options for the licence work programme, including a potential redrill of the Tvillingen South prospect. Partners in the licence are Maersk Oil Norway AS (operator with 50 per cent), Edison Norge AS (30 per cent) and North Energy (20 per cent).

19 Jan 2015

PSA carries out audit on 'Leiv Eiriksson' semisub

The PSA has carried out an audit of groups at particular risk and emergency preparedness on Leiv Eiriksson. From 10 to 13 November 2014, the PSA carried out an audit of the efforts of Ocean Rig and RWE Dea to identify and follow up groups at potentially particular risk and emergency preparedness on the Leiv Eiriksson mobile drilling facility. RWE Dea is the operator of production licence PL420 in block 35/9 in the northern North Sea. RWE Dea has a contract with Ocean Rig to use Leiv Eiriksson to drill an exploration well in a prospect named Atlas. The purpose of the audit was to verify that Ocean Rig had established a systematic management system for occupational health and safety and emergency preparedness, and that, as the operator, RWE Dea had followed up its obligations to ensure that Ocean Rig complies with the regulatory requirements in these areas. The audit revealed non-conformities relating to; management system for OHAS and emergency preparedness, roles and clarification of responsibilities in respect of OHAS on the facility, competence and communication in the OHAS domain, information on emergency preparedness analyses and knowledge of performance requirements, assessments in the emergency preparedness analysis, the certificates for the MOB boat and davits, employee participation and the principal's supervisory responsibility.

7 Jan 2015

Maersk spuds Tvillinen South prospect

North Energy ASA (“North Energy”) a partner in production licence 510 in the Norwegian Sea has announced that Maersk Oil has begun exploration drilling on the Tvillingen South prospect. The prospect is located on the Haltenbanken in the Norwegian Sea, approximately 28 km southeast of the Kristin field. The well, 6406/6-4, will be drilled with Leiv Eiriksson. Partners in the licence are Maersk Oil Norway AS (operator with 50 per cent), Edison International Norway Branch (30 per cent) and North Energy (20 per cent).

19 Dec 2014

RWE hits dust with North Sea wildcat

RWE Dea Norge AS, operator of production licence 420, is in the process of concluding the drilling of wildcat well 35/9-12 S. The well was drilled about 20 kilometres southwest of the Gjøa field in the North Sea and about 80 kilometres southwest of Florø. The objective of the well was to prove petroleum in Upper Jurassic reservoir rocks (Intra Heather formation sandstone). Well 35/9-12 S encountered reservoir rocks in two sandstone layers in the Heather formation, both of good quality and with traces of petroleum. The well will be classified as dry. Extensive data acquisition and sampling have been carried out. This is the fourth exploration well in production licence 420. The licence was awarded in APA 2006. Well 35/9-12 S was drilled to vertical and measured depths of 3423 and 3531 metres below sea level, respectively and was terminated in the Rannock formation in the Middle Jurassic. Water depth at the site is 358 metres. The well will be permanently plugged and abandoned. Well 35/9-12 S was drilled by the Leiv Eiriksson drilling facility, which will now drill wildcat well 6406/6-4 in production licence 510 in the Norwegian Sea, where Maersk Oil Norway AS is the operator.

15 Dec 2014

Maersk given go-ahead to spud Tvillingen South prospect

The Norwegian Petroleum Directorate has granted Maersk Oil Norway AS a drilling permit for wellbore 6406/6-4, cf. Section 8 of the Resource Management Regulations. Wellbore 6406/6-4 will be drilled from the Leiv Eiriksson drilling facility at position 64°38'31.62" north and 6°46'02.77" east after completion of drilling wildcat well 35/9-12 S for RWE Dea Norge AS in production licence 420. The drilling programme for wellbore 6406/6-4 relates to drilling of a wildcat well in production licence 510. Maersk Oil Norway AS is the operator with an ownership interest of 50 per cent. The other licensees are Edison International Norway Branch (30 per cent) and North Energy ASA (20 per cent). The area in this licence consists of parts of block 6406/5 and part of block 6406/6. The well will be drilled about 35 kilometres southeast of the Kristin field. Production licence 510 was awarded on 23 January 2009 (APA 2008). 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.

4 Dec 2014

Maersk set to spud Tvillingen Sor well in Norway

Maersk Oil Norway AS (Maersk) is the operator for production licence 510 in blocks 6406/5 and 6406/6 at Haltenbanken in the Norwegian Sea. Exploration well 6404/6-4 is to be drilled in a prospect called Tvillingen Sør. The area is around 180 kilometres NNW of Kristiansund. Water depth at the site is approx. 260 metres. The PSA has now given Maersk consent for exploration drilling, which will begin in December 2014 and is estimated to last 120 days. The well is to be drilled by the Leiv Eiriksson mobile drilling facility.

4 Nov 2014

RWE DEA prepares to drill wildcat in PL 420

The Norwegian Petroleum Directorate has granted RWE Dea Norge AS a drilling permit for well 35/9-12 S, cf. Section 8 of the Resource Management Regulations. Well 35/9-12 S will be drilled from the Leiv Eiriksson drilling facility at position 61°15`28.34" north and 3°44`46.61" east after completing the drilling of wildcat wells 34/6-3 S and 34/6-3 A for Total E&P Norge AS in production licence 554. The drilling program for well 35/9-12 S relates to drilling of a wildcat well in production licence 420. RWE Dea Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Statoil Petroleum AS (40 per cent) and Idemitsu Petroleum Norge AS (30 per cent). The area in this licence consists of part of block 35/9. The well will be drilled about 80 kilometres southwest of Florø. Production licence 420 was awarded on 16 February 2007 (APA 2006). This is the fourth 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.

