Infield Rigs News

21 Dec 2012

Statoil makes third discovery offshore Tanzania

Statoil today announces that the Lavani-2 exploration and appraisal well has resulted in a new natural gas discovery offshore Tanzania. The Statoil-operated Lavani-2 well successfully appraised the Lavani-1 discovery reservoir in the Palaeogene. When deepening the well to the second target, a separate and significant gas bearing reservoir in the Cretaceous was encountered. Statoil and its co-venturer ExxonMobil Exploration and .... [+ read more] Production Tanzania Limited will announce updated total volumes in Block 2 next year. An increase in the upside potential of the Block is expected following further evaluations of the well. The Lavani-2 discovery is the venture's third discovery in 2012. "These three discoveries continue to support our confidence in the Block 2 potential in Tanzania. The Lavani-2 well tested the deeper Saffron target and this new discovery looks promising," says Nick Maden, senior vice president in Exploration International in Statoil. The discovery is important for Statoil's international growth and demonstrates how Statoil's exploration strategy of focusing on high-impact opportunities is paying off. The Lavani-2 well also provides information that will be incorporated into models to help determine the optimal development concept for a possible natural gas development in Tanzania. "The Lavani-2 is the third well in an ambitious drilling campaign of four wells within one year. The next well will be the appraisal of the Zafarani discovery. In parallel the venture is acquiring new 3D seismic to help us identify additional targets in Block 2," adds Maden. "We are pleased to hear about additional gas resources in Block 2 and eagerly awaiting for further information," says the Minister for Energy and Minerals, Hon. Prof. Sospeter Muhongo. The Lavani-2 well was drilled to a total depth of 5270 metres in water depths of 2580 metres. The well was drilled by Ocean Rig Poseidon. The Lavani-2 well is located about 5 kilometres southeast of the Lavani-1 discovery well and 20 kilometres south of the Zafarani-1 well. Statoil operates the licence on Block 2 on behalf of Tanzania Petroleum Development Corporation (TPDC) and has a 65% working interest, with ExxonMobil Exploration and Production Tanzania Limited holding the remaining 35%. Statoil has been in Tanzania since 2007, when it was awarded the licence for Block 2.

16 Dec 2012

Jaguar-1 exploration well update

Drilling operations at the Jaguar-1 well in the Georgetown Block, Guyana, have ended and the well will be plugged and abandoned at a depth of 4,876 metres, without reaching the primary objective. The decision to stop drilling at this point was unanimously agreed by all partners based on safety criteria and was taken after reaching a point in the well where .... [+ read more] the pressure design limits for safe operations prevented further drilling to the main objective. Jaguar-1 was a high pressure, high temperature well which was spudded in February 2012 using the Atwood Beacon rig. Whilst the primary Late Cretaceous objective was not reached, samples of light oil were successfully recovered from two Late Cretaceous turbidite sands above the primary objective.

10 Dec 2012

Spud South Kecapi-1 Exploration Well

Salamander announces the commencement of its exploration drilling programme in the North Kutei basin, East Kalimantan, Indonesia with the spudding of the South Kecapi-1 DIR and DIRA exploration wells in the Bontang PSC. Salamander has a 100% operated interest in the Bontang PSC. The South Kecapi-1 DIR well will be drilled to a depth of approximately 2,450 metres total vertical .... [+ read more] depth sub sea (‘TVDSS’). On completion it will then be sidetracked approximately 1.5 km to the west with the South Kecapi-1 DIRA being drilled to a depth of approximately 2,100 metres TVDSS. The South Kecapi-1 DIR/DIRA wells are targeting gas and oil pay in a series of stacked Pliocene – Upper Miocene sandstone reservoirs. The combined mean pre-drill estimate of prospective recoverable resources is approximately 275 Bcf and 20 MMbo. The wells will be drilled by the Ocean General semi-submersible rig in a water depth of 388 metres. On completion of the South Kecapi-1 DIR/DIRA wells the rig will move to the South East Sangatta PSC to test the North Kendang prospect.

4 Dec 2012

Well result – Zaedyus-2, offshore French Guiana

Following speculation in the French press, Tullow Oil plc (Tullow) announces that the Zaedyus-2 appraisal well (GM-ES-2), offshore French Guiana, has completed drilling. The well, drilled 5km up-dip from the Zaedyus-1 well, encountered a total of 85 metres of reservoir quality sands with oil shows in several objectives but did not encounter commercial hydrocarbons at this location. Results of drilling, logging .... [+ read more] and sampling to date have shown that the reservoirs at this location are not in communication with Zaedyus-1. Integration of information obtained from the two wells with the 3D seismic data suggests the reservoirs are geologically separated from Zaedyus-1. As Zaedyus-2 is up-dip and disconnected from Zaedyus-1, this result has no bearing on the bulk of the undrilled prospectivity which is located downdip of Zaedyus-1. Future drilling on the Zaedyus fan system should therefore target the significant upside in the Zaedyus down-dip prospects and the down-dip elements of Zaedyus Deep. The Zaedyus-2 well was drilled in the Guyane Maritime licence using the Stena DrillMax Dynamically Positioned Drillship. The well was drilled in water depths of 1,894 metres and has been drilled to a depth of 6,200 metres and logging operations are ongoing. The second well in this four-well programme is Priodontes-1, targeting an adjacent prospect within the same Cingulata fan system, and is expected to commence drilling in early December. Tullow has a 27.5% stake in the Guyane Maritime licence and is partnered by Shell, who are operator and hold a 45% stake, Total (25%) and Northpet (2.5%), a company owned 50% by Northern Petroleum plc and 50% by Wessex Exploration plc.

4 Dec 2012

Keppel FELS delivers jackup rig early to new Mexican customer

Keppel FELS has delivered Primus, a KFELS B Class jackup rig, to offshore Mexican oil field services company, Integradora de Servicios Petroleros Oro Negro (Oro Negro), seven days early and with a perfect safety record. Named earlier today at Keppel FELS, Primus was officially delivered on 16 November 2012. It is the first of two rigs by Keppel FELS for .... [+ read more] Oro Negro after the Mexican company purchased them from Jasper Investments. Primus is Oro Negro's first jackup rig and is suited for deployment in various parts of the world including the Gulf of Mexico.

27 Nov 2012

Brugdan II well temporarily suspended

Statoil and its partners ExxonMobil and Atlantic Petroleum have decided to temporarily suspend operations on the Brugdan II well offshore the Faroe Islands. The Brugdan II well has drilled into the sub-basalt section, but the primary objective has not yet been reached. The decision to suspend the drilling is based on the expected bad weather as we enter the winter .... [+ read more] season. The Faroese authorities have authorised a suspension until end 2013. The well is located around 80 km offshore from the Faroe Islands and was spud in June 2012. It has been drilled with the COSL Pioneer semi-submersible rig in a water depth of around 450 meters. The Brugdan II well is the second exploration well that has been drilled in licence 006 which covers an area of approximately 579 square kilometres. Statoil has been in the Faroe Islands since 2000 and holds a significant acreage position with 6 operated licences. The licences are all sub-basalt and have a varied geology within different plays. The position in the Faroe Islands is in line with the company's exploration strategy of early access of scale and establishing a leading position in frontier areas. Statoil Færøyene AS has 50% equity in the Brugdan licence. The partners are partners ExxonMobil Exploration and Production Faroe Islands Ltd 49% and Atlantic Petroleum P/F 1%. The Brugdan II well is the 8th exploration well drilled in Faroese waters since 2001.

27 Nov 2012

FOGL complets Scotia well

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

19 Nov 2012

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

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

15 Nov 2012

Pacific Drilling Announces Contract for the Pacific Khamsin

Pacific Drilling S.A. (NYSE: PACD) announced today that its ultra-deepwater drillship the Pacific Khamsin has been awarded a contract by a wholly-owned indirect subsidiary of Chevron Corporation for operations in West Africa. The minimum duration of the contract is for an initial two-year term, with contract commencement expected by end of the third quarter of 2013. The contract provides for an .... [+ read more] option, to be exercised at the client’s discretion prior to shipyard delivery of the drillship, which could result in an additional year of contract term. Estimated maximum contract revenues related to the initial two-year term, including mobilization and demobilization, are expected to be approximately $527 million, bringing Pacific Drilling’s total contract backlog as of November 15, 2012, to approximately $3.4 billion. Pacific Drilling CEO Chris Beckett stated, “We are proud to announce the further expansion of our relationship with subsidiaries of Chevron Corporation to this fourth drillship. This contract exemplifies our commitment to providing quality drilling operations for our clients and allows us to leverage the operations support infrastructure which we have already developed in the region.” Pacific Khamsin is scheduled for delivery by Samsung Heavy Industries in Korea in the second quarter of 2013. The drillship will be capable of operating in water depths of up to 12,000 feet and drilling wells up to 40,000 feet deep.

13 Nov 2012

NW-1 Exploration Well Update

The B8/38-8 exploration well targeting the Northwest Terrace prospect (“NW-1”) has been drilled to TD. The NW-1 well was targeting a small fault terrace structure located north of the Bualuang field. The well reached a TD of 1,792 metres true vertical depth sub-sea (“TVDSS”) and a program of wire-line logging, pressure and liquid sampling undertaken. The well encountered thin oil-bearing early .... [+ read more] Miocene T2 sandstones below 1,725 metres TVDSS. Well-developed sections of both the T5 and T4 mid-Miocene sandstones were found to be water-wet. The initial conclusion is that the sand-rich section of the T5 has led to leakage across the bounding fault at this location. The well is currently being plugged and abandoned as a sub-commercial oil discovery.

7 Nov 2012

LUNDIN PETROLEUM COMMENCES TEMBAKAU EXPLORATION WELL, OFFSHORE PENINSULA MALAYSIA

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that it has commenced the fourth well in its 2012 Malaysian drilling campaign with the spud of Tembakau-1 exploration well in PM307 Block, offshore east coast Peninsula Malaysia. The well will target hydrocarbons in Oligocene and Miocene aged sands in a low-relief structure 50 km to the northwest of the Bertam-2 .... [+ read more] oil discovery made by Lundin Petroleum in 2011. Tembakau-1 is a vertical well to be drilled by the jackup rig West Courageous to a depth of 1,650 metres in approximately 80 metres water depth. The drilling of the well is expected to take two to three weeks. Lundin Petroleum holds 75 percent interest in PM307 through its subsidiary Lundin Malaysia BV. Lundin Malaysia BV's partner is PETRONAS Carigali Sdn Bhd with 25 percent interest. Lundin Malaysia BV operates six blocks in Malaysia, namely PM307, PM308A, PM308B, SB303, SB307 & SB308.

25 Oct 2012

LUNDIN PETROLEUM COMPLETES OFFSHORE PENINSULA MALAYSIA EXPLORATION WELL

Lundin Petroleum AB (Lundin Petroleum) has completed the Merawan Batu-1 exploration well in Block PM308B, offshore east coast Peninsula Malaysia. The exploration well targeted hydrocarbons in Oligocene aged sands in a faulted anticline in an undrilled area 50 km to the west of the Janglau oil discovery made by Lundin Petroleum in 2011. The objective reservoirs were successfully penetrated but .... [+ read more] proved to be water-bearing. The well will be plugged and abandoned as a dry hole. The jackup rig West Courageous will now move to drill the Tembakau prospect in Block PM307. Lundin Petroleum holds 75 percent interest in PM308B through its subsidiary Lundin Malaysia BV. Lundin Malaysia BV's partner is PETRONAS Carigali Sdn Bhd with 25 percent interest. Lundin Malaysia BV operates six blocks in Malaysia, namely PM307, PM308A, PM308B, SB303, SB307 & SB308.

24 Oct 2012

Keppel FELS delivers Safin’s first KFELS B Class jackup rig

Keppel FELS Limited (Keppel FELS) has delivered Paradise 400, a high-specification KFELS B Class jackup rig to Safin Gulf FZCO (Safin) ahead of schedule and with a strong safety record. The rig is a refurbishment and upgrade of a KFELS B Class jackup rig that Keppel FELS purchased in 2011. Developed by Keppel's jackup rig design arm, .... [+ read more] Offshore Technology Development, the KFELS B Class rig is able to operate in water depths of 400 ft with a drilling depth of 30,000 ft. It is equipped with a full 15,000 psi BOP system, 70-feet cantilever outreach, with upgraded mud pit storage capacity of 4,000 bbls and accommodation for up to 150 personnel.

24 Oct 2012

RWE Dea Norge secures rig capacity for Titan drilling in 2013

RWE Dea Norge AS, a subsidiary of the German oil and gas company RWE Dea AG, has signed an agreement with Dolphin Drilling AS to use the Bredford Dolphin rig, in cooperation with three other oil companies. For RWE Dea Norge the contract entails full rig capacity in the years ahead for the planned drilling program in the production license (PL) .... [+ read more] 420 in the North Sea. The company is the operator and holds 30% interest in the license. “Having secured the rig capacity for Titan in 2013 is an important milestone to push the development and operation of the field in the following years,” says Hans-Joachim Polk, Managing Director of RWE Dea Norge. Bredford Dolphin will be used to drill an important appraisal well at Titan towards the end of 2013 to confirm the size of the Titan discovery. RWE Dea Norge previously drilled a well at Titan and preliminary estimates of the discovery are 12 million cubic metres (recoverable) oil equivalents. The company is also planning another exploration well in early 2014 with the Leiv Eiriksson rig. RWE Dea is optimistic that the PL420 license will gain significant value. The rig agreement with Dolphin Drilling has been concluded with Lundin, Noreco and Repsol, and is coordinated by AGR. The contract is for a total of eight wells over a period of 570 days, with the option of an extension and a minimum of five further wells.

