Infield Rigs News

20 Dec 2011

Pacific Drilling Receives Delivery of its Ultra-Deepwater Drillship the Pacific Santa Ana

Pacific Drilling S.A. (NYSE:PACD) (NOTC:PDSA) announced today that it has received delivery of its newest drillship, the Pacific Santa Ana. The drillship features the most advanced drilling technology in the offshore drilling industry, including dual load path capability and dual gradient drilling upgrades. The Pacific Santa Ana is capable of operating in water depths of up to 12,000 feet and drilling .... [+ read more] wells 40,000 feet deep. Pacific Drilling CEO, Chris Beckett, stated, “We are very proud to announce the delivery of the Pacific Santa Ana. This drillship incorporates the newest advances in offshore drilling technology and is the first ultra-deepwater rig equipped for dual gradient drilling, an innovation that is expected to provide significant benefits in drilling safety and efficiency. The delivery of the Pacific Santa Ana, the fourth rig in our fleet, completes the first phase of Pacific Drilling’s growth strategy to become the industry’s preferred ultra-deepwater drilling contractor.”

10 Dec 2011

Keppel to deliver sixth ultra-deepwater semi to Ensco over the past 42 months

Keppel FELS Limited (Keppel FELS) is on course to deliver ENSCO 8505, the sixth of seven ENSCO 8500 Series® ultra-deepwater semisubmersible (semi) drilling rigs to Ensco (NYSE: ESV) safely, on time and within budget. The rig is expected to be completed in the first quarter of 2012 with zero lost-time incidents in over five million man-hours worked. Upon completion, ENSCO .... [+ read more] 8505 is contracted in the U.S. Gulf of Mexico with Anadarko, Apache and Noble Energy.

9 Dec 2011

Noble Discoverer recalled to Alaska

The drillship Noble Discoverer will be recalled to Alaska early in the new year to fulfill contract obligations and is now unlikely to be able to complete drilling the Ruru exploration well for Shell Todd Oil Services (STOS). Should the Ruru well not be completed, it will be safely plugged and abandoned in line with strict Shell standards and New Zealand .... [+ read more] regulations. The ship owner Noble Drilling Corporation is finalizing plans to safely recover the Riser and the LMRP which became detached during bad weather earlier in the year. The early recall is as a result of the long lead-times associated with working in the Arctic and Shell’s commitment to adding and testing additional control systems onboard the Discoverer. The Discoverer has always been prioritized for Alaska and the additional time in a U.S. shipyard will allow time to make any Arctic-specific modifications to the drilling vessel in advance of 2012 drilling. Last year, STOS took advantage of the opportunity to book the vessel for the Ruru venture when activities in Alaska were put on hold. In February of 2011 the Discoverer began drilling the Ruru well which is 40 kilometres off the South Taranaki coast. The work was suspended in April when, as a precautionary measure and in accordance with best practice, the crew secured the well and safely disconnected the Lower Marine Riser Package (LMRP) to prepare for a severe storm. In the process some of the anchor lines failed. The vessel moved into deeper waters to ride out the storm and later docked at Port Taranaki to shelter for the winter period. Repair work was carried out locally, contributing millions of dollars to the Taranaki community. A Maritime NZ investigation concluded the Discoverer was operated appropriately in response to the incident and there were no ongoing safety issues with the vessel. In September the vessel headed to dry dock in Brisbane for its five-yearly class certification and arrived back at Port Taranaki at the end of last month.

8 Dec 2011

Pacific Drilling Statement Regarding the Status of Pacific Scirocco

The Pacific Scirocco is currently undergoing client requested upgrades as well as modifications to ensure engine reliability. The rig has mobilized to a quayside in South Africa in order to complete the project prior to commencing operations in Nigeria. These preemptive repairs will delay contract commencement, potentially until the end of the fourth quarter of 2011. However, .... [+ read more] we expect that the delay will be covered under loss of hire insurance. The Pacific Santa Ana will undergo similar engine modifications prior to delivery during the fourth quarter of 2011.

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 .... [+ read more] 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.

7 Dec 2011

Corcovado arrives at quayside

In wintery weather on Monday 5th December one of Ocean Rig’s four new drillships, the Corcovado arrived in Vats from a project in Greenland. Unfortunately a rig at Westcon changed their plans so there was insufficient quay capacity at the Westcon Yard, therefore the Corcovado will be in Vats for its upgrade project. Westcon will assist with preparation of .... [+ read more] the vessel for a contract in South America for the Brazilian company Petrobras.

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 .... [+ read more] 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.

18 Nov 2011

Successful appraisal of the Teak discovery offshore Ghana

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

9 Nov 2011

Montserrado-1 makes a non-commercial oil discovery

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

3 Nov 2011

Rig secured for development drilling in Greater Stella area

Ithaca Energy Inc. announces that it has signed an agreement with Ensco Offshore UK Limited to provide a jack up drilling unit for development drilling on the Stella and Harrier fields to commence in 2012. Further to the recently announced Development Concept selection for the Stella and Harrier Fields in Block 30/6a of the Central North Sea, the Company .... [+ read more] has signed a Letter of Award for the Ensco 100 drilling unit for the development drilling campaign on the Stella and Harrier fields. The campaign, which will include the drilling of 5 firm wells and up to 3 options for additional wells, will commence on Stella in H2 2012.

1 Nov 2011

EXPLORATION WELL MINDOU MARINE-1 ON CONGO (BRAZZAVILLE) MARINE XI LICENCE WAS DRY

The exploration well Mindou Marine-1, located offshore in Block Marine XI Congo (Brazzaville), has reached total depth at 3,515 metres. The well did not encounter oil shows in the target pre-salt section. The well will now be logged, and a full geological interpretation of the results will be undertaken. This well fulfilled the Phase II drilling commitment on the .... [+ read more] licence and is the first of a two to three well programme on Blocks Marine XI and XIV. Lundin Petroleum has an 18.75 percent working interest in the licence which is operated by SOCO International.

26 Oct 2011

14/10-9 Well Spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-9 well (the "Well") was spudded at 10.45 hrs BST on 25 October 2011. The Well, situated on Licence PL032, which is 100% owned and operated by Rockhopper, is the eighth well to be drilled on the Sea Lion feature. It is .... [+ read more] located approximately 5.9 km to the south west of the 14/10-2 discovery well and is designed to investigate reservoir presence and hydrocarbon charge within the Sea Lion Main Complex towards the southern edge of the Company's acreage and is also an exploration well on the Eastern side of the Casper prospect. Drilling operations are expected to take approximately 33 days and a further announcement will be made once drilling is completed.

24 Oct 2011

BP makes gas discovery in Egypt's Nile Delta

BP Egypt today announced the Salmon gas discovery in the North El Burg Offshore Concession, Nile Delta. Salmon is the third gas discovery BP has made in the concession following Satis-1 and Satis-3 Oligocene deep gas discoveries. Salmon, drilled by IEOC, the affiliate of ENI in Egypt, on behalf of concession operator BP, is located 50 kilometers to the north .... [+ read more] of Damietta. The wireline logs and pressure readings confirmed the presence of gas in two shallow Pleistocene intervals. The well was drilled by Scarabeo IV rig in water depths of 87m and reached a total depth of 1600m. Further appraisal work to evaluate the resources is underway. Hesham Mekawi, President and General Manager of BP Egypt stated "The success of Salmon highlights the great potential of the shallow reservoirs within the Nile Delta, and helps unlock additional resources in surrounding acreage. It demonstrates the ongoing cooperation with the Ministry of Petroleum to deliver new gas discoveries and incremental supply to meet the future growth of the gas business in Egypt." The parties to the North El Burg Offshore Concession agreement are: BP (operator 50%) and IEOC (50%).

21 Oct 2011

Doubling of Aldous volumes

Statoil ASA (OSE: STL, NYSE: STO), together with partners Petoro AS, Det norske oljeselskap ASA and Lundin Norway AS, has confirmed significant additional volumes in its appraisal well in the Aldous Major South discovery (PL265) in the North Sea. The results of appraisal well 16/2-10 have increased production license PL265 estimates to between 900 million and 1.5 billion barrels of recoverable .... [+ read more] oil equivalent. This is a doubling of the previously announced PL265 volumes of between 400 and 800 million barrels of oil equivalent. It has previously been confirmed that there is communication between Aldous in PL265 and Avaldsnes in PL501, and that this is one large oil discovery. “Aldous/Avaldsnes is a giant, and one of the largest finds ever on the Norwegian continental shelf. Volume estimates have now increased further because the appraisal well confirms a continuous, very good and thick reservoir in Aldous Major South,” says Tim Dodson, executive vice president for Exploration in Statoil. Final data show that the oil column in appraisal well 16/2-10 is approximately 60 metres. These data also confirm that the reservoir is of the same, excellent quality as in the Aldous Major South discovery well 16/2-8. This is the main reason for the substantial upward revision of PL265 volumes. The Aldous/Avaldsnes discovery extends over a large area of ??approximately 180 square kilometres, and there is considerable variation in both reservoir thickness and oil column height in the structure. Additional appraisal wells will be drilled in both licenses. Statoil will await the results from these wells before providing updated and more accurate volume estimates for the combined discovery. After completion of the appraisal well, the Transocean Leader drilling rig will move to the Troll field in the North Sea. Aldous Major South is situated in production license PL265 in the North Sea, and appraisal well 16/2-10 was drilled 4.2 kilometres north of the 16/2-8 discovery well. Statoil is the operator and has a 40% interest in PL265. The partners are Petoro AS (30%), Det norske oljeselskap ASA (20%) and Lundin Norway AS (10%). Well 16/2-10 is the seventh exploration well in PL265. The license was awarded in the North Sea Awards 2000. Avaldsnes is located in production licence PL501. Lundin Norway AS is the operator with a 40% interest, while partners Statoil and Maersk have 40% and 20% interests, respectively.

18 Oct 2011

Discovery in Aldous appraisal well

Statoil ASA is, together with partners Petoro AS, Det norske oljeselskap ASA and Lundin Norway AS, about to complete drilling of appraisal well 16/2-10 in the Aldous Major South structure (PL 265) in the North Sea. Drilled by Transocan Leader drilling rig, appraisal well 16/2-10 has proven an oil column in a range between 50 and 55 metres in Jurassic .... [+ read more] sandstone. Statoil has earlier communicated preliminary volumes for the Aldous structure in PL 265 to be between 400 and 800 million barrels of recoverable oil equivalent. Statoil will present updated volume estimates when the well data have been fully analysed. Appraisal well 16/2-10 is located 4.2 kilometres north of discovery well 16-2/8 in the Aldous Major South structure on the Utsira Height in the North Sea. Well 16/2-10 is the seventh exploration well in the licence. Aldous Major South is located in PL 265 where Statoil is operator (40 percent) and the partners are Petoro (30), Det norske oljeselskap (20) and Lundin (10).

13 Oct 2011

Giant rig West Elara arrives in Ølensvåg

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

13 Oct 2011

Signal International Announces Contract to Upgrade Semisubmersible

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

7 Oct 2011

Keppel to build third Super A Class jackup for Ensco at US$245 million

Keppel FELS Limited (Keppel FELS) has secured a contract to build an enhanced KFELS Super A Class harsh environment jackup rig from Ensco plc (NYSE: ESV) for US$245 million. The rig is scheduled for delivery in 3Q 2014. This contract arose from the exercise of an option which was part of Ensco's order of two KFELS Super A Class rigs .... [+ read more] on 10 February 2011.

1 Oct 2011

Keppel FELS to deliver Vietnam’s first drilling tender rig

Keppel FELS Limited (Keppel FELS) is on track to deliver Vietnam's first semisubmersible drilling tender (SSDT) to PetroVietnam Drilling & Well Services Corp (PV Drilling) ahead of schedule, within budget and with a perfect safety record. Built to Keppel's award-winning KFELS SSDT 3600E design, the rig is well-suited for harsh environments and will be deployed on a multi-year charter to .... [+ read more] PetroVietnam's Bien Dong Petroleum Operating Company.

28 Sep 2011

All go for Gudrun drilling

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

28 Sep 2011

Enyenra-3A well result announcement

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

26 Sep 2011

14/10-8 Well Spud

ockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-8 exploration well (the "Well") was spudded at 03:45hrs BST on 25 September 2011. The Well is situated on Licence PL032, which is 100% owned and operated by Rockhopper, and is located approximately 4.1km to the south-south-east of the 14/10-2 discovery well, .... [+ read more] outside of the Sea Lion Discovery Area. This well is designed to investigate reservoir and hydrocarbon presence within the Sea Lion Main Complex in an area of relatively low amplitudes and is also an exploration well on both the Casper and Kermit oil prospects. Drilling operations are expected to take approximately 28 days and a further announcement will be made once drilling is completed.