3 Nov 2014

Total completes Garantiana appraisal drilling

Total E&P Norge AS, operator of production licence 554, has completed drilling of appraisal well 34/6-3 S on the 34/6-2 S oil discovery and wildcat well 34/6-3 A. The wells were drilled about 30 kilometres northeast of the Visund field in the northern North Sea. Appraisal well 34/6-3 S is located 2 kilometres southwest of the 34/6-2 S discovery well. The objective of the well was to delineate the 34/6-2 S oil discovery made in the Cook formation in the Lower Jurassic in 2012. Before drilling of the appraisal well, the discovery was estimated at 6 million Sm3 recoverable oil. A secondary target was to prove petroleum in the Statfjord group in the Lower Jurassic, higher up on the structure than well 34/6-2 S. Appraisal well 34/6-3 S proved a total gross oil column of 120 metres in the Cook formation. The reservoir quality is very good. The Statfjord group is dry. The oil/water contact was not encountered. Preliminary calculation of the size of the oil discovery is between 6 and 14 million Sm3 of recoverable oil. Extensive data acquisition and sampling were carried out, including a successful formation test in the Cook formation. The well was tested with a stable production rate of 940 standard cubic metres (Sm3) of oil per flow day through a 24/64-inch nozzle opening, and with a maximum production rate of 1100 Sm3 oil per flow day through a 28/64-inch nozzle opening. The test showed good flow properties with stable flow pressure and low pressure decline, and consistent pressure build-up. The well produced oil with a gas-oil ratio of 19m3/m3. Extensive data analyses and studies have been started to confirm the resource estimate and to assess possible development solutions. The objective of wildcat well 34/6-3 A was to prove petroleum in Early Jurassic reservoir rocks in a separate structure right next to the 34/6-2 S discovery. The secondary exploration target was to prove petroleum in the Statfjord group in the Lower Jurassic. The well encountered a 12-metre net oil column in the Cook formation. The recoverable resources estimate is up to 0.5 million Sm3 oil. The Statfjord group is dry. The well was terminated in the Statfjord group. Sampling and data acquisition were carried out. The well was not formation tested. These are the third and fourth exploration wells in production licence 554, which was awarded in APA 2009. Well 34/6-3 S was drilled to a measured depth of 4462 metres (3791 metres vertical depth below the sea surface) to the Statfjord group in the Early Jurassic. Well 34/6-3 A was drilled to a measured depth of 4019 metres (3724 metres vertical depth) under the sea surface. Water depth is 381 metres. The wells will be permanently plugged and abandoned. The wells were drilled by the Leiv Eiriksson semi-submersible drilling facility, which will now drill wildcat well 35/9-12 S in production licence 420 in the northeastern North Sea, where RWE Dea is the operator.

13 Aug 2014

'Leiv Eiriksson' given permission to spud 34/6-3 S well in Norway

The Norwegian Petroleum Directorate has granted Total E&P Norge AS a drilling permit for wellbore 34/6-3 S cf. Section 8 of the Resource Management Regulations. Wellbore 34/6-3 S will be drilled from the Leiv Eriksson drilling facility at position 61°34'29.55" north and 2°43'48.70" east after completing drilling of well 35/9-11 A for RWE Dea Norge AS in production licence 420. The drilling programme for wellbore 34/6-3 S relates to drilling of a wildcat well in production licence 554. Total E&P Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Spike Petroleum, Det Norske and Svenska Petroleum, all with 20 per cent each. The area in this licence consists of part of block 34/6. The well will be drilled about 110 kilometres west of Florø. Production licence 554 was awarded on 19 February 2011 in APA 2010 on the Norwegian shelf. This is the third well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

16 Jul 2014

RWE-DEA given approval to use 'Leiv Eiriksson' to drill Atlas prospect

RWE-DEA Norge AS has received consent to carry out exploration drilling of well 35/9-X S Atlas in production licence 420 in the North Sea using the ‘Leiv Eiriksson’ mobile drilling facility. Water depth at the site is around 358 metres and it is around 81 kilometres south-west of Florø. Drilling is planned to begin in mid-August 2014, with a duration of approx. 66 days, depending on whether a discovery is made. ‘Leiv Eiriksson’ is a semi-submersible drilling facility of the SS Trosvik Bingo 9000 type. ‘Leiv Eiriksson’ received the PSA's Acknowledgement of Compliance (AoC) in July 2008.

30 May 2014

Total spuds Garantiana

Total E&P Norge AS began drilling on the Garantiana prospect (34/6-2S) at 21.30 on 30th May 2014. The drilling is performed by the semi-submersible ‘Leiv Eiriksson’ rig, which is owned and operated by Ocean Rig. Garantiana is an oil prospect that was discovered in 2012. It is located in the North Sea, 128 kilometres west of Florø, which is base for the operation. Total E&P Norge AS is operator and has a 40% share in the license.

28 May 2014

Total set to drill third well in PL554

The Norwegian Petroleum Directorate (NPD) has granted Total E&P Norge AS a drilling permit for well 34/6-3S, cf. Section 8 of the Resource Management Regulations. Well 34/6-3S will be drilled from the Leiv Eriksson drilling facility in position 61° 34’ 29.55" north and 2°, 43’, 48.70" east, after concluding drilling of wildcat well 35/9-6 S for RWE Dea Norge AS in production licence 420. The drilling programme for well 34/6-3 S relates to the drilling of a third well in production licence 554. Total E&P is the operator with an ownership interest of 40 per cent. The other licensees are Spike Petroleum (20 per cent), Det Norske (20 per cent) and Svenska Petroleum (20 per cent). The area in this licence consists of 156.15 square kilometres, all in block 34/6. The well will be drilled about 120 kilometres west of Florø. Production licence 554 was awarded on 10 February 2010 (APA 2009). This is the third well drilled in the licence. The objective of the well was primarily to delineate the oil discovery in the Cook formation, made in well 34/6-2 S. The secondary objective of the well was to explore the upside potential of the Statfjord formation. A sidetrack is also planned in order to prove potential hydrocarbons in the Statfjord and Cook formations. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

27 May 2014

RWE completes three appraisal wells in Norway

RWE Dea Norge AS, operator of production licence 420, has completed drilling of appraisal wells 35/9-11 S and 35/9-11 A on the 35/9-6 S oil, gas and condensate discovery. The discovery was proven in Jurassic reservoir rocks in the winter of 2010. Appraisal wells 35/9-11 S and 35/9-11 A were drilled 1.7 kilometres southwest of the 35/9-6 S discovery well. Before wells 35/9-11 S and A were drilled, the operator’s resource estimate for the discovery was between 2 and 10 million Sm3 recoverable oil equivalents. Well 35/9-11 A was drilled 30 metres from 35/9-11 S for optimal core samples. The objective of the wells was delineating the 35/9-6 S discovery to the southwest by proving additional resources and reducing the uncertainty regarding reservoir thicknesses and properties. Wells 35/9-11 S and 35/9-11 A encountered oil in the Heather formation, Brent Group, Drake formation and top part of the Cook formation and Statfjord Group in Jurassic reservoir rocks. The reservoirs have different pressure regimes. Formation water was encountered in the lower part of the Cook formation, but no oil/water contact was encountered in the other formations. The reservoir quality in the Heather, Tarbert, Etive, Cook formations and Statfjord Group is poor. Extensive data acquisition and sampling have been carried out. Pressure data indicates that there is no communication with the northern part of the 35/9-6 S discovery. The resources in the discovery will now be evaluated based on the results from the new wells. These are the second and third exploration wells in production licence 420. The licence was awarded in February 2007 (APA 2006). Appraisal wells 35/9-11 S and 35/9-11 A were drilled to respective vertical depths of 3733 and 3795 metres below the sea surface with associated measured depths of 3800 and 3860 metres below the sea surface. 35/9-11 S was terminated in the Dunlin Group and 35/9-11 A in the Statfjord Group, both in Lower Jurassic. Water depth is 368 metres. The wells were temporarily plugged and abandoned. The wells were drilled by the Leiv Eiriksson drilling facility, which will now proceed to production licence 554 in the northern North Sea to drill appraisal well 34/6-3 S, where Total E&P Norge AS is the operator.