22 Oct 2012

Spudding of Bualuang B8/38-8 (NW-1) Exploration Well

Salamander Energy plc announces the start of its exploration campaign in the Greater Bualuang area, offshore Gulf of Thailand. The B8/38-8 (NW-1) well is testing one of a number of fault terraces to the north west of the Bualuang oil field. Resource potential of 10 – 15 MMbo has been identified in a cluster of prospects to the north .... [+ read more] of the field. The B8/38-8 (NW-1) well will be drilled by the Atwood Mako jack up rig that is under long term contract to the Group and recently concluded a short drilling programme from Bualuang Alpha Platform. B8/38-8 (NW-1) is expected to be a 14 day well and is the first of two exploration wells that are currently envisaged as part of the immediate programme. The Bualuang Bravo Platform construction is complete and the load-out, sail-away, hook up and commissioning will commence later this month. Once installed, the rig will move onto the Bravo Platform for a 16 well development drilling programme, which will lead to a sharp rise in production from the Bualuang field in 2013.

11 Oct 2012

LUNDIN PETROLEUM COMPLETES EXPLORATION WELL ON THE ALBERT PROSPECT IN NORTHERN NORTH SEA

Lundin Petroleum AB (Lundin Petroleum), through its wholly owned subsidiary Lundin Norway AS (Lundin Norway), has completed the drilling of exploration well 6201/11-3 in PL519. The well targeted the Albert prospect, which is situated 65 km north west of the Snorre Field in the northern North Sea, offshore Norway. The main objective of well 6201/11-3 was to test Cretaceous .... [+ read more] and Triassic age sandstones of a multiple target structure. The well encountered oil in thin Cretaceous reservoir sequence at the predicted level for the primary target. The thin thickness and uncertain distribution of the reservoir do not give a basis for resource estimation at this stage. Further geophysical and geological studies are required to clarify the potential in the discovery. The Triassic secondary reservoir was tight without movable hydrocarbons. A minor column of movable hydrocarbons were also encountered in a Palaeocene secondary target. The semi-submersible drilling rig Bredford Dolphin drilled the well to a total depth of 2,975 metres below mean sea level and in a water depth of 382 metres. Ashley Heppenstall, President and CEO of Lundin Petroleum comments; "The existence of oil bearing Cretaceous reservoir in the Albert well is encouraging. In the event we can find thicker Cretaceous reservoir sections over this large structure there remains potential for commercial discoveries in this area." The rig will next be utilized by Wintershall for one well before it returns to Lundin Petroleum to drill an appraisal well on Lundin Petroleum's discovery Johan Sverdrup in PL501. Lundin Petroleum is the operator of PL519 with 40 percent interest. Partners are Bayerngas Norge AS, Norwegian Energy Company ASA and Spring Energy with 20 percent interest each.

2 Oct 2012

Saudi Aramco set to deploy its first KFELS Super B Class jackup rig after early delivery from Keppel FELS

Keppel FELS Limited (Keppel FELS), has delivered to Aramco Overseas Company B.V., a subsidiary of Saudi Aramco, its first KFELS Super B Class jackup drilling rig. Named SAR 202, the rig was delivered 13 days ahead of schedule, on budget and with a perfect safety record on 2 October 2012. The vessel has been transported to Saudi Arabia for .... [+ read more] final preparations and is on track for deployment in offshore Saudi Arabia. Customised to Saudi Aramco's requirements, SAR 202 is equipped with a high capacity hook load of two million pounds for operations in high temperature and high pressure wells. Capable of drilling down to 30,000 feet, the proprietary KFELS Super B Class design is a global benchmark for ultra deep well drilling rigs.

2 Oct 2012

Saudi Aramco set to deploy its first KFELS Super B Class jackup rig after early delivery from Keppel FELS

Keppel FELS Limited (Keppel FELS), has delivered to Aramco Overseas Company B.V., a subsidiary of Saudi Aramco, its first KFELS Super B Class jackup drilling rig. Named SAR 202, the rig was delivered 13 days ahead of schedule, on budget and with a perfect safety record on 2 October 2012. The vessel has been transported to Saudi Arabia for .... [+ read more] final preparations and is on track for deployment in offshore Saudi Arabia. Customised to Saudi Aramco's requirements, SAR 202 is equipped with a high capacity hook load of two million pounds for operations in high temperature and high pressure wells. Capable of drilling down to 30,000 feet, the proprietary KFELS Super B Class design is a global benchmark for ultra deep well drilling rigs.

25 Sep 2012

FOGL spuds Scotia well in Falkland Islands

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

25 Sep 2012

Scotia - Fl 31/12-01 Well Spud

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

20 Sep 2012

Atwood Mako Rig Spudded First Well

Salamander Energy plc announces that the Atwood Mako jack up rig (the “Mako”) has arrived on location and commenced development drilling from the Bualuang Alpha platform on the Group’s B8/38 licence in the Gulf of Thailand. The Mako is on long term contract, and will initially complete a short development drilling programme on the Bualuang Alpha Platform. Salamander will then .... [+ read more] be using the rig to drill two exploration prospects on its acreage in the Greater Bualuang area ahead of an extended development drilling campaign from the Bualuang Bravo platform from the end of October.

20 Sep 2012

Drilling in Beaufort Sea Approved

Earlier today, the Bureau of Safety and Environmental Enforcement (BSEE) announced that Shell is now permitted to move forward with initial drilling activities in the Beaufort Sea. The approval of Shell’s Beaufort Sea Application for Permit to Drill (APD) is another major milestone achieved and clears the way for the Kulluk to begin drilling offshore Alaska. In the days to come, .... [+ read more] the Kulluk will connect to anchors that have been pre-staged in the Beaufort Sea and drilling will commence. The arrival of the Beaufort Sea APD signals continued progress for Shell’s 2012 drilling program and coincides with the Noble Discoverer’s re-entry into the Chukchi Sea. In the weeks ahead we look forward to operating safely and responsibly, putting Americans to work and adding to Shell’s long, successful history of drilling offshore Alaska.

17 Sep 2012

Fairmount Sherpa Tows Atwood Condor from Mauritius to Trinidad

Fairmount Marine’s tug Fairmount Sherpa has delivered rig Atwood Condor fast and safely to Port of Spain, Trinidad. The semi-submersible rig was towed from Port Louis, Mauritius, over a distance of 8,100 nautical miles with an average speed of 8.5 knots. Before crossing the Atlantic Ocean Fairmount Sherpa and her tow made a planned four days stop-over at Walvis Bay, Namibia. .... [+ read more] During this stop-over the Fairmount Sherpa performed several cargo and passengers runs between the rig and the port.

17 Sep 2012

FOGL announces gas discovery with Loligo well

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

10 Sep 2012

Kabeljou-1 well returns poor results in Namibia

Chariot Oil & Gas Limited (Chariot), the Africa focused oil and gas exploration company, confirms that the Kabeljou-1 (2714/6-1) exploration well in Southern Block 2714A in the Orange basin offshore Namibia has reached a total depth of 3,150 metres TVDss and logging operations were conducted over the weekend. The well was drilled by the ‘Ocean Rig Poseidon’ drillship. Preliminary logging results .... [+ read more] indicate that no commercial hydrocarbons were found and the well will be plugged and abandoned. All pre-drill reservoir targets were evaluated. The well intersected the Nimrod delta as planned, although the reservoir was less developed than anticipated at this location. A comprehensive evaluation programme was conducted to further understand the stratigraphy, lithology and the nature of the formation fluids in this remote area. Detailed analyse will now by undertaken on the data collected and this information will be used to calibrate the existing data set. A resource update of the remaining prospectivity in the block will be provided once this evaluation has been completed.

10 Sep 2012

Drillship Discoverer Moves Off Burger Well

As a precautionary measure and in accordance with our approved Chukchi Sea Ice Management Plan, Shell has made the decision to temporarily move off the Burger-A well to avoid potentially encroaching sea ice. Once the ice moves on, the Noble Discoverer will re-connect to anchors and continue drilling. Shell uses a combination of satellite images, radar and on-site reconnaissance to monitor .... [+ read more] ice movement.

9 Sep 2012

Shell begins drilling in the Chukchi Sea

Shell is pleased to announce today, September 9 2012, that crews aboard the Noble Discoverer began drilling at Shell’s “Burger” prospect in the Chukchi Sea. It’s the first time a drill bit has touched the sea floor in the U.S. Chukchi Sea in more than two decades. Today marks the culmination of Shell’s six-year effort to explore for potentially significant .... [+ read more] oil and gas reserves, which are believed to lie under Alaska’s Outer Continental Shelf. In the days to come, drilling will continue in the Chukchi Sea, and we will prepare for drilling to commence in the Beaufort Sea. We look forward to continued drilling progress throughout the next several weeks and to adding another chapter to Alaska’s esteemed oil and gas history. We’re proud to be offshore Alaska, and we’re extremely proud of the preparation we’ve put in place to do it right.

4 Sep 2012

Hurricane appraisal well successful test results

Ithaca Energy Inc. announces that it has completed a successful drill stem test ("DST") on the Andrew sandstone interval in the Hurricane appraisal well, 29/10b-8, The DST achieved a gross maximum flow rate of approximately 24 million standard cubic feet of gas per day ("MMscf/d") with associated condensate of 1,200 barrels per day ("bbl/d") from a 44/64-inch fixed choke. The wellbore .... [+ read more] will now be suspended as a future Andrew reservoir production well with the capability of also producing from the Rogaland reservoir. Well 29/10b-8 was drilled to appraise sands in the eastern lobe of the Hurricane structural closure, located in the Company's Greater Stella Area ("GSA") of the UK Central North Sea. The well intersected 32 feet of Eocene Rogaland sandstone with an average porosity of 28% over the net sands. A full core of the Rogaland reservoir section was extracted. Fluid samples and downhole pressure data have confirmed the presence of liquid rich gas throughout the interval; the samples indicate a condensate-gas ratio ("CGR") of between 60 and 110 barrels of condensate per MMscf. Sufficient data was obtained to remove the need to perform a well test on this interval. Analysis of pressure data indicates the hydrocarbon-water contact is likely to be the same as that in the Hurricane discovery well, 29/10-4Z (located in the western lobe of the structure), at 9,438 feet True Vertical Depth Subsea. The well also intersected 20 feet of Palaeocene Andrew sandstone reservoir, similar in nature and thickness to that observed in the main Andrew sandstone reservoir of the Stella field, approximately 10 kilometres east of Hurricane. The reservoir is of good quality, similar to that of Stella with average porosity of 26% over the net sands, and is considered to potentially be part of a more extensive Andrew sand unit in the area. During the main flow period lasting approximately 24 hours, the Andrew interval achieved an average gross flow rate of approximately 17 MMscf/d with associated condensate of 870 bbl/d (52 degrees American Petroleum Institute ("API") Gravity) from a half inch choke. A gross maximum flow rate of 24 MMscf/d with associated condensate of 1,200 bbl/d was also achieved, with the full production potential of the well being limited by surface equipment. The well will now be suspended for future potential use as a production well for the Andrew reservoir, with the capability of also being used for future production from the Rogaland reservoir. Nick Muir, Chief Technical Officer, commented: The successful results of the Hurricane appraisal well have clearly demonstrated the significant potential of the Andrew reservoir play fairway in the Company Greater Stella Area. A work programme has already been launched to assess the development options and ultimately recoverable volumes for Hurricane, both in terms of the Rogaland and Andrew reservoirs, and the optimal solution for its integration into the ongoing development of the nearby Stella and Harrier fields; this will include the likely use of the current well as a producer. All the major contracts for the Stella development have now been awarded and the next key milestone will be the selection of the yard in which the modification works will be performed on the FPF-1 floating production unit." The well was drilled using the WilHunter enhanced pacesetter semi-submersible rig, owned by Awilco Drilling plc and managed by the services of Applied Drilling Technology International ("ADTI"). The Joint Venture partners in the Ithaca operated Block 29/10b (Hurricane) are Ithaca Energy (UK) Ltd (54.66%), Dyas UK Ltd (25.34%) and Petrofac Energy Developments UK Limited (20%).

30 Aug 2012

Approval to Begin Initial Drilling Offshore

The Department of Interior has approved preparatory operations in non-oil-bearing zones in the Chukchi Sea. The Administration’s decision to approve initial drilling into non-oil-bearing zones in the Chukchi Sea reflects the national importance of exploring the energy resource offshore Alaska. Once the Noble Discoverer drill ship reaches its drill location, it will connect with anchors that have been pre-staged in .... [+ read more] the Chukchi Sea and work will commence. Shell has dedicated more than six years to gain the confidence and trust of regulators and to earn to the right to begin this historic operation. We appreciate the effort the Department of Interior has made to understand, scrutinize, and support this project of national significance. In the weeks ahead we look forward to operating safely and responsibly, putting Americans to work and finding out even more about the oil and gas reserves that are believed to lie under Alaska’s Chukchi Sea.