23 Sep 2011

Lundin Petroleum commences drilling on the Janglau prospect

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that it has commenced the drilling of the Janglau prospect located in Block PM308A, offshore the east coast of Peninsular Malaysia. The Janglau-1 exploration well will test the hydrocarbon potential of Eocene to Oligocene alluvial sands overlying a Pre-Tertiary high that also forms a second objective of the well.The Janglau prospect .... [+ read more] is located to the north-east of the PM308A block, 7 km to the east of the Rhu oil discovery made in 1991. The planned total depth is 3,950 meters subsea and the well will be drilled using the jack-up drilling rig Offshore Courageous. The well is expected to take approximately 45 days. Lundin Petroleum operates and holds 35 percent interest in PM308A through its wholly owned subsidiary Lundin Malaysia BV. Partners in PM308A are JX Nippon Oil & Gas Exploration (Peninsular Malaysia) Limited with 40 percent interest and PETRONAS Carigali Sdn. Bhd. with 25 percent. Lundin Malaysia BV operates 6 Blocks in Malaysia, namely PM308A, PM308B, PM307, SB303, SB307 and SB308.

22 Sep 2011

DRC 2011 offshore drilling campaign launched with Libwa 12

The shallow-draft Hercules H260 RIG arrived in DR Congo the 1st of September for a drilling campaign that is expected to last approximately six months. This is a major milestone for the DRC subsidiary, with the first offshore drilling operation since the Perenco takeover of the offshore operatorship in July 2004. The planned campaign will consist of three new .... [+ read more] wells, one re-entry and one heavy work-over. The first well, the challenging LIB-12 dual lateral well is being drilled to unlock the southern part of the Libwa field. The campaign will then continue with MIB-19, targeting attic oil in the mature Mibale field followed by an appraisal well in Misato (MIS-4), one re-entry (LUBI-1X) and a heavy workover in Libwa (LIB-11). It demonstrates Perenco's commitment to exploit offshore undeveloped oil reserves in difficult reservoirs. The wells' selection and the launch of this campaign are a direct consequence of the good teamwork between the subsidiary and the Headquarter support departments: Geosciences (London) and Drilling & Completion (Paris). The drilling campaign has been launched while the SW1 is still in work-over operation and with the addition of one onshore rig, three pulling units and a hydraulic frac set-up in simultaneous operation, resulting in the highest activity rate for the subsidiary since Perenco's arrival in DRC in 2001.

22 Sep 2011

Small discovery on Aldous Major North

Statoil, together with partners Petoro AS, Det norske oljeselskap ASA and Lundin Norway AS, has drilled the Aldous Major North prospect (PL 265) in the North Sea. Samples taken from well 16/2-9S, drilled by the rig Transocean Leader, have proved a column of oil of up to 8 metres in formations dating from the Upper Jurassic period. Due to .... [+ read more] the limited reservoir quality, the partnership will consider further exploration drilling on Aldous Major North in order to clarify the structure’s potential. Well 16/2-9S was drilled some 12 kilometres north of the Aldous Major South oil discovery (16/2-8). Aldous Major North and Aldous Major South are two independent structures in the PL 265 licence and there was higher uncertainty related to well 16/2-9S in the northern part of the licence. “Statoil has previously communicated that the combined Aldous Major South and Avaldsnes discoveries may constitute an oil structure of between 500 and 1200 million barrels of recoverable oil equivalents, and we stand firm on this estimate,” says Gro G. Haatvedt, Statoil’s senior vice president for exploration on the Norwegian continental shelf. Following completion of well 16/2-9S on the Aldous Major North prospect, Transocean Leader will return to Aldous Major South to drill appraisal well 16/2-10. “An appraisal well on Aldous Major South demonstrates that we have great faith in the area’s potential and that the partnership would like to see speedy clarification of the total resource potential in order to secure the rapid development of this discovery,” says Haatvedt. Aldous Major North and Aldous Major South are located in production licence 265, where Statoil is operator (40%) along with partners Petoro (30%), Det norske oljeselskap (20%) and Lundin (10%).

10 Sep 2011

Keppel AmFELS delivers fourth consecutive Rowan rig ahead of schedule

Keppel AmFELS LLC, a wholly owned US subsidiary of Keppel Offshore & Marine Ltd (Keppel O&M), has completed the delivery of its fourth EXL jack-up rig to a subsidiary of Rowan Companies, Inc. (Rowan) (NYSE: RDC) with a perfect safety record, four months ahead of schedule and within budget. The jack-up rig was christened Rowan EXL-IV yesterday by Ms. Mary .... [+ read more] J. Dunaway and Ms. Audra M. Williamson, daughters of Mr. Johnnie Huckabay, one of Rowan's senior rig managers. The rig was delivered on September 1, 2011 and is scheduled to depart Keppel AmFELS' yard in Brownsville, Texas in October 2011.

9 Sep 2011

Securing more rig capacity

Statoil has signed a contract with North Atlantic Norway to hire the West Hercules rig which can be used for exploration and production drilling internationally and on the Norwegian continental shelf (NCS). Statoil has signed an agreement with North Atlantic Norway Ltd (Norwegian Branch), a company in the Seadrill group, for hire of the West Hercules rig for use on exploration .... [+ read more] prospects and production licences. The semi-submersible rig will be deployed to start drilling from Q3 2012. “With its many capabilities, West Hercules will contribute to maintaining a sustainable activity level of exploration, and also to execute on our company’s ambitious exploration strategy in the years to come,” says Tim Dodson, Statoil’s executive vice president for Exploration. “Inclusion of this rig in our portfolio provides the necessary flexibility we are looking for and it supports our earlier communicated strategy of revitalising the NCS with high value barrels and deliver on our exploration programme globally. Acquiring this rig is an important contribution to securing Statoil’s rig capacity.” The daily rate for the rig is USD 490.000. A mobilisation fee of USD 50 million is also payable. The contract is for a fixed four-year period. Statoil has secured a one-year option on the same conditions. ”Statoil’s focus continues to be on bringing more modern and flexible rigs to our portfolio,” says Jon Arnt Jacobsen, Statoil’s chief procurement officer. “West Hercules is the first-available suitable rig which is already in operation. This, together with its advanced capabilities such as deep waters, high pressure/high temperature and completion, has prompted Statoil to act on this opportunity. This modern rig will be complementary to our portfolio and bring us more flexibility. It will be utilised on targeted wells internationally and on the NCS.” West Hercules is a sixth generation, high specification, deep water, semi-submersible drilling unit, built in 2008. It has a high load carrying capacity and an efficient drilling floor layout with improved safety and working environment measures. West Hercules can run parallel drilling operations and is designed with a dynamic positioning system and a water depth capacity up to 3,000 metres. West Hercules is expected to complete a three-year contract for Husky Oil China Ltd for operations off China in May 2012.

8 Sep 2011

Apalis-1 well deemed non-commercial by African Petroleum

African Petroleum Corporation Limited (African Petroleum) has completed drilling the first well (Apalis-1) in deepwater offshore Liberia Block LB-09. The results of Apalis-1 confirm Blocks LB-08 and LB-09 (100% owned by African Petroleum) are located in a prospective oil basin, which is a major step forward. The geological and geophysical data have confirmed the critical components of a working hydrocarbon system .... [+ read more] are present and functioning. African Petroleum is now accelerating a multi well drilling program on the 25+ exploration prospects identified in both blocks offshore Liberia and plans to spud the next well during Q4 2011 and Q1 2012. Apalis-1 was drilled to a depth of 3,665 meters and encountered oil shows in several geological units including the shallower (Tertiary) and deeper (Cretaceous) and petrophysical analysis indicates the presence of hydrocarbons. No commercial quality reservoir with hydrocarbons was encountered and consequently no well production test was undertaken.

7 Sep 2011

LUNDIN PETROLEUM SPUDS EXPLORATION WELL MINDOU MARINE-1 ONCONGO BRAZZAVILLE MARINE XI LICENCE

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of the exploration well Mindou Marine-1, located offshore in Block Marine XI Congo-Brazzaville, has commenced. The planned depth is approximately 3400 metres below meansea level and the well will be drilled by using the semi-submersible drillingrig ENSCO 5003. The drilling operation is expected to take 50 days. The .... [+ read more] well is targeting a pre-salt Toca formation carbonatereservoir within a combination structural and stratigraphic trap. This wellwill fulfill the Phase II drilling commitment on the licence and is the firstof a two to three well programme on blocks Marine XI and XIV. Lundin Petroleum has an 18.75 percent working interest inthe licence which is operated by SOCO International.

1 Sep 2011

CAT BA-1X sub-commercial oil and gas discovery

Salamander Energy announces the completion of the Cat Ba–1X (“101-CB-1X”) exploration well in Block 101-100/04, offshore northern Vietnam. Block 101-100/04 was the subject of a farm out as announced on 31st May 2011. The 101-CB-1X well was drilled to a total depth of 1,724 metres. The well encountered 38 metres of net hydrocarbon pay in Tertiary clastics, the secondary objective .... [+ read more] of the well. The pay section comprises a series of gas-bearing sandstones underlain by an oil-bearing reservoir. A full suite of wire-line logs and pressure data were recorded over the reservoir sections and samples of oil and gas were recovered. These data show that the Tertiary reservoirs are of good quality, however pressure data and seismic mapping indicates the in-place resource volumes encountered by the well are probably below levels needed for commercial development. No oil shows were observed and only low levels of gas were recorded while drilling the primary objective, the Palaeozoic ‘buried hills’ play. Subsequent wire-line logging did not reveal any zones of interest. The Cat Ba-1X well has subsequently been plugged and abandoned as a sub-commercial discovery.

22 Aug 2011

14/10-7 Exploration Well Spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-7 exploration well (the "Well") was spudded at 0600hrs BST on 22 August 2011. The Well is situated on Licence PL032, which is 100% owned and operated by Rockhopper. The Well is located approximately 3.3km to the north west of the 14/10-2 .... [+ read more] discovery well, just outside of the Sea Lion Discovery Area. The Well is designed to investigate reservoir and hydrocarbon presence towards the northern limit of the currently mapped extent of the Sea Lion Main Complex within an area of relatively low amplitudes. Accordingly, the Sea Lion Main Complex will be the only target, with reservoir expected to be thinner than encountered in the 14/10-2 discovery well. Drilling operations are expected to take approximately 32 days and a further announcement will be made once drilling is completed.

17 Aug 2011

Pacific Drilling Announces Three-Year Contract for the Pacific Mistral

Pacific Drilling S.A. (NOTC: PDSA) announced today that its ultra-deepwater drillship the Pacific Mistral has been awarded a three-year contract by Petróleo Brasileiro S.A. (“Petrobras”) for operations in Brazil. The contract is expected to commence in the fourth quarter of 2011, and estimated maximum contract revenues, including mobilization and client requested modifications, are expected to be approximately $536 million. Pacific .... [+ read more] Drilling Chief Executive Officer Chris Beckett stated: “We are pleased to announce the beginning of a core, strategic relationship with Petrobras. This contract for the Pacific Mistral underscores our commitment to work with the best operators in the industry and also expands our operating presence in the Atlantic Basin, a region of focus for our activities.” The Pacific Mistral was delivered by Samsung Heavy Industries in June 2011. The rig is equipped for and capable of operating in water depths of up to 12,000 feet and drilling wells 37,500 feet deep.

11 Aug 2011

African Petroleum spuds Apalis-1 prospect in Liberia

African Petroleum Corporation Limited (African Petroleum) commenced drilling its first exploration well in Liberia on 8th August 2011 with the ‘Maersk Deliverer’semi-submersible deepwater drilling rig. The Company has a 100% interest in Blocks LB-08 and LB-09 and is fully funded for a further 5 additional exploration wells. African Petroleum will be drilling the Apalis Prospect on Block LB-09 in Liberia with .... [+ read more] estimated prospective recoverable oil resources of 500 (mean case) to 1,000 (upside) million barrels. Detailed technical analysis of the 3D seismic data acquired in 2010 has shown that the Apalis Prospect may contain multiple sand reservoirs in the Upper Cretaceous Maastrichtian and Turonian as well as in the Aptian and Albian. Some of the potential reservoirs in the Apalis Prospect have a well-developed 3D seismic class 3/4 AVO response, similar to those reported for nearby discoveries in Sierra Leone and Ghana. Due to the tightening rig market and limited availability of deepwater 5th generation drilling rigs in the West African region, African Petroleum has entered into agreements with Lukoil Overseas Cote d’Ivoire E&P Ltd (Lukoil), Vanco Cote d’Ivoire Ltd (Vanco) and AP Moller-Maersk (Maersk) that the ‘Maersk Deliverer’ will be released to Vanco and Lukoil for two wells after the drilling of the Apalis Prospect and will then be returned to African Petroleum for one additional well. The agreement to swap drilling slots with Lukoil and Vanco enhances the flexibility of the Company’s 2-3 well drilling program planned for 2012 as it allows the Maersk Deliverer to be reserved for the deepest water exploration drilling targets. Additionally, the planned interval between the “Apalis” well and the second well allows for the integration of both the geological and operational information to be better utilized in planning the 2012 wells. African Petroleum is currently planning to contract a second deepwater rig in 2012 to accelerate drilling plans in the West African Transform Margin.