25 Apr 2014

RWE granted permission to drill new appraisal well in Norway

The Norwegian Petroleum Directorate (NPD) has granted RWE Dea Norge AS a drilling permit for wellbore 35/9-11 A, cf. Section 8 of the Resource Management Regulations. Wellbore 35/9-11 A will be drilled from the Leiv Eiriksson drilling facility at position 61°21’25.60” north and 3°40’44.56” east. The drilling programme for wellbore 35/9-11 A relates to drilling of an appraisal well in production licence 420. RWE Dea Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Statoil Petroleum AS (40 per cent) and Idemitsu Petroleum Norge AS (30 per cent). The area in this licence consists of parts of block 35/9. The well will be drilled about 14 kilometres west of the Gjøa field. Production licence 420 was awarded on 16 February 2007 (APA 2006). This is the third well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

3 Mar 2014

'Leiv Eirkisson' spuds appraisal well on Titan discovery in Norway

RWE Dea Norge commenced drilling a well at production license (PL) 420, to appraise the Titan discovery. Recoverable volumes are estimated at approximately 12 million standard cubic metres oil equivalents. It is the first of two wells to be drilled on PL420 this year. RWE Dea Norge has contracted the semi-submersible rig Leiv Eiriksson to drill well 35/9-11 S on Titan (PL420) in the North Sea. A promising discovery was made on the license in 2010. The complexity of the reservoir necessitated the collection of new 3D seismic data in 2012. Following interpretation of the data, the decision to drill was made. The appraisal well will be drilled at a water depth of 370 meters and is expected to be completed in 60 to 120 days, depending on results. The primary target is the Brent Group at approximately 3,770 meters below sea level, with secondary targets in the Heather and Cook formations. “Everything is in place to ensure that the drilling will be completed without incidents, and hopefully with good results”, says Hugo Sandal, Managing Director of RWE Dea Norge. “We discovered oil and gas resources in this prospect in 2010, and are now eager to explore the size of the discovery. We have accumulated a comprehensive geological understanding of this area of the North Sea, which is one of our core areas on the Norwegian Continental Shelf”, Sandal continues. Titan is located about 16 kilometers west of the Gjøa field in the North Sea. In 2010, RWE Dea Norge discovered both oil and gas in well 35/9-6 S in a 435 meter hydrocarbon column in the Heather, Cook, and Drake Formations and in the Brent Group. Current estimates are in the range of 12 million standard cubic metres recoverable oil equivalents.

21 Feb 2014

Total E&P Norge AS use make oil discovery with 25/5-9 wildcat well in Norway

Total E&P Norge AS, operator of production licence 102 F, is about to complete drilling of wildcat well 25/5-9. The well was drilled about 10 kilometres east of the Heimdal field in the central part of the North Sea, and about 200 kilometres northwest of Stavanger. The objective of well 25/5-9 was to prove petroleum in Paleocene reservoir rocks (the Heimdal formation). The well encountered a 21-metre gross oil column in the Heimdal formation, of which 19 metres were of good reservoir quality. The oil/water contact was encountered. Preliminary estimations of the size of the discovery are between 0.5 and 2 million standard cubic metres (Sm3) of recoverable oil. The licensees will assess the discovery together with nearby prospects with regard to further follow-up. Data acquisition and sampling have been carried out. As expected, the sampling and pressure readings indicate very good production properties. This is the first exploration well in production licence 102 F. The licence, which was recently carved out of another production licence, 102 D, was awarded on 10 October 2013. The well was drilled to a vertical depth of 2240 metres below the sea surface, and was terminated in Palaeocene rocks in the Heimdal formation. Water depth is 121 metres. The well will be permanently plugged and abandoned. Well 25/5-9 was drilled by the Leiv Eiriksson drilling facility, which will now proceed to production licence 420 in the northern North Sea to drill appraisal well 35/9-11 S, where RWE Dea Norge AS is the operator.

19 Nov 2013

Total to use 'Leiv Eiriksson' to spud wildcat well on Trell prospect

The Norwegian Petroleum Directorate (NPD) has granted Total E&P Norge AS a drilling permit for well 25/5-8, cf. Section 8 of the Resource Management Regulations. Well 25/5-8 will be drilled from the Leif Eiriksson drilling facility at position 59°37’05.65” north and 02°23’44.48” east. The drilling programme for well 25/5-8 relates to drilling of a wildcat well in production licence 102 F. Total E&P Norge AS is the operator with a 50 per cent ownership interest. The other licensees are Petoro AS with 30 per cent, Centrica Resources (Norge) AS with 10 per cent and Det norske oljeselskap ASA with 10 per cent. The area in this licence comprises part of block 25/5 in the central part of the North Sea. Production licence 102 F was awarded on 10 October 2013 (APA 2011). This is the first exploration well to be drilled in the licence, and within the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities before the drilling activity commences.

