Leiv Eiriksson (Transocean) (Semisub)

Cairn secures rigs for 2011 Greenland Exploration

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04 January 2011

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.

Source: http://www.cairnenergy.com/index.asp?pageid=251&newsid=30


More News for Operator: Transocean

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.

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.

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.

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.

7 Jun 2012

Paon-1X exploration well discovers oil in Côte d'Ivoire

Tullow Oil plc (Tullow) announces that the Paon-1X exploration well in the CI-103 licence offshore Côte d'Ivoire has intersected good quality light oil in a Turonian fan system. Paon-1X is the first deepwater exploration well drilled in the CI-103 licence and has encountered 31 metres of net oil pay in a gross interval of 74 metres of turbidite sands. Pressure data indicates that this interval contains a continuous hydrocarbon column and samples show that it is a light oil of 41 degrees API. Further analysis is required to determine reservoir quality and the extent of the fan system. Following completion of logging operations, the well will be suspended for possible future use in appraisal and development operations. The Eirik Raude dynamically positioned semi-submersible rig drilled the Paon-1X well to a final depth of 5,090 metres in water depths of 2,193 metres. Tullow (45%) operates the CI-103 licence and is partnered by Anadarko Petroleum (40%) and the Societé Nationale d'Opérations Pétrolières de Côte D'Ivoire (Petroci) (15%).

16 Mar 2012

Enyenra-4A appraisal well successful

Tullow Oil plc (Tullow) announces that the Enyenra-4A appraisal well, in the Deepwater Tano licence offshore Ghana, has successfully encountered oil in very good quality sandstone reservoirs. Good evidence of communication with the Owo-1 discovery wells and the Enyenra appraisal wells confirms the significant extent of the Enyenra light oil field. Located just under seven kilometres south west of Enyenra-2A and almost 21km south of the Enyenra-3A well which defined the northern end of the Enyenra oil field, the Enyenra-4A well was drilled to define the southern extent of the field. Results of drilling, wireline logs, samples of reservoir fluids and pressure data show that Enyenra-4A has intersected 32 metres of net oil pay. Pressure data from the oil leg has demonstrated that the oil is in static communication with the oil seen in the other wells in the field and indicate a continuous oil column of approximately 600m. The Ocean Olympia drillship drilled Enyenra-4A to a total depth of 4,174 metres in water depths of 1,878 metres. Wireline logging has been completed and injectivity tests are under way to provide important data for the design of the water injection system. On completion of operations, the well will be suspended for later use. The drillship will return at a later date to the Deepwater Tano block to perform a drill stem test on the oil zone in the Ntomme-2A well. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy (18.00%), Anadarko Petroleum (18.00%), Sabre (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

9 Mar 2009

Significant discovery at Tweneboa-1 exploration well offshore Ghana

Tullow Oil plc (Tullow) announces that the Tweneboa-1 exploration well, drilled in the Deepwater Tano licence offshore Ghana, has discovered a significant highly-pressured light hydrocarbon accumulation. The well encountered 21 metres of net pay and was drilled to a depth of 3,593 metres and is currently being deepened to further assess the discovery and the up-dip limit of a potential deeper fan system. The well was optimally located to penetrate multiple targets, including the edge of an undrilled major Turonian fan system. Further drilling will now be required to test core areas within this potentially giant stratigraphic trap where thicker Turonian reservoir sections are mapped. The upside area of approximately 200 square kilometres includes two de-risked prospective parts, Owo and Ntomme. The Tweneboa-1 well was drilled by the Eirik Raude deepwater rig in a water depth of 1,148 metres some 25 kilometres west of the Jubilee Field. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy (18%), Anadarko Petroleum (18%), Sabre Oil & Gas (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

8 Jan 2009

Successful Mahogany-3 appraisal and exploration well

Tullow Oil plc (Tullow) announces that the Mahogany-3 well located in the West Cape Three Points licence offshore Ghana has intersected significant light oil columns in both the Jubilee field appraisal objective and also a deeper exploration target. In total, 33 metres of net pay have been penetrated. The primary objective of Mahogany-3 was to appraise the Jubilee field reservoir section away from the strong seismic amplitudes which have been the main targets to date. Results of drilling, wireline logs and samples of reservoir fluid indicate that 16 metres of high quality stacked oil bearing sandstones have been encountered. This confirms a significant extension of the Jubilee field to the southeast. The secondary objective of the well was to drill Mahogany Deep, an exploration target which has been identified on 3D seismic but lies at a previously untested stratigraphic level. In this section, the well encountered 17 metres of good quality oil bearing reservoir sandstones at levels significantly deeper than the oil water contacts previously intersected on the Jubilee field. This success opens up further potential in the region and is the subject of ongoing evaluation. The well has been drilled by the Eirik Raude semi-submersible rig to a depth of 4,028 metres in a water depth of 1,236 metres. Once wireline logging operations have been completed, casing will be set in advance of further drilling which is being carried out to gain further information on the regional geology. Following the conclusion of activities on Mahogany-3, the rig will move to the Tweneboa-1 exploration well location in the Deepwater Tano block. Drilling activities are expected to commence before the end of January. Tullow has a 22.9% interest in the West Cape Three Points licence. Other partners include Kosmos Energy (Operator 30.875%), Anadarko Petroleum (30.875%), the E.O. Group (3.5%), Sabre Oil & Gas (1.854%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest). Tullow is the Unit Operator of the Jubilee Field and the Technical Operator for this well.

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.

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.

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.

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.

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.

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.

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.

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%.

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%.

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.

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.

17 Apr 2014

Total makes discovery at Saphir-1XB well

The Total-operated Saphir-1XB exploration well on Block CI-514 proved the presence of liquid hydrocarbons in the deep offshore west of Ivory Coast. “Drilled in an abrupt margin play, this first well is the first discovery in the San Pedro Basin, a frontier exploration area in Ivory Coast,” commented Marc Blaizot, Senior Vice President, Exploration at Total. "Having confirmed the presence of a petroleum system containing light oil, we will next evaluate this very promising find and focus on its extension to the north and east." Lying in 2,300 meters of water, Saphir-1XB is the first well in Block CI-514. It was drilled to a total depth of 4,655 meters, encountering around 40 meters of net pay containing light 34° API oil, in a series of 350 meters of reservoirs. The data acquired during drilling are being analyzed and will be used to determine the area’s potential and design the delineation program. Total is pursuing its intensive exploration program in the area, with plans to drill two wells in Blocks CI-515 and CI-516 by year-end. Total E&P Côte d’Ivoire operates Block CI-514 with a 54% interest, alongside CNR International (36%) and PETROCI Holding (10%).

31 Dec 2013

Lukoil completes first exploration well in Sierra Leone

LUKOIL Overseas, operator of international upstream projects and a 100% subsidiary of LUKOIL, completed drilling of the first exploration well on Savannah structure (SL-5-11 deepwater block) offshore Sierra Leone. The well depth is more than 4,700 m, water depth at the drilling site exceeds 2,000 m. Drilling was accomplished using Ocean Rig Eirik Raude, world's largest self-propelled offshore platform of the 5th generation. Platform's height is 122 m, length is 119 m, width is 85 m, and displacement is 53 thousand tons, velocity is 7 knots, crew is 120 persons. Drilling was completed according to the schedule, with no violations of safety or environmental requirements, in strict adherence to the contractual obligations. The set objectives were achieved: targeted prospects were penetrated, oil saturated reservoirs were identified; oil samples were taken from the Turonian sands. Currently, the appraisal of potential hydrocarbon deposits is being performed. The results of this appraisal, as well as other data obtained while drilling, will undergo comprehensive analysis and classification. This work scheduled to be completed by the end of this year is aimed to expand the information available on the geological structure and petroleum potential of Sierra-Leonian - Liberian basin. In 2011, LUKOIL Overseas as the Operator with a 49% share entered the PSA for exploration and development of SL-5-11 block. This block, covering an area of 4,022 square kilometers, is located on the shelf and continental slope of the Atlantic Ocean at a water depth ranging from 100 to 3,300 meters. A standard contract for exploration and development of the block was concluded for the term of 30 years by project participants, including Oranto (30%) and PanAtlantic (21%). The minimum exploration program includes re-interpretation of historical seismic data, an electric exploration survey and drilling of one exploration well. Due to the importance of this program as an organic part of LUKOIL broad-scale drilling campaign in West Africa, the ceremonial launch of drilling in SL-5-11 block in September 2013 was attended by Ernest Bai Koroma, President of Sierra Leone, Guennady Gatilov, Deputy Minister of Foreign Affairs of Russia, and Andrey Kuzyaev, President of LUKOIL Overseas.