27 Aug 2012

Drillship Discoverer Departs Dutch Harbor

On August 25, 2012, the drillship Noble Discoverer departed Dutch Harbor for the waters of the Chukchi Sea. This activity marks another positive step forward in delivering on Shells 2012 Chukchi Exploration Plan. The Discoverer will steam north to Shell’s Burger prospect, where mooring anchors have already been placed. .... [+ read more]

27 Aug 2012

New oil discovery on Utsira High

Statoil has made an oil discovery in the Geitungen prospect on Utsira High in the North Sea together with partners Petoro, Det norske oljeselskap and Lundin. Exploration well 16/2-12 drilled by the drilling rig Ocean Vanguard has proven a 35 metre oil column in a high quality reservoir dating from the Jurassic period. Statoil estimates the volumes in Geitungen to be .... [+ read more] between 140 and 270 million barrels of recoverable oil equivalents (o.e.). Oil was also proven in the basement rocks. This is regarded as a possible upside in connection with the development of the area/discovery. "A new oil discovery in the Johan Sverdrup area, in the mature part of the North Sea reinforces Statoil's faith in the exploration potential of the Norwegian continental shelf, and demonstrates that we deliver on our strategy of revitalising the NCS with high value barrels," says Gro Haatvedt, senior vice president exploration Norway in Statoil. Geitungen was drilled approximately three kilometres north of the Johan Sverdrup discovery and was defined as a separate prospect in the licence PL 265. Well data indicate that there probably is communication between the two discoveries. "The Geitungen discovery will be included in the on-going development work for the Johan Sverdrup field. The discovery should therefore be seen in relation with the on-going appraisal program in Johan Sverdrup to narrow down the volume range and uncertainty", says Øivind Reinersten, Statoil VP for Johan Sverdrup field development. There is an extensive appraisal program going on in the Johan Sverdrup discovery, both in PL265 operated by Statoil and PL501 operated by Lundin. Statoil as pre-unit operator plans to communicate a volume range for the Johan Sverdrup pre-unit at a later stage. "Statoil aims to capture the full potential in the greater Utsira High area. In APA2011* we secured new promising acreage both north and south of Johan Sverdrup. We are currently working to improve seismic imaging of the greater Utsira High and have ambitious drilling plans with about 8-12 wells scheduled for 2012-2014", says Haatvedt. Following completion of well 16/2-12, the Ocean Vanguard drilling rig will move to Johan Sverdrup to drill two appraisal wells in the central and southern parts of PL 265. Well 16/2-12 is the eighth well in production licence 265. The well was drilled to a vertical depth of 2045 metres below sea level at a sea depth of 115 metres. Statoil is operator for production licence PL265 with an ownership share of 40% interest. The licence partners are Petoro AS (30%), Det norske oljeselskap ASA (20%) and Lundin Norway AS (10%).

25 Aug 2012

QGOG Constellation Announces the Arrival of the Ultra-deepwater Drillship, Amaralina Star, to Brazil

QGOG Constellation announces the arrival to Brazil of the ultra-deepwater drillship Amaralina Star on August 25, to be operated by its subsidiary, Queiroz Galvão Óleo e Gás (QGOG). The unit was built to operate in ultra-deepwaters to water depths of up to 10,000 feet and to drill wells depths of up to 40,000 feet. It will be able to operate in .... [+ read more] the Brazilian pre-salt area. The Amaralina Star incorporates the highest technological standards and will contribute to expanding and diversifying QGOG’s expertise in ultra-deepwater drilling. QGOG differentiates itself through deploying cutting-edge technology and a specialized and well-trained workforce. “Operating the Amaralina Star, a state of the art ultra-deepwater rig, is a key milestone for the Company, as it will be the first drillship we will operate, expanding our know-how in the area of offshore operations”, said QGOG President Leduvy Gouvea. The Amaralina Star was built by the Samsung Heavy Industries shipyard, located in South Korea. The shipyard is also currently building the Laguna Star drillship, which belongs to QGOG Constellation and will be operated by QGOG. The two units have been chartered to Petrobras under a six-year contract, with options to renew for six additional years. Drilling services will be provided by QGOG.

25 Aug 2012

BP makes two gas discoveries in Egypt's Nile Delta

BP Egypt today announced the Taurt North and Seth South gas discoveries in the North El Burg Offshore Concession, Nile Delta. These are the fourth and fifth discoveries made by BP in the concession following Satis-1 and Satis-3 Oligocene deep discoveries and Salmon-1 shallow Pleistocene discovery. The two wells were drilled by IEOC on behalf of concession operator BP, using .... [+ read more] Scarabeo IV rig in water depths of 110 and 78 meters respectively. The wireline logs, fluid samples and pressure data confirmed the presence of gas in one Pleistocene interval in Taurt North and two Plio-Pleistocene intervals in Seth South. Options to tie both discoveries to nearby existing infrastructure are being studied. Hesham Mekawi, President and General Manager of BP Egypt stated, "The discoveries show our commitment to develop the remaining potential of the shallow reservoirs within the Nile Delta and make the best use of the existing infrastructure. 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%).

14 Aug 2012

Hurricane well proceeding to drill stem test

Ithaca Energy Inc. announces that operations at the Hurricane appraisal well, 29/10b-8, which lies within the Company's Greater Stella Area in the UK sector of the Central North Sea are now proceeding to a Drill Stem Test ("DST"). The well has been drilled to a total measured depth of 10,779 feet to appraise hydrocarbon bearing sands in the eastern lobe .... [+ read more] of the Hurricane structural closure and logs indicate that the well has encountered hydrocarbons (possibly liquid rich gas) in both the Rogaland and Andrew sands. Pressure and fluid sampling has been undertaken across both reservoir sand intervals. An initial DST will be conducted over the Andrew sand interval. A further update will be issued when the DST results from the Andrew formation become available. The Joint Venture partners in the Ithaca operated Block 29/10b (Hurricane) are Ithaca Energy (UK) Ltd (54.66%), Dyas UK Ltd (25.34%) and Petrofac Energy Developments UK Limited (20%).

13 Aug 2012

Talland Navigation orders newbuild jackup from COSCO (Dalian)

The board of directors of COSCO Corporation (Singapore) Limited (COSCO) wishes to announce that COSCO (Dalian) Shipyard Co, Ltd., a subsidiary of COSCO’s 51% owned subsidiary, COSCO Shipyard Group Co. Ltd., has secured a USD170 million contract from Talland Navigation Limited Corporation, a subsidiary of Foresight Limited (London) to build one jackup drilling rig based on the LeTourneau Super 116E design. .... [+ read more] The rig will be built to ABS classification, with notation A1 and will be a self-elevating unit. The unit will be capable of drilling to depths of 30,000 feet whilst operating in waters up to 350 feet deep. The rig is scheduled to be delivered in the first quarter of 2015.

6 Aug 2012

FOGL spuds Loligo prospect in Falkland Islands

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

6 Aug 2012

Commencement of Loligo well operations

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

2 Aug 2012

Ophir strikes gas with Papa-1 well

Ophir Energy plc (Ophir) announces that the Papa-1 well has made the first Cretaceous gas discovery outboard of the Rufiji Delta in Block 3, offshore Tanzania and is the sixth consecutive discovery by Ophir offshore Tanzania. Papa-1 is located ca. 100km in Block 3, offshore Tanzania; 53km south east of the earlier Pweza-1 discovery. The well spudded on 29th May 2012 .... [+ read more] in 2,186m of water and was drilled by the drillship ‘Deep Sea Metro 1’ to a total depth of 5,544m subsea in 57 days. Papa-1 represents the first exploration test of Upper Cretaceous Intraslope play outboard of the Rufiji Delta and the first well to be drilled in Block 3. The well was designed to evaluate sandstones of Campanian and Albian age within the structural Papa prospect. Papa-1 encountered an 89m gas bearing column in interbedded, Campanian sandstones. Ophir management's preliminary analysis of the discovery suggests an in place resource of 0.5 - 2.0 TCF. Further detailed petrophysical and core analysis will commence shortly to calibrate the logging data and refine the in place and recoverable resource estimates. The Papa discovery further de-risks the deeper, Upper Cretaceous Intraslope play in Tanzania. Additional resources have now been discovered in the Cretaceous stratigraphy outboard of both the Rovuma and Rufiji Deltas by the Mzia-1 and Papa-1 wells. An update of the in place and recoverable resource estimates from the Mzia and Papa discoveries on the new Cretaceous Intraslope play will follow the ongoing petrophysical analysis. The BG-Ophir Joint Venture's first four discoveries have successfully tested targets of Miocene, Oligocene and Paleocene age in the Tertiary Intraslope Play and are currently estimated to have discovered total recoverable resources of ca. 7 TCF (1167 MMBOE). The fifth discovery, Mzia, and the sixth discovery, Papa, both in the new Upper Cretaceous Intraslope Play are expected to add considerable additional recoverable resource to this total. The ‘Deep Sea Metro 1’ drillship will now be sub-let to Apache for a single well in Block L8, Kenya, adjacent to Ophir's Block L9 (60%), before returning to continue operations with the Ophir-BG Joint Venture in Tanzania. The Joint Venture will recommence drilling in Block 1, Tanzania in October 2012. Next in the sequence will be two step-out exploration and appraisal wells around the 3.4 TCF (567 MMBOE) Jodari discovery for a potential hub for the LNG development in Block 1.

31 Jul 2012

FOGL begins contracting of 'Leiv Eiriksson' semisub

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

31 Jul 2012

Leiv Eiriksson Rig on Contract

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

27 Jul 2012

GEITUNGEN EXPLORATION WELL HAS SPUDDED, NORWAY

Lundin Petroleum AB's (Lundin Petroleum) wholly owned subsidiary Lundin Norway AS (Lundin Norway) is pleased to announce that Statoil Petroleum AS (Statoil) has commenced the drilling of exploration well 16/2-12 targeting the Geitungen structure. The well is located in licence PL265, between the Johan Sverdrup discovery and the 16/2-9S Aldous Major North discovery in the Norwegian North Sea. The .... [+ read more] main objective of the well 16/2-12 is to prove the presence of oil bearing Jurassic sandstones similar to the Johan Sverdrup discovery. The planned total depth is 2,060 metres below mean sea level. The well will be drilled with the drilling rig Ocean Vanguard and the duration is expected to be 40 days. Lundin Norway holds 10 percent interest in PL265. Partners are Statoil (operator) with 40 percent interest, Petoro (30 percent) and Det norske oljeselskap ASA (20 percent).

27 Jul 2012

Drilling of Kabeljou-1 exploration well commences in Nambia

Chariot Oil & Gas Limited (Chariot), the independent Africa focused oil and gas exploration company, is pleased to announce that drilling operations have commenced on the Nimrod prospect. This is the second well in Chariot’s 4 to 5 well drilling programme offshore Namibia. The operator has confirmed that the drilling campaign began this morning on the Kabeljou (2714/6-1) exploration well using .... [+ read more] the ‘Ocean Rig Poseidon’ drillship. The Nimrod prospect is located in the Orange Basin in Southern Block 2714A where Chariot has a 25% equity interest. Petrobras Oil and Gas BV has a 30% interest in the licence and is the operator with BP Exploration (Namibia) Limited having 45%. The drilling location is 77 kilometres offshore Namibia in 360 metres of water with an estimated total drilling depth of approximately 3,350 metres true vertical depth subsea (TVDss). The drilling and logging operations are expected to take approximately 60 days and a further announcement will be made when the well results are known.

24 Jul 2012

'Sevan Brasil' accepted by Petrobras

'Sevan Brasil' has completed the acceptance testing and has on the 24 July 2012 commencedwork under its six year contract with Petrobras in Brazil.The rig will now move to its first well location and begin drilling operations under the direction of Petrobras. .... [+ read more]

23 Jul 2012

EDC’s Saturn jack up rig ends 5th year without LTI

Eurasia Drilling Company Limited ("EDC" or the "Company" - LSE: EDCL), the leading onshore and offshore drilling service provider in the CIS, today announces that its offshore jack up drilling rig, the Saturn, (previously Trident XX) achieved the major milestone of working continuously for five years without a Lost time Incident (LTI) in June 2012. The commitment to incident free .... [+ read more] operations by EDC's offshore crews and onshore management combined with the full support of EDC's contractors are the main contributory factors to reaching this goal. Saturn is owned and managed by the Turkmenistan Branch of BKE Shelf Ltd in Ashgabat and has worked almost entirely throughout this five year period in Turkmenistan for Petronas Carigali apart from a 6 month spell in 2010 when it worked for CMOC (Caspi Meruerty Operating Company B.V) in Kazakhstan.

19 Jul 2012

Divers Confirm Noble Discoverer Did Not Run Aground

Divers have confirmed the Noble Discoverer did not run aground after slipping anchor in Dutch Harbor, Alaska. Still, our goal remains flawless operations and this is an incident Shell and Noble Drilling take very seriously. Even a “near miss” is unacceptable. While an internal investigation will determine why the Discoverer slipped anchor, we are pleased with the speed and .... [+ read more] effectiveness of the mitigation measures we had in place.

16 Jul 2012

Stebbing prospect reaches total depth

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

15 Jul 2012

Drillship Drifts While Anchored Near Dutch Harbor

On July 14, 2012, while anchored off the coast of Dutch Harbor, Alaska, the Noble Discoverer drill ship drifted toward land. Shell quickly engaged one of its support vessels, the Lauren Foss, which safely towed the Discoverer back to its previous location. A ROV (Remote Operated Vehicle) inspection of the Discoverer found no indication that the ship was damaged or .... [+ read more] ran aground. As a precaution, a dive team will conduct another inspection. The Noble Discoverer is currently anchored off the coast of Dutch Harbor with the Lauren Foss on standby and towlines connected. The ship’s anchor, which is used to secure the drill ship just off the coast, is very different from the eight-anchor [PES] spread mooring system used during drilling operations. Our goal remains flawless operations. Shell and Noble Drilling take all incidents very seriously. Even a “near miss” is unacceptable. While an internal investigation will determine why the Discoverer slipped anchor, we are pleased with the speed and effectiveness of the mitigation measures we had in place. Any lessons from this incident will be applied to future operations, here and elsewhere.

9 Jul 2012

Hurricane appraisal well commences

Ithaca Energy Inc. (TSX:IAE)(LSE:IAE) announces that it has commenced drilling of the Hurricane appraisal well in Block 29/10b (Ithaca operated), which lies within the Company's Greater Stella Area in the UK sector of the Central North Sea. The well is being drilled using the WilHunter semi-submersible rig. The Company has contracted the services of Applied Drilling Technologies International ("ADTI") to .... [+ read more] manage drilling operations under "turnkey" contract arrangements. The well programme is anticipated to take between 75 to 85 days to complete, including the performance of a drill stem test.