29 Oct 2013

OMV drills dry well northeast of Johan Castberg with 'Leiv Eiriksson' semisub

Dry well northeast of the gas/oil discovery 7220/8-1 Johan Castberg in the Barents Sea – 7324/7-1 S. OMV (Norway) AS, operator of production licence 537, is in the process of completing the drilling of wildcat well 7324/7-1 S. The well has been drilled about five kilometres northwest of the oil discovery 7324/8-1 ("Wisting Central") and about 170 kilometres northeast of the gas/oil discovery 7220/8-1 Johan Castberg. The well's primary exploration target was to prove petroleum in Middle Triassic reservoir rocks (the Kobbe formation). The secondary exploration target was to prove petroleum in reservoir rocks from the Middle to Late Triassic (the Snadd formation). Reservoir rocks were encountered in the Kobbe and Snadd formations, but with poorer than expected reservoir properties. The well was classified as dry, with traces of petroleum. Data acquisition and sampling have been carried out. This is the second exploration well in production licence 537. The production licence was awarded in the 20th licensing round in 2009. The well was drilled to a vertical depth of 2454 metres below the sea surface and was terminated in The Kobbe formation in rocks from the Middle Triassic age. Sea depth is 413 metres. The well will now be permanently plugged and abandoned. Well 7324/7-1 was drilled with the Leiv Eiriksson drilling facility, which will now proceed to production licence 040 in the North Sea to drill well 30/40-D, where Total E&P Norge AS is the operator.

6 Sep 2013

'Leiv Eiriksson' completes drilling of Barents sea wildcat

OMV (Norge) AS, operator of production licence 537, is in the process of completing drilling of wildcat well 7324/8-1. The well proved oil. The discovery was made about 170 kilometres northeast of 7220/8-1 Johan Castberg and about 310 kilometres north of Hammerfest. The objective of the well was to prove petroleum in Middle and Early Jurassic reservoir rocks (upper Realgrunnen subgroup). The well encountered a 50-60-metre oil column in the Realgrunnen subgroup with reservoir properties as expected. Preliminary calculations estimate the size of the discovery at between 10-26 million standard cubic metres (Sm3) of recoverable oil. The results confirm oil in the play from the Early and Middle Jurassic Age. The well was not formation-tested, but extensive data acquisition and sampling were carried out. Further delineation of the discovery will be considered. This is the first exploration well drilled in production licence 537, which was awarded in the 20th licencing round in 2009. The well was drilled to a vertical depth of 905 metres below the sea surface and terminated in the Snadd formation from the Late Triassic. Water depth is 373 metres. The well will now be permanently plugged and abandoned. Well 7324/8-1 was drilled by the Leiv Eriksson drilling facility, which will proceed on to drill wildcat well 7324/7-1 on another prospect in the same production licence.

1 Aug 2013

'Leiv Eiriksson' semisub completes delineation well on Norvarg discovery in PL 535

Total E&P Norge AS, operator of production licence 535, is about to complete drilling of appraisal well 7225/3-2 on the 7225/3-1 gas discovery (Norvarg discovery). The appraisal well was drilled about 5 km from the discovery well. The discovery was proven in 2011, in reservoir rocks from the Middle Jurassic (Stø formation) and Late and Middle Triassic (Snadd, Kobbe and Havert formations). It was drilled about 275 kilometres north of Hammerfest in the Barents Sea. Before well 7225/3-2 was drilled, the operator’s resource estimate for the discovery was between 10 and 50 billion Sm3 of recoverable gas. The exploration target for the well was to delineate the 7225/3-1 gas discovery in reservoir rocks from the Middle Triassic (Kobbe formation). The secondary exploration target was to delineate the discovery in Middle Jurassic reservoir rocks (Stø formation). The well encountered gas in the Kobbe formation and with reservoir rocks of varying quality. The reservoir has better porosity than the 7225/3-1 discovery, but similar permeability and productivity. Reservoir rocks in the Stø formation were aquiferous. Two formation tests have been carried out in the upper and lower part of the reservoir. The maximum production rate was 175 000 Sm3 gas per flow day through a 52/64-inch nozzle opening. Extensive data acquisition and sampling have been carried out. Pressure sensors have been installed to observe the pressure development after the well was terminated. The preliminary assessment of results from the appraisal well indicate a possible reduction in the resource estimates for Norvarg, compared with the original estimates that followed from the discovery well. This is the second exploration well in production licence 535. The licence was awarded in the 20th licensing round in 2009. The appraisal well was drilled to a vertical depth of 2171 metres below the sea surface, and was terminated in the Klappmys formation in the Lower Triassic. Water depth is 383 metres. The well will now be permanently plugged and abandoned. The well was drilled by the "Leiv Eiriksson" drilling facility, which will proceed to production licence 537 in the Barents Sea to drill wildcat well 7324/7-1 S, where OMV Norge AS is the operator.

31 Jul 2013

Norvarg appraisal well results

Ithaca Energy Inc. announces that the appraisal well (7225/3-2) test programme on the Norvarg discovery located in licence PL535 in the Norwegian sector of the Barents Sea has been completed. The appraisal well was drilled approximately 275 km north of the Hammerfest LNG plant on Melkøya, in a water depth of 377 metres, to delineate the Triassic Kobbe Formation of the Norvarg gas discovery. Two formation tests were carried out in the upper and lower parts of the Kobbe Formation, with the well flowing at a maximum gross production rate of 175,000 standard cubic metres of gas per day (approximately 6.2 million standard cubic feet per day) on a 52/64-inch choke. Extensive data acquisition, wire line logging, coring and sampling has been carried out. The well has also been completed with down hole gauges capable of transmitting data after abandonment, which will give further information about the extent of the reservoir. The Norvarg appraisal well was drilled to test the eastern segment of the structure and to assess the quality and productivity of the Kobbe reservoir. The results of the appraisal well have confirmed the extensive nature of the Norvarg discovery and the presence of movable gas throughout the Kobbe reservoir, with no water contacts seen. As predicted the quality of the Kobbe reservoir is variable and further analysis is required to confirm the productivity of some of the reservoir intervals. Work will now be undertaken by the partnership to analyse and interpret the acquired data and evaluate the estimated recoverable hydrocarbons on the structure and potential future development options. Moveable gas identified in the deeper levels of the reservoir than those in the exploration well will be taken into account in the evaluation of the potential reserves. The well was drilled to a vertical depth of 2171 metres below sea level and terminated in the Klappmyss Formation in the Early Triassic. The well will now be permanently plugged and abandoned. This is the second well on PL535. The licence was awarded in the 20th Licensing Round in 2009. Well 7225/3-2 was drilled using Ocean's Leiv Eiriksson semi-submersible rig.