12 Sep 2013

Lukoil begins exploration drilling in Sierra Leone

Official events attended by Ernest Bai Koroma, President of the Republic of Sierra Leone, Gennady Gatilov, Deputy Minister of Foreign Affairs of Russia, and Andrey Kuzyaev, President of LUKOIL Overseas, have been held today in Sierra Leone on the occasion of the launch of drilling on the SL-5-11 block in the deepwater shelf of the West Africa. The official launch took place at the Eirik Raude drilling rig which started with spudding a deepwater well in the Savannah prospect. The target depth of the wildcat to be drilled within, will exceed 4,700 meters, the water depth at the drilling location is more than 2,000 meters. Eirik Raude is the largest 5th generation self-propelled offshore drilling rig in the world. The rig has a height of 122 m, width of 85 m, deadweight of 52,500 tons and transit speed of 7 knots, crew - 120 people. LUKOIL Overseas, operator of LUKOIL's international upstream projects, has entered into the PSA for exploration and development of block SL-5-11 in June 2011 as an operator with a 49% share. The other project partners are Oranto (30%) and PanAtlantic (21%). Block SL-5-11 covers an area of 4,022 square kilometers on the shelf and continental slope of the Atlantic Ocean with water depth ranging from 100 to 3,300 meters. 2D and 3D seismic data was acquired on 1,500 square kilometers leading to the identification of several prospects. From the geological point of view, the block belongs to the Sierra Leone-Liberia basin where a number of sizable oil discoveries have recently been made. A standard contract for exploration and development of the block was concluded for the term of 30 years. The exploration program for the block includes re-interpretation of historical seismic data, an electric exploration survey and drilling of one exploration well. The current exploration period will expire on December 31, 2013. Obligations of the next exploration period will depend on the drilling results.

2 Apr 2014

Lukoil completes first exploration well in Ivory Coast

LUKOIL Overseas (operator of LUKOIL Group's overseas upstream projects) has completed drilling its first offshore exploration well, Capitaine East-1x, at block CI-101 in the Republic of Côte d'Ivoire. The well penetrated through 140 meters of sandstone from a Turonian formation. The survey confirmed the presence of hydrocarbons, indicating the oil potential of the area. The Capitaine East-1X well target depth exceeds 5,200 m; the water depth at the well location exceeds 2,000 m. Drilling was conducted using the Eirik Raude, a 5th generation self-propelled semi-submersible drilling rig. At the end of 2013 LUKOIL completed drilling an appraisal well at the Independance field, located north-east of block CI-101 (at the adjacent CI-401 block). Currently, a survey is in progress to determine the block's resource potential. A proposal to drill another appraisal well at the Independance field will be considered soon. LUKOIL entered a Production Sharing Agreement (PSA) for the exploration, appraisal, development and production of hydrocarbons in blocks CI-101 and CI-401 in 2006. Shares in the project are distributed as follows: LUKOIL: – 56.66% (operator since 2012), PanAtlantic (formerly Vanco) – 28.34%, state-owned PETROCI Holding – 15%.

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.

12 May 2004

Eirik Raude for the Barents Sea

A charter worth around NOK 340 million covering use of the Eirik Raude drilling rig in the Barents Sea has been awarded by Statoil to owner Ocean Rig. Due to run for an estimated 155 days, this contract has been placed on behalf of the licensees in three exploration areas. Statoil plans to operate one well each in areas G and F, while Hydro intends to drill one in area C. ”We’ve opted for Eirik Raude because it’s among the most suitable vessels for the job,” explains Tor Gunnar Gloppen in the rig management unit of Exploration & Production Norway. ”It’s big, new and built to work in environmentally-sensitive arctic waters. Over the past couple of years, it’s operated off Canada in areas with weather just as tough as in the Barents Sea.” Statoil and Hydro signed a letter of intent with Ocean Rig in April on drilling the three wells, but the rig to be used has only now been clarified. Plans call for the first well to be spudded in late autumn. Eirik Raude will also do a minor job for Hydro on the Troll field in the North Sea before moving to the Barents Sea. The Troll work is included in the charter’s overall value.

12 Aug 2004

Barents Sea permit sought

An application for an emission permit to drill on the Uranus prospect in the Barents Sea has been submitted by Statoil to the Norwegian Pollution Control Authority (SFT). This exploration well will be second in the most environment-friendly drilling campaign ever conducted on the Norwegian continental shelf. Statoil’s request for a permit is accompanied by an environmental risk analysis and emergency response plan for the operation. The application is based on the principles enshrined in the recent impact assessment for offshore operations in the northern Norwegian Sea and the Barents Sea. These require the well to be planned with no discharges to the sea except with the hole section for surface casing – in other words, the topmost 400 metres. Discharges in the latter case will consist largely of natural substances such as salt and clay. But it will be necessary to emit about two kilograms of pipe dope, a small portion of which is characterised as environmentally harmful. Since the amount is so small, this is considered acceptable. The well will utilise water-based mud, and drill cuttings are to be shipped to land. Statoil’s application relates to the 7227/11-1S wildcat in production licence 202, which is due to be spudded in early 2005 after Norsk Hydro has finished a wildcat on the Obelix prospect. Both operators will use Eirik Raude in the Barents Sea. One of the world’s most modern and advanced drilling rigs, it is designed for safe operation in harsh-weather areas. Statoil has devoted considerable efforts, in cooperation with other players in the region, to reaching the goal of zero discharges.

13 Apr 2005

Drilling on Eirik Raude halted

Statoil has decided to stop all drilling from the Eirik Raude rig, which is drilling the Guovca exploration well in the Norwegian sector of the Barents Sea. Hydraulic oil was accidentally spilled from the rig yesterday, 12 April, probably caused by a leak from a hydraulic hose. “We take a very serious view of the incident and are now setting up a working group with participants from the rig operator Ocean Rig,” says Tim Dodson, Statoil’s senior vice president for exploration on the Norwegian continental shelf. "This group will identify short and long-term measures to avoid similar leaks in the future." "The progress of the drilling activity is of secondary importance, and we will take the time we need before we start up again." The Guovca well was spudded on 2 April.

4 Apr 2005

Barents Sea wildcat spudded

A wildcat in the Guovca prospect operated by Statoil in the Barents Sea was spudded on 2 April from the Eirik Raude rig. Statoil had planned to drill the Uranus exploration well in the Barents Sea before Guovca, but had to reprioritise the drilling programme as handover of the rig from Hydro was delayed. Work on drilling and completing the well is expected to take 20-30 days. Once Guovca is completed, Eirik Raude will move to the Norwegian Sea for a well on Statoil’s Tulipan prospect in block 6302/6. The rig is then due to return to the Barents Sea during the autumn to drill the Uranus wildcat. “We’ve adopted a number of measures to ensure safety and protect the environment while drilling this well,” explains Ørjan Birkeland, Statoil’s Barents Sea exploration manager. “These include detailed planning and training of personnel in cooperation with the rig contractor and other suppliers.”