10 Aug 2011

Pacific Drilling Announces Pacific Bora Operations Commencement

Pacific Drilling S.A. (NOTC: PDSA) announced today that its ultra-deepwater drillship the Pacific Bora commenced operations at the Agbami Field in Nigeria on August 10, 2011. The rig is contracted for three years to a wholly owned Chevron subsidiary. .... [+ read more]

10 Aug 2011

Pacific Drilling Announces Pacific Bora Operations Commencement

Pacific Drilling S.A. (NOTC: PDSA) announced today that its ultra-deepwater drillship the Pacific Bora commenced operations at the Agbami Field in Nigeria on August 10, 2011. The rig is contracted for three years to a wholly owned Chevron subsidiary. The Pacific Bora is capable of operating in water depths of up to 10,000 feet and drilling wells .... [+ read more] 37,500 feet deep.

8 Aug 2011

High-impact discovery in the North Sea

Statoil ASA and partners Petoro AS, Det norske oljeselskap ASA and Lundin Norway AS have made a high-impact oil discovery on the Aldous Major South prospect (PL 265) in the North Sea. Well 16/2-8, drilled by the Transocean Leader drilling rig, has identified an approximately 65-metre oil column in Jurassic sandstone. The acquired data confirm that this is a reservoir of .... [+ read more] excellent quality. Statoil has previously described the well as a high-impact well (*), and the result confirms Statoil’s belief in the exploration potential on the Norwegian continental shelf in line with what was communicated at the Capital Markets Day event in New York in June. Preliminary volumes are estimated to be between 200 and 400 million barrels of oil equivalent (boe) for this part of the structure in PL 265, and Statoil expects additional upside in the licence both north and south of the discovery. Aldous Major South is located west of Lundin’s Avaldsnes discovery (licence PL 501), where Statoil has a 40% stake, and some 35 kilometres south of the Statoil-operated Grane field. Well 16/2-8 indicates the same oil-water contact as in the Avaldsnes discovery well, which suggests the likelihood of communication between the two structures. The Avaldsnes discovery encountered a 17-metre oil column. Statoil will update its total resource estimate for the area when the wells are completed and the data analysed. “Aldous Major South is a considerable oil discovery in one of Statoil’s core areas. Together with the Avaldsnes discovery this may allow for a new stand-alone development in the North Sea. As the largest resource owner our priority is to find the optimal solution for the area, adding maximum value to all partners,” says Gro G. Haatvedt, Statoil’s senior vice president for Exploration on the Norwegian continental shelf. After completing this well Transocean Leader will start drilling the Aldous Major North well. This well also has a considerable volume potential. The partnership is planning two appraisal wells in PL 265 next year and Statoil has secured rig capacity for this. The result of the ongoing drilling of the Lundin-operated well (well 16/2-7) in the Avaldsnes structure will help further clarify the area’s potential. Aldous Major South is located in licence 265. Statoil is the operator and has a 40% interest. The other partners are Petoro (30%), Det norske oljeselskap (20%) and Lundin (10%).

3 Aug 2011

Spudding of CAT BA-1X exploration well

Salamander Energy announces the spud of the Cat Ba–1X (“101-CB-1X”) exploration well in Block 101-100/04, offshore northern Vietnam. The 101-CB-1X well will be drilled to a depth of approximately 1,900 metres. The primary objective is a Palaeozoic carbonate, (buried hill) structure with secondary objectives in the overlying Tertiary clastic section. The mean gross pre-drill estimate of prospective recoverable resource is .... [+ read more] approximately 100 MMbo. The well will be drilled by the Aquamarine Driller jack-up rig in a water depth of 49 metres. It is expected to take approximately 25 days to complete on a dry hole basis. Salamander holds a 30% operated interest in Block 101-100/04, subject to final government approval of the farm-out of 20% interest to JX-Nippon Oil & Gas Exploration Corporation announced in May 2011.

31 Jul 2011

Keppel completes ultra deepwater rig for Saipem

Keppel FELS Limited (Keppel FELS) is on track to deliver Scarabeo 9, a 6th generation ultra-deepwater semisubmersible drilling rig, to Saipem S.p.A (Saipem) on time and with no lost time incidents. A significant part of Keppel FELS' workscope on Scarabeo 9 involved the completion and commissioning of marine and drilling systems onboard. .... [+ read more]

27 Jul 2011

Kora-1 exploration well drilling completion announced

Ophir Energy plc ("Ophir") announces the completion of drilling operations on the Kora-1 well in the AGC Profond Production Sharing Contract (PSC)*. Final wireline logging is now being carried out and the well will be plugged and abandoned as an unsuccessful exploration well. Kora-1 was a frontier exploration well drilled by the Maersk Deliverer semisubmersible in 2,600m of water and targeting .... [+ read more] a salt-cored, dip-closed anticline. The well was drilled to a total depth of 4447.5m subsea. Formation Evaluation While Drilling (FEWD) data shows that the primary (Albian) and secondary (Coniacian and Barremian) reservoir intervals were penetrated close to their anticipated depths, but the well encountered a predominantly claystone and thinly-bedded limestone sequence rather than the prognosed sandstone reservoir facies. In the absence of reservoir facies it is difficult to immediately assess the potential presence of hydrocarbons on the available FEWD data. A fuller analysis of the data will be required before the wider implications for the prospectivity of the Senegal-Guinea Bissau portion of the MSGBC Basin can be determined. In June 2011, Ophir completed the last of a series of farm outs on the asset. After the farm outs, Ophir's costs on the Kora-1 well have effectively been carried by the other partners. The beneficial interests in the AGC Profond PSC and the Kora-1 well are as follows:

18 Jul 2011

14/10-6 Appraisal Well Spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-6 appraisal well ("the Well") was spudded at 2125 hrs BST on 15 July 2011. The Well is situated on Licence PL032, which is 100% owned and operated by Rockhopper, and is the third appraisal well to be drilled on the Sea Lion feature .... [+ read more] since Rockhopper's oil discovery in May 2010. The Well is located some 4.1km to the west of the 14/10-2 discovery well, on the western side of the structural low at top reservoir, and 2.3km to the south-west and 14m updip from the 14/10-4 appraisal well. The Well is designed to investigate reservoir and hydrocarbon presence outside what the Company considers the minimum case area. Both Sea Lion Main and Lower fan intervals are targets, with all the Sea Lion Main fan expected to be above the Oil-Water Contact established by the 14/10-4 appraisal well, and with reservoir expected to be thinner than encountered in previous wells on the Sea Lion feature. Drilling operations are expected to take approximately 38 days and a further announcement will be made once drilling is completed.

15 Jul 2011

Makore-1 well encounters thick water-bearing sands

Kosmos Energy (NYSE: KOS) announces today that the company's Makore-1 exploration well on the West Cape Three Points Block offshore the Republic of Ghana encountered 37 meters (121 feet) of good-quality Campanian-age water-bearing sandstone reservoirs and 46 meters (151 feet) of good-quality Turonian-age water-bearing sandstone reservoirs. The Makore-1 well was Kosmos' first well in the southeastern portion of the block. The .... [+ read more] well explored a stratigraphic trap in a Turonian-age fan system. The Makore-1 well is located 25 km (15 miles) southeast of the company's Mahogany-1 exploration well that discovered the Jubilee Field. The "Atwood Hunter" semi-submersible rig drilled the Makore-1 well in a water depth of 1,409 meters (4,623 feet) to a total depth of 3,876 meters (12,716 feet). The "Atwood Hunter" will remain on the block to drill the Akasa-1 exploration well, formerly known as the Dahoma Up-dip prospect. The Akasa-1 well is expected to be spudded shortly. Kosmos is the operator of the West Cape Three Points Block in which the company holds a 30.875% interest. An affiliate of Anadarko Petroleum Corporation has a 30.875% interest; an affiliate of Tullow Oil plc has a 22.896% interest; E.O. Group Limited has a 3.5% interest; Sabre Oil & Gas Holdings Limited has a 1.854% interest; and the Ghana National Petroleum Corporation has a 10% carried interest.

12 Jul 2011

LUNDIN PETROLEUM DISCOVERS GAS IN ITS FIRST MALAYSIAN EXPLORATION WELL

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that it has discovered gas in the Tarap-1 well that was drilled in Block SB303, offshore Sabah, East Malaysia. Tarap-1 was drilled with the Offshore Courageous rig in a water depth of approximately 70 meters. The well was directionally drilled to a measured depth of 2,675 metres. The Tarap discovery .... [+ read more] is a stratigrahic trap and the well encountered gas in each of the 5 independently sealed stacked Miocene sands targeted. Gross total vertical pay thickness for the sands encountered is approximately 150 metres. An extensive data acquisition program was completed including pressure measurements, sampling and a mini flow test in selected zones. The data recovered from the well will be analysed further in order to determine a range of resource estimates. Ashley Heppenstall, President and CEO of Lundin Petroleum comments:" This is an encouraging start to the drilling campaign in Malaysia and provides strong support for our strategy in South East Asia of pursuing organic growth and value creation in focused core areas. With a large number of prospects and leads already identified within SB303, I'm confident that we can continue grow our resource base in this area in the coming years. Sabah currently has two gas demand centres located in Kota Kinabalu and Labuan Island that are supplied from existing offshore infrastructure. The addition of a third demand centre with the construction of the Sabah Oil and Gas Terminal at Kimanis and the Sabah-Sarawak gas pipeline gives us a broad range of options to explore for gas monetisation in the area." The rig will now move to drill the Cempulut prospect, also in SB303, the second well in Lundin Petroleum's five well drilling campaign in Malaysia in 2011. Lundin Petroleum holds a 75 percent interest in SB303 through its subsidiary Lundin Malaysia BV. Lundin Malaysia BV's partner is PETRONAS Carigali Sdn Bhd with a 25 percent interest.

11 Jul 2011

Pacific Drilling Signs Contract for the Pacific Scirocco

Pacific Drilling S.A. (NOTC: PDSA) announced today that a Letter of Award has been converted to a definitive contract for the Pacific Scirocco following the necessary approvals from authorities. The minimum duration of the contract is for an initial one-year term, with contract commencement expected during the third quarter of 2011. The contract provides for options, to be exercised at .... [+ read more] the client’s discretion, which could result in up to four additional years of contract term with an escalating dayrate dependent upon the option timing and term elected. Estimated maximum contract revenues related to the initial one-year term are expected to be approximately $200 million, excluding client requested modifications and miscellaneous adjustments. The Pacific Scirocco is capable of operating in water depths of up to 12,000 feet and drilling wells 40,000 feet deep.

11 Jul 2011

Secures exploration rig for Norwegian continental shelf

Statoil has signed a new contract with Songa Offshore for hire of the rig Songa Trym, which will be used for exploration drilling on the Norwegian continental shelf (NCS). Statoil has signed a new agreement with Songa Offshore relating to rig hire for use on its exploration prospects on the NCS. The semi-submersible rig has been chartered for work .... [+ read more] on the Troll field until Q2 2012. It will be deployed to drill new exploration wells from Q3 2012. The rig will be considered for operation on several licences. “Access to rigs is vital in maintaining our exploration activity on the NCS, where we envisage great potential in both near field exploration and exploration in frontier areas. This rig will help Statoil fulfil its exploration ambitions,” says Gro Gunleiksrud Haatvedt, Statoil’s head of exploration on the NCS. The daily rate for the rig is USD 355.000, with upgrade costs additional. The contract is for a fixed three-year period, though Statoil has also secured two one-year options on the same conditions. ”The contract reflects a sustainable price level for this type of rig. We have built up a good relationship with Songa and are pleased to have secured Songa Trym as an exploration rig on the NCS for the next few years,” says Statoil’s chief procurement officer, Jon Arnt Jacobsen. Songa Trym has been in use on Troll since 2005 and has helped realise planned drilling activities in the area. It is a conventional exploration rig that can drill to depths of 400 metres.

11 Jul 2011

Pacific Drilling confirms Total contract for 'Pacific Scirocco'

Pacific Drilling S.A. (Pacific Drilling) announced today that a Letter of Award has been converted to a definitive contract for the ‘Pacific Scirocco’ following the necessary approvals from authorities. The minimum duration of the contract is for an initial one-year term, with contract commencement expected during the third quarter of 2011. The contract provides for options, to be exercised at the .... [+ read more] client’s discretion, which could result in up to four additional years of contract term with an escalating dayrate dependent upon the option timing and term elected. Estimated maximum contract revenues related to the initial one-year term are expected to be approximately USD200 million, excluding client requested modifications and miscellaneous adjustments.

