| Africa - West |
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| Bowleven IDs Hydrocarbons in Etinde Permit |
| Jul 15, 2010 - Bowleven has reached a final depth of 10,000 feet (3,048 meters) on the IE-3 appraisal well. Samples and pressure data indicates that the well has encountered multiple hydrocarbon-bearing reservoirs compromising both gas condensate and light oil. The objective of the well was to appraise the extent and the communication of the upper Isongo reservoir up dip of the previous wells drilled on the IE field, and also to target additional deeper Isongo reservoirs. Gas condensate was encountered in the upper Isongo sand objective. Additionally, logging and sampling of the secondary objectives have identified significant multiple-stacked reservoirs containing light oil and gas condensate pay. A further detailed analysis is required to fully evaluate the impact of the reserves base, and to reduce the remaining risks around the development of the IE field. A multiple test program will be conducted, and following testing, the rig might relocate to the MLHP-5 exploration well location. The appraisal well, in Block MLHP-7, is the first in a multi-well drilling program planned for the Etinde permit during 2010. The area comprises three shallow water blocks (MLHP-5, MLHP-6 and MLHP-7) in offshore Cameroon, West Africa. |
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| Total Acquires Chevron Stake in Sao Tome License |
| Jul 15, 2010 - Total will acquire Chevron's 45.9% interest in Block 1 in the Joint Development Zone in the Gulf of Guinea. The JDZ license spans 172,974 acres (700 square kilometers) in water depths ranging from 5,249 to 5,906 feet (1,600 to 1,800 meters). The license, governed by a treaty signed by Nigeria and Sao Tome and Principe in 2001 for a 45-year period, contains one discovery, Obo-1 well. Total will operate Block 1 in partnership with Addax Petroleum JDZ 1 Limited, Dangote Energy Equity Resources and Sasol Exploration and Production Nigeria Limited. The transaction is subject to governmental approvals. Total stated that the proximity to its operated licenses and facilities in Nigeria would enable cost reductions in developing the license's resources. |
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| Eni Hits Oil Pay in Block 15/06 |
| Jul 12, 2010 - Eni and Sonangol discovered an oil accumulation in the Cabaca South East-1 well in Block 15/06, located offshore Angola. The well, in a depth of 1,542 feet (470 meters), reached its multi-targeted objective in the deepest levels of Miocene age, where oil-bearing reservoirs, with a total of 1,476 feet (450 meters) of gross thickness, were proven. Reportedly, preliminary evaluations indicate the discovery holds high-quality oil, and potentially confirming the need for a second production hub in the northeastern area of the block. Current engineering studies and activities prior to the development of West Hub will provide guidance for a second production center, East Hub, which will double production from Block 15/06. Serving as operator of the block is Eni, holding a 35% working interest. Partners in the block include Sonangol Pesquisa e Producao (15%), SSI Fifteen Limited (20%), Total (15%), Falcon Oil Holding Angola SA (5%), Petrobras International Braspetro B.V. (5%) and Statoil Angola Block 15/06 Award AS (5%). |
| Project Details: Cabaca South East |
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| Asia - Caspian |
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| BP Awards Contracts for Chirag Development |
 Jul 9, 2010 - BP and partners have awarded six contracts, worth an estimated US $814 million, for the development of the Chirag project. According to Dow Jones, the contracts were granted to BOS Shelf, a joint venture between Saipem and Azerbaijan state oil company Socar; the ATA consortium between AMEC, Tekfen Holding and Azfen; and Kellogg Brown & Root. The Azeri-Chirag-Gunashli (ACG) oil field is located in the Caspian Sea, 75 miles (120 kilometers) offshore Azerbaijan in 394 feet (120 meters) of water. BP operates the project, holding a 34.1% interest. |
| Project Details: Azeri-Chirag-Gunashli |
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| S. America - Brazil |
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| Petrobras Commences Operation of Urugua's FPSO |