23 Sep 2005

Completing Tulipan wildcat

A small gas find has been made by Statoil on its Tulipan prospect in the Norwegian Sea. As operator for production licence 251, which covers this structure, the group is currently completing the 6302/6-1 wildcat there. Small quantities of gas were encountered in early Tertiary sandstones at a depth of just over 2,600 metres beneath the seabed. Statoil is currently completing a very extensive logging programme in the well, which will form the basis for further analyses. The wildcat terminated in late Cretaceous rocks about 2,950 metres beneath the seabed. “This represents a new play model on the Norwegian continental shelf,” reports Knut Chr Grindstad, exploration manager for the deepwater part of the Norwegian Sea. “The well accordingly opens exciting perspectives in a completely new area. Unfortunately, however, it yielded only a small discovery.” Drilled by Eirik Raude, the well is located in 1,260 metres of water roughly 130 kilometres west of Hydro’s Ormen Lange gas development. Statoil has a 90 per cent interest in Tulipan, with Norske Shell holding the remaining 10 per cent. BG Norge is acquiring 20 per cent of Statoil’s share, subject to government approval. Eirik Raude will now move to the Barents Sea to drill on Eni’s Goliat discovery before spudding an exploration well on Statoil’s Uranus prospect.

12 Sep 2005

Eirik Raude resumes exploration drilling

The drilling rig, "Eirik Raude," was able to resume exploration drilling in the Barents Sea on Monday afternoon after getting the green light from the Norwegian Petroleum Directorate. Ocean Rig, the company that owns "Eirik Raude," was ordered on 17 February to evaluate the quality of all the rig's emergency barriers against accidental spills into the sea. As operator of the exploration drilling operation, Hydro was ordered to ensure that the evaluation was adequately conducted. The Norwegian Petroleum Directorate concluded on Monday that the order had been fulfilled and that exploration drilling could resume. The order to halt drilling was issued on Thursday, in the wake of two accidental spills into the sea, respectively, on 8 and 16 February.

23 Mar 2005

Barents Sea drilling concluded

Hydro has concluded its drilling operation of exploration well 7220/6-1 at the Obelix prospect in the Barents Sea. The well was drilled with the exploration rig 'Eirik Raude' to evaluate a limestone prospect of Carbon and Permian age. Drilling was concluded 1,515 metres below the sea bed. Traces of hydrocarbons were found at the expected reservoir level. Attempts to test the samples showed that the hydrocarbons were not producible, and the well will not be tested. 'Eirik Raude' will now move on to drill a further two exploration wells further east in the Barents Sea. The drilling operations in the Barents Sea are being carried out in accordance with stringent environmental requirements imposed by the authorities for oil activities in the area. In spite of two accidental emissions during drilling, the operations at Obelix have not had any damaging effect on the environment.

17 Feb 2005

Accidental spill from Eirik Raude

An accidental emission from the drilling rig "Eirik Raude" on Wednesday, 16 February, has resulted in four cubic meters of drilling fluid being spilled into the sea. The drilling fluid contains mostly clay and brine. Hydro has informed the Norwegian Pollution Control Authority about the incident, despite the fact the emission is not harmful to the environment. Hydro and the company Ocean Rig, Eirik Raude's owner, have done substantial work to avoid spills that can be harmful to the natural environment during current exploration drilling in the Barents Sea. During exploration drilling, a drilling fluid is used consisting mainly of water, clay, salt and other biodegradable components. This emission of four cubic meters of drilling fluid also included approximately 160 kilos of glycol, which is classified as a "yellow" chemical. The company regrets the incident and will work to avoid new episodes. The incident occurred when a large wave disconnected a rubber hose from a riser under the rig. Hydro is now investigating the accident and, together with Ocean Rig, will implement necessary measures to avoid any new spills into the sea.

3 May 2005

Drilling resumes on Guovca

Eirik Raude has today, 3 May, resumed drilling a wildcat on Statoil’s Guovca prospect in the Barents Sea after a three-week halt, in agreement with the Petroleum Safety Authority Norway. Together with contactor Ocean Rig, Statoil has completed a detailed investigation relating to the accidental discharge of hydraulic oil on 12 April. This incident prompted the group to halt drilling by Eirik Raude on its own initiative. The authorities also initiated an inquiry and refused to allow new operations before the discharge and compensatory measures had been reviewed in detail. According to the official investigation, the direct reason why about one cubic metre of hydraulic oil leaked out was the rupture of a hose. The latter should have been replaced, and the inquiry revealed failures in the monitoring system on the rig. Statoil takes a serious view of this incident, which exposed weaknesses in routines and systems, and has initiated a series of measures with Ocean Rig to prevent such incidents in the future. In the review after 12 April, all hoses and systems have been thoroughly checked and the damaged hydraulic hose replaced. Although Statoil believes that the requirement for two barriers was met when the discharge occurred, supply hoses beneath the rig’s cellar deck have been moved up to the deck. To ensure closer monitoring of operations on board, Statoil has reinforced the crew with an additional drilling engineer. The group has also carried out an impact assessment of the discharge, which shows that this limited leak of hydraulic oil has had no effect on the marine environment. “Everyone working for us has an obligation in relation to health, safety and the environment,” says Tim Dodson, senior vice president for exploration on the Norwegian continental shelf. “We set very high environmental and safety standards, and it’s up to us to demonstrate that we comply with these.” Statoil has been in close touch with the Norwegian Petroleum Directorate, the Petroleum Safety Authority Norway and the Norwegian Pollution Control Authority over the discharge and its investigation. “The measures implemented before drilling resumed have been adopted in close consultation with the authorities,” says Mr Dodson. “By taking these steps, we’re minimising the possibility of future undesirable incidents.”

10 Oct 2005

Rig leak posed no threat

A discharge of hydraulic oil from the Eirik Raude drilling rig in the Barents Sea on 12 April posed no environmental threat, according to an official inquiry report. This document has been drawn up by the Petroleum Safety Authority Norway (PSA) and the Norwegian Pollution Control Authority (SFT). Eirik Raude was drilling the Guovca wildcat for Statoil when the accident happened. Work stopped at once, and contractor Ocean Rig and Statoil sought to clarify the background for the leak. This internal investigation also concluded that the discharge of about one cubic metre of hydraulic oil had no impact on the marine environment. “The official report is in line with our own assessment of the causes of the accident,” says Ørjan Birkeland, Statoil’s exploration manager for the Barents Sea. “We’re glad it confirms that no environmental damage was done. It also supports the view that, despite the leak, this was one of Norway’s most environment-friendly drilling operations.” The internal inquiry found that the direct cause of the leak was a split hose. After the hose had been replaced, drilling resumed following a three-week shutdown.

30 May 2005

Tulipan wildcat spudded

The first exploration well on Statoil’s Tulipan prospect in the Norwegian Sea has been spudded by the Eirik Raude drilling rig. Located in block 6302/6 west of Hydro’s Ormen Lange gas field, this operation is being conducted in 1,250 metres of water and should last for two-three months. Plans call for the wildcat to be drilled to a total measured depth of just over 3,000 metres beneath the seabed. “Only 10 deepwater wells have been drilled off Norway until now, so the area is little explored,” says Knut Chr Grindstad, exploration manager for the Norwegian Sea. Statoil intends to drill two more exploration wells in this part of the Norwegian continental shelf during 2005.

18 Feb 2005

Will ensure "Eirik Raude" meets demands

Hydro supports and will follow up the Norwegian Petroleum Directorates order and ensure that rig company Ocean Rig conduct a thorough evaluation of spill barriers on the rig "Eirik Raude" before drilling resumes in the Barents Sea. Exploration drilling on the "Eirik Raude" rig was stopped on Wednesday, February 16, after an accidental spill of drilling fluids into the sea. ”Hydro will ensure that the drilling rig, "Eirik Raude", meets the authorities and the company’s technical and environmental demands concerning the present drilling operation in the Barents Sea. The company supports the Norwegian Petroleum Directorate’s wish for an additional inspection of the rig’s spill barriers and will ensure that a thorough evaluation will be carried out before drilling resumes,” says Hydro Oil & Energy, Operations head, Øystein Michelsen. There have been two minor spills from "Eirik Raude" during the present drilling operation in the Barents Sea during the past two weeks. Both discharges consisted mainly of organic, biodegradable matter, and were reported to the Norwegian Pollution Control Authority and the Norwegian Petroleum Directorate. The spills did not result in any environmental consequences.