5 Jul 2011

Songa providing Statoil with a new rig type

Statoil has awarded the contract for construction of two new drilling rigs for use on the Norwegian continental shelf (NCS) to Songa Offshore. The contract for the two category D rigs is worth an aggregate USD 2,47 billion for a fixed eight-year charter period. "Stepping up our industrialisation of the NCS we are very pleased to announce that Songa will help .... [+ read more] realise our industrial approach and we wish to give them recognition for their long-term perspective on this partnership", says Jon Arnt Jacobsen, Statoil's chief procurement officer. "Through joint efforts we intend to rejuvenate the rig fleet on the NCS and ensure that we use the right rig for the right purpose." "This procurement process has certainly attracted great interest among rig entrepreneurs, contractors and investors", says Jon Arnt Jacobsen. "Many bidders have taken part in this process and the competition has been keen. Considering that we are ready to start this less than two years after the idea was launched, I consider this a success story!" Capable of operating in 100 to 500 metres of water this specially designed category D drilling rig can drill wells down to 8,500 metres. It will be a workhorse on mature fields, primarily drilling production wells and completing wells, enabling Statoil and its partners to produce more oil from the fields. Troll is the very cornerstone of Norwegian gas production, and also one of the largest oil fields on the NCS, oil production in 2010 totalling more than 120 000 barrels per day. Holding many world records Troll will now also be the first field to be serviced by the new specially designed rigs. Statoil has awarded the contract for the charter of the two first category D rigs on behalf of the Troll licence. "Statoil and its Troll partners have high ambitions for the further development of the field and we are pleased to have taken a decision to charter two specially designed rigs", says Hans Jakob Hegge, Statoil's senior vice president for Eastern North Sea operations in Development and Production Norway. "We will now have a tool capable of performing the demanding tasks ahead. The rig capacity on the NCS is limited, and increased capacity is essential to ensure enhanced recovery. The new rigs are expected to operate 20% more efficiently than conventional rigs, and we look forward to having the new rigs up and running from 2014." A hull designer, several topside suppliers, yard and rig entrepreneurs have helped develop the category D rig concept. Songa has assigned the rig construction work to the DSME yard in South-Korea. Aker Solutions has been picked as the supplier of the drilling equipment. The project concept and design has taken one year and the implementation period is expected to take three years, including detail engineering, construction and transportation to the NCS. The mobilisation from the yard in South-Korea to the North Sea is included in the contract value and will take about three months. The rig hand-over is scheduled for the second half of 2014. The fixed contract period is for eight years per rig, with four three-year options, i.e. in practice a 20-year contract per rig. This is a long-term approach, which ensures rig capacity for Statoil's growth ambitions, as well as predictability for the rig company. Statoil is considering including two more category D rigs in its portfolio. For this purpose Statoil has secured the opportunity to exercise its option for two category D rigs from Songa Offshore, but is also continuing its evaluation of the received bids from other bidders. During the last half of 2011 Statoil will consider various contractual solutions to ensure the construction of another two category D rigs, including the opportunity to take an ownership position in the rigs.

5 Jul 2011

Songa providing Statoil with a new rig type

Statoil has awarded the contract for construction of two new drilling rigs for use on the Norwegian continental shelf (NCS) to Songa Offshore. The contract for the two category D rigs is worth an aggregate USD 2,47 billion for a fixed eight-year charter period. "Stepping up our industrialisation of the NCS we are very pleased to announce that Songa will help .... [+ read more] realise our industrial approach and we wish to give them recognition for their long-term perspective on this partnership", says Jon Arnt Jacobsen, Statoil's chief procurement officer. "Through joint efforts we intend to rejuvenate the rig fleet on the NCS and ensure that we use the right rig for the right purpose." "This procurement process has certainly attracted great interest among rig entrepreneurs, contractors and investors", says Jon Arnt Jacobsen. "Many bidders have taken part in this process and the competition has been keen. Considering that we are ready to start this less than two years after the idea was launched, I consider this a success story!" Capable of operating in 100 to 500 metres of water this specially designed category D drilling rig can drill wells down to 8,500 metres. It will be a workhorse on mature fields, primarily drilling production wells and completing wells, enabling Statoil and its partners to produce more oil from the fields. Troll is the very cornerstone of Norwegian gas production, and also one of the largest oil fields on the NCS, oil production in 2010 totalling more than 120 000 barrels per day. Holding many world records Troll will now also be the first field to be serviced by the new specially designed rigs. Statoil has awarded the contract for the charter of the two first category D rigs on behalf of the Troll licence. "Statoil and its Troll partners have high ambitions for the further development of the field and we are pleased to have taken a decision to charter two specially designed rigs", says Hans Jakob Hegge, Statoil's senior vice president for Eastern North Sea operations in Development and Production Norway. "We will now have a tool capable of performing the demanding tasks ahead. The rig capacity on the NCS is limited, and increased capacity is essential to ensure enhanced recovery. The new rigs are expected to operate 20% more efficiently than conventional rigs, and we look forward to having the new rigs up and running from 2014." A hull designer, several topside suppliers, yard and rig entrepreneurs have helped develop the category D rig concept. Songa has assigned the rig construction work to the DSME yard in South-Korea. Aker Solutions has been picked as the supplier of the drilling equipment. The project concept and design has taken one year and the implementation period is expected to take three years, including detail engineering, construction and transportation to the NCS. The mobilisation from the yard in South-Korea to the North Sea is included in the contract value and will take about three months. The rig hand-over is scheduled for the second half of 2014. The fixed contract period is for eight years per rig, with four three-year options, i.e. in practice a 20-year contract per rig. This is a long-term approach, which ensures rig capacity for Statoil's growth ambitions, as well as predictability for the rig company. Statoil is considering including two more category D rigs in its portfolio. For this purpose Statoil has secured the opportunity to exercise its option for two category D rigs from Songa Offshore, but is also continuing its evaluation of the received bids from other bidders. During the last half of 2011 Statoil will consider various contractual solutions to ensure the construction of another two category D rigs, including the opportunity to take an ownership position in the rigs.

25 Jun 2011

Keppel on track to deliver third harsh environment N-Class rig to Rowan

Keppel FELS Limited (Keppel FELS) is on track to deliver its third KFELS N-Class jack-up rig to Rowan Companies, Inc. (Rowan) (NYSE: RDC) on time and within budget. The KFELS N-Class combines state-of-the-art design with the dual capabilities of performing drilling and production activities efficiently and safely. Equipped to operate in some of the harshest offshore environments in the world, .... [+ read more] Rowan Norway has been chartered to Xcite Energy for work in the severe conditions of the UK North Sea.

21 Jun 2011

Seadrill sells the jack-up rig West Janus

Hamilton, Bermuda, June 21, 2011 - Seadrill has entered into an agreement to sell the 1985 built jack-up drilling rig West Janus to Harrington LLC in Dubai for a total consideration of US$73 million. Seadrill expects to record a gain on the sale in excess of US$50 million on closing. Closing of the agreement and the transfer of ownership of .... [+ read more] the unit is scheduled upon completion of the rig's present drilling assignment in the second half of 2011. Seadrill's fleet of jack-up rigs remains the world largest modern jack-up fleet with a total of 19 units built after 2006, including rigs under construction. Furthermore, Seadrill has options for construction of six further units at attractive prices. Alf C Thorkildsen, CEO of Seadrill Management AS says, "We remain optimistic about the market outlook for premium jack-up rigs, and at the same time continue to highgrade our fleet by disposing some older units, whilst adding new rigs to it. The disposal of West Janus further reduces the average age of the modern Seadrill jack-up fleet to 2.6 years, and is in line with our strategy of focusing our company on modern, premium offshore drilling units."

16 Jun 2011

Keppel to deliver fifth ENSCO 8500 Series® ultra-deepwater rig

Keppel FELS Limited (Keppel FELS) is on track to deliver ENSCO 8504, the fifth of seven ENSCO 8500 Series® ultra-deepwater semisubmersible drilling rigs being built exclusively for Ensco plc (NYSE: ESV). Keppel FELS expects to deliver the rig on time, within budget and with no lost time incidents. ENSCO 8504 has been contracted to TOTAL E&P Deep Offshore Borneo B.V. .... [+ read more] for deployment in Brunei.

8 Jun 2011

Delivery of 'Maersk Deliverer' rig again delayed

African Petroleum (APCL) entered into a contract with Maersk Drilling in September 2010 for a two well programme using the Maersk Deliverer drilling rig. The ‘Maersk Deliverer’ is the third in a series of three state-of-the-art newbuild ultra deepwater development semi-submersibles in Maersk Drilling’s fleet and is capable of drilling in water depths of up to 3,000 metres.As mentioned in the .... [+ read more] March 2011 Quarterly Report, the Company was due to take delivery of the drilling rig in June 2011. However, Maersk Drilling has now advised that its current contractual drilling commitments with Amerada Hess Corporation for the ‘Maersk Deliverer’ rig has been extended due to that company making a discovery offshore Ghana. As a consequence, the Company now expects to take delivery of the ‘Maersk Deliverer’ in August 2011.

6 Jun 2011

Athena Development Drilling Completed

Ithaca Energy Inc. (TSX VENTURE:IAE)(AIM:IAE) announces the final production well on the Athena field has been drilled and fully cased. The well encountered a considerable section of oil saturated net reservoir, with good porosities. Development drilling has now been successfully concluded and the project remains on schedule for production start up in Q4 2011 at approximately 22,000 barrels of oil per .... [+ read more] day ("bopd") (gross), approx. 5,000 bopd (net to Ithaca), in-line with previous disclosure. Athena field development well 14/18b-A2Z ("the Well") intersected 515 feet (measured depth) of net reservoir in the sub horizontal section of the well bore which was drilled to a total measured depth of 15,497 feet. The drilling rig, Sedco 704, is now proceeding to run completion equipment and perforate the Well, the three existing suspended production wells and the water injection well. The Well was directionally drilled to the northwest of the Athena field where it encountered the principal reservoir section, the Scapa A reservoir, at 11,967 feet (measured depth), 8,851 feet (true vertical depth subsea), in line with prognosis. Electric logs acquired across the entire reservoir section of interbedded Scapa age sandstones and shales confirmed a series of reservoir sands with porosities up to 20%. Two of the thickest, high porosity sandstone units were encountered close to the top of the reservoir section and Management anticipates that these will contribute to strong flow rates when the Well comes into production. A production liner has been run across the reservoir section. The ongoing modification and recertification work on the Floating Production, Storage and Offloading ("FPSO") vessel, BW Athena (currently in dry dock in Dubai) is well advanced. The vessel has been successfully separated for installation of a turret docking section which is currently being welded into the structure amidships. The vessel will be extended by approximately 65 feet. The FPSO will return to UK waters for hook up to the turret mooring buoy by the end of Q3 2011.

3 Jun 2011

Exploration Offshore Greenland

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

2 Jun 2011

Pacific Drilling Receives Delivery of its Drillship the Pacific Mistral

Pacific Drilling S.A. (NOTC: PDSA) announced today that it has received delivery of its newest drillship, the Pacific Mistral. The Pacific Mistral can operate in water depths of up to 12,000 feet and drill wells of up to 35,000 feet total depth. The rig features technologically advanced equipment that allows customers to improve drilling efficiency, including offline handling capabilities. .... [+ read more] Pacific Drilling CEO Chris Beckett stated, “We are proud to announce the delivery of the Pacific Mistral. This constitutes the third on-time, on-budget delivery in Pacific Drilling’s fleet of six premium ultra-deepwater drillships. The final payment to the shipyard was substantially funded by our Project Facilities Agreement lenders, consisting of two Export Credit Agencies and nine commercial banks based in the United States and Europe. We are in the advanced stages of negotiations with several major E&P companies and expect to announce a drilling contract for the Pacific Mistral in the near future.” With its best-in-class drillships and highly experienced team, Pacific Drilling is a fast growing company that is dedicated to becoming the preferred ultra-deepwater drilling contractor. In addition to the three ultra-deepwater drillships delivered to date, Pacific Drilling expects delivery of an additional drillship in August 2011 and has two drillships on order at Samsung for delivery during 2013.

2 Jun 2011

Pacific Drilling takes delivery of 'Pacific Mistral'

Pacific Drilling S.A. (Pacific Drilling) announced today that it has received delivery of its newest drillship, the ‘Pacific Mistral’. The ‘Pacific Mistral’ can operate in water depths of up to 12,000 feet and drill wells of up to 35,000 feet total depth. The rig features technologically advanced equipment that allows customers to improve drilling efficiency, including offline handling capabilities. Pacific .... [+ read more] Drilling CEO Chris Beckett stated, “We are proud to announce the delivery of the ‘Pacific Mistral’. This constitutes the third on-time, on-budget delivery in Pacific Drilling’s fleet of six premium ultra-deepwater drillships.