| Jul 15, 2010 - Petrobras has commenced operation of the Cidade de Santos FPSO in the Urugua field. Three wells were connected to the FPSO, Urugua-6, Urugua-8 and Urugua-10, and production should start later this week, reaching a rate of 25,000 bopd. A fourth well will be connected in December, and Urugua's full production rate of 35,000 bopd should be reached by year-end. The vessel will also develop the Tambua field, making it the first FPSO installed for the development of two oil and gas fields in the Santos Basin. Moored 99 miles (160 kilometers) offshore in a water depth of 4,265 feet (1,300 meters), the FPSO is capable of producing 10 MMcm/d and 35,000 bpd of oil and condensate with the capacity to store up to 740,000 barrels of oil. Urugua's development calls for four horizontal oil wells and five gas wells directly connected to the vessel. Tambua will have three horizontal wells of non-associated gas connecting to the FPSO by a submarine production manifold. Produced oil will offload to shuttle tankers while gas will flow through an 18-inch, 108-mile (174-kilometer) long pipeline from the FPSO to the PMXL-1 platform in the Mexilhao field. |
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| Australia |
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| Origin Energy Increases Kupe Reserves Estimate |
 Jul 14, 2010 - Origin Energy Ltd announced that following a detailed reserves review, the initial proved and probable (2P) reserves in the Kupe field have increased. Initial gas reserves have increased by 8%, LPG reserves by 5%, and light oil reserves by 27%. The reserves review integrated new petrophysical, fluid sample, and well test information from development wells drilled in 2008 with full field static and dynamic reservoir models. The models were updated to enable matching of the new technical information with limited early field production data. As a result of this modeling, 2P reserves are now estimated at 74.2 MMboe. The Kupe gas and light oil/condensate field is located offshore New Zealand in the Taranaki basin in a water depth of 115 feet (35 meters). The field lies in the Kupe Central Field Area (CFA) within PML 38146 and is operated by Origin Energy, which holds a 50% interest. Genesis Energy holds a 31% interest; New Zealand Oil and Gas Limited holds a 15% interest; and Mitsui E&P Australia Pty Limited holds a 4% interest. |
| Project Details: Kupe |
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| Apache Drills Barberry-1 in TL/2 Permit |
| Jul 13, 2010 - Apache Oil Australia commenced drilling on the Barberry-1 well, located in the TL/2 permit in the Carnarvon Basin, Western Australia. The ENSCO 109 (previously Ocean Shield) jackup is performing the drilling operations. Apache has elected to drill this well on a sole risk basis, as Tap Oil and joint venture partners have elected to not participate in the well. Under the TL/2 joint operating agreement, non-participating joint partners retain the right to participate in a successful discovery subject to back-in penalties. Apache operates the well, holding a 51.8% interest; Pan Pacific Petroleum holds 23.2%; Santos holds 15%; and Tap holds 10%. |
| Project Details: Barberry |
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| Apache Reaches TD on Laurel, Fails to Hit Pay |
| Jul 13, 2010 - Apache Oil Australia has reached total depth on the Laurel-1 well in the TP/7 permit in the Carnarvon Basin, Western Australia. Drilled by the Ocean Shield jackup in 128 feet (39 meters) of water, the well will be plugged and abandoned. Data gathered from the well will be incorporated into an existing evaluation of the permit. Apache Oil Australia serves as the operator, holding a 64.66% interest; Santos holds 18.71%; Tap holds 12.47%; and PPP holds the remaining 4.16%. |
| Project Details: Laurel |
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| Chevron Discovers Gas in Sappho-1 Offshore Australia |
| Jul 13, 2010 - Chevron discovered gas in the WA-392-P permit area in the Carnarvon Basin offshore Western Australia. Drilled by the Atwood Eagle semisub, the Sappho-1 well reached a depth of 15,406 feet (4,696 meters) and encountered about 246 feet (75 meters) of net gas pay. Chevron operates the permit with a 50% interest, while Shell Development (Australia) and ExxonMobil each hold 25%. |
| Project Details: Sappho |
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| Emerson Serves as Main Automation Contractor for Prelude Project |
| Jul 9, 2010 - Emerson was appointed by Technip Samsung Consortium to serve as Main Automation Contractor for the Prelude project. Supporting Technip Samsung Consortium, the project's FEED contractor, Emerson will be responsible for providing the strategy, design and engineering of the process control and monitoring technologies to support the production facility. The FLNG facility will operate as an integrated extraction, gas processing, and liquefaction plant. Prelude's facility will be 1,575 feet (480 meters) long, 246 feet (75 meters) wide, and will have a production capacity of 3.5 to 4MM tons of LNG per year, with the ability to process and export liquefied petroleum gas and condensate. When fully ballasted, the vessel will weigh an estimated 600,000 tons (544,311 tonnes), and will have the flexibility to relocate to another gas field once production is complete. The Prelude gas field is located in the Browse Basin offshore Western Australia in the WA-371-P permit. Containing an estimated 2 to 3 Tcf of recoverable gas, the Prelude field is 100% owned and operated by Shell. |