13 Jan 2006

Exploration well in Barents Sea

Drilling began on an exploration well on Statoil's Uranus prospect in the Barents Sea from the Eirik Raude rig on 13 January. Expected to take about 70 days, the well is to be drilled to a total depth of about 4,000 metres. Statoil has previously made a small discovery in the same area. "This well is part of our work to investigate the further potential in this area," says Ørjan Birkeland, Statoil's Barents Sea exploration manager. The Uranus prospect is located 120 kilometres from land in block 7227/11 in production licence 202. Once Uranus is completed, Eirik Raude will move to the Norwegian Sea where it will drill an exploration well on the Statoil-operated Edvarda prospect.

25 Jul 2006

Dry Edvarda well

The drilling of exploration well 6403/6-1 in the Edvarda structure in the Norwegian Sea is completed. No gas or oil was found. ”It is of course disappointing that we did not strike hydrocarbons, but the deep-sea areas in the Norwegian Sea are rather unexplored. This new data point will be an important contribution in the efforts to find more oil and gas in the region,” say Kjersti Seim, exploration manager for the Norwegian Sea deep-sea area. The well was drilled to a total depth of 4095 metres below sea level. The drilling rig Eirik Raude performed the drilling in 1720 metres of water. The purpose was to examine the potential for oil and gas in possible sandstones from the Cretaceous period in the Edvarda prospect. Edvarda is located some 100 kilometres north-west of the gas field Ormen Lange in the southern part of the Norwegian Sea, some 230 kilometres northwest of Kristiansund. Statoil is operator for production licence 322, with an interest of 90%., whereas 10% is owned by Shell.

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).

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.

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”.

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.

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.

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.

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.

22 Mar 2012

African Petroleum contracts 'Eirik Raude' for two wells in Liberia

Following its Narina -1 discovery in Liberia, West African focused oil and gas exploration company, African Petroleum Corporation Limited (African Petroleum), is pleased to announce that it has signed a contract with Ocean Rig UDW, for a two well programme with the option for a third well, to continue its drilling program in Blocks 8 & 9, Liberia West Africa, and within the Company’s other West Africa Blocks. The programme will be completed using the ‘Eirik Raude’, a deepwater 5th generation semi-submersible, drilling rig and it is expected to commence operations in Q3 or Q4 2012.African Petroleum’s contracting of the ‘Eirik Raude’ demonstrates the Company’s ability to secure deep water drilling rigs in a very tight rig market and ensures that it can deliver its extensive exploration programme.

8 Jan 2013

African Petroleum spuds Bee Eater-1 well

African Petroleum Corporation Limited (African Petroleum) started drilling the Bee Eater-1 well in Block LB-09 offshore Liberia on the 4th January 2013 with Ocean Rig’s semi-submersible rig, the ‘Eirik Raude’. The Bee Eater-1 well is located 9.5 km north west of the 2012 Narina discovery which discovered high quality oil in Turonian reservoirs. The Bee Eater - 1 well will test a potentially westerly extension of the Narina-1 Turonian oil discovery in an axial position of the fan for improved reservoir quality and is located up dip of the postulated Narina -1 OWC. Mean recoverable un-risked prospective resources for the Bee Eater/Narina fan system, which extends over an area of 300 sq km, are estimated as 840 MMstb and 2396 MMstb for the additional prospects identified on Blocks LB-08 & LB-09 (3236 MMstb in total). ERC Equipoise have provided a recent update on the prospective resources for Liberia Blocks LB-08 & LB-09 which is available on the company website www.africanpetroleum.com.au.The second well in this drilling program will be drilled with the ‘Eirik Raude’ in Liberia following on immediately after completion of the Bee Eater-1 well. A number of potential well locations in Blocks LB-08 & LB-09 are under consideration dependent on the outcome of the Bee Eater-1 well. Karl Thompson CEO comments "2012 has been a very successful year for the company with the Narina-1 discovery in Liberia and the expansion of the exploration portfolio with the addition of 5 more exploration blocks in Senegal, Sierra Leone and Cote d’Ivoire. Extensive 3D seismic surveys have been acquired on the blocks in Senegal and Cote d’Ivoire with very encouraging results and are being evaluated to include in our forward drilling program. We are looking forward to a very active exploration program in 2013 starting with the drilling of the high potential Bee Eater prospect in Liberia LB-09 and follow on drilling in Liberia plus Cote d’Ivoire and The Gambia/Senegal coast.”

20 Feb 2013

African Petroleum announces discovery at Bee Eater-1

African Petroleum Corporation Limited (African Petroleum) announces a discovery at the Bee Eater-1 well. The well was designed to test the Turonian fan by way of a large step out of 9.5km, west of the original Narina-1 oil discovery and has encountered 48 metres of Narina equivalent oil bearing Turonian sandstone out of a 135 metre oil interval, in line with the Company’s pre-drill expectations. Bee Eater-1 spudded on the 4th January 2013 using the ‘Eirik Raude’ drilling rig which has taken 48 days to drill the well, of which 21 days was downtime due to a malfunctioning Blow-out Preventer (BOP). The well was drilled to a total depth of 4,100 metres in a water depth of 1,067 metres.

8 Dec 2011

Lukoil and Vanco announce discovery in Ivory Coast

LUKOIL Overseas Cote d’Ivoire Ltd. together with Vanco Cote d’Ivoire Ltd. (Vanco) and PETROCI Holding, announces a discovery in Block CI-401. The Independance-1X exploration well drilled on Block CI-401 has penetrated the targeted objective and found a series of good-quality sandstones containing light oil and gas condensate. Full analysis of well results, including wireline logs, reservoir pressures and fluid samples, confirms that the well penetrated 8 meters (26 feet) of hydrocarbon pay in two good-quality Turonian-aged sand packages. Hydrocarbon samples recovered from the Independance-1X well indicate 40 degrees API gravity. The well will be temporarily abandoned at a total depth of 4,132 meters. Independance-1X was drilled in a water depth of 1,689 meters, approximately 93 kilometers (58 miles) southeast of Abidjan. The Independance -1X is the second exploration well to be drilled in Block CI-401, which encompasses an area of 619 square kilometers (152,948 acres) in water depths ranging from 950 to 2,100 meters. On September 30th, 2005, the Government of the Republic of Cote d’Ivoire, Vanco Cote d’Ivoire Ltd. and PETROCI Holding signed a Production Sharing Contract covering Block CI-401. LUKOIL Overseas Cote d’Ivoire Ltd. joined the block in 2007. Vanco (Operator) holds a 28.34% participating interest with LUKOIL holding 56.66%. PETROCI Holding, the state oil company, holds a 5% participating interest together with 10% carried interest. LUKOIL will continue the analysis of the discovery, its scale and development prospects in order to make further investment decision for commercialization of the project.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

15 Oct 2014

Ocean Rig to follow Transocean and Seadrill by applying for MLP listing

Drilling contractor Ocean Rig is preparing to potentially follow in the footsteps of other drilling contractors including Transocean and Seadrill, with the filing of initial paperwork to form a US master limited partnership (“MLP”). Ocean Rig intends to use top rigs on long-term contracts to provide a source of steady cash flow for potential investors. The MLP will be given the name ‘Ocean Rig Partners LP’ and its fleet will initially be made up of a trio of newbuild drillships, ‘Ocean Rig Athena’, ‘Ocean Rig Mylos’ and ‘Ocean Rig Skyros’. The company did not provide financial details on the proposed offering. Earlier this year Transocean successfully created its own MLP, Transocean Partners LLP which owns and operates three rigs working in the US GoM.

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.

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.

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.

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.

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.

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).

15 Jan 2015

Ocean Rig announces full financing for Ocean Rig Apollo

Ocean Rig UDW Inc. (NASDAQ:ORIG) ( “Ocean Rig”), a global provider of offshore deepwater drilling services, announced today that it has received firm commitments from lenders for up to a USD475 million syndicated secured term loan to partially finance the construction costs of the Ocean Rig Apollo. The facility amount is for the lesser of USD475 million and 70% of the fair market value of the drillship. This facility has a five year term, and approximate 12 year repayment profile, and bears interest at LIBOR plus a margin. This financing is led by DNB and the lending syndicate consists of DVB Bank and potentially other commercial lenders as well as the Import-Export Bank of Korea (KEXIM).