5 Jul 2012

Keppel to build jackup in Kazkhstan

Teniz Burgylau LLP (Teniz) and a consortium consisting of Keppel Kazakhstan LLP and ERSAI Caspian Contractor LLP have signed a contract for the turnkey construction of the first self-elevating floating drilling rig to be built in Kazakhstan. The project for the construction of Kazakhstan’s FDR is one of the breakthrough innovative projects in the country. The project documentation developed by Keppel .... [+ read more] FELS Ltd. was agreed with the authorized bodies of the RK and classification societies: American Bureau of Shipping (ABS) and Russian Maritime Register of Shipping (RMRS). FDR’s systems are designed for the use in corrosive environments and in the presence of hydrogen sulfide. The project provides for compliance with SFAS zero discharge, that is, a complete ban on discharges into the marine environment of wastes resulting from industrial activity, so that all waste will be collected and transported in sealed containers to shore for treatment and disposal. The project is implemented by Teniz and supported by the National Company KazMunaiGaz. Construction of the FDR will take place at Keppel’s shipyard in the Mangistau region, involving up to 1,000 people and will be completed in the first quarter of 2015. The first jackup drilling rig to be built in Kazkhstan will be designed to operate in water depths from 5-80m.

3 Jul 2012

Fairmount Sherpa Delivered Drillship Peregrine 1 to Singapore

Fairmount Marine’s tug Fairmount Sherpa has delivered drillship Peregrine 1 safely in Singapore. The Peregrine 1 was towed to from Salvador in Brazil to Singapore. For this job the Fairmount Sherpa was mobilized from Rio de Janeiro where the tug had delivered rig ODN TAY IV. Upon arrival in Salvador the Fairmount team prepared the Peregrine 1 for towage. After these .... [+ read more] preparations Fairmount Sherpa commenced the towage of Peregrine 1 across the Atlantic Ocean, clearing Cape of Good Hope and across the Indian Ocean towards Singapore - a voyage of over 9,100 miles, which was done at an average speed of 8.5 knots. En route a bunker stop was made in Port Louis, Mauritius.

3 Jul 2012

Far East-1 Well Update

Salamander Energy provides an operational update on testing operations at the Far Eat prospect in its operated B8/38 licence, Gulf of Thailand. Further to the announcement on 26th June 2012, a barefoot DST was conducted over a zone of potential oil pay in the Ratburi carbonates. The test results are conclusive, analysis of produced fluids point to formation water .... [+ read more] being present in the tested section. The Far East-1 well will now be plugged and abandoned as a dry hole and the rig is being prepared for release. The Bualuang North West Terrace exploration well will now be drilled later in the year as part of the wider exploration programme across both the B8/38 and G4/50 licence areas.

2 Jul 2012

Significant gas and condensate discovery in the North Sea

Statoil has made a significant gas and condensate discovery in the King Lear prospect in the southern part of the Norwegian North Sea along with its partner Total E&P Norge. Exploration well 2/4-21 drilled by the jack-up rig Maersk Gallant in production licences 146 and 333, has proven a 48-metre gas/condensate column in the main bore 2/4-21 and an additional 70-metre .... [+ read more] gas/condensate column in the side-track 2/4-21A. Statoil estimates the total volumes in King Lear to be between 70 and 200 million barrels of recoverable oil equivalent (o.e.). “Statoil had earlier defined King Lear as a potential high-impact prospect. The drill results confirm our expectations and show once again that the Norwegian continental shelf still delivers high value barrels,” says Gro Gunleiksrud Haatvedt , senior vice president exploration Norway in Statoil. Data acquisition is currently being finalised in the sidetrack. As King Lear is a high-pressure, high-temperature well, special attention is given to ensuring safe drilling operations. The King Lear discovery is an important contribution to Statoil’s corporate strategy of revitalising the NCS with high-value barrels. “King Lear lies approximately 20 kilometres north of the Ekofisk field. It is encouraging to see that this part of the Norwegian continental shelf – home to the first commercial oil find in Norway – is still delivering significant discoveries,” says Haatvedt. “This reinforces our faith in the exploration potential of the Norwegian continental shelf. Not only does it have a proud past, but also an exciting future,” she adds. Statoil will plan for appraisal drilling of the discovery as well as exploration drilling on other interesting prospects in the licences. Going forward, Statoil as operator will look into an optimal development solution for King Lear and evaluate if the discovery should be developed as a stand-alone or as a tie-in to infrastructure in the area. This area, normally considered an oil province, may on the basis of this discovery and other gas resources form the basis for future gas development. Wells 2/4-21 and 2/4-21 A are the eleventh and twelfth wells drilled in production licence PL146. Well 2/4-21 was drilled to a vertical depth of 5,344 metres below sea level in 67 metres of water, while well 2/4-21 A was drilled to a vertical depth of 5,237 metres below sea level. Statoil is operator for production licences PL146 and PL333 with an ownership share of 77.8%. The licence partner is Total E&P Norge (22.2%). The King Lear discovery is the eighth high-impact* discovery made by Statoil over the last 15 months. The other high-impact discoveries are Zafarani and Lavani in Tanzania, Skrugard and Havis in the Barents Sea, Johan Sverdrup (formerly Aldous/Avaldsnes) in the North Sea, and Peregrino South and Pão de Açúcar (non-operated) in Brazil.

29 Jun 2012

Acceptance testing update for 'Sevan Brasil'

'Sevan Brasil' is in the final phase of the acceptance testing for Petrobras. We expect to leave Rio de Janeiro in the middle of next week for sea trials which are expected to take 5-7 days to complete and acceptance of the rig should be before15 July. .... [+ read more]

29 Jun 2012

'ST Bahari-1' completes A22 development well on East Zeit field

Dana Petroleum plc ("Dana") is pleased to announce it has just completed two successful appraisal/development wells in the Gulf of Suez area, with Zeitco, our joint venture company. Offshore, on the East Zeit A platform, the A22 development well was spudded on 30th April with the Sino Tharwa ST Bahari-1 jackup rig and reached a total depth of 12,051 feet maximum .... [+ read more] depth in the Kareem Marker Formation. The well targeted an undeveloped area of the field with poorer reservoir quality, and after drilling a 1,426-foot horizontal section within the Marker reservoir, has now been completed as an oil producer. Production started on 25 June, at rates around 2,000 bbls oil per day.

29 Jun 2012

LUNDIN PETROLEUM COMPLETES CLAPTON EXPLORATION WELL IN SOUTHERN NORTH SEA

Lundin Petroleum AB's (Lundin Petroleum) wholly owned subsidiary Lundin Norway AS (Lundin Norway) has completed the Clapton exploration well 2/8-18S in PL440S. The well is located about 5 km east of the Eldfisk Øst Field and 10 km north of the Valhall Field in the North Sea. The primary exploration target was to prove hydrocarbons in chalks of the Shetland .... [+ read more] Group. The well encountered reservoir rocks as expected in the Shetland Group. The reservoir properties were poorer than expected. Data acquisition and sampling have been carried out. The well was drilled to a vertical depth of 2,619 m below the sea surface and was terminated in Creatceous rocks of the Hidra Formation. Water depth at the site is 69 metres and the well was drilled by the jack-up rig Maersk Guardian. The well will now be permanently plugged and abandoned as a dry well. Lundin Norway is a partner in PL440S with 18 percent interest. The Operator is Faeroe Petroleum with 40 percent. The other partners are Dana (20%), Noreco (12%) and Det norske (10%).

27 Jun 2012

Shell Drill Rigs Depart for Alaska Waters

On Wednesday, June 27, the Noble Discoverer and the Kulluk conical drilling unit departed Seattle, Washington to make the journey to Dutch Harbor, Alaska. A portion of the associated drilling fleet departed at approximately the same time. “Shell is pleased to announce its two Alaska-bound drilling rigs, the Kulluk and the Noble Discoverer, along with associated support vessels, have departed Seattle, .... [+ read more] Washington and are now en route to Dutch Harbor, Alaska. "Upon arrival in Dutch Harbor, the fleet will await the opportunity to make entry into the Beaufort and Chukchi Seas. Once open water allows, the rigs will sail to their respective theaters and commence exploratory drilling,” said Pete Slaiby, VP Alaska. The journey north marks the beginning of another historic offshore exploration program in Alaska. We look forward to adding to our long, successful history in the Beaufort and Chukchi Seas; providing jobs and verifying what could prove to be an extremely valuable natural resource base for Alaska and the Nation.

27 Jun 2012

Shell Drill Rigs Depart for Alaska Waters

On Wednesday, June 27, the Noble Discoverer and the Kulluk conical drilling unit departed Seattle, Washington to make the journey to Dutch Harbor, Alaska. A portion of the associated drilling fleet departed at approximately the same time. “Shell is pleased to announce its two Alaska-bound drilling rigs, the Kulluk and the Noble Discoverer, along with associated support vessels, have departed Seattle, .... [+ read more] Washington and are now en route to Dutch Harbor, Alaska. "Upon arrival in Dutch Harbor, the fleet will await the opportunity to make entry into the Beaufort and Chukchi Seas. Once open water allows, the rigs will sail to their respective theaters and commence exploratory drilling,” said Pete Slaiby, VP Alaska. The journey north marks the beginning of another historic offshore exploration program in Alaska. We look forward to adding to our long, successful history in the Beaufort and Chukchi Seas; providing jobs and verifying what could prove to be an extremely valuable natural resource base for Alaska and the Nation.

22 Jun 2012

Pacific Drilling Announces Five-Year Contract for the Pacific Sharav

Pacific Drilling S.A. (NYSE: PACD) announced today that its ultra-deepwater drillship the Pacific Sharav has been awarded a five-year contract by Chevron U.S.A. Inc. for operations in the United States Gulf of Mexico. Estimated maximum contract revenue, including mobilization and client requested modifications, is expected to be approximately $1,076 million, bringing Pacific Drilling’s total contract backlog as of June 22, 2012, .... [+ read more] to approximately $3.2 billion. Pacific Drilling CEO Chris Beckett stated, “We are proud to announce the expansion of our relationship with Chevron to include a third drillship. This contract exemplifies our strategic commitment to building strong customer relationships and allows us to leverage the operations support infrastructure which we have already developed in the region.” Pacific Sharav is scheduled for delivery by Samsung Heavy Industries in Korea in the fourth quarter of 2013, upon completion of construction and client requested modifications. The drillship will be capable of operating in water depths of up to 12,000 feet and drilling wells up to 40,000 feet deep.

20 Jun 2012

Keppel FELS to deliver Ukraine’s second KFELS B Class jackup rig

Keppel FELS Limited (Keppel FELS), a wholly owned subsidiary of Keppel Offshore & Marine Ltd (Keppel O&M), is on track to deliver Ukraine's second KFELS B Class jackup rig ahead of schedule, within budget and with a perfect safety record. This follows the redelivery of their first jackup rig of the same design, in Ukraine in May this year. Built .... [+ read more] to Keppel's proprietary KFELS B Class design, this second jackup rig will be deployed on the Ukrainian shelf of the Black Sea for its owner Chernomornaftogaz. According to Ukraine's official estimates in 2011, the country boasts proven reserves of natural gas (1200 billion cubic meters) and oil and gas condensate (220 million tons). The rig was named NEZALEZHNIST (which means independence in Ukrainian), at Keppel FELS today with Mr Evgen Bakulin, Chairman of the Board of Ukraine's National Joint-Stock Company, Naftogaz, as the Guest of Honour.

18 Jun 2012

Bualuang Far East-1 Exploration Well Spud

Salamander Energy plc announces the spud of the Bualuang Far East-1 (“FE-1”) exploration well in Block B8/38, Gulf of Thailand. The Bualuang Far East prospect is located approximately 7km to the northeast and up-dip of the Bualuang oil field. The FE-1 well will be drilled to a total vertical depth of 1,452 metres subsea. The primary target is the T5 .... [+ read more] Miocene sandstones with secondary targets comprising an underlying Permian-age Ratburi carbonate and a T4 Miocene sandstone stratigraphic trap. The main T5 objective has potential mean recoverable resources of 20 million barrels of oil. The well will be drilled by the Ensco-53 jack up rig and is expected to take approximately 20 days to complete on an untested basis. Salamander has a 100% interest in, and is the operator of, the B8/38 production licence. This contains the Bualuang oil field and East Terrace oil discovery.

18 Jun 2012

Wawa-1 exploration well finds oil and gas-condensate

Tullow Oil plc (Tullow) announces that the Wawa-1 exploration well in the Deepwater Tano licence offshore Ghana has intersected oil and gas-condensate in a Turonian turbidite channel system. Wawa-1 encountered 20 metres of gas-condensate pay and 13 metres of oil pay in turbidite sands. Samples show the oil to be good quality between 38 and 44 degrees API. The well was .... [+ read more] drilled 10 kilometres north of the Enyenra-3A well, testing the previously undrilled, updip portion of the licence. Pressure data shows that it is a separate accumulation from the TEN fields. The well will now be suspended for possible future use in appraisal and development operations. The Atwood Hunter semi submersible rig drilled the Wawa-1 well to a final depth of 3,322 metres in water depths of 587 metres. Tullow (49.95%) operates the Deepwater Tano licence and is partnered by Kosmos Energy (18.00%), Anadarko Petroleum (18.00%), Sabre (4.05%) and the Ghana National Petroleum Corporation (GNPC) (10% carried interest).