| Project Details: Prelude |
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| Asia - SouthEast |
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| Premier Targets First Oil from Chim Sao in 1Q11 |
 Jul 15, 2010 - Premier Oil reported that its Chim Sao project in Vietnam remains on schedule to commence production in July 2011. The gas export pipeline was installed and tie-in of subsea lines and manifolds is underway. Later this month, the topsides will be installed while the FPSO conversions are proceeding as planned, with sail away scheduled for the first quarter of 2011. Chim Sao is located on Block 12W and 12E in 377 feet (115 meters) of water, around 248 miles (400 kilometers) southeast of Ho Chi Minh City, offshore Vietnam. Premier serves as the operator of the oil and gas field, holding a 53.125% interest. Partners on the field include Santos (31.875%) and PVEP (15%). |
| Project Details: Chim Sao |
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| Premier Continues Gajah Baru Development |
| Jul 15, 2010 - Development of the Gajah Baru project is 58% complete, reported Premier. The wellhead platform and jacket installation will take place in September, and first production is on schedule for October 2011. The Gajah Baru gas field is located on the West Natuna Block A in the West Natuna Sea, Indonesia. Premier is the operator of the field and holds a 28.67% interest; the other partners in the field are Kufpec (33.33%), Amerada Hess (23%) and Petronas (15%). |
| Project Details: Gajah Baru |
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| Pearl Oil Plugs, Abandons Liyun Well |
| Jul 15, 2010 - Pearl Oil is plugging and abandoning the Liyun-1 well after reaching a total depth of 9,032 feet (2,753 meters). Logging over both the primary objective Kujung I reef and the section below indicates that a significant amount of hydrocarbons are not present. Liyun-1 is an exploration well in the Bulu Production Sharing Contract, and is located in the East Java Basin offshore Indonesia in a water depth of 180 feet (55 meters). Pearl Oil is the operator of the Bulu Production Sharing Contract, holding a 42.5% interest; AWE holds a 42.5% interest; PT Satria Energindo holds a 10% interest; and PT Satria Wijaya Kusuma holds the remaining 5% interest. |
| Project Details: Liyun |
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| Newfield Shuts East Belumut Production, Repairs Pipeline Damage |
 Jul 12, 2010 - An unidentified marine vessel has damaged an oil pipeline connecting the East Belumut platform to the Tinggi platform. Newfield Exploration, operator, has shut-in production from the oil field and the leak was isolated. The East Belumut field was producing about 20 Mbopd prior to shut-in. It should take approximately six to eight weeks to complete and return East Belumut to production. The field is located in license PM 323, about 160 miles (257 kilometers) offshore Peninsular Malaysia in 240 feet (73 meters) of water. |
| Project Details: Belumut |
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| Pan Pacific Petroleum Acquires Interest in Vietnam Block |
| Jul 12, 2010 - Pan Pacific Petroleum received the necessary approvals to acquire a 5% interest in the Block 07/03 Production Sharing Contract from Premier Oil Vietnam South. Under the terms of the original farm-out agreement with POVS, PPPV agreed to acquire 15% equity in the block by funding part of POVS' costs of the Ca Rong Do discovery well, CRD-1. However, under the terms of the Petroleum Law in Vietnam and the Block 07/03 Production Sharing Contract, PetroVietnam exercised its right of pre-emption to the extent of 10% of the proposed 15% farm-out interest. Block 07/03 spans 1.21 million acres (4,915 square kilometers) offshore Vietnam in the southern Nam Con Son Basin, and is adjacent to Block 12W, containing the Chim Sao and Dua oil fields. Currently, planning is underway to drill an appraisal well in the fourth quarter of 2010 or the first quarter of 2011. |
| Project Details: Ca Rong Do |
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| Europe - North Sea |
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| Statoil Turns on Gjoa's Power |