4 Jul 2013

OMV set to drill 7324/7-1 S wildcat well with 'Leiv Eiriksson' semisub

The Norwegian Petroleum Directorate has granted OMV Norge AS a drilling permit for wellbore 7324/7-1 S, cf. Section 8 of the Resource Management Regulations. The 7324/7-1 S wellbore will be drilled from the Leiv Eriksson drilling facility at position 73°29` 17.73" N and 24°16´ 48.50" E. The drilling program for wellbore 7324/7-1 S concerns the drilling of a wildcat well in production licence 537. OMV Norge AS is the operator with an ownership interest of 25% and the other licensees are Idemitsu Petroleum Norge AS with 20%, Petoro AS with 20%, Tullow Oil Norge AS with 20% and Statoil Petroleum AS with 15%. The production licence consists of blocks 7324/7 and 7324/8. The production licence was awarded in the 20th licensing round in 2009. Wildcat well 7324/7-1 S will be the second exploration well in production licence 537. The drilling permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

4 Jul 2013

'Leiv Eiriksson' semisub given approval to drill Wisting prospect for OMV in Norway

The Norwegian Petroleum Directorate has granted OMV Norge AS a drilling permit for wellbore 7324/8-1, cf. Section 8 of the Resource Management Regulations. The 7324/8-1 wellbore will be drilled from the Leiv Eriksson drilling facility at position 73°27` 6.23" N and 24°24´ 15.43" E. The drilling programme for wellbore 7324/8-1 concerns the drilling of a wildcat well in production licence 537. OMV Norge AS is the operator with an ownership interest of 25% and the other licensees are Idemitsu Petroleum Norge AS with 20%, Petoro AS with 20%, Tullow Oil Norge AS with 20% and Statoil Petroleum AS with 15%. The production licence consists of blocks 7324/7 and 7324/8. The production licence was awarded in the 20th licensing round in 2009. Wildcat well 7324/8-1 is the first exploration well in production licence 537. The drilling permit is contingent upon the operator securing the other permits and consents required by other authorities prior to commencing the drilling activity.

24 Jun 2013

Norvarg appraisal well update

Ithaca Energy Inc. ("Ithaca" or the "Company") announces that the appraisal well (7225/3-2) being drilled on the Norvarg discovery, located in PL535 in the Norwegian sector of the Barents Sea, has confirmed the presence of hydrocarbons in the Kobbe formation based on the results of wire line logs and formation tests and cores. The partnership has decided to perform a drill stem test (DST) on the well to assess the quality of the Kobbe reservoir and the volume potential in the northeastern part of the Norvarg closure. Appraisal drilling operations commenced on 25 April 2013. The well is being drilled using Ocean's Leiv Eiriksson semi-submersible rig. The well is located in 377 metres of water, approximately 275 kilometres north of the Hammerfest LNG plant on Melkøya. The partners in the licence are Total E&P Norge (operator - 40 per cent interest), North Energy (20 per cent), Ithaca Petroleum Norge (13 per cent), Statoil (10 per cent*), Det Norske (10 per cent*), and Rocksource Exploration Norway (7 per cent).

4 Apr 2013

Total E&P Norge AS set to use 'Leiv Eirkisson' semisub on Norvarg appraisal

The Norwegian Petroleum Directorate has granted Total E&P Norge AS a drilling permit for well 7225/3-2, cf. Section 8 of the Resource Management Regulations. Wellbore 7225/3-2 will be drilled from the Leiv Eiriksson drilling facility at position 72 57` 05.17" north and 25 58´ 23.34" east. The drilling programme for well 7225/3-2 relates to drilling of an appraisal well in production licence 535. Total E&P Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are North Energy ASA with 20 per cent, Det norske oljeselskap ASA with 20 per cent, Valiant Petroleum Norge AS with 13 per cent and Rocksource Exploration Norway AS with 7 per cent. The production licence consists of blocks 7225/3 and 7226/1, and was awarded in the 20th licensing round in 2009. Wildcat well 7225/3-2 is the second exploration well in production licence 535. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to starting drilling activities.

27 Nov 2012

FOGL complets Scotia well

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, announces the results of the Scotia exploration well. FOGL is the operator of the well, holding a 40% interest, whilst Noble Energy Inc. holds a 35% interest and Edison International Spa, holds the remaining 25% interest. Under the terms of the farm-out agreements, FOGL is paying 15% of the costs of this well. Well 31/12-01 was drilled to a depth of 5,555m. The well penetrated the mid Cretaceous aged reservoir objective on prognosis. The Scotia objective had been identified on the basis of its seismic amplitude response. Strong gas shows (C1 to C51)were encountered whilst drilling the target section. Interpretation of wireline log data indicates that the target interval 4719m to 4769m comprises 50m of hydrocarbon bearing fine grained sandstones and claystones. The wireline logs indicate that, at this location within Scotia, the sandstones form fairly poor quality reservoir, although some zones have up to 20% porosity. Other thin hydrocarbon bearing sandstones were encountered beneath the main target in the interval 4900m to 5164m. Subsequent evaluation of the main interval using a wireline formation testing tool did not flow hydrocarbons, indicating that the reservoir has low permeability. The well was deepened below the main target in order to penetrate and sample Cretaceous aged source rocks. Rock cuttings and sidewall core samples have been obtained from several potential source rock intervals and these will be sent to the laboratory for detailed analysis. The results should provide vital information on the quality and maturity of these source rocks and also provide a better understanding of the distribution of oil and gas within this part of the South and East Falklands basin. A further announcement on the results of this work will be made in the first quarter of 2013. The Scotia well has proven a working hydrocarbon system in the mid Cretaceous Fan play and has also demonstrated that Scotia is a viable stratigraphic trap. Whilst reservoir quality at this particular location was poor, it should be recognised that the seismic amplitude anomaly that defines Scotia covers an area of approximately 350 square kilometres. As such, further technical work is required to assess just how representative this result is, and whether or not better quality reservoir may exist elsewhere within Scotia. The well data will be invaluable for calibrating the forthcoming 3D seismic programme. The 3D seismic will be used to map sand fairways in the play and, when combined with detailed analysis from the Scotia well, should allow identification of better quality reservoir and differentiation between oil and gas prospects. FOGL now intends to plug and abandon the well and this is expected to take approximately 10 days. On the basis that the well is completed within this timeframe, it is estimated that the Company's cash balance post the 2012 drilling campaign will be approximately USD220 million.