18 Jun 2012

Keppel to deliver seventh ultra-deepwater semi to Ensco

Keppel FELS Limited (Keppel FELS) is set to deliver ENSCO 8506, the seventh semisubmersible (semi) drilling rig in the ultra-deepwater ENSCO 8500 Series® to Ensco (NYSE: ESV) safely, on time and within budget. ENSCO 8506 has been contracted to Anadarko Petroleum Corporation for deployment in the U.S. Gulf of Mexico in 4Q 2012. .... [+ read more]

14 Jun 2012

Second high-impact discovery for Statoil offshore Tanzania

Statoil (OSE: STL, NYSE:STO) and partner ExxonMobil have made a large gas discovery in the Statoil-operated Block 2 licence in Tanzania. The logging results from the Lavani well confirm a new high-impact discovery for Statoil, with a preliminary resource estimate of 3 trillion cubic feet (Tcf) of gas in place. The Lavani well has encountered 95 metres of excellent quality reservoir .... [+ read more] sandstone with high porosity and high permeability. “The result from Lavani, which is only 16 kilometres south of our recent Zafarani discovery, confirms the high potential in Block 2. We are also pleased to announce that the recently drilled Zafarani sidetrack added another 1 Tcf of gas in place. This is in addition to the up to 5 Tcf announced in February. The results so far mark an important step towards a possible natural gas development in Tanzania,” says executive vice president for Exploration in Statoil, Tim Dodson. “The Lavani discovery demonstrates how Statoil’s strategy of focusing on high-impact opportunities is paying off and supports the company’s ambition for international growth,” Dodson adds. The Lavani well, drilled in 2,400-metre water depth, is the second exploration well in Block 2 – which covers an area of approximately 5,500 square kilometres. The well is drilled by Ocean Rig Poseidon with operations still ongoing. The Lavani discovery is the seventh high-impact discovery made by Statoil over the last 14 months. The other high-impact discoveries are Zafarani in Tanzania, Skrugard and Havis in the Barents Sea, Johan Sverdrup (formerly Aldous/Avaldsnes) in the North Sea, and Peregrino South and Pão de Açúcar (non-operated) in Brazil. Statoil operates the licence on Block 2 on behalf of Tanzania Petroleum Development Corporation (TPDC) and has a 65% working interest, with ExxonMobil Exploration and Production Tanzania Ltd. holding the remaining 35%. Statoil has been in Tanzania since 2007, when it was awarded the licence for Block 2. (*) ”High-impact well” = a total of more than 250 million barrels of oil equivalent (boe), or 100 million boe net to Statoil.

14 Jun 2012

LUNDIN PETROLEUM TEMPORARILY SUSPENDS ALBERT EXPLORATION WELL OFFSHORE NORWAY

Lundin Petroleum AB (Lundin Petroleum) announces that drilling of exploration well 6201/11-3 in PL519 targeting the Albert prospect has been temporarily suspended until August. The Bredford Dolphin drilling rig is moving to a Norwegian yard to complete its five year renewal survey before returning to complete the Albert exploration well. Lundin Petroleum originally anticipated that the well would be completed prior .... [+ read more] to the date of the renewal survey but due to delays in drilling this was not possible. The main objective of well 6201/11-3 is to test Cretaceous and Triassic age sandstones of a multiple target structure. The well has been temporarily suspended above the primary targets at 2,120 meters where the 13 3/8 casing has been set. The planned total depth is 3,150 meters. Lundin Petroleum is the operator of PL519 with 40 percent interest. Partners are Bayerngas Norge AS, Norwegian Energy Company ASA and Spring Energy Norway AS with 20 percent interest respectively.

11 Jun 2012

Fairmount Fuji Assisted Stena Icemax

Fairmount Marine’s multipurpose support vessel Fairmount Fuji has assisted drill ship Stena Icemax while making a stop-over at Cape Town. On request of the owner of Stena Icemax the Fairmount Fuji carried out several cargo runs from the port of Cape Town to the anchorage. Stena Icemax was under way from the Far East to French Guiana and required to make .... [+ read more] a stop-over at Cape Town for crew change and replenishment. Stena Icemax is a 228 meters long new build drill ship designed for deep water operations in harsh environments. Fairmount Fuji is a multipurpose support vessel with a spacious aft deck of 280 square meters and with towing capabilities. Directly after assisting Stena Icemax the Fairmount Fuji was prepared for her next assignment in West Africa region, where she will act as an accommodation and general support vessel for an offshore operator.

7 Jun 2012

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

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

24 May 2012

LUNDIN PETROLEUM SPUDS CLAPTON EXPLORATION WELL IN SOUTHERN NORTH SEA

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 2/8-18S in PL440S has commenced. The well will target the Clapton prospect, which is situated 10 km north of the Valhall Field, offshore Norway. The main objective of well 2/8-18S is to test the hydrocarbon potential in the Ekofisk, Tor and Hod formations. Lundin Petroleum .... [+ read more] estimates the Clapton prospect to contain unrisked, gross, prospective resources of 65 million barrels of oil equivalent (MMboe). The planned total depth is 2,718 meters below mean sea level and the well will be drilled using the jackup drilling rig Maersk Guardian. Drilling is expected to take approximately 60 days. Lundin Petroleum is a partner in PL440S with 18 percent interest. The Operator is Faroe Petroleum with 40 percent. The other partners are Dana (20%), Noreco (12%) and Det norske (10%).

24 May 2012

Pacific Drilling Announces Extension of Initial Term for the Pacific Scirocco to Two Years

Pacific Drilling S.A. (NYSE: PACD) announced today that a subsidiary of Total S.A. has elected to extend the initial contract term for the Pacific Scirocco from one to two years. The contract provides for further options, to be exercised at the client’s discretion, which could result in up to three additional years of contract term with an escalating dayrate. Estimated maximum .... [+ read more] contract revenues related to the additional one year term are expected to be approximately $173 million, bringing the rig’s total contract backlog as of May 24, 2012, to approximately $307 million.

16 May 2012

Fairmount Alpine Towed Rig Ocean Whittington to Gulf

Fairmount Marine’s tug Fairmount Alpine has towed the rig Ocean Whittington from offshore Belem, Brazil, to offshore Galveston, US. For this job Fairmount Marine was contracted by the rigs owner, Diamond Offshore Drilling, for which Fairmount has performed a series of towages in recent years. Ocean Whittington is a semi-submersible drilling rig for deep water operations. The rig has worked offshore .... [+ read more] the northern Brazilian coast since 2009. To tow the rig to the Gulf Fairmount Marine mobilized tug Fairmount Alpine, which was in South Africa after performing escort services for bulk carrier Vale Beijing. When Fairmount Alpine arrived at the location of the Ocean Whittington offshore Belem, she was requested to perform heading control duties to the rig prior the start of the towage. Upon readiness of the Ocean Whittington the convoy departed for the journey towards offshore Galveston. The tow over a distance of 3,625 miles was performed by the Fairmount Alpine with an average speed of 7.8 knots.

16 May 2012

ABS to Class Advanced Capability Deepwater Drillship

Ensco plc has selected ABS as the class society for its advanced-capability, ultra deepwater drillship to be built at the Samsung Heavy Industries, Co. Ltd (SHI) Shipyard in Geoje, South Korea. The ENSCO DS-8 will be the sixth Samsung DP3 drillship in the fleet and will extend the benefits of Ensco’s fleet standardization strategy. With drilling capabilities in water depths to .... [+ read more] 12,000 feet and a total vertical drilling depth of 40,000 feet, this new vessel will meet the demands of ultra deepwater drilling. “Samsung is the market leader in drillship newbuilds and utilizes advanced shipbuilding technology. We’re proud that ABS will be the first class society to deliver this new drillship design,” says In Yong Jeong, ABS District Principal Surveyor. “This contract demonstrates that ABS has the experience and expertise to class deepwater drillships that sometimes come with inevitable technical challenges.” New features on the ENSCO DS-8 include retractable thrusters, enhanced safety and environmental features, improved dynamic positioning capabilities and advanced drilling and completion functionality, including below-main-deck riser storage, triple fluid systems, offline conditioning capability and enhanced client and third-party facilities. “An ongoing trend of new deepwater oil and gas discoveries around the globe is creating a high demand for equipment capable of tapping those resources,” says Ensco Chairman, President and CEO Dan Rabun. “Our track record of leading and deepwater performance increasingly makes us the driller of choice for operators working in complex offshore fields. Our high-grading strategy will ensure that we continue to be equipped to respond to rising demand.” The drillship also is set to receive the environmentally friendly notations from ABS, including ENVIRO+ denoting that the vessel adheres to enhanced environmental standards and the dynamic positioning notation DPS 3. Construction cost, including commissioning, systems integration testing, project management and spares is expected to be approximately $645 million. The vessel is scheduled for delivery in the third quarter of 2014.

16 May 2012

Mzia-1 Gas Discovery - Block 1 Offshore Tanzania

Ophir Energy plc ("Ophir" or "the Company") is pleased to announce its fifth consecutive gas discovery offshore Tanzania. The Mzia-1 well in Block 1 intersected a 178m gas bearing column and 55m of net pay in the Upper Cretaceous. Mean in place resource is estimated at 3.5 TCF, with significant potential upside. Further technical work will determine the recoverable resource of .... [+ read more] this substantial, commercial gas discovery. Mzia-1 was the first Ophir-BG JV well to solely target the Upper Cretaceous of the Rovuma Delta and tested stacked reservoir intervals. The well was located 45km off the coast of Tanzania and 45km north of the Mozambique maritime border, spudded in 1,639m of water and drilled to a total depth of 4858m subsea. Two stacked reservoir intervals were intersected with gas columns of 55m and 123m respectively. Total net pay was 55m and no gas water contacts were observed. An additional, shallower potential reservoir interval was observed but not intersected at this location; this interval has been de-risked by the Mzia-1 result and offers upside potential. Total low case, mean and high case in place resources for the Mzia-1 discovery are estimated at 2.0 - 3.5 - 6.0 TCF respectively. As this is the first well calibration point in the Cretaceous, further technical work will now be undertaken to determine the recoverable resource volumes of this substantial, commercial discovery. Mzia was the fifth well to be drilled by the Ophir-BG joint venture offshore Tanzania. Prior to Mzia-1, the first four wells had discovered total mean recoverable resources of 7 TCF. The Mzia-1 result will add substantially to this total. Ophir holds 40% of Blocks 1, 3 and 4; BG operates the Blocks with 60%. The Metro 1 drillship will now move north to Block 3 to drill the Papa-1 well, a test of the equivalent Upper Cretaceous section in the Rufiji Delta. Papa-1 has a pre-drill mean estimated prospective resource of 3.1 TCF and a 40% chance of success. Results from the Papa-1 well are expected in July 2012. Separately, the 3D seismic acquisition programme to explore a potential continuation of Tertiary basin floor fan prospectivity from Mozambique into the eastern portion of Block 1 is nearing completion, with preliminary processing, mapping and interpretation expected by Q3 2012.

14 May 2012

Statoil secures rig for drilling offshore Newfoundland

Statoil has reached an agreement to use Seadrill’s West Aquarius deepwater drilling rig for Statoil’s 2012-2013 exploration activities offshore Newfoundland, Canada. “We have ambitious exploration targets offshore Newfoundland, and securing rig capacity is essential for reaching those targets,” says Geir Richardsen, head of Exploration for Statoil in Canada. “We look forward to putting this rig’s capabilities into action.” Starting .... [+ read more] late 2012, Statoil will begin a three-well drilling program, offshore Newfoundland, including two exploration wells in the Flemish Pass Basin as well as an exploration well in the Jeanne d'Arc Basin. “I am pleased that the company has acquired future rig capacity as exploration activity is a key component of Statoil’s ambitions to become a producing operator offshore Newfoundland,” says Kjell Magnus Myge, head of Procurement for Statoil in Canada. The West Aquarius drilling rig is a sixth generation semi-submersible DP3 vessel built in South Korea in 2009. The vessel can operate in harsh environments up to 3,000 m water depth. The rig has been taken on as an assignment from ExxonMobil Deepwater Rig Limited. Statoil is an international energy company with high ambitions for international growth, and with business operations in 37 countries around the world. Statoil’s North American activities are managed out of two main offices located in Houston, Texas, USA and Calgary, Alberta, Canada. Statoil also has offices in Anchorage, Alaska, Austin, Texas, Stamford, Connecticut , Washington, D.C., Williston, North Dakota, USA and St. John’s, Newfoundland, Canada.

14 May 2012

Chariot fails to find commercial discovery at Tapir South

Chariot Oil & Gas Limited (Chariot), the Africa focused oil and gas exploration company, confirms that the Tapir South (1811/5-1) exploration well in Northern Block 1811A in the Namibe basin offshore Namibia has reached a total depth of 4,879 metres TVDss. The well was drilled by the ‘Mærsk Deliverer’ semi-submersible drillship in 2,134 metres of water and operated by Chariot’s wholly .... [+ read more] owned Namibian subsidiary, Enigma Oil & Gas (Pty) Limited. Preliminary logging results indicate that, although excellent reservoirs were penetrated, no commercial hydrocarbons were found and the well will be plugged and abandoned. The well encountered 173 metres of net reservoir sand of Cretaceous age, including two zones in excess of 30 metres with average porosities of 24% and evidence of good permeabilities. Carbonate intervals were also penetrated with porosities up to 18% over a net interval of 28 metres; these results exceeded our pre-drill estimates. Detailed analyses will be conducted on the data collected during the drilling of Tapir South. This information will be used to calibrate the existing data set and a resource update of the remaining prospectivity in the block will be provided once this evaluation has been completed.

11 May 2012

Borders & Southern spud Stebbing prospect

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

10 May 2012

Statoil launches ambitious exploration campaign in the Skrugard area

Statoil ASA, together with partners Eni Norge AS and Petoro AS, has established a plan for further exploration drilling in the Skrugard area. The exploration campaign will comprise four new prospects and is scheduled to commence late 2012. The objective is to follow up on the Skrugard and Havis discoveries and to test further upside potential in this area of the .... [+ read more] Barents Sea, including production licences PL532 and PL608. “We are very satisfied with our recent exploration achievements in the Barents Sea. In less than a year, we have made two substantial oil discoveries in PL532, proving 400-600 million barrels of recoverable oil. We have also drilled a successful appraisal well on Skrugard confirming volume estimates and collecting data for field development planning,” says Knut Harald Nygård, Statoil vice president for exploration in the Skrugard area. “We see good opportunities for further upside in the area, and have identified four new interesting prospects. In some of these we have observed flat spots of the same type as in the Skrugard and Havis discoveries.” The four prospects will be drilled back to back with the West Hercules drilling rig, which will be winterised to meet the weather conditions in the Barents Sea. The drilling campaign will start in PL532 with the Nunatak prospect due to be spud in December this year. Then the rig will proceed to the Skavl prospect located in the same licence, and thereafter to the Iskrystall prospect in the neighbouring licence PL608. The fourth prospect to be drilled will be announced at a later stage. Statoil’s ambition is to complete drilling of all four prospects by late spring/early summer 2013. “With the Skrugard and Havis discoveries, we are establishing a new strategic hub in the northernmost part of the Norwegian continental shelf. Proving additional volumes in the area would make the development even more robust,” says Erik Strand Tellefsen, Statoil vice president for Skrugard field development. Statoil is operator for production licences PL532 and PL608 with an ownership share of 50% in each. The licence partners in both licences are Eni Norge AS (30%) and Petoro AS (20%).