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.

2 Feb 2015

'Eirik Raude' semisub begins mobilisation to Falkland Islands

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is pleased to announce that the drilling unit Eirik Raude has begun its mobilisation to the North Falkland Basin ("NFB") from West Africa.

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).

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.

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.

3 Mar 2015

'Eirik Raude' arrives in Falkland Islands

Falkland Oil and Gas Limited (“FOGL”), the oil and gas exploration company focused on its extensive license areas to the North, South and East of the Falklands islands, and Rockhopper Exploration plc (“RKH”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, are pleased to announce that the drilling unit Eirik Raude has arrived in the North Falkland Basin (“NFB”) and will shortly be moving to location to commence the first well, on the Zebedee prospect, of the six well drilling campaign that will see two wells drilled in the NFB then one to the south of the islands, followed by two more in the north and a final slot in the south.

6 Mar 2015

Premier spuds Zebedee prospect

Rockhopper Exploration plc (“Rockhopper”), has announced that the 14/15-5 well (“Zebedee”) was spudded by Premier Oil on 6th March 2015. The well is located on licence PL004b in which Rockhopper has a 24% working interest and is an exploration well. The Zebedee well will test a total of seven stacked fan bodies with varying geological chances of success (GCoS) of 9 - 52%. Net prospective Pmean resources are estimated at 68 million barrels (mmbbls) in a range of 13 - 178 mmbbls. Drilling, coring and logging operations are expected to take approximately 30 days. A further release will be made when those operations are completed. The well was spudded by the Eirik Raude semisub rig which will drill a further five wells in the Falkland Islands. The current drilling order is, Zebedee in licence PL004b, Isobel Deep in licence PL004a, Humpback in southern licence area, Jayne East in licence PL004c, Chatham in licence PL032 and a sixth well yet to be decided. The North Falkland Basin wells are anticipated to cost approximately USD50 million each.

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.

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.

2 Apr 2015

Premier strikes oil and gas with Zebedee-1

Premier Oil Plc (“Premier”) has announced that the Zebedee well (14/15b-5) in PL004b (Premier 36 per cent equity) discovered 81 feet of net oil-bearing reservoir and 55 feet of net gas-bearing reservoir. The well penetrated multiple targets in the Cretaceous F2 and F3 formations with a total hydrocarbon net pay of 136 feet. The reservoir at both the Hector and Zebedee intervals is of good quality and the above results are in line with prognosis. Good oil shows were recorded at the deeper F3 targets but at this location the sands are not well developed. The well will now be plugged and abandoned as a successful exploration well. The Eirik Raude rig will then drill the first exploration test of the Elaine/Isobel fan complex in the southern part of the North Falkland Basin with the Isobel Deep well. The results of this well are expected in late April.

9 Apr 2015

Isobel Deep well spud in Falkland Islands

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, has announced that the 14/20-1 'Isobel Deep' well (the "Well") was spudded, by Premier Oil as operator, at 22:20 local time on the 8th April 2015. The Well is located on licence PL004a in which Rockhopper has a 24% working interest and is an exploration well on the Isobel deep prospect. The Isobel Deep Well will be the first test of the F3 fan system entering the basin from the South East margin as a sequence of stacked reservoirs. This well will be targeting the Isobel deep fan in the area of maximum mapped reservoir thickness and has a GCoS of 20%. The well is targeting Gross Pmean resources of 72mmbbls (range 9-207mmbbls) although the complex as a whole in this area has gross Pmean prospective resources of just over 500mmbbls. Drilling operations are expected to take approximately 30 days and no coring or testing is planned for this well. A further release will be made when drilling is completed. The North Falkland Basin wells are anticipated to cost approximately USD50 million each. As a result of the various carry arrangements, the total net cash exposure to Rockhopper of the four wells is estimated at approximately USD25 million.

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.

13 Apr 2015

Falkland Oil and Gas Limited announces change to drilling programme

Falkland Oil and Gas Limited ("FOGL"), the exploration company focused on its extensive licence areas to the North, South and East of the Falkland Islands, has announced that Noble Energy ("Noble") and its joint venture partners FOGL and Edison International ("Edison") have elected to defer a potential second well in the South and East Falkland basin. The joint venture partners have concluded; having taken into account a number of factors, that the optimum course of action is to defer the drilling of a second well in the southern basin. In these circumstances FOGL was amenable to a proposal from Noble, that in order to fulfil the drilling commitment, they should utilise the contracted drilling slot to drill a well in the North Falklands Basin. Noble, Edison and FOGL remain fully committed to exploration in the South and East basin and still firmly believe in its prospectivity. The well on the Humpback prospect is considered by the joint venture partners to be the prime 'play opening' well. It is an important test of concept, in terms of evaluating the Cretaceous deepwater fan play and the presence of oil within the Fitzroy sub-basin. Humpback is located near a cluster of similar prospects totalling over one billion barrels of oil. The operator estimates that the Humpback prospect contains between 250 and 650 mmbbls of gross prospective resources (un-risked). If the initial drilling results are encouraging, the joint venture partners will look to fully appraise Humpback and drill other similar prospects within the play area. Such further exploration and appraisal drilling would be part of a future campaign, with wells on either Scharnhorst and/or Starfish also possibly forming part of such a programme. This decision does not impact any existing agreements between FOGL and Noble. In the event that another exploration well is drilled after Humpback, within the joint venture's licence area, FOGL would still retain a partial carry of the drilling costs under the terms of the Noble farm out agreement. FOGL is fully funded for the firm four wells and will be left in a stronger and more sustainable financial position as a result of this decision. Following this agreement, the revised drilling schedule is 1. Zebedee, 2. Isobel Deep, 3. Humpback, 4. Jayne East, 5. Chatham, 6. Rhea. The drilling program is currently being carried out by the Eirik Raude semisub which recently spudded the Isobel Deep well.

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.

24 Apr 2015

Premier runs into trouble whilst drilling Isobel Deep

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is providing an update on the operations on the 14/20-1 Isobel Deep well ("Well") that was spudded, by Premier Oil as operator, on 8th April 2015. Following successful setting of the 13 3/8" casing string at a depth of 1273.9m mdrkb, the Well has encountered problems with the BOP stack as a result of equipment malfunction which has required the Well to be suspended and BOP stack recovered for the necessary repairs. The Operator has decided to move the rig and set conductors at the Chatham and Jayne East locations. The rig will return to the Isobel Deep location to continue drilling on completion of BOP repairs and a further operational update will be issued at that time. No spud announcements will be made for the Chatham or Jayne East wells but information on the setting of conductors will be made in the next operational update.

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.

11 May 2015

Cairn Energy cements Senegal drilling programme

Cairn Energy PLC (“Cairn”) and its joint venture partners have submitted a three year evaluation work plan to the Government of Senegal including an initial programme of three firm and three optional exploration and appraisal wells, with drilling starting in Q4 2015 in Cairn’s new basin play offshore Senegal focused on the acreage around the SNE-1 discovery well. Cairn estimates that the existing two discoveries and the currently identified prospects and leads have an estimated mean risked resource base of more than a billion barrels. The company has selected the Ocean Rig Athena drillship for the drilling programme and is in the final stages of finalising the rig contract. The drillship is currently contracted to ConocoPhillips in Angola until June 2017 and it is not yet clear whether the contract will be a sublet or if Cairn is taking over part of ConocoPhillips’ contract. The firm three well programme is currently planned to include two appraisal wells of the SNE-1 discovery which will core and test the reservoir, as well as one shelf exploration well. There will also be a 2,000km2 3D seismic data acquisition campaign over the Sangomar and Rufisque blocks to help fully map the prospectivity of the contract area. A work programme and budget for the three optional wells will be presented to joint venture partners in Q3 2015. Targets for these wells will be drawn from a combination of further evaluation of the SNE-1 discovery, additional exploration in the shelf region, and exploration in the acreage around FAN-1. Drilling plans for these wells will be subject to ongoing FAN studies and the results of the first three firm wells. Simon Thomson, Chief Executive of Cairn said: “Cairn made two significant discoveries offshore Senegal in 2014 proving a hydrocarbon system in a new and emerging Atlantic Margin Basin. We are excited about the exploration and appraisal opportunity of this world class asset. We have now submitted a three year evaluation work plan to the Government of Senegal which is designed to lay the foundation for a long term multi-field, multi phase exploitation plan. Our focus will be to add value in Senegal within a balanced, well funded company. We are well placed to take advantage of this exciting opportunity as we build on the success of last year.”