25 Sep 2012

FOGL spuds Scotia well in Falkland Islands

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, is pleased to announce that the Scotia exploration well FI 31/12-01 was spudded on 25th September 2012. The well is located 315 km east - northeast of Stanley, Falkland Islands and 114 km from the Loligo prospect. FOGL is the operator of the well, holding a 75% interest, together with its partner Edison International Spa, which holds the remaining 25% interest. Under a farmout agreement announced on 6 August 2012, Noble Energy Inc. will also participate in this well for a 35% interest, thereby reducing FOGL's interest to 40%. The farmout agreement has been approved by the Falkland Islands Government and the changes to the licences will be formally executed in the near future. Scotia is the second of FOGL's two well exploration programme using the ‘Leiv Eriksson’ semi submersible drilling rig.

25 Sep 2012

Scotia - Fl 31/12-01 Well Spud

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, is pleased to announce that the Scotia exploration well FI 31/12-01 was spudded on 25 September 2012. The well is located 315 km east - northeast of Stanley, Falkland Islands and 114 km from the Loligo prospect. FOGL is the operator of the well, holding a 75% interest, together with its partner Edison International Spa, which holds the remaining 25% interest. Under a farmout agreement announced on 6 August 2012, Noble Energy Inc. will also participate in this well for a 35% interest, thereby reducing FOGL's interest to 40%. The farmout agreement has been approved by the Falkland Islands Government and the changes to the licences will be formally executed in the near future. Scotia is the second of FOGL's two well exploration programme using the Leiv Eriksson semi submersible drilling rig. The well is designed to test the Scotia prospect within the mid Cretaceous fan play. It is anticipated that the well operations will be around 75 days with a total depth of approximately 5,000 metres.

17 Sep 2012

FOGL announces gas discovery with Loligo well

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, is pleased to announce that the Loligo exploration well is a gas discovery. The Loligo well has proven a working hydrocarbon system in the northern part of the East Falkland basin. The results also demonstrate that Loligo is a viable stratigraphic trap. It is clear from the initial well results that the main hydrocarbon phase within the T1 to T5 aged reservoir objectives is gas, but it has not been possible to determine whether this gas has any liquid content. Well 42/07-01 has been drilled to a depth of 4,043 metres. FOGL is the operator of the well, holding a 75% interest; its joint venture partner Edison International Spa (Edison), holds the remaining 25% interest. The well penetrated six Tertiary aged reservoir objectives on prognosis. These comprise the T1, T1 deep, T2 (Trigg), T2 deep (Trigg deep), T3 (Three Bears) and T5 targets. These objectives had all been identified on the basis of their seismic amplitude responses. Very strong gas shows (C1 to C5) were encountered whilst drilling through each of these horizons. Analysis of the wireline log data indicates that all six targets comprise fine grained sandstones, siltstones and claystones. FOGL interprets that these sediments have been deposited either outside, or at the distal (outer) end of the slope channel system. Gas bearing zones were encountered over a 1,300 metre vertical interval from 2,420 to 3,720 metres. Petrophysical analysis of the T1 to T3 intervals inclusive (2,420 to 2,885 metres) indicates porosities ranging from 18% to 35% in the gas bearing zones. Due to the thin bedded nature of these sediments it is difficult to assess precisely both hydrocarbon saturation and the total net hydrocarbon bearing reservoir. Preliminary estimates however, suggest hydrocarbon saturations ranging from 40% to 60% and net hydrocarbon bearing reservoir of between 10 and 20 metres. Within the T5 target two main hydrocarbon bearing zones were encountered (3,462 to 3,558 metres and 3,608 to 3,705 metres). The net hydrocarbon bearing reservoir in these two zones was 46 and 59 metres respectively. Porosities ranged between 23% and 30%, averaging 24% and hydrocarbon saturations between 40% and 75%. Attempts were made to obtain pressure data and collect fluid samples. This was unsuccessful, probably due to the fine grained nature of sediments in the gas bearing zone and also, not having access to the specialised test equipment appropriate for this type of formation. Further detailed evaluation of all the well data, together with the existing seismic is now required in order to better define reservoir distribution and more precisely map the channel systems. Determining the reservoir potential of the thin bedded sandstones and siltstones using detailed petrophysical evaluation will be undertaken once the sidewall core samples have been analysed back in the UK. These studies will facilitate a better assessment of resource potential and also help define the work that will be required to further appraise this discovery over what is a large complex. The area of the previously mapped amplitude response at the target horizons range from approximately 250 square kilometres at T2 to over 600 square kilometres at T1. The T5 hydrocarbon zones were better than expected based on pre-drill estimates, but more work will now be required to define their areal extent. FOGL now intends to plug and abandon the well, which is expected to take approximately 10 days. FOGL and Edison believe that it would be premature to drill a second well on Loligo at the current approved location (Loligo north-west) before having undertaken detailed analysis of the current well results. Accordingly the decision has been taken that the next well will be on the Scotia prospect in the Mid Cretaceous fan play. On the basis that Scotia is also drilled within budget, it is estimated that the Company's cash balance post the 2012 exploration campaign will not be less than US$200m. A further announcement will be made when the Scotia well is spudded.

6 Aug 2012

FOGL spuds Loligo prospect in Falkland Islands

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, is pleased to announce the Loligo exploration well 42/07-01 was spudded on Friday 3 August 2012. The well is located approximately 200 km east of the Falkland Islands. FOGL is the operator of the well, holding a 75% interest, together with its joint venture partner Edison International Spa, who hold the remaining 25% interest in licence PL028. It is the first of a two well exploration programme using the 'Leiv Eriksson' semi submersible drilling rig.

6 Aug 2012

Commencement of Loligo well operations

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, is pleased to announce the Loligo exploration well 42/07-01 was spudded on Friday 3 August 2012. The well is located approximately 200 km east of the Falkland Islands. FOGL is the operator of the well, holding a 75% interest, together with its joint venture partner Edison International Spa, who hold the remaining 25% interest in licence PL028. It is the first of a two well exploration programme using the Leiv Eriksson semi submersible drilling rig. The well is designed to test the Loligo Complex, which is a large Tertiary aged stratigraphic trap with multiple reservoir objectives. It is anticipated that the well operations will be around 60 days.

31 Jul 2012

Leiv Eiriksson Rig on Contract

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, notes the announcement made today regarding the 'Completion of the 2012 drilling programme' by Borders & Southern Petroleum plc. The Leiv Eiriksson is now under contract to FOGL and its joint venture partner Edison International Spa. The rig has commenced its move to the Loligo well location. A further update will be provided once the well has spudded.