9 May 2012

LUNDIN PETROLEUM SPUDS EXPLORATION WELL ON THE ALBERT PROSPECT IN NORTHERN NORTH SEA

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that drilling of exploration well 6201/11-3 in PL519 has commenced. The well will target the Albert prospect, which is situated 65 km northwest of the Snorre Field in the northern North Sea, offshore Norway. The main objective of well 6201/11-3 is to test Cretaceous and Triassic age sandstones of a .... [+ read more] multiple target structure. Lundin Petroleum estimates the Albert prospect to contain unrisked, gross, prospective resources of 177 million barrels of oil equivalent (MMboe). The planned total depth is 3,150 meters below mean sea level and the well will be drilled using the semi-submersible drilling rig Bredford Dolphin. Drilling is expected to take approximately 55 days. Lundin Petroleum is the operator of PL519 with 40 percent interest. Partners are Bayerngas Norge AS, Norwegian Energy Company ASA and Spring Energy Norway AS with 20 percent interest each.

7 May 2012

Chevron Commences Operations on Next-Generation Drillship in Deepwater Gulf of Mexico

Chevron Corporation (NYSE: CVX) announced that the Pacific Santa Ana, a deepwater drillship built to Chevron's specifications, has arrived in the Gulf of Mexico to work for Chevron under a five-year contract with a subsidiary of Pacific Drilling S.A. (NYSE: PACD). Pacific Santa Ana is the first drillship designed with the capacity to perform dual gradient drilling (DGD). "Pacific Santa .... [+ read more] Ana will enable us to demonstrate dual gradient drilling, which has the potential to change the way deepwater wells are drilled," said George Kirkland, vice chairman, Chevron Corporation. "This new process builds on our record of technology leadership in deepwater." "The addition of Pacific Santa Ana as Chevron's fifth drillship in the deepwater Gulf of Mexico demonstrates our long-term commitment to developing America's energy resources," said Gary Luquette, president of Chevron North America Exploration and Production Company. "We are bullish on the Gulf, where robust energy exploration and development is vital to our nation's economy and energy security." Unlike conventional deepwater drilling, which uses a single drilling fluid weight in the borehole, dual gradient drilling employs two weights of drilling fluid – one above the seabed, another below. This allows drillers to more closely match the pressures presented by nature and effectively eliminates water depth as a consideration in well design. DGD also allows drillers to more quickly detect and appropriately react to downhole pressure changes, which can enhance the safety and efficiency of deepwater drilling operations. Pacific Santa Ana is equipped with a DGD riser, a mud lift pump handling system, six mud pumps – three for drilling fluid and three for seawater – extensive fluid management system enhancements and more than 72,000 feet of DGD-related cables. After additional equipment is installed and tested, Pacific Santa Ana will be used for exploratory and development drilling in the deepwater Gulf of Mexico.

4 May 2012

Fairmount Sherpa Towed ODN Tay IV to Brazil

Fairmount Marine’s tug Fairmount Sherpa has towed the rig ODN Tay IV from Las Palmas towards a location offshore Rio de Janeiro, Brazil. For this job Fairmount Marine was contracted by Odebrecht Oil and Gas for the third time in a row. ODN Tay IV is a semi-submersible drilling rig for deep water operations owned by Odebrecht Oil & Gas, part .... [+ read more] of leading Brazilian multinational Odebrecht SA. The rig has undergone an upgrading at a shipyard at Las Palmas, Canary Islands. For her next assignment for Brazilian oil company Petrobras the ODN Tay IV had to be towed to Brazil. Tug Fairmount Sherpa towed the ODN Tay IV over a distance of 3,800 miles from Las Palmas to a location offshore Rio de Janeiro. The towage took just 30 days by an average speed of 5.2 knots. Upon arrival Fairmount Sherpa was requested to stay connected to ODN Tay IV to perform heading control duties during the inward clearance of the rig and preparations prior departure to the field.

4 May 2012

Teak-4A appraisal well update

Kosmos Energy, the Operator of the Teak-4A appraisal well offshore Ghana, in which Tullow Oil plc (Tullow) is a 26.396% partner, yesterday evening, issued the following press release: DALLAS, Texas, May 3, 2012 – Kosmos Energy (NYSE: KOS) announced results from the Teak-4A appraisal well, located in the West Cape Three Points Block, offshore Ghana. Located 6.1 kilometers (3.8 miles) northwest .... [+ read more] of the Teak-1 discovery well, the Teak-4A well was targeting the stratigraphic extension of the Teak discovery area. The well encountered thin, non-commercial reservoirs and is being plugged and abandoned. Kosmos and partners have begun integrating well results into the Teak field model to determine forward appraisal and development plans. The Atwood Hunter rig drilled Teak-4A to a total depth of 2,850 meters (9,348 feet) in water depth of 554 meters (1,817 feet). Following the completion of operations at the Teak-4A well, the drilling rig will set gauges at the Teak-2A well and perform a drill stem test at the Akasa oil discovery on the West Cape Three Points Block. Kosmos Energy is the operator of the West Cape Three Points Block with a 30.875 percent interest. The Company’s partners include Anadarko Petroleum Corporation (30.875 percent), Tullow Oil plc (26.396 percent), Sabre Oil & Gas Holdings Ltd. (1.854 percent), and the Ghana National Petroleum Corporation (10 percent carried).

26 Apr 2012

Fairmount Expedition Delivered Scarabeo 6 to Rotterdam

Fairmount Marine’s tug Fairmount Expedition has delivered the semisubmersible drilling rig Scarabeo 6 safely in Rotterdam, the Netherlands, for her dry-dock period at shipyard Keppel-Verolme. The 27 year old Scarabeo 6, owned by Italian offshore company Saipem, was towed from offshore Abu Qir, Egypt, towards Rotterdam over a distance of 3,290 miles. The tow was executed by Fairmount Expedition together with .... [+ read more] tug Normand Neptun at an average speed of 5.7 knots. A bunker stop was made in Algaciras, Spain. For this job Fairmount Expedition was contracted by EDT Offshore Egypt.

23 Apr 2012

Darwin East has good hydrocarbon shows

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

5 Apr 2012

'Maersk Deliverer' spuds Tapir South well in Namibia

Chariot Oil & Gas Limited (AIM: CHAR), the independent Africa focused oil and gas exploration company, is pleased to announce that its wholly owned subsidiary, Enigma Oil & Gas Exploration (Pty) Limited, has commenced drilling the first well, 1811/5-1, of its 4 to 5 well drilling programme offshore Namibia. Drilling operations began this morning on the Tapir South prospect using the .... [+ read more] ‘Maersk Deliverer’ semi-submersible drilling rig, with Chariot as Operator. The prospect has a 25% Chance of Success and a mean un-risked prospective resource potential of 604 million barrels of oil. In the event of success, the results of this well will significantly increase the Chance of Success on certain of the Company’s other prospects within the Tapir Trend. Tapir South (1811/5-1) will be only the second well ever to be drilled in the Namibe Basin. It is located 80km offshore Namibia in the Company’s northern block 1811A, in which Chariot has a 100% equity interest. The well is being drilled to an estimated total vertical depth subsea of 5,100m and, as announced following the Placing of 20 March 2012, this will now include extended drilling time to ensure that one of the deeper identified targets is drilled and fully evaluated. This deeper target is believed to be a carbonate section, age equivalent to the reservoir in recent sub-salt discoveries in the on-trend Kwanza basin offshore Angola. The drilling and logging operations are expected to take approximately 70 days and a further announcement will be made when the well results are known. The Tapir South prospect is part of the Tapir Trend where three prospects have been identified on a large ridge formed by a rotated fault block containing the potential carbonate target, draped by deep marine sediments with turbidite sandstone levels forming a stack of overlying targets. Tapir South is the southernmost of three culminations on the ridge and forms a focal point for charge migration from an adjacent basin in which excellent oil prone source rocks are believed to be present and currently generating oil. The second well to be drilled in the Chariot exploration programme, Kabeljou (2714/6-1), targeting the Nimrod prospect is now likely to spud earlier than previously reported. The Operator has informed Chariot that it now expects to secure a drilling unit in Q3 2012.

2 Apr 2012

Keppel AmFELS secures repeat jackup order from Mexico worth US$205 million

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 worth US$205 million. Slated for delivery in 1Q 2014, this latest high specification unit will be based on the LeTourneau Super 116E design with leg lengths .... [+ read more] of 511 ft and the capability to drill wells up to 30,000 ft at a water depth of 375 ft.

26 Mar 2012

Result of Jodari-1 well in block 1 offshore Tanzania

Jodari-1 was designed as a play-finder well to test slope-channel targets of Miocene, Lower Tertiary and Upper Cretaceous age. Log analysis shows that the well intersected the edge of a Miocene accumulation and two intervals of Lower Tertiary age, with 113m and 11m of gross pay respectively and high quality reservoirs. The Upper Cretaceous encountered formation gas but was not considered .... [+ read more] pay at this location. The significantly greater aggregate pay thickness and excellent net to gross ratio have substantially exceeded pre-drill expectations and result in the 3.4 TCF mean recoverable resource estimate. The well was spudded on 7th January 2012 in 1153m of water and was drilled by the drillship "Deep Sea Metro 1" to a total depth of 4465m subsea in 73 days. The Metro-1 drillship will now return to Mzia-1 (where the top hole section was drilled in early January prior to commencing Jodari-1) in order to complete the bottom portion of the well. The Mzia-1 well is estimated to take 75 days to drill and is targeting a 4.6 TCF Upper Cretaceous prospect with a different seismic anomaly to that calibrated by the Jodari-1 well. Jodari-1 was the fourth well to be drilled by the Ophir-BG joint venture in their jointly held acreage and was the first well to be operated by BG. Ophir holds 40% of Blocks 1, 3 and 4; BG operates with 60%.

25 Mar 2012

Fairmount Fuji Assisted Drillship Stena Forth

Fairmount Marine’s multipurpose support vessel Fairmount Fuji has assisted drillship Stena Forth, owned by Swedish Stena Drilling, when passing by Cape Town, South Africa. Fairmount Fuji was contracted to perform several cargo runs. Stena Forth anchored offshore Cape Town for crew changes and replenishments. Fairmount Fuji is equipped with a spacious 280 square meters deck. This made her ideal for the .... [+ read more] transport of goods. Fairmount Fuji sailed up and down between Cape Town port and Cape Town anchorage for a number of cargo runs.

23 Mar 2012

Small oil discovery in the Oseberg Area Unit

Statoil, together with partners in the Oseberg Area Unit, has made a small oil discovery in the production license PL053 in the North Sea. Statoil and its partners are in the process of concluding drilling operations in the exploration well 30/6-28S located in the production license PL053 in the Oseberg Area Unit. The well drilled by the rig COSL Pioneer .... [+ read more] proved an oil column of 12 metres in the Statfjord Formation. The estimated volume of the discovery is in the range of 12-18 million barrels of recoverable oil equivalents. "The oil discovery is located beneath the Oseberg field and is a good candidate to be connected to the Oseberg production facilities. These could be fast and high-value barrels for the partnership," says Knut Henrik Dalland, vice president Operations Oseberg. The oil discovery lies in the Crimp prospect, which was the secondary target for the exploration well 30/6-28S. The primary target was the Crux prospect that Statoil earlier defined as a high impact gas opportunity. With the Crux prospect Statoil tested a hypothesis for the existence of a separate gas-filled structure underlying the Oseberg field. However, the Crux prospect did not contain hydrocarbons. "The well 30/6-28S had two objectives. First, to test a new play in the area – the Crux prospect, which was a high risk / high reward opportunity. Second, to test an infrastructure-near prospect called Crimp, with relatively modest volumes but attractive economics. Unfortunately, we have not found gas in the Crux prospect, but we are pleased with the oil discovery in Crimp. Even though our high impact opportunity has not materialised, we have delivered some valuable additional resources to the Oseberg Unit," says Tore Løseth, vice president Exploration Licenses North Sea. After completion of the exploration well 30/6-28S, the COSL Pioneer drilling rig will move to the Glitne field. Exploration well 30/6-28S is situated in the production license PL053 in the Oseberg Area Unit in the North Sea. Statoil is the operator and has a 49.3 % interest. The partners are Petoro AS (33.6 %), Total E&P Norge AS (10.0 %), ExxonMobil E&P Norway AS (4.7 %) and ConocoPhillips Skandinavia AS (2.4 %).

22 Mar 2012

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

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

16 Mar 2012

Enyenra-4A appraisal well successful

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

10 Mar 2012

Shell Begins Drilling In Beaufort Sea

With the conclusion of the fall Kaktovik whale hunt and in accord with the Conflict Avoidance Agreement (CAA) signed by Shell and the Alaska Eskimo Whaling Commission (AEWC), exploratory drilling at Shell’s prospect in the Beaufort Sea has commenced. On October 3, 2012, at approximately 2:45PM AKDT, the Kulluk began drilling at Shell’s Sivulliq prospect. The occasion is historic in that .... [+ read more] it’s the first time two rigs have been drilling simultaneously offshore Alaska in over two decades. The Noble Discoverer has been drilling at Shell’s Burger prospect in the Chukchi Sea since September. "In the weeks ahead we look forward to operating safely and responsibly, putting Americans to work and adding to Shell’s long, successful history of drilling offshore Alaska," said Pete Slaiby, VP Alaska.