12 May 2015

Ocean Rig delays delivery of two newbuild drillships

Ocean Rig UDW Inc (“Ocean Rig”) today released its financial results for Q1 2015. The company posted a profit of USD41.1 million for the first three months of 2015, recovering from last year’s USD1.5 million first quarter loss. However, Ocean Rig’s Chairman and Chief Executive officer George Economou warned that “the market remains challenging with limited visibility of new contracts and is likely to remain through the near term”. With reference to this the company took the decision to delay the delivery of the Ocean Rig Crete and Ocean Rig Amorgos newbuild drillships until Q1 2018 and Q1 2019. Both units had previously been ordered to be delivered in 2017.

12 May 2015

'Eirik Raude' restarts Isobel Deep drilling

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, has announced the following operations update. The Erik Raude semisub rig has now completed repairs to its BOP control system and has undergone the subsequent re-testing of the BOP stack following its return to the Isobel Deep well location where drilling re-commenced on 11th May 2015. Since suspending operations on the Isobel Deep (14/20-1) well on 24th April 2015, the rig has spudded and suspended the Jayne East (14/15c-6) well at 541m mdrkb on 29th April 2015 and spudded and suspended the Chatham (14/10-10) well at 1388m mdrkb on 4th May 2015.

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.

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.

18 May 2015

Ocean Rig and Eni complete drilling contract agreement

Ocean Rig UDW Inc. (“Ocean Rig”) today announced that in connection with the previously announced omnibus agreement with Eni Angola S.p.A (“Eni”), all closing connections including approvals by national authorities and signing of definitive documentation has been satisfied. The omnibus agreement was originally announced by Ocean Rig on the 8th January 2015. As a result of the completed agreement, the contract for the Ocean Rig Poseidon has been extended for a full year, until Q2 2017 and the unit now has a total contract backlog of USD367 million. Meanwhile the Eni has entered into a new contract for the Ocean Rig Olympia which is expected to commence drilling in Angola in Q3 2015 for a minimum period of eight months and a total contract value of USD91 million.

19 May 2015

Potential oil shows at Isobel Deep

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is pleased to provide the following update ahead of the Company's AGM today in relation to the Isobel Deep Well. Following the penetration of a sand interval with suspected elevated formation pressure and oil shows, the operator (Premier Oil) has decided to set a cement plug over this interval and run the contingent 9 5/8" casing string in the shale section above, prior to drilling through the prognosed Isobel reservoir interval to the well TD (“Total Depth”). The contingent casing string will enable additional flexibility while drilling and evaluating the target formation. This scenario had been anticipated and the additional 9 5/8" casing is already on the rig. The presence of oil shows is not necessarily indicative of net pay and conclusive results for the well will not be available until drilling operations have been completed and logging data collected. A further announcement on the results of the well will now be likely in early June.

28 May 2015

Premier announces discovery at Isobel Deep

Premier Oil is pleased to announce an oil discovery at the Isobel Deep exploration well 14/20-1 in the North Falkland Basin, approximately 30km south of the Sea Lion field. The Isobel Deep exploration well has been drilled to a depth of 8,289 feet reaching top reservoir on prognosis. The bottom 75 feet of the well consists of oil bearing F3 sands. These sands were at a higher than expected reservoir pressure and this resulted in an influx into the well. As part of the operations to remove the influx, oil was recovered from the well and appears similar in nature to Sea Lion crude. As a result of the new geological information it has been decided to suspend operations on the well and release the rig to drill in the South Falkland Basin. The rig is expected to return to continue operations in the North Falklands Basin in August. Premier is now considering the optimal appraisal programme for the Elaine/Isobel complex in PL004.

15 Jun 2015

Noble Energy spuds Humpback well

Falkland Oil and Gas Limited (“FOGL”), the oil and gas exploration company focused on its extensive licence areas to the North, South and East of the Falklands islands, is pleased to announce that the 'Humpback' exploration well, (the "Well") was spudded on 13th June 2015. The well is located on licence PL012 in which FOGL has a 52.5% working interest and will target the Humpback prospect. Humpback is located within a cluster of similar prospects, in the Fitzroy sub-basin, which have a total, combined, prospective resource of over one billion barrels of oil. The well will test multiple stacked reservoirs within the Cretaceous Diomedea fan complex. The Humpback well is located in a water depth of approximately 1,260 metres and is expected to reach a total depth of 5,350 metres. The well is anticipated to take approximately 65 days to drill. A further release will be issued once logging is completed. FOGL is partially carried through the costs of this well by Noble Energy (Licence Operator) and has a paying interest of 27.5%.

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.

25 Sep 2015

North Falkland Basin Exploration Update

Rockhopper Exploration plc (AIM: RKH), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is pleased to announce that agreement has been reached to drill a further well on the Isobel/Elaine complex. The re-drill well will target the Isobel Deep reservoir which was oil bearing in well 14/20-1, but could not be logged or sampled for mechanical reasons. This new well will be drilled a suitable distance (approximately 4km) from the original well bore and is also expected to encounter additional reservoir targets in the Elaine South and Isobel Shallow Fans. This well will replace the Jayne East well in the current drilling campaign (subject to the final regulatory approvals). As part of the agreement to drill a further well on the Isobel/Elaine complex, Rockhopper has reached agreement with Falkland Oil & Gas Limited ("FOGL") on the terms of compensation for not drilling the Jayne East well. Under the agreement, Rockhopper will pay FOGL $4.0 million ($2.0 million immediately with the balance expected to be paid later in 2016). As per the original farm out agreement, Rockhopper and Premier Oil will carry FOGL on its 40% equity share of the re-drill well costs. The rig, which is currently drilling to the south of the Falkland Islands, is expected to return to the North Falkland Basin in mid to late October 2015.

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.

8 Oct 2015

Oceam Rig releases update on current fleet status

Ocean Rig UDW Inc. (“Ocean Rig”) has released an update to the current status of the company’s offshore rig fleet. In the release Ocean Rig announced that the Ocean Rig Skyros commenced its new six year contract with Total in Angola on the 1st October 2015 as well as giving updates as to the Leiv Eiriksson, Eirik Raude and Ocean Rig Olympia units. With regards to the latter three units, Ocean Rig announced that upon completion of their current contracts the company will look to cold stack the units if no new contracts can be secured and in the cases of the Eirik Raude and Leiv Eiriksson semisubs the company may choose to dispose of the assets through scrapping. Meanwhile the company also announced that on the 25th September it received a notice from Petrobras of a material breach under the contract for the Ocean Rig Mylos drillship which would enable Petrobras to terminate the contract if the breach is not remedied within 75 days. Ocean Rig announced that it intends to defend its rights under the contract.

7 Oct 2015

Ocean Rig Announces Fleet Update

The Eirik Raude is currently completing its third well in a six-well program in the Falklands and is now expected to remain employed in the Falkland Islands into January of 2016. Currently, there are no further prospects of employment for the rig in the Falkland Islands 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.

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.

7 Oct 2015

Ocean Rig Announces Fleet Update

The Ocean Rig Olympia has successfully started its new contract in Angola as of August 15, 2015. The rig is expected to move to the Ivory Coast for one well in the fourth quarter of 2015 and return to Angola to complete its remaining contract until June 2016. Currently, there are no prospects for further employment and if no employment is found the rig will be cold stacked and the respective SPS will be postponed.