31 Jul 2012

FOGL begins contracting of 'Leiv Eiriksson' semisub

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, notes the announcement made today regarding the 'Completion of the 2012 drilling programme' by Borders & Southern Petroleum plc. The 'Leiv Eiriksson' is now under contract to FOGL and its joint venture partner Edison International Spa. The rig has commenced its move to the Loligo well location.

16 Jul 2012

Stebbing prospect reaches total depth

Borders & Southern (BOR) reports results from its Stebbing well. Well 61/25-1 was drilled to a total measured depth of 3060m (true vertical depth of 3011m). The well penetrated the upper Tertiary target on prognosis but was unable to reach lower targets due to anomalous pressure conditions. The lower targets remain unevaluated. The well encountered very strong gas shows (C1 to C5) whilst drilling the Tertiary section. Petrophysical analysis of the wireline logs suggest an interval (2500m to 2651m) of thin bedded siltstones and claystones with a net to gross of 36% and an average porosity of 19%. Due to the thin bedded character of this sequence it was not possible to obtain a clear indication of the fluid type or saturation. The geophysical anomalies identified on seismic are coincident with this zone containing hydrocarbons. Our initial assessment is that this upper target is unlikely to be commercial although further technical evaluation is required. Strong gas shows continued below the upper target. However, progress was slow due to lost circulation and well flows which occurred in consecutive hole sections. Several of these flows contained gas. On each occasion the well was successfully controlled but it became necessary to set additional strings of casing, using the contingency casing considered in the well design. In the final 6" hole section, the fluid pressures continued to rise giving further well flows and it became impossible to continue drilling whilst maintaining well integrity. A decision was therefore made to cease drilling. It is very disappointing not to have reached all the potential reservoir targets in this well. The geological and engineering data will now be reviewed in detail in order to understand the complexities of this prospect. The Company now intends to plug and abandon the well in line with regulatory requirements and assign the rig to Falkland Oil and Gas. An announcement will be made once this has been completed.

11 May 2012

Borders & Southern spud Stebbing prospect

Borders & Southern (BOR) is pleased to announce that exploration well 61/25-1 was spudded on 11 May 2012. The well is located approximately 170 km south of the Falkland Islands. Borders &Southern is the operator of the well, holding a 100% interest in licence PL018. It is the second of a two well exploration programme. The well is designed to test the Stebbing prospect, a thrust cored anticline structure with an area of closure of 85 square kilometres. Objectives comprise Tertiary and Upper Cretaceous sandstone reservoirs. The well duration is estimated to be 49 days. However, this is a wildcat exploration well and geological challenges might cause variation from this initial estimate. A further announcement will be made once the well has reached its total depth and the wireline logs have been run and their interpretation completed.

23 Apr 2012

Darwin East has good hydrocarbon shows

Borders & Southern (BOR) is pleased to announce a significant gas condensate discovery. Well 61/17-1 was drilled to a total depth of 4876m and came in very close to prognosis. As predicted, the strong AVO anomaly represented a porous sandstone reservoir containing hydrocarbons. Whilst drilling, the well encountered good hydrocarbon shows from 4633m down to 4810m. The main reservoir interval, comprising good quality massive sandstone, was found to be 84.5m thick with net pay of 67.8m. Average porosity for this interval is 22%, with maximum values reaching 30%. Fluid samples from the reservoir have been recovered and will be brought back to the UK for analysis. Once the lab analysis is complete and the results integrated with other data collected from the well, the Company will be able to comment on the liquid content of the reservoir. It is too early to give an accurate resource estimate, but this large simple structure, with a seismic amplitude anomaly measuring 26 square kilometres, is likely to contain significant volumes. The well has successfully proven a working source rock, good quality reservoir and competent seals in the South Falkland Basin. The Company has an extensive prospect inventory to exploit this success. The Company now intends to complete wireline logging operations, plug and abandon the well in line with regulatory requirements and move to the Stebbing prospect, the second well in the current drilling programme. An announcement will be made once this well has spudded.

7 Feb 2012

RWE Dea secures rig capacity in Norway

RWE Dea Norge AS has secured rig capacity for drilling three wells in in the North Sea and the Norwegian Sea during the years 2013 to 2015. The wells will be drilled with the Leiv Eiriksson rig, owned by Ocean Rig UDW Inc. RWE Dea is participating in a rig consortium which is coordinated by Rig Management Norway AS. The consortium has signed a new contract for the fifth-generation semi-submersible drilling rig Leiv Eiriksson with Ocean Rig UDW Inc. The contract is for a firm period of three years with options for extensions. The rig will commence its operations in Norwegian waters late 2012. “We are very pleased to have contracted an excellent rig with a good track record” says Hans-Joachim Polk, Managing Director of RWE Dea Norge. He explains: “We will use it to drill exploration wells on acreage with very promising hydrocarbon potential, and appraise our recent discoveries. The contract constitutes an important step in our plan to strengthen RWE Dea’s position as an operator in Norway”.

1 Feb 2012

Darwin East prospect successfully spudded

Borders & Southern Petroleum plc is pleased to announce that their exploration well 61/17-1 was spudded on 31st January 2012. The well is located approximately 140 km south of the Falkland Islands. B&S is the operator of the well, holding a 100% interest in licence PL018. It is the first of a two well exploration programme. The well is designed to test the Darwin East prospect, a fault / dip closed structure with a Lower Cretaceous sandstone reservoir target. The well will investigate geophysical attributes that include a flat spot, amplitude conformance to structure and an AVO anomaly. It is anticipated that operations will take about 45 days. A further announcement will be made once the well has reached total depth and the wireline logs have been run and their interpretation completed.

2 Dec 2011

Rig Update

FOGL, the oil and gas exploration company focused on its extensive licence areas to the South and East of the Falkland Islands, is pleased to note the Borders & Southern Petroleum plc ("B&S") announcement that the Leiv Eiriksson rig has been released by Cairn Energy PLC from drilling operations in Greenland and is now en route to the Falkland Islands for the upcoming B&S and FOGL combined drilling programme. We anticipate that the two B&S wells will take approximately three months to drill and therefore expect to commence our first well on the Loligo prospect in late April or early May 2012 and the second well to spud on completion of Loligo.

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.