18 May 2011

Jacky Field Well Operations

Ithaca Energy Inc. announces that the J03 well on the Jacky field ("the well") has been suspended having encountered a smaller than anticipated oil column in the Beatrice 'A'; Sand reservoir. Given the result of the well, technical work is ongoing to determine whether to re-enter the well and complete it as a water injector to maximise oil recovery from the .... [+ read more] Jacky field. Meanwhile, the drilling unit for the J03 well, Northern Enhancer, currently located over the Jacky platform, will commence a workover operation to replace downhole pumps in the J01 production well. This operation is estimated to last approximately 15 days.

16 May 2011

LUNDIN PETROLEUM SPUDS SKALLE EXPLORATION WELL IN BARENTS SEA

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

10 May 2011

Oil discovery in the North Sea

Oil has been proven by Statoil and its partners Det norske oljeselskap ASA and Svenska Petroleum Exploration AS on the North Sea Krafla prospect. The well is located in block 30/11 around 26 kilometres south of the Oseberg South field. Based on preliminary calculations the size of the discovery is between 12.5 and 56.5 million barrels of recoverable oil equivalent. .... [+ read more] ”Statoil has had great exploration success in mature areas during the last years,” says Gro Gunleiksrud Haatvedt, Statoil’s head of exploration on the Norwegian continental shelf (NCS). “The North Sea is a strategically important area to Statoil, and this discovery on Krafla confirms once again that the company can still find interesting volumes close to established infrastructure.” ”These discoveries can quickly be put on stream and help extend the life of our installations,” she says. Drilled by the Ocean Vanguard rig the well proved a column of around 200 metres in good quality reservoir rocks. ”Previously six exploration wells have been drilled in block 30/11 without commercial success, so we are very pleased that Statoil seems to have made a fast track discovery in our first operated well in this license,” says Tom Dreyer, exploration manager for the Northern North Sea. “Although data collection is still ongoing, the results so far clearly indicate that this is an oil discovery. If this is the case then we have unlocked the exploration potential of this area and have several follow-up opportunities.” When the Krafla well is completed, the Ocean Vanguard will start drilling the planned sidetrack well on Krafla West, which is located west of the recently drilled well. The find will probably be developed and produced by tie-back to one of the subsea installations in the Oseberg area. The licensees in PL035/PL272 are: Statoil (operator) (50%), Det norske oljeselskap ASA (25%) and Svenska Petroleum Exploration AS (25%).

3 May 2011

14/10-5 Appraisal Well Spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-5 appraisal well ("the well") was spudded at 13.20hrs BST on 1 May 2011. The well is situated on Licence PL032, which is 100% owned and operated by Rockhopper. The well is located just north of the Sea Lion 14/10-2 discovery well .... [+ read more] and 13 metres updip at top reservoir level. The well is designed to appraise the Sea Lion main fan reservoir and investigate hydrocarbon column and reservoir distribution. The location is 77 metres updip at top reservoir level from the recently drilled 14/10-4 appraisal well. Specialist flow test equipment is being mobilised and Rockhopper intends, if reservoir is as prognosed, to flow test the well to obtain a greater understanding than was possible during the test of well 14/10-2 last year. Drilling operations are expected to take approximately 38 days and a further announcement will be made once drilling is completed.

2 May 2011

Pacific Drilling Receives a Letter of Award from Total in Nigeria

Pacific Drilling S.A. (NOTC: PDSA) announced today that their latest generation drillship, the Pacific Scirocco, has received a Letter of Award from Total E&P Nigeria Limited, subject to completion of formalities with relevant government agencies in the near future, to perform exploration and development work in Nigeria. The minimum duration of the award is for a one-year initial term at .... [+ read more] a dayrate of $470,000 plus mobilization and client requested upgrades. The agreement further contemplates two one-year options at Total’s discretion. “We are very pleased to announce a new core relationship with Total, a leading deepwater operator, consistent with our vision to work with the best in the industry,” commented Pacific Drilling CEO Chris Beckett. “This represents Pacific Drilling’s third commitment from a major oil company, including the two previously announced contracts for the Pacific Santa Ana and the Pacific Bora both contracted to Chevron in the Gulf of Mexico and Nigeria respectively.” Pacific Drilling’s fourth ultra-deepwater drillship, the Pacific Mistral, is under construction at Samsung Heavy Industries. The Mistral is on target for on time delivery in May 2011 and is the subject of advanced discussions with various clients. In March 2011 Pacific Drilling ordered two additional drillships from Samsung Heavy Industries, the Pacific Khamsin and the Pacific Sharav, scheduled for delivery in April and September 2013 respectively.

2 May 2011

Total issue LOA for 'Pacific Scirocco' drillship in Nigeria

Pacific Drilling S.A. (Pacific Drilling) announced today that their latest generation drillship, the ‘Pacific Scirocco’, has received a Letter of Award from Total E&P Nigeria Limited, subject to completion of formalities with relevant government agencies in the near future, to perform exploration and development work in Nigeria. The minimum duration of the award is for a one-year initial term at .... [+ read more] a dayrate of USD470,000 plus mobilisation and client requested upgrades. The agreement further contemplates two one-year options at Total’s discretion.

20 Apr 2011

'Pacific Scirocco' drillship delivered to Pacific Drilling

Pacific Drilling S.A. received on-time delivery of its newest drillship, the ‘Pacific Scirocco’. The ‘Pacific Scirocco’ is designed to operate in water depths of up to 12,000 feet and is equipped with the newest and most technologically advanced equipment, including a dual derrick with double load path. CEO Chris Beckett stated, “We are proud to be involved in the .... [+ read more] construction of this new addition to our expanding fleet. The ‘Pacific Scirocco’ boasts some of the most modern equipment and highest capabilities of any drillship in the market. As previously stated, we expect to sign the ‘Pacific Scirocco’ to a contract with a top quality E&P company in the near future.”

20 Apr 2011

Pacific Drilling Receives Delivery of its New Drillship the Pacific Scirocc

Pacific Drilling S.A. received on-time delivery of its newest drillship, the Pacific Scirocco. The Pacific Scirocco is designed to operate in water depths of up to 12,000 feet and is equipped with the newest and most technologically advanced equipment, including a dual derrick with double load path. CEO Chris Beckett stated, “We are proud to be involved in the .... [+ read more] construction of this new addition to our expanding fleet. The Pacific Scirocco boasts some of the most modern equipment and highest capabilities of any drillship in the market. As previously stated, we expect to sign the Pacific Scirocco to a contract with a top quality E&P company in the near future.” With its best-in-class drillships and highly experienced team, Pacific Drilling is a fast growing company that is dedicated to becoming the preferred ultra-deepwater drilling contractor. Pacific Drilling’s fleet of four of the newest ultra-deepwater drillships is expected to be in operation by the end of 2011, with two additional drillships on order at Samsung for delivery during 2013.

18 Apr 2011

14/15-3 exploration well result

Based on drilling and wireline logging, the well encountered two sand-prone sections in the Upper and Middle F2 intervals, which were the primary targets (2323 metres to 2334 metres and 2365 metres to 2389 metres). The sands have a combined gross thickness of 35 metres and oil shows were encountered throughout both intervals while drilling. The reservoir quality is .... [+ read more] generally poor having only 5.6 metres of net reservoir with an average porosity of 13%. A thin interval of around 1.2 metres at the top of the Middle F2 zone is interpreted to be oil bearing from log analysis. Wireline formation pressure measurements were attempted, but no valid pressures were obtained, indicating that the reservoirs are low permeability at this location. As a result no wireline sampling was attempted. The depositional model suggests these sands are sourced from the east and therefore better reservoir quality may be expected downdip. In addition, there are indications from seismic of further sands along strike on the Ninky structural high, which were not penetrated in this well. These opportunities will be evaluated with the new 3D seismic as part of the Operator's prospect inventory update. Operations on the Ninky well will now be completed and the well will be plugged and abandoned. Upon completion of operations on the Ninky well, the Ocean Guardian drilling rig will return to Rockhopper. Rockhopper will drill a minimum of 3 additional wells using the Ocean Guardian drilling unit. Rockhopper's next well is planned to be located near to the 14/10-2 discovery well. Specialist flow test equipment is due to be in the Islands in early May and Rockhopper intends to flow test the well if appropriate using this equipment to obtain a greater understanding than was possible during the test of well 14/10-2.

14 Apr 2011

Oil find near Peregrino

A new oil find has been made by Statoil immediately adjacent the Peregrino field in the Campos Basin offshore Brazil. An exploration well drilled in the Peregrino South structure a few kilometres south of Peregrino has encountered oil in sandstones of the Carapebus geological formation. A significant gross oil column of 130 metres has been proven in the well and .... [+ read more] further work will be performed to confirm the volumes. The drilling operation is still ongoing to penetrate deeper reservoir units and explore additional upside potential below the main reservoir unit. Significant upside “The results confirm the significant potential in the Peregrino area and underline the beliefs we have had in the upside,” says Tim Dodson, executive vice president for Exploration in Statoil. “The well verifies the upside potential and will together with the Peregrino Southwest discovery from 2007 play an important role in further development of the Peregrino area.” “The results will indeed be implemented into our plans for further development of the field,” says Kjetil Hove, head of Statoil’s Brazil activities and vice president in the company’s Development and Production International business area. Following the completion of the Peregrino South well, one additional appraisal well in the Peregrino Southwest structure will be drilled to conclude the overall size of the new development. Oil production from the Peregrino field started last week and will gradually ramp up to a plateau of 100,000 barrels of oil equivalent per day, making Statoil an important long-term operator and partner in Brazil’s growing oil and gas industry. The initial development of the field is estimated to contain 300 to 600 recoverable million barrels of oil equivalents, and the new discovery will add additional volumes going forward. Drilling of the well is being carried out by the Blackford Dolphin rig at a water depth of 120 metres. Operated by Statoil, the Peregrino field is 85 kilometres off the Brazilian coast from Rio de Janeiro. In May 2010 Statoil sold a 40% stake of the Peregrino field to the Sinochem Group. Statoil holds 60% ownership and the operatorship of the field and Sinochem the remaining 40%. The closing of the transaction is pending governmental approvals.

8 Apr 2011

Delivery of 'Maersk Deliverer' delayed

African Petroleum Corporation Limited (African Petroleum) holds 100% of Blocks LB-08 and LB-09, located offshore Liberia, West Africa. Further to the Company’s announcement dated 11th March 2011 (11th March Announcement), the Company advises that due to operational delays being encountered by the existing operator, its 2011 two well deepwater offshore drilling programme in West Africa, using the ‘Maersk Deliverer’, is now .... [+ read more] expected to commence in relation to the first well in Block LB-09 in June 2011 (rather than May 2011 as previously contemplated in the 11th March Announcement).

4 Apr 2011

Gas discovery block 1 offshore Tanzania

Ophir Energy plc (Ophir), the Africa-focused upstream oil and gas company, is pleased to announce that a gas discovery has been made in the Chaza-1 exploration well offshore Tanzania. This is the first gas discovery in Block 1 but the third consecutive discovery made in this drilling campaign following on from the Chewa and Pweza discoveries made in Block 4. The .... [+ read more] Chaza-1 well was operated by Ophir (40%) on behalf of a joint venture with BG International (BG) (60%). The well is located approximately 18km from the coastline in 952m of water. The Chaza-1 well was drilled to a total depth of 4,895m sub-sea. The well encountered a high quality gas bearing reservoir of which is associated with a distinctive seismic anomaly. Chaza-1 is the third of a three-well sequence which forms part of an Initial Work Programme across Blocks 1, 3 and 4. The Deepsea Stavanger will now move back to the Chewa location in Block 4 to side-track and appraise the earlier announced Chewa-1 discovery and deepen the well to test older reservoir objectives. The Ophir/BG Joint Venture has interests in Blocks 1, 3 and 4 offshore southern Tanzania. These blocks cover more than 27,000km2 of the Mafia Basin and northern portion of the Ruvuma Basin in water depths ranging from approximately 100m to greater than 3,000m. The Ophir/BG Joint Venture is currently completing the acquisition of approximately 5,000km2 of additional 3D seismic data across all three blocks.