14 Oct 2015

'Ocean Rig Athena' to mobilise to Senegal in the coming days

FAR Limited (“FAR”) and its Senegal joint venture partners have executed contracts for the use of the Ocean Rig Athena drillship for a drilling program in FAR’s highly prospective offshore Senegal Blocks starting in the coming weeks. The Ocean Rig Athena is under long term contract with ConocoPhillips and the ConocoPhillips drilling organisation will play a key role in project managing the drilling program. The drillship is currently in Angola and FAR expects it will commence mobilisation to Senegal in the next few days. The firm drilling program includes three wells including two appraisal wells on the world class SNE-1 oil discovery that will include a coring and testing program, plus one shelf exploration well to further evaluate the shelf area prospectivity. This drilling, logging, coring and testing program is expected to be completed by mid- 2016. The first two wells (SNE-2 and SNE-3) will be drilled to appraise the SNE field and are aimed at progressing towards proving the threshold economic field size which FAR estimates is in the order of 200 mmbbls for a foundation project. The third well (BEL-1) in the drilling program will be the first exploration well to be drilled in the blocks following the discoveries in the FAN-1 and SNE-1 wells. This well will be aimed at building the resource base within tie-back range of a possible future hub development over the SNE field. It will be drilled into the Bellatrix Prospect which has been mapped by FAR to contain 168 mmbbls of oil on a gross, unrisked, prospective resource basis with 25 mmbbls net to FAR. The day rate for drilling for the Senegal joint venture has been adjusted downwards to reflect prevailing market conditions, where day rates have dropped by up to 50% for deep water drilling units offshore Africa. These reduced rates are expected to allow the drilling and testing program to be completed for a heavily reduced cost in comparison to what was envisaged 12 months ago under a higher oil price environment.

19 Oct 2015

'Ocean Rig Athena' enroute to Senegal

FAR Limited (“FAR”) has announced that the Ocean Rig Athena drillship has commenced mobilisation from Luanda, Angola in preparation for the appraisal and exploration drilling program in FAR’s highly prospective blocks, offshore Senegal. The SNE discovery made in late 2014 will be appraised with the first two wells in the three well drilling program. The firm drilling program will include a coring and testing program, two appraisal wells for SNE (SNE-2 and SNE- 3) plus one shelf exploration well (BEL-1) to further evaluate the shelf area prospectivity. The three wells will be drilled, logged, cored and tested in a program expected to be completed by mid-2016. BEL-1 will be the first exploration well to be drilled in the blocks following the discoveries in the FAN-1 and SNE- 1 wells.

29 Oct 2015

53/02-01 Humpback exploration well results

Falkland Oil and Gas Limited (AIM:FOGL), the exploration company focused on its extensive licence areas to the North, South and East of the Falkland Islands, announces the results from the 53/02-01 Humpback exploration well and also, notes the announcement from the Operator, Noble Energy made at 20:30 on 28 October 2015. The Humpback well was drilled to a total depth of 5,136 meters (measured depth). The well encountered non-commercial quantities of oil and gas within a number of sandstone intervals, including the main APX-200 target. All of the pre-drill targets were penetrated close to prognosis in the well. An additional 25 meters of sandstone was encountered below the APX-200 bringing the total in the well to 65 meters. The deeper sandstones, exhibit only moderate porosity (10% to 15%) and low hydrocarbon saturations. For a number of operational reasons, it was not possible to obtain fluid samples from any of the hydrocarbon bearing zones in the well. FOGL will now evaluate these results in more detail and assess the impact on the prospectivity of the Diomedea fan complex and the rest of the southern licences. The results do however demonstrate a working hydrocarbon system and Humpback was only one of a number of geological plays within the Fitzroy sub-basin. Importantly the results will allow calibration of the 3D seismic data and this may facilitate the mapping of higher quality sands elsewhere within the large area covered by 3D seismic. Once operations have been completed on Humpback, the Eirik Raude rig will return to the North Falklands Basin to drill a second well on the Elaine/Isobel fan complex. The Elaine/Isobel fan complex, based on the operator’s estimates, has multiple reservoir targets and gross mean un-risked resources of 400 million barrels of oil. A further announcement will be made on the commencement of this well.

2 Nov 2015

Drilling commences offshore Senegal

Drilling has started on the appraisal program to evaluate the world class SNE oil discovery offshore Senegal. The three wells SNE-2, SNE-3 and BEL-1 will be drilled back to back in a program that is estimated to be completed in mid-2016. Both SNE-2 and SNE-3 appraisal wells will be logged, cored and flow tested. The aim of the appraisal program is to progress towards proving a minimum economic field size for the SNE discovery, which FAR estimates to be approximately 200 million barrels of oil. In addition the BEL-1 well will also evaluate the Bellatrix prospect which lies on the untested Buried Hills exploration play (refer Figures 1, 2). For reasons of operational efficiency, the top hole of SNE-3 will be drilled first by the Ocean Rig Athena. The rig will be then be mobilised to the SNE-2 well location where SNE-2 will then be drilled to total depth (TD). Operations on the top hole of the SNE-3 well and drilling to total depth (TD) on the SNE-2 well are expected to last approximately 6 weeks after which the coring, logging and flow testing program will commence on SNE-2. On completion of the operations on SNE-2, SNE-3 will be re-entered and drilling and evaluation will be carried out before commencement of the BEL-1 well.

5 Nov 2015

SNE-2: First appraisal well starts drilling offshore Senegal

The first appraisal well to be drilled on the SNE oil field located 100km offshore Senegal has been spudded. The SNE-2 well will be drilled in approximately 1,100 metres of water and drilled to a TDVSS (total vertical depth subsea) of approximately 2,770 metres before an evaluation program including logging, coring and flow testing is undertaken. Three evaluation wells, SNE-2, SNE-3 and BEL-1, will be drilled back to back in a program that is estimated to be completed in mid-2016. Both SNE-2 and SNE-3 appraisal wells will be logged, cored and flow tested. The aim of the appraisal program is to progress towards proving a minimum economic field size for the SNE discovery, which FAR estimates to be approximately 200 million barrels of oil. In addition, the BEL-1 well will drill the Bellatrix exploration prospect which will evaluate the untested Buried Hills play. BEL1 will also appraise the northern portion of the SNE oil field (refer Figures 1, 2). For reasons of operational efficiency, the top hole of SNE-3 was drilled prior to the spud of SNE-2 (to a depth of 1,750 metres) by the Ocean Rig Athena (refer ASX announcement 2 Nov 2015). Drilling of the SNE-2 well is expected to take approximately 5 weeks after which the logging and flow testing program will commence. On completion of the operations on SNE-2, SNE-3 will be re-entered and drilling and evaluation will be carried out on SNE-3 before commencement of the BEL-1 well. FAR and its joint venture partners will be operating a tight hole policy, and therefore FAR does not anticipate making any further announcements regarding the drilling program until the SNE-2 well has reached TDVSS.

23 Nov 2015

Isobel Deep Re-drill Well Spud

Falkland Oil and Gas Limited (AIM:FOGL), the oil and gas exploration company focused on its extensive license areas to the North, South and East of the Falklands islands, is pleased to announce that the 14/20-2 ‘Isobel 2’ well (the "Well") was spudded, by Premier Oil as operator, on 21 November 2015. The well is located on licence PL004a , in which FOGL has a 40% working interest, and lies approximately 4 km away from the 14/20-1 Isobel Deep oil discovery. The well will target the Isobel Deep reservoir and is a re-drill of the 14/20-1 well drilled earlier this year, which failed to reach Total Depth owing to operational issues. The well will test the F3 fan systems, which are mapped as entering the basin from the south east margin and comprise a sequence of stacked reservoirs. In addition to Isobel Deep, the well will also penetrate four other fans within the complex, comprising: Elaine South, Isobel, Doreen and Irene. The Elaine/Isobel fan complex, based on the operator’s estimates, has multiple reservoir targets and gross, mean un-risked resources of 400 million barrels of oil. A further release will be issued once the well has been completed and this is expected to be in January 2016. FOGL is fully carried through the costs of this well by Premier Oil and Rockhopper Exploration.