30 Mar 2005

BP makes sixth oil discovery in the ultra-deepwater Block 31 Angola

Sociedade Nacional de Combustíveis de Angola (Sonangol) and BP today announced the ‘Ceres-1’ oil discovery in ultra-deepwater Block 31, offshore Angola. Ceres-1 is the sixth successful discovery BP has drilled in Block 31, following Plutão, Saturno, Marte, Venus and Palas. It is located 32 kilometres south east of the Plutão discovery, and 31 kilometres north west of the Palas discovery announced earlier in 2005. Ceres-1 was drilled by the semi-submersible drilling rig, the Leiv Eiriksson, in 1,633 metres water depth some 360 kilometres north west of Luanda, Angola and reached a total depth 4,334 meters below sea level. The well tested at a maximum rate of 5,844 barrels of oil a day through a 44/64 inch choke. Further work is ongoing to evaluate the size of the discovery. Sonangol is the concessionaire of Block 31. BP as Operator holds 26.67 per cent. Partners in Block 31 are Esso Exploration and Production Angola (Block 31) Limited. (25 per cent), Sonangol E.P. (20 per cent), Statoil Angola A.S. (13.33 per cent), Marathon Petroleum Angola, Limited (10 per cent) and TEPA (BLOCK 31), Limited, (a subsidiary of the Total Group) with 5 per cent.

14 Feb 2005

BP makes fifth oil discovery in the ultra-deepwater Block 31 Angola

Sociedade Nacional de Combustíveis de Angola (Sonangol) and BP today announced the ‘Palas-1’ oil discovery in deepwater Block 31, offshore Angola. Palas-1 is the fifth successful discovery BP has drilled in Block 31, following Plutão, Saturno, Marte and Venus. It is located 62 kilometres to the southeast of the Plutão discovery,and in a potentially new development area in the southeast of the block. Palas-1 was drilled by the semi-submersible drilling rig, the Leiv Eiriksson, in 1,602 metres water depth some 325 kilometres north west of Luanda, Angola and reached a total depth of 3,745 metres below sea level. The well was tested at a maximum rate of 5,330 barrels of oil a day (b/d) through a 40/64ths inch choke. Further work will be needed to evaluate the full extent of the Palas discovery. Sonangol is the concessionaire of Block 31. BP as operator holds 26.67 per cent. Partners in Block 31 are Esso Exploration and Production Angola (Block 31) Limited. (25 per cent), Sonangol E.P. (20 per cent), Statoil Angola A.S. (13.33 per cent), Marathon Petroleum Angola, Limited (10 per cent) and TEPA (BLOCK 31) Limited, (a subsidiary of the Total Group) with 5 per cent.

29 Mar 2004

BP announces Chumbo discovery in deepwater Angola

Sociedade Nacional de Combustíveis de Angola (Sonangol) and BP today announced the Chumbo 1 oil discovery in the deepwater Block 18, offshore Angola. This was the second discovery in 2003 and eighth overall in the block. The Chumbo-1 well was drilled by the semi-submersible drilling rig, the Leiv Eiriksson, in 1,600 metres water depth some 200 kilometres off the Angolan coast. The well flowed at a rate of 1,080 barrels per day in a test undertaken to evaluate the oil formation. Further work will be needed to evaluate the full extent of the Chumbo 1 discovery, that lies some 10 kilometres to the south south- west of the Platina–1 oil discovery in the same block. Block 18 was awarded in the middle of 1996 by Sonangol to Amoco as Operator and Shell, with a 50 per cent equity each. Following the merger between BP and Amoco in 1999, BP now manages the interest formerly held by Amoco.

29 Mar 2004

BP makes seventh discovery in Angola's Block 18

Sociedade Nacional de Combustíveis de Angola (Sonangol) and BP today announced the ‘Cesio 1’ oil discovery in the deepwater Block 18, offshore Angola. This was the first of two exploration wells which BP drilled in Block 18 in 2003. The Cesio-1 well was drilled by the semi-submersible drilling rig, the Leiv Eiriksson, in 1600 metres water depth some 170 kilometres off the Angolan coast. Further work will be needed to evaluate the full extent of the Cesio 1 discovery. It lies some 25 kilometres to the south-west of the planned Greater Plutonio development. Block 18 was awarded in the middle of 1996 by Sonangol to Amoco as Operator and Shell, with a 50 per cent equity each. Following the merger between BP and Amoco in 1999, BP now manages the interest formerly held by Amoco.

24 Nov 2003

BP announces third ultra-deepwater discovery off Angola

Sociedade Nacional de Combustíveis de Angola (Sonangol) and BP today announced the 'Marte' oil discovery in the ultra-deepwater Block 31, offshore Angola. This is the fourth exploration well BP has drilled in Block 31, and the third successful discovery following the Plutão and Saturno discoveries, which lie some 20 to 25 kilometres from Marte. BP plans to drill one further exploration well, Vénus-1, in this area this year. BP is currently exploring various development concepts. The proximity of Marte to Plutão and Saturno makes a joint development likely, however, further work will be required to define the scope of any subsequent development. The Marte-1 well was drilled in a water depth of 2,000 metres some 175 kilometres off the Angolan coast, and reached a total depth of 4,193 metres below sea level. It flowed at 5,200 barrels a day during testing. Block 31 and its operatorship was awarded in 1999 by Angola's state oil company Sonangol to BP with a 26.67% equity together with its partners Esso Exploration and Production Angola (Block 31) Limited 25%, Sonangol, E.P. 20%, Statoil Angola A.S.13.33%, Marathon Petroleum Angola Block 31 Limited 10% and EPA (Block 31) Ltd (a member of the Total group of companies) 5%.

28 Jul 2003

BP announces second ultra-deepwater discovery off Angola

Sociedade Nacional de Combustíveis de Angola (Sonangol) and BP today announced the Saturno oil discovery in the ultra-deepwater Block 31, offshore Angola. This is the third exploration well BP has drilled in Block 31, and the second successful discovery following the Plutao discovery announced last September. The Saturno-1 was drilled by the semi-submersible drilling rig, the Leiv Eiriksson, in 1,804 metres water depth some 170 kilometres off the Angolan coast and reached a total depth of 4,707 metres below sea level. Further work will be needed to evaluate the full extent of the Saturno discovery. It lies some 14 kilometres to the north-east of the Plutão discovery. Saturno flowed at 5,000 barrels a day during tests. Block 31 and its operatorship was awarded in 1999 by Angola's state oil company Sonangol to BP with a 26.67% equity together with its partners Esso Exploration and Production Angola (Block 31) Limited 25%, Sonangol, E.P. 20%, Statoil Angola A.S.13.33%, Marathon Petroleum Angola Block 31 Limited 10% and EPA (Block 31) Ltd (a member of the Total group of companies) 5%.

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