1 Apr 2011

Major oil discovery in the Barents Sea

Statoil, along with partners Eni Norway and Petoro, has made a significant oil discovery on the Skrugard prospect in the Barents Sea. The breakthrough discovery is one of the most important finds on the Norwegian continental shelf in the last decade. Statoil and its partners are in the process of concluding drilling operations on the Skrugard prospect, which is located approximately .... [+ read more] 100 kilometres north of the Snøhvit gas field in the Barents Sea. The well was drilled with the Polar Pioneer rig, and has proven gas column of 33 metres and an oil column of 90 metres. The oil is anticipated to be easily producible. The estimated volume of the discovery is between 150–250 million recoverable barrels of oil equivalent (boe), while Statoil sees opportunities for further upside in the license of up to 250 million barrels – for a potential total of 500 million boe. “The Skrugard find is significant and a break-through for frontier exploration in the Barents Sea. This opens a new oil province that can provide additional resource growth,” says Tim Dodson, executive vice president for Exploration in Statoil. He emphasises that it is too early to say something concrete about the total potential of the area, but ventures to characterise the Skrugard find as the most important exploration event on the Norwegian continental shelf in the last decade. The discovery is vital in order to maintain the technology and technical environments in the oil and gas industry in Norway in the future. Statoil has plans for both the drilling of a new prospect in the same license next year, and a possible appraisal drilling at Skrugard. The Skrugard prospect was Statoil's first priority in the 20th licensing round on the Norwegian continental shelf, which was awarded in April 2009. Over the course of the spring the Norwegian government will allocate acreage in the 21st licensing round. Acreage in areas nearby Skrugard is expected to be assigned during the round. Drilling operations have been conducted in a safe, efficient and environmentally friendly manner. Several core samples have been taken in order to understand reservoir properties, and some data collection in the well still remains. In total there have been over 80 wells drilled in the southern Barents Sea, and Statoil has been the operator for more than 60 of these. The Snøhvit gas field, which is operated by Statoil, is the only field centre established so far in the Barents Sea, while Eni's Goliat field is under development. “The Barents Sea is large, and we can not say that we have cracked the code for the entire area yet. But we have confirmed that our exploration model is correct. This is a break-through, and an important step in understanding how the geology – and thus the hydrocarbon systems in the Barents Sea – works,” says Dodson. “If the volume estimates are confirmed, then this discovery could provide a basis for an independent development. Given that it takes between five to 10 years from discovery to production, we are planning for the future now. Our ambition is to put this find into production as quickly as possible,” he adds. Statoil is the operator of license 532 with a 50% share. The license partners are Eni (30%) and Petoro (20%).

29 Mar 2011

Ninky 14/15-3 exploration well spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, notes the announcement by Desire Petroleum plc (the "Operator") that the 14/15-3 exploration well on the Ninky prospect was spudded at 02.45 BST on 29 March 2011. Rockhopper has a 7.5% interest in the well. The Operator described the prospect as a combined structural dip .... [+ read more] and stratigraphic pinch-out trap with multiple reservoir targets within the Barremian source rock interval. The well has a planned total depth of circa 2,620 metres and drilling operations are expected to take approximately 30 days. The Operator will make a further announcement once logging is complete.

29 Mar 2011

Keppel receives US$8 million from QGOG for early delivery of Alpha Star

Keppel FELS Limited (Keppel FELS) has delivered Alpha Star, the second of two DSSTM 38 semisubmersible rigs, to Brazil's Queiroz Galvão Óleo e Gás (QGOG) four months ahead of schedule and with zero lost time incidents. This continues Keppel FELS track record of delivering its rigs on time or ahead of schedule. It is the third early delivery this year, .... [+ read more] following the early delivery of the semisubmersible drilling tender, West Jaya, to Seadrill and of the KFELS N Class rig, Rowan Stavanger, for Rowan Companies. The rig has been chartered by Petrobras for six years to support exploration and production activities offshore Brazil.

28 Mar 2011

Teak-2 exploration well discovers hydrocarbons offshore Ghana

Tullow Oil plc (Tullow) announces that the Teak-2 exploration well in the West Cape Three Points licence offshore Ghana has discovered 27 metres of net hydrocarbon bearing Campanian and Turonian reservoirs. The well was targeting an undrilled fault block between the Jubilee field and the Teak-1 discovery, located 1.8 km southwest of the recent Teak-1 well and 3.5 km northeast of .... [+ read more] the Mahogany-2 well. Results of drilling, wireline logs and samples of reservoir fluids confirm that the well has intersected five intervals containing high quality oil, gas and gas-condensate. Six metres of net oil and gas pay were encountered at the top of good quality Campanian reservoirs, over 100 metres thick. Jubilee equivalent Turonian reservoirs contain 21 metres of net hydrocarbon pay, 16 metres of which is rich gas. Static pressure data suggests this potentially forms a gas cap to the Jubilee oil field. Future analyses and pressure interference testing will determine hydrocarbon contacts and the extents of these two adjoining fields. The Atwood Hunter rig drilled Teak-2 to a total depth of 3,409 metres in water depths of 885 metres. On completion of operations, the well will be suspended for future use and the rig will move to drill the Banda-1 well which is targeting Campanian and Cenomanian reservoirs in the east of the licence. Tullow has a 22.896% interest in the West Cape Three Points licence and its partners are Kosmos Energy (Operator) and Anadarko Petroleum Corporation (30.875% each), the E.O.Group (3.5%), Sabre Oil & Gas Holdings Ltd (1.854%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

19 Mar 2011

Keppel FELS delivers 7th KFELS SSDT to Seadrill ahead of schedule

Keppel FELS Limited (Keppel FELS) has delivered its seventh KFELS semisubmersible drilling tender (SSDT), West Jaya, to Seadrill Limited (Seadrill). Completed two weeks ahead of schedule, the vessel was delivered with a perfect safety record and within budget. West Jaya is built to Keppel's proven KFELS SSDT 3600E design which was conferred the ASEAN outstanding engineering achievement award in December .... [+ read more] 2009 for its eco-friendly features and sustainable operations. Seadrill are in negotiation with BP Trinidad & Tobago LLC for West Jaya to work in the Immortelle field for two years.

17 Mar 2011

New rig for Statoil’s fast-track portfolio

Statoil has awarded Songa Offshore a contract for hire of the semi-submersible rig Songa Delta, for use in the fast-track portfolio on the Norwegian continental shelf (NCS). The contract value is approximately USD 400 million. The rig will carry out production drilling for Statoil’s fast-track portfolio on the NCS. It will be used for drilling and completing wells, and will quickly .... [+ read more] be able to contribute to the production of the fields. “We will be able to realise small finds that normally would not be profitable through fast-track developments and standardised solutions,” says Ivar Aasheim, head of field development on the NCS. “Securing drilling capacity is vital to be able to execute our fast-track developments. This helps to maintain the production level on the NCS.” Plans call for the rig to start its production assignment for Statoil in the summer of 2012. Jon Arnt Jacobsen, Statoil chief procurement officer, is pleased that the company has acquired future rig capacity. “We are pleased to have secured yet another rig from Songa Offshore. This contract award addresses our ambition to sustain production,” says Jacobsen. “The rig will work specifically for Statoil’s fast-track developments, and will play an important part in maintaining the pace of our fast-track projects.” The contract period is three years firm, and includes a one-year option following the completion of the drilling programme. Statoil has an option to extend the contract period from three to four years firm.

15 Mar 2011

Japan Drilling Company awards US$210 million jackup contract to Keppel

Keppel FELS Limited (Keppel FELS) has secured a contract worth about US$210 million from Japan Drilling Company (JDC) to build a KFELS Super B Class jackup rig. Slated for delivery in the first quarter of 2013, the rig will be JDC's first newbuild rig order in six years and Keppel FELS' first for JDC. .... [+ read more]

11 Mar 2011

Enyenra-2A appraisal well proves major light oil field

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

7 Mar 2011

Keppel to build new jackup worth US$195 million for Mexico

Keppel AmFELS LLC, a US wholly-owned subsidiary of Keppel Offshore & Marine Ltd (Keppel O&M), has won a contract from Mexico's Perforadora Central SA de CV (Perforadora Central) to build a repeat jackup rig valued at about US$195 million. Slated for delivery in 1Q 2013, this latest high specification unit will be based on the LeTourneau Super 116E design. Unlike .... [+ read more] the existing LeTourneau Super 116Es, this will be the first Super 116E newbuild to be further enhanced to provide for an additional 1,500 kips of elevated load. It will have leg lengths of 511 ft and the capability to drill wells up to 30,000 ft at a water depth of 375 ft. Mexico is the world's sixth largest producer of oil and has the seventh largest natural gas reserve in the western hemisphere. PEMEX, Mexico's national oil company, has recently announced plans to invest approximately Ps. 286.3 billion (US$23.6 billion) in 2011, more than 80% of which would be allocated to exploration and production activities.

7 Mar 2011

Athena field final development well drilling commenced

Ithaca Energy Inc. announces today that the Sedco 704 semi submersible drilling unit has commenced the drilling of the final production well for the development of the Athena field ("Athena"). Well 14/18b-A2 ("the well") is being drilled from the Athena drill centre and is the final well to be drilled of a 180 day campaign of drilling and .... [+ read more] completion activities. The well is planned to be directionally drilled to produce oil reserves lying in the north west of Athena. In addition, this well is planned to intersect the top reservoir (Top Scapa A sands) at a point within the appraised Athena oil pool and continue north, drilling at a high angle to provide valuable information relating to an area of the field targeted for future development. The drilling and completion of the well as a producer is scheduled to last approximately 80 days. Co-venturers in the Athena are Ithaca (operator, 22.5%), Dyas UK Ltd (47.5%), EWE Aktiengesellschaft (20%) and Zeus Petroleum Limited (10%).

28 Feb 2011

Completion of Trident XX acquisition from Transocean

EDC announced that it has completed the acquisition of the Trident XX jack-up drilling rig from Transocean for a total consideration of US$ 260 million. The Trident XX is a Keppel FELS CS Mod V cantilever jack-up capable of operating in water depths to 350 feet and capable of drilling to 26,000 feet. The rig is presently operating in Turkmen .... [+ read more] waters of the Caspian Sea on a long-term contract with PETRONAS Carigali (Turkmenistan) Sdn Bhd, which runs through 2012.

23 Feb 2011

Noble Corporation Announces Letter of Intent on Noble Jim Day

Noble Corporation (NYSE: NE) today announced that the Company has secured a Letter of Intent ("LOI") with a subsidiary of Royal Dutch Shell plc for the 12,000 foot ultra-deepwater semisubmersible Noble Jim Day to operate in the U.S. Gulf of Mexico. Under the terms contemplated by the LOI, the effective date of the commitment would be February 15, 2011 and the .... [+ read more] contract would extend through January 31, 2012. The LOI contemplates that Noble would receive a standby rate if Shell is unable to secure drilling permits. Beginning the sooner of August 1, 2011 or Shell securing a drilling permit for use of the unit, the operating dayrate would be $485,000 per day. During the operating period, the unit would be eligible for a performance bonus of up to 15 percent of the dayrate. The LOI is subject to execution of the drilling contract, although the parties have agreed to a base form of contract and certain of the particular modifications for this work. "We are extremely pleased to see the Noble Jim Day be awarded this LOI so that it can go on the payroll and earn a dayrate effective from mid-February," said David W. Williams, Chairman, President and Chief Executive Officer, Noble Corporation. "This is an extremely high quality rig and there was significant customer interest, however, other opportunities that would have required a mobilization out of the U.S. Gulf would have precluded us from being able to begin recognizing revenue until much later in the year. Furthermore, the terms of the LOI ensure that under the contract we would earn a full operating dayrate beginning no later than August 1st with potential upside if Shell is able to secure a drilling permit sooner. And the short-term nature of the commitment positions us well if dayrates increase as expected in the latter half of the year."

23 Feb 2011

THE EARB EXPLORATION WELL IN PL505 HAS SPUDDED, OFFSHORE NORWAY

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

21 Feb 2011

14/10-4 Appraisal Well Spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-4 appraisal well was spudded at 0040hrs GMT on 19 February 2011. 14/10-4 is the first appraisal well to be drilled on the Sea Lion feature situated on Licence PL032, which is 100% owned and operated by Rockhopper. The appraisal well (14/10-4) .... [+ read more] is located 2.3km away from the Sea Lion 14/10-2 discovery well, in the southern lobe of the Sea Lion fan system. 14/10-4 is designed to investigate reservoir and hydrocarbon columns downdip of the Sea Lion 14/10-2 discovery well. The planned Target Depth of circa 3,000 metres will investigate the possibility of deeper sands than those encountered in the Sea Lion discovery well. Drilling operations are expected to take approximately 38 days and a further announcement will be made once drilling is completed.