 Jul 15, 2010 - On July 11, Statoil turned on Gjoa's power, making it Norway's first floating platform to get its electrical power from the mainland. The electricity comes from Statoil's Mongstad facility, north of Bergen, through a 90,000-volt, 62-mile (100-kilometer) long subsea cable. The cable compromises both static and flexible parts, running from the seabed and up to the platform. Gjoa is located on Blocks 35/9 and 36/7 in the Norwegian North Sea in a water depth of 1,181 feet (360 meters). Partners in the project include Gaz de France with a 30% interest, Petoro also with 30%, Statoil with 20%, Shell with 12% and RWE with the remaining 8%. |
| Project Details: Gjoa |
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| Total Receives Approval to Develop Islay |
 Jul 15, 2010 - The United Kingdom Department of Energy and Climate Change and the Norwegian Ministry of Petroleum and Energy granted approval to Total for the development of the Islay gas field. Islay will connect to the Alwyn facility with first gas planned for the second half of 2011. Estimated to hold 17 million barrels of oil equivalent, the field is anticipated to reach a peak production rate of 2.5 MMcm/d plus associated condensates. The Islay field is located in Block 3/15 in the UK sector of the North Sea in a water depth of 394 feet (120 meters). |
| Project Details: Greater Alwyn |
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| Nexen Appraises Blackbird Oil Field |
 Jul 14, 2010 - Nexen has successfully appraised the Blackbird oil field in the UK Central North Sea. The 20/2a-9 well reached a total measured depth of 12,000 feet (366 meters), targeting a high quality Upper Jurassic oil discovery. It encountered approximately 330 vertical feet (101 meters) of gross oil-bearing section. Preliminary wireline log analysis indicates 75 feet (23 meters) total thickness of good quality, oil-bearing reservoir sands. The operator plans to complete the well and flow test it, and then suspend it as a future oil producer. Well 20/2a-6 might be tied-back to the Ettrick FPSO. Blackbird is located on Block 20/2a in a water depth of 367 feet (112 meters), about 4 miles (6 kilometers) south of the Ettrick field. Nexen serves as the operator and holds an 80% working interest; Dana Petroleum holds 12%; and Atlantic Petroleum holds 8.27%. |
| Project Details: Ettrick |
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| Statoil Awards Aker Framework Agreement for Gudrun |
 Jul 14, 2010 - Statoil entered into a framework agreement with Aker Solutions to study and modify installations in the Sleipner area of the North Sea. Initially, the agreement covers modifications of the Sleipner A and Sleipner T platforms as part of the Gudrun field development. The contract value is estimated at NOK 900 million, and according to Statoil, the intention of the agreement is to ensure the best possible use of the Sleipner installations for tie-back of new fields in the area. Aker Solutions' framework agreement includes engineering, purchasing, fabricating and installing equipment. Sleipner will process oil and gas from Gudrun as well as supplying power to the Gudrun platform. Gas will be processed on Sleipner A before transported to Sleipner T for carbon dioxide removal. The treated gas will be transported from Sleipner A to the gas markets. Gudrun, estimated to contain around 127 MMboe, is located in PL 025 in which Statoil serves as the operator, holding a 46.8%; Marathon holds a 28.2 %; and GDF holds the remaining 25%. |
| Project Details: Sleipner Area |
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| DONG Agrees to Marulk's Development |
 Jul 14, 2010 - DONG has agreed to a development plan for the Marulk gas field in the Norwegian sector of the North Sea. According to the plan, Marulk will be developed by two production wells connected to and controlled from a production vessel at the Norne field via a seabed installation. Expected to come online in the second quarter of 2012, Marulk's gas will be exported via facilities on Norway's west coast through a Gassled pipeline system. The development and the investment are still subject to governmental approval. Situated on Blocks 6507/2, 6507/3, 6607/12 and 6607/11 in a water depth of 1,250 feet (381 meters) is the Marulk field. Eni holds a 20% operating interest in Marulk; Statoil holds 50%; and DONG holds the remaining 30% interest. |
| Project Details: The Greater Norne Area |
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| Statoil Gets Green Light to Use Troll O2 |
 Jul 14, 2010 - Statoil received consent from The Petroleum Safety Authority Norway to use the new Troll O2 subsea template with pipelines, which will connect to the Toll C facility. Troll O2 is located 3.7 miles (6 kilometers) north of Troll C. The tie-in entails connecting the pipeline and umbilical to the existing subsea template on Troll O1 and using the existing production pipeline from Troll O1 to route the oil to Troll C. The water depth of the area ranges from 1,083 to 1,148 feet (330 to 350 meters). Start-up of the new template is scheduled for July 20, 2010. Troll, a natural gas and oil field, lies in the northern part of the Norwegian sector of the North Sea, about 40 miles (65 kilometers) west of Kollsnes, near Bergen. The field compromises the main Troll East and Troll West structures in Blocks 31/2, 31/3, 31/5 and 31/6. Statoil, holding a 30.59%, operates the field; Petoro holds 56%; A/S Norske Shell holds 8.1%; ConocoPhillips holds 1.62%; and Total holds 3.69%. |