7 Mar 2012

EDC announces renaming of Trident XX jack-up rig to Saturn

Eurasia Drilling Company Limited ("EDC" or the "Company" - LSE: EDCL), the leading onshore and offshore drilling service provider in the CIS, announces that in February 2012 its Trident XX jack-up drilling rig was renamed SATURN. The Saturn is a Keppel FELS CS Mod V cantilever jack-up delivered in 2001, and is capable of operating in water depths to .... [+ read more] 350 feet and drilling to 26,000 feet. The SATURN is the highest specification jack-up rig currently operating in the Caspian Sea, with features including three 2,200hp mud pumps, a 3,000hp drawworks and a 15,000 psi high-pressure BOP system. The jack up rig, which was acquired in February 2011 from Transocean, is presently operating in Turkmen waters of the Caspian Sea on a long-term contract with Petronas Carigali (Turkmenistan) Sdn Bhd which will run through 2012.

6 Mar 2012

Successful appraisal of the Skrugard discovery

Statoil ASA, together with partners Eni Norge AS and Petoro AS, is about to complete drilling of appraisal well 7220/5-1 in the Skrugard discovery in the Barents Sea. The objectives of the appraisal well were to confirm the previous volume estimate for the Skrugard discovery and to collect reservoir and overburden data for field development planning. Both objectives have been met. .... [+ read more] Drilled by Transocean Barents drilling rig, appraisal well 7220/5-1 has proven a gas column of 26 meters overlaying an oil column of about 48 meters. Both column heights and reservoir properties came in as expected. This confirms the previous volume estimate for the Skrugard discovery and the total resource estimate for the Skrugard and Havis structures in the range of 400-600 million barrels of recoverable oil. “We are very satisfied with the results of the first appraisal well on Skrugard. All findings are in line with our expectations. We are now evaluating further exploration drilling in the area,” says Knut Harald Nygård, vice president exploration Skrugard area. Skrugard/Havis will be the northernmost field development on the Norwegian continental shelf so far. “The positive result confirms the basis for a development of Skrugard and Havis. The data and fluid samples acquired from the well are very valuable in our work to establish a robust development solution for the area and our aim to develop the Barents Sea into a core area for Statoil,” says Erik Strand Tellefsen, vice president for Skrugard field development. “We are currently considering several alternative development concepts. The reservoir engineering work is mainly done in-house while we are in the process of awarding several study contracts to engineering companies for the subsea and platform installations,” Tellefsen adds. Appraisal well 7220/5-1 is located about three kilometres north of discovery well 7220/8-1 in the Skrugard structure, and six kilometres northeast of Havis discovery. This is the third well in production licence 532, which was awarded in 2009 in connection with the 20th licensing round. The well is drilled to a vertical depth of 1740 metres below sea level at a water depth of 388 metres. Statoil is operator for PL532 with a share of 50%. The licence partners are Eni Norge AS (30%) and Petoro AS (20%).

6 Mar 2012

'Sevan Brasil' departs China

On the 6th of March 'Sevan Brasi'l departed China on the Mighty Servant I. The rig is expected to arrive in Brazil in the middle of April. .... [+ read more]

2 Mar 2012

New rig concept to improve recovery

Statoil is preparing an invitation to tender for a new type of drilling rig for mature fields on the Norwegian continental shelf (NCS). The new rigs, known as category J, will be jack-ups designed by the industry on behalf of Statoil. Statoil will propose for licence groups to take on ownership of these rigs. In order to realise the full potential .... [+ read more] of the NCS, increasing drilling activity on mature fields is important. Lower rig rates, greater drilling efficiency and access to rigs are key factors to meet this challenge. The new rig concept is designed to meet these requirements. “The key to maintain today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields. We need to drill more wells to deliver on our production ambitions,” says Øystein Arvid Håland, head of drilling and well in Statoil. The new category J rigs will be able to operate at water depths from 70 to 150 meters and drill wells down to 10,000 meters. It is a tailor-made jack-up rig for operations in harsh environment on both surface- and subsea wells in the shallow-water segments on the NCS. It will be a tool primarily for drilling and completion of production wells. “Statoil has the capacity and competence to drive technology and innovation to drill more efficiently and rejuvenate the rig fleet on the NCS. The new category J rigs will deliver wells 20% more efficient than conventional rigs. We aim to achieve reduced cost and time per well with safe and efficient operations,” says Håland. The rig design is currently being developed in collaboration with various industry players like hull designers, topside suppliers, construction yards and drilling contractors. “Statoil is continuously working to secure a rig fleet with the right capacities and capabilities to suit our needs. However, upgrade and adaptions on many of the existing rigs appear 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 rigs meet the right requirements,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “Now we follow up our industrial approach by proposing to take ownership of the rigs through licenses to improve economics further. As a long-term industrial player on the NCS, we look forward to working with suppliers who have competence in building and operating rigs to develop new and cost-effective solutions,” says Jacobsen. Statoil plans for invitation to tender for minimum two cat J rigs to be issued in July and for the contracts to be awarded in the 2nd half of 2012. The rigs are to be delivered in the 2nd half of 2015.

2 Mar 2012

New rig concept to improve recovery

Statoil is preparing an invitation to tender for a new type of drilling rig for mature fields on the Norwegian continental shelf (NCS). The new rigs, known as category J, will be jack-ups designed by the industry on behalf of Statoil. Statoil will propose for licence groups to take on ownership of these rigs. In order to realise the full potential .... [+ read more] of the NCS, increasing drilling activity on mature fields is important. Lower rig rates, greater drilling efficiency and access to rigs are key factors to meet this challenge. The new rig concept is designed to meet these requirements. “The key to maintain today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields. We need to drill more wells to deliver on our production ambitions,” says Øystein Arvid Håland, head of drilling and well in Statoil. The new category J rigs will be able to operate at water depths from 70 to 150 meters and drill wells down to 10,000 meters. It is a tailor-made jack-up rig for operations in harsh environment on both surface- and subsea wells in the shallow-water segments on the NCS. It will be a tool primarily for drilling and completion of production wells. “Statoil has the capacity and competence to drive technology and innovation to drill more efficiently and rejuvenate the rig fleet on the NCS. The new category J rigs will deliver wells 20% more efficient than conventional rigs. We aim to achieve reduced cost and time per well with safe and efficient operations,” says Håland. The rig design is currently being developed in collaboration with various industry players like hull designers, topside suppliers, construction yards and drilling contractors. “Statoil is continuously working to secure a rig fleet with the right capacities and capabilities to suit our needs. However, upgrade and adaptions on many of the existing rigs appear 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 rigs meet the right requirements,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “Now we follow up our industrial approach by proposing to take ownership of the rigs through licenses to improve economics further. As a long-term industrial player on the NCS, we look forward to working with suppliers who have competence in building and operating rigs to develop new and cost-effective solutions,” says Jacobsen. Statoil plans for invitation to tender for minimum two cat J rigs to be issued in July and for the contracts to be awarded in the 2nd half of 2012. The rigs are to be delivered in the 2nd half of 2015.

2 Mar 2012

New rig concept to improve recovery

Statoil is preparing an invitation to tender for a new type of drilling rig for mature fields on the Norwegian continental shelf (NCS). The new rigs, known as category J, will be jack-ups designed by the industry on behalf of Statoil. Statoil will propose for licence groups to take on ownership of these rigs. In order to realise the full potential .... [+ read more] of the NCS, increasing drilling activity on mature fields is important. Lower rig rates, greater drilling efficiency and access to rigs are key factors to meet this challenge. The new rig concept is designed to meet these requirements. “The key to maintain today’s production level on the NCS towards 2020 is improved recovery from existing fields and fast and effective development of new fields. We need to drill more wells to deliver on our production ambitions,” says Øystein Arvid Håland, head of drilling and well in Statoil. The new category J rigs will be able to operate at water depths from 70 to 150 meters and drill wells down to 10,000 meters. It is a tailor-made jack-up rig for operations in harsh environment on both surface- and subsea wells in the shallow-water segments on the NCS. It will be a tool primarily for drilling and completion of production wells. “Statoil has the capacity and competence to drive technology and innovation to drill more efficiently and rejuvenate the rig fleet on the NCS. The new category J rigs will deliver wells 20% more efficient than conventional rigs. We aim to achieve reduced cost and time per well with safe and efficient operations,” says Håland. The rig design is currently being developed in collaboration with various industry players like hull designers, topside suppliers, construction yards and drilling contractors. “Statoil is continuously working to secure a rig fleet with the right capacities and capabilities to suit our needs. However, upgrade and adaptions on many of the existing rigs appear 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 rigs meet the right requirements,” says Jon Arnt Jacobsen, chief procurement officer in Statoil. “Now we follow up our industrial approach by proposing to take ownership of the rigs through licenses to improve economics further. As a long-term industrial player on the NCS, we look forward to working with suppliers who have competence in building and operating rigs to develop new and cost-effective solutions,” says Jacobsen. Statoil plans for invitation to tender for minimum two cat J rigs to be issued in July and for the contracts to be awarded in the 2nd half of 2012. The rigs are to be delivered in the 2nd half of 2015.

2 Mar 2012

'ST Bahari-1' completes A12Z well on East Zeit Field

Dana Petroleum plc ("Dana") is pleased to announce that Zeitco, its joint venture with the Egyptian General Petroleum Company (“EGPC”), has successfully completed its first well of 2012, A12Z on the East Zeit field. The well was drilled with the newbuild SinoTharwa jackup rig ST Bahari 1, after successful commissioning with Zeitco. Initial production rates of over 1,000bbls oil per day .... [+ read more] have been recorded for the last week. When production stabilises, this will significantly enhance production from the East Zeit field, which was previously producing around 3,400bbls oil per day. Dana's Managing Director in Egypt, Nick Dancer, said; “A12Z is the first in a three well campaign, as part of a USD169 million investment Dana is making in Zeitco this year. This level of investment, coupled with the first multi-well campaign on the East Zeit field since 2004, shows Dana’s commitment to Egypt and partnership with EGPC.” Zeitco is an Egyptian joint venture company formed to operate the East Zeit concession, on behalf of the equal shareholders, EGPC and Dana Petroleum. Dana Petroleum has a 100% working interest in East Zeit.

29 Feb 2012

Fairmount Summit Delivers Delba III to Brazil

The Fairmount Summit has delivered the new build drilling rig ODN DELBA III safely from the Persian Gulf to a location offshore Rio de Janeiro, Brazil. The total voyage over a distance of 10,625 miles was performed with an average speed of 6.0 knots. ODN DELBA III is a semi-submersible drilling rig for deep water operations built in Abu Dhabi for .... [+ read more] Odebrecht Drilling Services, part of Odebrecht S.A., a leading Brazilian multinational. Odebrecht contracted Fairmount Marine to tow ODN DELBA III from Muscat, Oman, to Rio de Janeiro, Brazil. For this job the Fairmount Summit was mobilized to the Persian Gulf. During the towage at a stop-over at Cape Town, South Africa, some cargo runs were performed by the also contracted Fairmount Fuji. This multi-purpose DSV/supply vessel had just returned to Cape Town after a survey job on the Atlantic Ocean. The towage of ODN DELBA III was Fairmount Marine’s second successful operation for Odebrecht in a short period. Earlier Fairmount Marine performed the towage of semi-submersible drilling rig NORBE VI, a sister unit of ODN DELBA III, for Odebrecht.

24 Feb 2012

Securing rig capacity to improve recovery on the NCS

Statoil is entering into new contracts to secure increased rig capacity on the Norwegian continental shelf (NCS). The company has chartered two more rigs to be purpose-built for mature fields. The rigs will contribute further to Statoil’s efforts to improve recovery on the NCS. Songa Offshore has been awarded contracts for building the two rigs. The estimated contract value is .... [+ read more] USD 1.33 billion per rig for a fixed charter period of 8 years, with options for extensions of another 4x3 years per rig. The contracts cover two category D rigs for medium water depth. This innovative rig concept has been developed by the industry for Statoil. “Statoil is committed to maximising the value of the NCS,” says executive vice president of Development and Production Norway in Statoil, Øystein Michelsen. “We have a world-class project portfolio on the NCS with a robust production outlook. In addition to the safe and efficient development of new fields, we continue to step up our efforts to improve recovery from existing fields. We are convinced that new efforts are needed to secure a rig fleet that can handle the demanding tasks ahead.” By increasing the capacity of category D rigs, the drilling and completion of production wells will be carried out at lower costs, more efficiently and in a safe manner. Reducing rig costs is important in order to realise the values in existing discoveries. New discoveries are often made close to existing fields. Fast development of such discoveries is necessary to utilise the existing infrastructure. “In order to further revitalise the NCS, Statoil sees the need for adding new rig capacity. We are targeting the allocation of rigs and rig concepts to ensure more capacity in the market, and we are already seeing results of these efforts,” says chief procurement officer in Statoil, Jon Arnt Jacobsen. One of the new category D rigs will be used on the Norne, Heidrun and Åsgård licences, the other will be part of Statoil’s strategic rig fleet and set up for year-round operations in the Barents Sea. “We have carried out a procurement process which has generated significant interest among rig entrepreneurs, contractors and investors. Statoil committed to Songa Offshore last year to realise the first two category D rigs, these new contract awards strengthen our cooperation. The contract awards will raise exciting possibilities for Songa Offshore, but will also lead to positive spinoffs for sub-suppliers involved in producing and preparing the rigs for operation,” says Jacobsen. In connection with the contracts Statoil will provide to Songa Offshore a bridge financing covering the pre-delivery payment by Songa to the shipyard (DSME). The financing is equivalent to 20% of the total construction contracts value, offered at normal market conditions, including security.