21 Feb 2011

Long-term contract for new rig design

Statoil is sending out an invitation to tender for a new type of drilling rig. It is specially-designed by the industry on behalf of Statoil for use on mature fields on the Norwegian continental shelf (NCS). The purpose is to make drilling and completion of production wells less expensive, more effective and safer, and thereby boost oil recovery. Discoveries on .... [+ read more] the NCS are getting smaller and it is becoming more important to increase drilling activity in mature fields to attain the full potential of the NCS. To meet this challenge, lower rig rates, greater drilling efficiency and access to rigs are key factors. “The rigs delivered to the NCS in recent years were first and foremost constructed for operations in deep water,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “That means that they are big and too costly for our requirements and challenges on the NCS. We are therefore taking steps to rejuvenate the rig fleet and ensure that the right rig meets the right requirements.” The specially-designed category D rig is able to operate at water depths of 100-500 metres and drill wells down to 8,500 metres. It will be a workhorse on mature fields, primarily for drilling production wells and well completion. In this way, Statoil and its partners can get more oil out of the fields. The rig has been developed in collaboration with various industry players. Statoil is issuing a tender for minimum two such rigs for work on the NCS. The contract will run for either eight years with four three-year options or for 20 years firm contract period. This is an unusually long period of contract which will reduce the risk for the drilling contractor who will build the rig. Statoil is also considering taking an ownership stake in the rig. “Statoil is taking responsibility for a long-term development of the NCS – we see that there are still big opportunities here,” says Jacobsen. “Now we need to think anew with regard to reducing drilling costs and we will see if it’s possible to achieve a more industrialised development.” It is many years since big discoveries were made on the NCS. Minor finds are made but the margins are lower. It is therefore necessary to reduce rig costs in order to realise the potential value. Small finds are also often made near existing fields. Fast developments are then important so that the existing infrastructure can be utilised. “The key to maintaining today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields,” says Øystein Michelsen, executive vice president for Development and Production Norway. “In order to implement these measures it is crucial that we secure a rig fleet which is adapted to suit the assignments and which can work more effectively.” A rig like this will be able to drill and do well completions in the North Sea and the Norwegian Sea throughout the year. “The goal is that the new rig will drill 20% more effectively than conventional rigs,” says Jon Arnt Jacobsen. “This will help to counteract the cost trends in the rig market.” Plans call for the contract to be awarded in the third quarter of 2011 and the rigs to be delivered in the second half of 2014.

21 Feb 2011

Long-term contract for new rig design

Statoil is sending out an invitation to tender for a new type of drilling rig. It is specially-designed by the industry on behalf of Statoil for use on mature fields on the Norwegian continental shelf (NCS). The purpose is to make drilling and completion of production wells less expensive, more effective and safer, and thereby boost oil recovery. Discoveries on .... [+ read more] the NCS are getting smaller and it is becoming more important to increase drilling activity in mature fields to attain the full potential of the NCS. To meet this challenge, lower rig rates, greater drilling efficiency and access to rigs are key factors. “The rigs delivered to the NCS in recent years were first and foremost constructed for operations in deep water,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “That means that they are big and too costly for our requirements and challenges on the NCS. We are therefore taking steps to rejuvenate the rig fleet and ensure that the right rig meets the right requirements.” The specially-designed category D rig is able to operate at water depths of 100-500 metres and drill wells down to 8,500 metres. It will be a workhorse on mature fields, primarily for drilling production wells and well completion. In this way, Statoil and its partners can get more oil out of the fields. The rig has been developed in collaboration with various industry players. Statoil is issuing a tender for minimum two such rigs for work on the NCS. The contract will run for either eight years with four three-year options or for 20 years firm contract period. This is an unusually long period of contract which will reduce the risk for the drilling contractor who will build the rig. Statoil is also considering taking an ownership stake in the rig. “Statoil is taking responsibility for a long-term development of the NCS – we see that there are still big opportunities here,” says Jacobsen. “Now we need to think anew with regard to reducing drilling costs and we will see if it’s possible to achieve a more industrialised development.” It is many years since big discoveries were made on the NCS. Minor finds are made but the margins are lower. It is therefore necessary to reduce rig costs in order to realise the potential value. Small finds are also often made near existing fields. Fast developments are then important so that the existing infrastructure can be utilised. “The key to maintaining today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields,” says Øystein Michelsen, executive vice president for Development and Production Norway. “In order to implement these measures it is crucial that we secure a rig fleet which is adapted to suit the assignments and which can work more effectively.” A rig like this will be able to drill and do well completions in the North Sea and the Norwegian Sea throughout the year. “The goal is that the new rig will drill 20% more effectively than conventional rigs,” says Jon Arnt Jacobsen. “This will help to counteract the cost trends in the rig market.” Plans call for the contract to be awarded in the third quarter of 2011 and the rigs to be delivered in the second half of 2014.

21 Feb 2011

Long-term contract for new rig design

Statoil is sending out an invitation to tender for a new type of drilling rig. It is specially-designed by the industry on behalf of Statoil for use on mature fields on the Norwegian continental shelf (NCS). The purpose is to make drilling and completion of production wells less expensive, more effective and safer, and thereby boost oil recovery. Discoveries on .... [+ read more] the NCS are getting smaller and it is becoming more important to increase drilling activity in mature fields to attain the full potential of the NCS. To meet this challenge, lower rig rates, greater drilling efficiency and access to rigs are key factors. “The rigs delivered to the NCS in recent years were first and foremost constructed for operations in deep water,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “That means that they are big and too costly for our requirements and challenges on the NCS. We are therefore taking steps to rejuvenate the rig fleet and ensure that the right rig meets the right requirements.” The specially-designed category D rig is able to operate at water depths of 100-500 metres and drill wells down to 8,500 metres. It will be a workhorse on mature fields, primarily for drilling production wells and well completion. In this way, Statoil and its partners can get more oil out of the fields. The rig has been developed in collaboration with various industry players. Statoil is issuing a tender for minimum two such rigs for work on the NCS. The contract will run for either eight years with four three-year options or for 20 years firm contract period. This is an unusually long period of contract which will reduce the risk for the drilling contractor who will build the rig. Statoil is also considering taking an ownership stake in the rig. “Statoil is taking responsibility for a long-term development of the NCS – we see that there are still big opportunities here,” says Jacobsen. “Now we need to think anew with regard to reducing drilling costs and we will see if it’s possible to achieve a more industrialised development.” It is many years since big discoveries were made on the NCS. Minor finds are made but the margins are lower. It is therefore necessary to reduce rig costs in order to realise the potential value. Small finds are also often made near existing fields. Fast developments are then important so that the existing infrastructure can be utilised. “The key to maintaining today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields,” says Øystein Michelsen, executive vice president for Development and Production Norway. “In order to implement these measures it is crucial that we secure a rig fleet which is adapted to suit the assignments and which can work more effectively.” A rig like this will be able to drill and do well completions in the North Sea and the Norwegian Sea throughout the year. “The goal is that the new rig will drill 20% more effectively than conventional rigs,” says Jon Arnt Jacobsen. “This will help to counteract the cost trends in the rig market.” Plans call for the contract to be awarded in the third quarter of 2011 and the rigs to be delivered in the second half of 2014.

21 Feb 2011

Long-term contract for new rig design

Statoil is sending out an invitation to tender for a new type of drilling rig. It is specially-designed by the industry on behalf of Statoil for use on mature fields on the Norwegian continental shelf (NCS). The purpose is to make drilling and completion of production wells less expensive, more effective and safer, and thereby boost oil recovery. Discoveries on .... [+ read more] the NCS are getting smaller and it is becoming more important to increase drilling activity in mature fields to attain the full potential of the NCS. To meet this challenge, lower rig rates, greater drilling efficiency and access to rigs are key factors. “The rigs delivered to the NCS in recent years were first and foremost constructed for operations in deep water,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “That means that they are big and too costly for our requirements and challenges on the NCS. We are therefore taking steps to rejuvenate the rig fleet and ensure that the right rig meets the right requirements.” The specially-designed category D rig is able to operate at water depths of 100-500 metres and drill wells down to 8,500 metres. It will be a workhorse on mature fields, primarily for drilling production wells and well completion. In this way, Statoil and its partners can get more oil out of the fields. The rig has been developed in collaboration with various industry players. Statoil is issuing a tender for minimum two such rigs for work on the NCS. The contract will run for either eight years with four three-year options or for 20 years firm contract period. This is an unusually long period of contract which will reduce the risk for the drilling contractor who will build the rig. Statoil is also considering taking an ownership stake in the rig. “Statoil is taking responsibility for a long-term development of the NCS – we see that there are still big opportunities here,” says Jacobsen. “Now we need to think anew with regard to reducing drilling costs and we will see if it’s possible to achieve a more industrialised development.” It is many years since big discoveries were made on the NCS. Minor finds are made but the margins are lower. It is therefore necessary to reduce rig costs in order to realise the potential value. Small finds are also often made near existing fields. Fast developments are then important so that the existing infrastructure can be utilised. “The key to maintaining today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields,” says Øystein Michelsen, executive vice president for Development and Production Norway. “In order to implement these measures it is crucial that we secure a rig fleet which is adapted to suit the assignments and which can work more effectively.” A rig like this will be able to drill and do well completions in the North Sea and the Norwegian Sea throughout the year. “The goal is that the new rig will drill 20% more effectively than conventional rigs,” says Jon Arnt Jacobsen. “This will help to counteract the cost trends in the rig market.” Plans call for the contract to be awarded in the third quarter of 2011 and the rigs to be delivered in the second half of 2014.

15 Feb 2011

CATERPILLAR EXPLORATION WELL IN NORWAY IS AN OIL DISCOVERY

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

12 Feb 2011

Keppel to deliver second DSSTM 38 deepwater rig ahead of schedule to Brazil

Keppel FELS Limited (Keppel FELS) is on track for an early and safe delivery of Alpha Star, the second of two DSSTM 38 semisubmersible rigs, to Brazil's Queiroz Galvão Óleo e Gás (QGOG). Keppel FELS was awarded a total of S$40,000 in safety bonuses from QGOG for the strong safety performance during the construction phase. The rig has been chartered .... [+ read more] by Petrobras for six years to support exploration and production activities offshore Brazil.

11 Feb 2011

West Alpha arrives at Westcon

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

10 Feb 2011

Well incident on Deepsea Atlantic last night

At 03.25 on Thursday morning a well incident was detected on the exploration rig Deepsea Atlantic. The incident was reported to the Petroleum Safety Authority Norway. Statoil will closely examine the incident and is dispatching its own personnel, and personnel from drilling operator Odfjell Drilling, to conduct investigations. The team will also determine the final classification of the incident. .... [+ read more] The incident led to the crew being mustered on board in accordance with regulations. Normalisation efforts on the rig commenced a half-hour later and the situation was quickly clarified. Work on the well has now been resumed. Deepsea Atlantic is exploring for Statoil close to the Gullfaks South field, where it is about to complete operations in connection with the gas and condensate discovery in well 34/10-53. This constitutes an independent exploration prospect unconnected to the main reservoir on the Gullfaks field. The well has been closed for seven days owing to bad weather conditions on the field. Normal procedures are followed after such an incident to ascertain any possible seepage in the well. When the blow-out preventer (BOP) was opened after the closure and mud circulated, gas was registered in the mud processing unit on the platform. The well control system was then immediately closed down in line with procedures. The gas in the well was circulated in a controlled manner and the second well barrier was thereby re-established. The well was drilled using conventional drilling technology in an area where there are not the same demanding reservoir and pressure conditions as on the main Gullfaks field. Pressure conditions during this drilling operation were in accordance with the calculations made in advance.

10 Feb 2011

Production and exploration rig chartered

Statoil has awarded Transocean a contract for hire of the Transocean Leader drilling unit to be used on our licenses on the Norwegian continental shelf. As operator of several licences Statoil has awarded a contract to Transocean for use of the semi-submersible Transocean Leader rig for drilling in Norway. Plans call for the rig to be used for production and exploration .... [+ read more] drilling on the Norwegian continental shelf during the contract period. “We are pleased with securing Transocean Leader for a new contract period. Chartering this rig will also contribute to Statoil's deepwater capacity being able to operate on water depths down to 1500 meters”, says newly appointed chief procurement officer in Statoil, Jon Arnt Jacobsen. The contract period is three years, starting in 2012, and includes a one-year option following the completion of the drilling programme. “The key to uphold present production level on the Norwegian continental shelf towards 2020 is enhanced recovery from existing fields, quick and efficient development of new fields and an active exploration programme. To implement these measures, it is crucial that we secure necessary rig capacity”, says executive vice president for Development & Production Norway, Øystein Michelsen. The Transocean Leader is a Aker H-4.2 self-propelled semi-submersible drilling unit capable of operating in harsh environments and water depths up to 4500 feet, built in 1987. The drilling unit has previously been chartered by Statoil for use on the Statfjord satellites in the North Sea and it is currently under a three-year contract with Statoil in the same area.