| Project Details: Troll Area |
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| Aker Wins Clair Ridge Jacket EPC Contract |
 Jul 12, 2010 - Aker Solutions received an EPC contract for the delivery of two steel jackets for the Clair Ridge project. Also included in the contract is load-out and sea fastening of the jackets and associated piles. The Drilling and Production jacket will have a total weight of 24,582 tons (22,300 tonnes), and the Quarter's Utility jacket will have a total weight of 9,921 tons (9,000 tonnes). Detailed engineering will start immediately, while fabrication in Verdal will commence in June 2011. The jacket will be ready for load-out in mid-February 2013 and delivered in March. Clair is located 46 miles (75 kilometers) west of Shetland, in approximately 459 feet (140 meters) of water. BP operates the field, holding a 28.6% interest. |
| Project Details: Clair |
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| PSA Grants Statoil Consent to Drill |
| Jul 9, 2010 - Statoil has received consent from The Petroleum Safety Authority Norway to conduct exploratory drilling in Production License 269 using the Transocean Leader semisub. The consent applies to drilling wildcat well 35/1-2 S in the Norwegian sector of the North Sea. The well is located on the Soleie prospect in waters measuring 1,342 feet (409 meters), and drilling is expected to last 105 days. Statoil wholly owns and operates the license. |
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| Mediterranean |
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| ADX Spuds Lambouka Offshore Tunisia |
| Jul 12, 2010 - Exploratory drilling has commenced on the Lambouka-1 well in the Kerkouane exploration license offshore Tunisia. Estimated to hold 270 million barrels of oil equivalent, Lambouka's primary objectives are the Miocene-aged Birsa formation and the Cretaceous-aged Abiod formation. Drilling is being performed by the Atwood Southern Cross semibub in a water depth of 1,312 feet (400 meters). ADX Energy operates the license, holding a 30% interest. |
| Project Details: Lambouka |
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| S. America - Other & Carib. |
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| BPZ Preps Peru Well for Commercial Production |
 Jul 13, 2010 - BPZ Resources has completed its CX11-22D well, and commenced drilling on the CX11-23D well on the Corvina field. The 22D well was drilled in an up dip location of the field to appraise its oil and gas potential, and was completed to simultaneously produce oil and for the re-injection of formation water to transition the field to commercial production. A preliminary evaluation shows the well has approximately 75 feet (23 meters) of net oil pay; 70 feet (21 meters) of prospective oil pay in the lower zones, and has about 75 feet (23 meters) of net gas pay above the oil zones. During a production test, the well flowed at a rate of 300 bopd but with high gas rates. Gas flowed from an opened higher interval to help better define the gas/oil contact. 22D failed to achieve a consistent initial production rate, so BPZ will work over the well to isolate the gas sand. The 22D well is being produced intermittently to manage the amount of gas produced with the oil. Additionally, BPZ spud the 23D well. The company will begin installing and commissioning gas and water re-injection equipment after the well is completed in order to commence commercial production on Nov. 30, 2010. The Corvina oil and gas field is situated in the offshore Block Z-1 in northwest Peru. BPZ Energy acquired a working interest in Block Z-1 in 2001 and became operator with a 100% interest in the license in 2004. |
| Project Details: Corvina |
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| Toroa Dry, Well Plugged and Abandoned |
| Jul 12, 2010 - The Toroa F61/5-1 well was drilled to a total depth of 8,123 feet (2,476 meters) and logging operations were completed. Hydrocarbons were not encountered, so the well will now be plugged and abandoned. A further evaluation will be performed, and an update will be provided upon completion. Situated roughly 62 miles (100 kilometers) south of the Falkland Islands in 1,969 feet (600 meters) of water, the well was drilled by the Ocean Guardian semisub. |
| Project Details: Toroa |
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