24 Feb 2012

Securing rig capacity to improve recovery on the NCS

Statoil is entering into new contracts to secure increased rig capacity on the Norwegian continental shelf (NCS). The company has chartered two more rigs to be purpose-built for mature fields. The rigs will contribute further to Statoil’s efforts to improve recovery on the NCS. Songa Offshore has been awarded contracts for building the two rigs. The estimated contract value is .... [+ read more] USD 1.33 billion per rig for a fixed charter period of 8 years, with options for extensions of another 4x3 years per rig. The contracts cover two category D rigs for medium water depth. This innovative rig concept has been developed by the industry for Statoil. “Statoil is committed to maximising the value of the NCS,” says executive vice president of Development and Production Norway in Statoil, Øystein Michelsen. “We have a world-class project portfolio on the NCS with a robust production outlook. In addition to the safe and efficient development of new fields, we continue to step up our efforts to improve recovery from existing fields. We are convinced that new efforts are needed to secure a rig fleet that can handle the demanding tasks ahead.” By increasing the capacity of category D rigs, the drilling and completion of production wells will be carried out at lower costs, more efficiently and in a safe manner. Reducing rig costs is important in order to realise the values in existing discoveries. New discoveries are often made close to existing fields. Fast development of such discoveries is necessary to utilise the existing infrastructure. “In order to further revitalise the NCS, Statoil sees the need for adding new rig capacity. We are targeting the allocation of rigs and rig concepts to ensure more capacity in the market, and we are already seeing results of these efforts,” says chief procurement officer in Statoil, Jon Arnt Jacobsen. One of the new category D rigs will be used on the Norne, Heidrun and Åsgård licences, the other will be part of Statoil’s strategic rig fleet and set up for year-round operations in the Barents Sea. “We have carried out a procurement process which has generated significant interest among rig entrepreneurs, contractors and investors. Statoil committed to Songa Offshore last year to realise the first two category D rigs, these new contract awards strengthen our cooperation. The contract awards will raise exciting possibilities for Songa Offshore, but will also lead to positive spinoffs for sub-suppliers involved in producing and preparing the rigs for operation,” says Jacobsen. In connection with the contracts Statoil will provide to Songa Offshore a bridge financing covering the pre-delivery payment by Songa to the shipyard (DSME). The financing is equivalent to 20% of the total construction contracts value, offered at normal market conditions, including security.

24 Feb 2012

Statoil operated high impact gas discovery off Tanzania

Statoil (OSE:STL, NYSE:STO) and partner ExxonMobil have made a large gas discovery offshore Tanzania in the first exploration well in Block 2. Statoil announced on February 17 that the partnership had encountered indications of natural gas in the Zafarani exploration well in the Block 2 licence offshore Tanzania. The logging results now show that the discovery is a high impact .... [+ read more] discovery, so far proving up to 5 Tcf of gas in-place. The well has encountered 120 metres of excellent quality reservoir with high porosity and high permeability. The gas-water contact has not been established and drilling operations are on-going. “This discovery is the first Statoil operated discovery in East Africa and an important event for the future development of the Tanzanian gas industry. It is also a demonstration of how Statoil’s exploration strategy of early access and high impact opportunities strongly supports the company’s ambition for international growth,” says Tim Dodson, executive vice president for Exploration in Statoil. “This discovery could potentially be a catalyst for large scale natural gas developments in Tanzania,” says Yona Killaghane, Managing Director of Tanzania Petroleum Development Corporation (TPDC). Earlier this week the partnership signed an addendum to the production sharing agreement for Block 2 which stipulates the commercial terms in case of a development of natural gas resources in the block with the Tanzanian authorities. The Zafarani discovery is the fifth high impact discovery made by Statoil in the last 12 months, with the other discoveries being Skrugard and Havis in the Barents Sea, Johan Sverdrup (former Aldous/Avaldsnes) in the North Sea and Peregrino South in Brazil. Statoil operates the licence on Block 2 on behalf of TPDC and has a 65% working interest with ExxonMobil Exploration and Production Tanzania Ltd. holding the remaining 35%. Statoil has been in Tanzania since 2007 when it was awarded the licence for Block 2. TPDC has the right to a 10% working interest in case of a development phase. Zafarani is the first exploration well that has been drilled in the licence which covers an area of approximately 5,500 square kilometres. The water depth at the well location is 2,582 metres and the well itself will be drilled to reach an expected total depth of around 5,100 metres. The drillship, Ocean Rig Poseidon, will after completing the drilling activities at Zafarani move to drill a second well in Block 2 on the Lavani prospect.

21 Feb 2012

African Petroleum announces discovery with Narina-1 well in Liberia

African Petroleum Corporation Limited (APCL) announces that the Narina-1 well, offshore block LB-09, Liberia, has made a significant oil discovery. The discovery confirms the prospectivity of both of these highly successful West African exploration plays on APCL’s Blocks LB-08 and LB-09. Oil was found in good quality reservoirs in a Turonian submarine fan system extending across a prospective are of 250 .... [+ read more] sq km. The Narina-1 well was drilled by the ‘Maersk Deliverer’ to a total depth of 4,850 metres (15,912 feet), in a water depth of 1,143 metres (3,750 feet) taking 43 days for completion.

21 Feb 2012

Jupiter-1 discovery offshore Sierra Leone

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

17 Feb 2012

Statoil confirms indications of gas offshore Tanzania

Statoil and partner ExxonMobil confirm that the Zafarani-1 well in Block 2 offshore Tanzania has encountered indications of natural gas in a good quality reservoir. Drilling operations are still on-going and it is too early to give any indication of size and commerciality. The well was spudded in early January 2012 and drilling operations are expected to take up to .... [+ read more] a total of 3 months to complete. The well is being drilled by the drill ship Ocean Rig Poseidon and is located some 80 kilometres off mainland Tanzania. It is the first exploration well that has been drilled in the licence which covers an area of approximately 5,500 square kilometers. The water depth at the well location is 2,582 meters and the well itself is planned to reach a total depth of 5,150 meters. Statoil operates the licence on Block 2 on behalf of Tanzania Petroleum Development Corporation (TPDC) and has a 65% working interest with ExxonMobil Exploration and Production Tanzania Ltd. holding the remaining 35%. Statoil has been in Tanzania since 2007 when it was awarded the licence for Block 2. “TPDC is pleased about these preliminary results and is eagerly awaiting further information on this operation,” says Yona Killaghane, Managing Director of TPDC. The final assessment of what has been encountered will be released at a later stage once drilling operations have been completed and the well results fully analysed.

7 Feb 2012

RWE Dea secures rig capacity in Norway

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

6 Feb 2012

Pacific Drilling Announces Ultra-Deepwater Drillship Pacific Mistral Begins Contract in Brazil

Pacific Drilling S.A. (NYSE: PACD) (NOTC: PDSA) announced today that its ultra-deepwater drillship the Pacific Mistral commenced operations in Brazil on February 6, 2012. The drillship is contracted for a three-year term to Petróleo Brasileiro S.A. .... [+ read more]

1 Feb 2012

Darwin East prospect successfully spudded

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

31 Jan 2012

Pacific Drilling Announces Ultra-Deepwater Drillship Pacific Scirocco Begins Contract in Nigeria

Pacific Drilling S.A. (NYSE: PACD) (NOTC: PDSA) announced today that its ultra-deepwater drillship the Pacific Scirocco commenced operations in Nigeria on December 31, 2011. The drillship is contracted for an initial one-year term to a subsidiary of Total S.A. (NYSE: TOT). The contract further provides for options, to be exercised at the client’s discretion, which could result in up to four .... [+ read more] additional years of contract term.

10 Jan 2012

'Sevan Brasil' begins seatrials

'Sevan Brasil' left the Cosco shipyard at 12 pm local Chinese time today and proceeded offshore to commence thruster installation and seatrials. These operations are expected to take approximately 4-6 weeks and following completion the rig will be secured for shipment and loaded on to heavy lift for transport to Brazil. .... [+ read more]

9 Jan 2012

Major new oil discovery in the Barents Sea

Statoil ASA (OSE:STL, NYSE:STO) has together with its partners Eni Norge AS and Petoro AS made a substantial oil discovery in the Havis prospect in the same licence as Skrugard (PL532) in the Barents Sea. This is the second high-impact discovery in the North in nine months. Well 7220/7-1, drilled by the drilling rig Aker Barents, has proved a 48 .... [+ read more] metre gas column and a 128 metre oil column. Statoil estimates the volumes in Havis to be between 200 and 300 million barrels of recoverable oil equivalents (o.e.). The provisional, updated total volume estimate for the Skrugard and Havis discoveries in PL532 is in the region of 400-600 million barrels of recoverable oil equivalents. “Havis is our second high impact oil discovery in the Barents Sea in nine months. The discovery’s volume and reservoir properties make it Skrugard’s twin. Skrugard and Havis open up a new petroleum province in the North,” says Helge Lund, President and CEO of Statoil ASA. Havis lies approximately 7 kilometres southwest of the Skrugard discovery, made in April of last year. Havis lies within the same production licence, but forms an independent structure. There is no communication between the two discoveries. The discovery provides further confirmation of Statoil’s faith in the exploration potential of the Norwegian continental shelf, and makes an important contribution to the revitalisation of the NCS in line with what was communicated at Capital Markets Day in June of last year. Moreover, Havis and Skrugard prove that persistence and long-term thinking bear fruits. Statoil has been exploring in the Barents Sea for more than 30 years and the company has been involved in 88 of a total 92 exploration wells drilled in the area. This has resulted in continuous competence building and a deep understanding of the hydrocarbon systems in the Barents Sea. Statoil has previously communicated that the Skrugard discovery will provide the basis for an independent development, with the Havis volumes the development project becomes even more robust. Going forward, the partnership will drill an appraisal well in the Skrugard discovery and assess further upside potential in the licence. “The Havis discovery boosts the development of Skrugard as a versatile new centre with processing and transport capacity. We are about to realise the Barents Sea as a core area on the Norwegian continental shelf,” says Statoil’s Erik Strand Tellefsen, vice president for Skrugard development. “The Skrugard and Havis discoveries will be important for industrial development and will further boost activity in the supplier industry, providing new jobs and generating spin-off effects throughout the region,” adds Lund. Well 7220/7-1 is the second well in production licence 532, which was awarded in 2009 in connection with the 20th licensing round. The well is drilled to a vertical depth of 2200 metres below sea level at a sea depth of 365 metres. Statoil is operator for production licence PL532 with an ownership share of 50%. The licence partners are Eni Norge AS (30%) and Petoro AS (20%).

9 Jan 2012

Keppel AmFELS to Construct and Upgrade Deepwater Semisubmersible for Diamond Offshore for US$150 million

Keppel AmFELS LLC, a US wholly-owned subsidiary of Keppel Offshore & Marine Ltd (Keppel O&M), has secured a contract from Diamond Offshore to construct and upgrade a moored semisubmersible rig with delivery scheduled for 3Q 2013. The estimated shipyard contract price is approximately US$150 million. The rig, to be named Ocean Onyx, will be constructed from an existing hull from .... [+ read more] a Diamond Offshore cold stacked unit, which previously operated as the Ocean Voyager. Keppel AmFELS' scope of work on the Ocean Onyx includes the reconstruction of the rig, installation of advanced equipment such as a modern drilling package, and installation of sponsons to the pontoons to enhance the stability of the rig in deepwater. The rig will be designed to operate in water depths of up to 6,000 feet and will have a variable deck load of 5,000 long tonnes, a five-ram blowout preventer, and quarters capacity for 140 personnel.

6 Jan 2012

Narina-1 well spudded in Liberia

African Petroleum Corporation Limitied (APCL) has commenced drilling of the Narina-1 exploration well on Block LB-09, offshore Liberia where the company has a 100% interest. APCL drilled the first well (Apalis-1) in 2011 with encouraging results. The Narina-1 well will primarily target a Turonian prospect similar to discoveries like Jubilee in Ghana and Mercury/Venus in Sierra Leone. APCL estimates the targeted .... [+ read more] prospect has potential recoverable oil resources 500 mmbbls (Mean) to 1,200 mmbbls (Upside) for the Turonian reservoir plus additional potential resources in both shallower and deeper reservoirs. The Narina-1 well will be drilled by the ‘Maersk Deliverer’ semisub.

4 Jan 2012

Another discovery in the Gullfaks area

Statoil’s drilling of the Skinfaks South well in the North Sea has been completed and the estimated volume is between 1.9 and 6.9 million barrels of oil equivalents. This is the fourth infrastructure-near discovery in the Gullfaks area in a 10 month period. Light oil has been confirmed in Middle Jurassic reservoir rocks (Brent group) and a 80 metre high .... [+ read more] column in good-quality reservoir rocks. "We are currently evaluating how this discovery can be connected to the existing infra-structure," says Tore Løseth, exploration vice president for North Sea. Skinfaks South is located directly west of the Gullfaks field in the North Sea Tampen area, where Statoil is focusing on infrastructure-led exploration (ILX). "Our exploration strategy for the Norwegian continental shelf focuses both on high-impact discoveries and what we call time-critical ILX, which is exploration close to installations that within a couple of years will have the capacity to receive the oil and gas we find," Tore Løseth says. Gullfaks is a good example of how an area has developed after its first major discovery. Discovered in 1978 the Gullfaks field contained an estimated 2.5 billion barrels of oil equivalent. The discovery of fields such as Gullfaks South, Rimfaks and Valemon has later added another billion barrels of oil equivalent to the area. Statoil has continued its exploration activities around Gullfaks, and in one year four new discoveries have been made: Rutil, Opal, Brent 10 A/B and now Skinfaks South. They will add a total of 50-100 million barrels of oil equivalents. In 2012, 40% of Statoil's exploration wells on the Norwegian continental shelf will be ILX wells. ILX drilling is to be carried out close to Oseberg, Snorre and Norne.

3 Jan 2012

West Alpha returns to Ølensvåg

Westcon Yard has received a Letter of Intent from North Atlantic Drilling (a company partially owned by Seadrill) for work on the submersible rig West Alpha, in the third quarter of 2012. The work includes intermediate inspection and various modification works to prepare the rig for a new contract with ExxonMobil on the Balder field. West Alpha will bore two wells, .... [+ read more] a job which has an anticipated value of US$100 million, and will have an option for drilling a further four wells.