10 Feb 2011

Teak-1 exploration well discovers hydrocarbons offshore Ghana

Tullow Oil plc (Tullow) announces that the Teak-1 exploration well in the West Cape Three Points licence offshore Ghana has discovered approximately 73 metres of net hydrocarbons in two Campanian and three Turonian-aged reservoirs. The well was located 4.6 km northeast of the Mahogany-2 well, 2.7 km outside the Jubilee Unit boundary. In the shallower Campanian-aged reservoirs, the well intersected 6 .... [+ read more] metres of oil pay in the upper zone and 33 metres of gas pay with an underlying 15 metre 40 degree API oil leg, in the lower zone. In the deeper stratigraphic Turonian-aged reservoirs, the well intersected 14 metres of gas-condensate pay in two separate zones and 5 metres of 32 degree API oil pay in a deeper level. The up-dip combination structural and stratigraphic Campanian trap is potentially 50 sqkm in area and will be the subject of further appraisal activity. Interpretation of the potential extent of each of the deeper Turonian zones is ongoing. The Atwood Hunter rig drilled Teak-1 to a total depth of 3,170 metres in water depths of 868 metres. On completion of operations, the well will be suspended for future use and the rig will move to drill the Teak-2 well which is targeting Campanian and Turonian age reservoirs in a separate fault block between the Teak discovery and the Jubilee field. Tullow has a 22.896% interest in the West Cape Three Points licence and its partners are Kosmos Energy (Operator) and Anadarko Petroleum Corporation (30.875% each), the E.O.Group (3.5%), Sabre Oil & Gas Holdings Ltd (1.854%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

9 Feb 2011

Discovery close to Gullfaks

Statoil has found gas and condensate around two kilometres west of the Gullfaks South field in the middle sector of the North Sea. The size of the discovery is estmated at between 19 and 75 million barrels of recoverable oil equivalent. Plans call for tie-back of the discovery to existing infrastructure in the Gullfaks South area. “The discovery by .... [+ read more] Gullfaks confirms once again that infrastructure-led exploration is important and leads to finds with high profitability that can quickly come on stream,” says Gro Gunleiksrud Haatvedt, senior vice president for exploration on the Norwegian continental shelf (NCS). The discovery was made in the Rimfaks valley where drilling of well 34/10-53 S confirmed a column of around 300 metres in good-quality reservoir rocks. Gas was found in the Brent group while no hydrocarbons were discovered in the Statfjord group. The well was drilled to a vertical depth of 3,847 metres below sea level, and was concluded in the Lower Jurassic rocks of the Statfjord group. Water depth in the area is 136 metres. “We regard the area around Gullfaks South to be prospective and the find confirms our faith in the area,” says Haatvedt. “Even if the volumes are modest compared to the large discoveries previously made on the NCS, discoveries of this type are important in order to maximise the potential on the NCS. They help extend the lifetime of the installations.” The well has not been formation tested, but further data acquisition and sampling are being made to determine the hydrocarbon system and estimate contacts. The well was drilled by the Deepsea Atlantic drilling rig. After completing the data acquisition and permanently plugging the well the rig is to drill a sidetrack well to Opal, which is a prospect in the Middle Jurassic reservoir rocks (Brent group) located west of the Rimfaks valley in production licence 050B. The licensees of PL050 and PL050B are Statoil (operator, 70%) and Petoro (30%).

7 Feb 2011

Anadarko strikes gas at Tubarao well in Mozambique

Anadarko Petroleum Corporation (“Anadarko”) today announced the latest in a string of major deepwater natural gas discoveries off the coast of Mozambique. The Tubarão discovery well encountered more than 110 net feet (34 meters) of natural gas pay and no water in a high-quality Eocene-age reservoir that is separate and distinct from the hydrocarbon accumulations in Anadarko s three previous discoveries .... [+ read more] in the Offshore Area 1 of the Rovuma Basin. The discovery at the Tubarão prospect opens an entirely new play style, which has additional opportunities in Mozambique s Offshore Area 1, Anadarko Sr. Vice President, Worldwide Exploration Bob Daniels said. This is our fourth significant discovery in the offshore Rovuma Basin and further strengthens our confidence in our geologic and geophysical models of the basin. Our seismic imaging indicates Tubarão s areal extent could cover about 15,000 acres that will be better defined with appraisal drilling. In addition, we continue to safely enhance our drilling efficiencies, procedures and methodology in Mozambique, as we drilled this well in half the time of our first exploration wells. The Tubarão discovery well was drilled to a total depth of approximately 13,900 feet (4,237 meters) in water depths of approximately 2,950 feet (898 meters), approximately 18 miles (29 kilometers) off the Mozambique coast. The partnership plans to preserve the wellbore at Tubarão for potential utilization in future testing. Once operations are complete, the partnership plans to mobilize the rig to the previously announced Windjammer discovery, approximately 26 miles (42 kilometers) northeast of Tubarão, to begin a coring program that will be followed by appraisal drilling in the Windjammer, Barquentine, Lagosta complex.

26 Jan 2011

LUNDIN PETROLEUM SPUDS TELLUS EXPLORATION WELL IN PL338, OFFSHORE NORWAY

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 16/1-15 in PL338 has commenced. The well will target the Tellus prospect, which is situated immediately to the north of the Luno field. The main objective of well 16/1-15 is to test Jurassic/Triassic age sandstones and conglomerates in a separate fault segment north of the .... [+ read more] Luno Field. We estimate the Tellus prospect to contain gross unrisked prospective resources of 40 million barrels of oil equivalent (MMboe), which could prove additional volumes to the Luno development. The planned total depth is approximately 2,500 meters below mean seal level and the well will be drilled using the semi-submersible drilling rig Bredford Dolphin. Drilling is expected to take approximately 45 days. Lundin Petroleum is the operator of PL338 with 50 percent interest. Partners are Wintershall Norge ASA with 30 percent and RWE Dea Norge AS with 20 percent interest.

19 Jan 2011

EDC negotiating with Transocean to acquire Trident XX drilling rig

Eurasia Drilling Company Limited ("EDC" or the "Company" - LSE: EDCL) today announced that it is in negotiations with an affiliate of Transocean for the acquisition of the TRIDENT XX jack-up drilling rig presently operating in the Caspian Sea. If agreed, the acquisition from Transocean is anticipated to close by January 31, 2011 or shortly thereafter, with an estimated transaction value .... [+ read more] of US$ 260 million. The TRIDENT XX is a Keppel FELS CS Mod V cantilever Jack-up capable of operating in water depths to 350 feet and drilling to 26,000 feet.

17 Jan 2011

Pacific Bora Awarded Initial 3-year Contract with Chevron

Pacific Drilling is pleased to announce that the Pacific Bora has been contracted to Star Deep Water Petroleum Limited, a wholly owned Chevron subsidiary to work on the continued development of the Agbami Field in Nigeria. Total revenue from the contract is expected to be approximately $585million over the initial three year term. The rig is expected to mobilize to .... [+ read more] Nigeria in late February upon completion of client requested enhancements to facilitate completion activities. This represents Pacific Drilling’s second contract with a Chevron subsidiary, including the previously announced contract for the Pacific Santa Ana, which is contracted to provide the first commercial application of Dual Gradient Drilling. Dual gradient techniques use a pump or other method to reduce the hydrostatic head from the mudline to the surface to that of seawater. Pacific Drilling has two further ultra-deepwater drillships (Pacific Scirocco and Pacific Mistral) under construction at Samsung Heavy Industries, both of which are on target for on time delivery in March 2011 and May 2011 respectively, and are the subject of advanced discussions with various clients.

17 Jan 2011

Pacific Drilling secure initial three year contract for 'Pacific Bora'

Pacific Drilling is pleased to announce that the ‘Pacific Bora’ has been contracted to Star Deep Water Petroleum Limited, a wholly owned Chevron subsidiary to work on the continued development of the Agbami Field in Nigeria. Total revenue from the contract is expected to be approximately USD585million over the initial three year term. The rig is expected to mobilize to Nigeria .... [+ read more] in late February upon completion of client requested enhancements to facilitate completion activities. This represents Pacific Drilling’s second contract with a Chevron subsidiary, including the previously announced contract for the ‘Pacific Santa Ana’, which is contracted to provide the first commercial application of Dual Gradient Drilling. Dual gradient techniques use a pump or other method to reduce the hydrostatic head from the mudline to the surface to that of seawater. Pacific Drilling has two further ultra-deepwater drillships (‘Pacific Scirocco’ and ‘Pacific Mistral’) under construction at Samsung Heavy Industries, both of which are on target for on time delivery in March 2011 and May 2011 respectively, and are the subject of advanced discussions with various clients.

14 Jan 2011

14/10-3 Exploration Well Spud

Rockhopper Exploration plc (AIM: RKH), the North Falkland Basin oil and gas exploration company, announces that the 14/10-3 exploration well was spudded at 1700hrs GMT on 13 January 2011. 14/10-3 is located 8km North West of the Sea Lion 14/10-2 discovery well on Licence PL032, which Rockhopper operates and holds a 100% working interest in. The well is located .... [+ read more] on the undrilled northern lobe of the Sea Lion fan system. The well will also penetrate the distal, downdip portion of the newly-identified and underlying S2 fan body which has been mapped over an area of 42 sq. km. 14/10-3 is situated outside of the Sea Lion Discovery Area. Total depth is planned to be ca. 3,000 metres. Drilling operations are expected to take approximately 38 days and a further announcement will be made once drilling is completed. It is currently anticipated that, on completion of operations on 14/10-3, Rockhopper will drill 14/10-4, an appraisal well on the southern lobe of the Sea Lion fan system within the Discovery Area, before the rig is released.

10 Jan 2011

Successful Cormoran-1 exploration well offshore Mauritania

Dana Petroleum, the operator of the Cormoran-1 exploration well in Mauritania, in which Tullow Oil plc (Tullow) is a 16.20% partner, today issued the following press release: Dana Petroleum advises that the Cormoran-1 exploration well has been drilled to a total depth of 4,695 metres below sea level and has been plugged and abandoned as a gas discovery. Stabilised gas flow .... [+ read more] rates of between 22 and 24 million standard cubic feet per day (MMscfpd) were obtained during a test of one of the four separate gas columns encountered by the well. The Cormoran-1 exploration well is located in Block 7, offshore Mauritania. It lies approximately 2km to the south of the Pelican-1 gas discovery well, which was drilled in late 2003. The well was drilled by Dana Petroleum, as Operator of Block 7, using the Maersk Deliverer deep water semi-submersible drilling rig. Water depth at the well location is approximately 1,630m. The primary purpose of the Cormoran-1 well was to test the Cormoran prospect, which adjoins but lies at a greater depth than the Pelican discovery. A secondary exploration objective was the Petronia prospect, which lies beneath the Cormoran prospect. A further objective of the well was to provide appraisal information on the Pelican gas discovery. The Cormoran-1 well encountered generally thin but good quality, gas-bearing, sands within the Pelican Group at depths between 3,376m and 3,711m true vertical depth subsea (TVDSS). This interval comprised two gas columns, one in the Upper Pelican Group (3,376 to 3,420m TVDSS) and one in the Lower Pelican Group (3,691 to 3,711m TVDSS). Good quality, gas-bearing, sands were also encountered within the Cormoran prospect, in the gross interval from 4,351 to 4,471m TVDSS, and at the top of the Petronia prospect, in the gross interval from 4,660m to 4,695m TVDSS. Drilling was stopped at a depth of 4,695m TVDSS for operational reasons (elevated pore pressures). The well was still in gas-bearing reservoir section at this depth. A drill stem test was carried out across a 33m interval in the Lower Pelican Group (3,679 to 3,712 TVDSS). Stabilised flow rates of up to 22 to 24 MMscfpd were obtained on a 32/64" choke, the flow rate being constrained by the need to avoid sand production. Substantially higher flow rates could have been achieved were it not for this operational constraint. Following the DST, the Cormoran-1 well was plugged and abandoned, this being done in such a way that the well could be re-entered in the future.

10 Jan 2011

Tweneboa-3 appraisal well confirms Greater Tweneboa Area resource potential

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

4 Jan 2011

Cairn secures rigs for 2011 Greenland Exploration

Cairn has secured two state of the art dynamically positioned drilling vessels for its 2011 dual rig exploration programme offshore Greenland. The “Leiv Eiriksson”, a fifth generation semi-submersible drilling rig and the “Ocean Rig Corcovado”, a sixth generation drillship, have been contracted to operate in the 2011 drilling season on Cairn’s offshore Greenland exploration programme. Both drilling vessels are operated .... [+ read more] 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.

4 Jan 2011

Cairn secures rigs for 2011 Greenland Exploration

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

3 Jan 2011

Noble Corporation Updates Noble Jim Day Contract Status

Noble Corporation (NYSE: NE) today reported that Marathon Oil Company ("Marathon") has provided notice that it is terminating the drilling contract for the ultradeepwater semisubmersible drilling rig Noble Jim Day. Marathon's stated reason for the termination was that the rig had not been accepted by Marathon by December 31, 2010. Noble believes the rig is ready to commence operations and should .... [+ read more] have been accepted by Marathon. The contract was for four years and represented approximately $752 million in contract backlog to Noble. "We are disappointed by Marathon's actions," said David W. Williams, Chairman, President and Chief Executive Officer, Noble Corporation. "Fortunately, the Noble Jim Day is one of the most capable rigs in existence and there are already a number of potential customers interested in a unit of this caliber." Noble also reported that an independent third-party has affirmed the rig's readiness. The Company also confirmed that the unit's subsea system, including the BOP, has received its certificate of compliance.