4 Jan 2016

Successful Senegal Appraisal Well

Cairn is pleased to announce the successful testing of the SNE-2 appraisal well offshore Senegal with positive results. Operations have been safely and successfully completed following drilling, coring, logging and drill-stem testing (DST). The well is now being plugged and abandoned. Following this first successful appraisal well, resource estimates for the SNE field will be fully revised and announced after the results of the further appraisal activity. Evaluation of the extensive dataset collected is continuing, with preliminary analysis focused on the DST. The SNE- 2 well is located in 1,200m water depth and is approximately 100 kilometres (km) offshore in the Sangomar Offshore block, reached the planned total depth (TD) of 2,800m below sea level (TVDSS). The well has been appraising the 2014 discovery of high quality oil in the SNE-1 well, some 3 km to the south.

21 Jan 2016

Ocean Rig announces notice of termination for the Ocean Rig Olympia

Ocean Rig, a global provider of offshore deepwater drilling services, announced today that “due to the dramatic fall of the crude oil price and the volatile market context, ENI has reassessed its drilling activities and taken the decision to exercise its right of terminating” the contract of the Ocean Rig Olympia.

12 Feb 2016

Termination of drilling contract

Premier and Noble Energy entered into a contract with Ocean Rig UDW (“Ocean Rig”) on 3 June 2014, for the provision of the Eirik Raude drilling unit for an exploration drilling campaign in the Falkland Islands. Following a number of material operational issues with the Eirik Raude rig during the term of the contract to date, Premier and Noble Energy issued a termination notice to Ocean Rig on 11 February 2016, terminating the contract with immediate effect. As a result, Premier will no longer be drilling the Chatham exploration well during the current campaign. However, we are in discussions with the Falkland Islands Government regarding the possibility of drilling this prospect in the future.

15 Feb 2016

Termination of drilling contract

TOTAL E&P Congo on February 11, 2016 has given notification to terminate for convenience the long-term contract of the 7th generation ultra-deepwater drillship Ocean Rig Apollo. As per the contract Ocean Rig is entitled to a termination fee that varies from 50% to 95% of the operating daily rate that will be payable over the balance of the contract. The Ocean Rig Apollo will demobilize from Congo in due course and is available for alternative employment. In connection with the termination of the drilling contract of the Ocean Rig Apollo, the Company has notified the agent under the respective loan agreement and is currently in discussions with its lenders about the consequences of such termination.

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.

15 Mar 2016

BEL-1 well starts drilling offshore Senegal

Following the successful drilling of the first two appraisal wells offshore Senegal, the third well to be drilled as part of the SNE oil field appraisal program offshore Senegal has been spudded. The BEL-1 well will be drilled in approximately 1,100 metres of water and drilled to a TDVSS (total vertical depth subsea) of approximately 2,757 metres before an evaluation program including logging and coring is undertaken (refer figures 1 and 2). The aim of the appraisal program is to progress towards proving a minimum economic field size for the SNE discovery, which FAR estimates to be approximately 200 million barrels of oil. In addition, the BEL-1 well will drill the Bellatrix exploration prospect which will evaluate the untested Buried Hills play. BEL-1 will also be deepened to appraise the northern portion of the SNE oil field (refer figure 3). Drilling of the BEL-1 well will be followed by a wireline logging and coring program before the well is plugged and abandoned according to plans. BEL-1 operations are expected to be completed next month. FAR and its joint venture partners will be operating a tight hole policy, and therefore FAR does not anticipate making any further announcements regarding the drilling program until the BEL- 1 well has reached TDVSS.

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.

18 Apr 2016

Spud of SNE-4 appraisal well

The SNE 4 well, which is 5 km south-east of the SNE-1 discovery well, was spudded over the weekend to appraise the eastern extent of the field. The SNE-4 well is located in 940m water depth and will be drilled to a total depth of 3,020m TVD. It will be drilled and logged and is expected to take approximately four weeks to complete. This further appraisal well in the SNE field will assist in progressing towards confirming the commercial viability of the field.

25 Apr 2016

Ocean Rig Announces Acquisition of Ultra Deepwater Drillship

Ocean Rig UDW Inc. (NASDAQ:ORIG) (“Ocean Rig” or the “Company”), a global provider of offshore deepwater drilling services, announced today that one of its subsidiaries has acquired the 6th generation ultra deepwater drillship Cerrado, being sold through an auction, for a purchase price of $65 million, which will be funded with available cash on hand. The drillship was built at Samsung Heavy Industries in 2011 to similar design specifications as the Company’s existing 6 th generation drillships built at Samsung, and will be renamed the Ocean Rig Paros upon its delivery to Ocean Rig. Another subsidiary of the Company has been acting as the manager of the drillship for its previous owners. The transaction is expected to close upon completion of the judicial auction procedure.

19 May 2016

Senegal Drilling Update: Successful SNE-4 appraisal well

The SNE-4 appraisal well offshore Senegal has been safely drilled, cored and logged ahead of schedule and under budget. Well results have successfully demonstrated the extension of the SNE oil field upper reservoir units in the eastern portion of the SNE field. The Operator, Cairn Energy PLC, has provided notice to release the Ocean Rig Athena drill ship after completion of SNE-4 operations. Evaluation of the extensive data set acquired from the highly successful SNE-2, SNE-3, BEL-1 and SNE-4 appraisal wells is continuing. The JV is evaluating development options and will determine the most effective way to further appraise this world class oil accumulation. Drilling is expected to resume in H2 2016.

7 Jun 2016

North Atlantic Drilling Ltd. announces amendment to agreement with Jurong

North Atlantic Drilling Ltd. ("NADL" or "the Company") refers to the press release on December 3, 2015 which announced a standstill agreement to defer delivery of the semi-submersible West Rigel ("the Unit"). Today the Company announces an amendment has been agreed with Jurong Shipyard Pte Ltd ("Jurong"), which extends the delivery deferral period by a further three months to September 2, 2016. The extension allows the parties to continue to explore commercial opportunities for the Unit. As previously agreed, in the event no employment is secured for the Unit and no alternative transaction is completed, the Company and Jurong will form a Joint Asset Holding Company for joint ownership of the Unit, to be owned 23% by the Company and 77% by Jurong.

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.

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.

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.

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.

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 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.

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.

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.

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.

9 Jan 2017

North Atlantic Drilling Ltd. announces amendment to agreement with Jurong Shipyard

North Atlantic Drilling Ltd. ("NADL" or "the Company") refers to the press release on December 3, 2015, June 7, 2016, August 25, 2016, and October 4, 2016 which announced a standstill agreement and subsequent amendments to defer delivery of the semi-submersible West Rigel ("the Unit"). Today the Company announces an amendment has been agreed with Jurong Shipyard Pte Ltd ("Jurong"), which extends the delivery deferral period to July 6, 2017. The extension allows the parties to continue to explore commercial opportunities for the Unit. As previously agreed, in the event no employment is secured for the Unit and no alternative transaction is completed, the Company and Jurong will form a Joint Asset Holding Company for joint ownership of the Unit, to be owned 23% by the Company and 77% by Jurong.

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.

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.

10 Feb 2017

Ocean Rig Athena On Route to Greece

Ocean rig has reached an agreement with ConocoPhillips to terminate the contract on the Ocean Rig Athena. ConocoPhillips will pay a termination fee as part of the termination agreement. The Ocean Rig Athena has now left Las Palmas and is on route to Greece where the rig will be cold stacked.

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.

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.

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.

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.

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.

7 Jul 2017

Delivery Delay for the West Rigel

North Atlantic Drilling (NADL) has amended an agreement with Jurong Shipyard which will see delivery date for the West Rigel semisub pushed back to 6 January 2018. Both parties will continue to explore commercial opportunities for the rig during the deferral period. In the event that no contract is secured and no alternative transaction is executed, NADL and Jurong will form a joint ownership company for the rig, owned 23% by NADL and 77% by Jurong.

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