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Recap: Worldwide Field Development News (Jan 27 – Feb 2, 2012)


This week the SubseaIQ team added 7 new projects and updated 86 projects. You can see all the updates made over any time period via the Project Update History search. The latest offshore field develoment news and activities are listed below for your convenience.

S. America – Venezuela
Repsol Begins Developing Perla Field
Feb 2, 2012 – Repsol has drilled five gas wells and plans to place each in production using offshore platforms and underwater connections, which will carry the gas onshore. The gas will be processed and sent through the Venezuelan distribution network. Repsol will develop the project in phases, with the first phase entailing an estimated investment of $1.5 billion, including the exploration and evaluation phase in which 300 MMcf/d of gas is expected to be produced. In the next two phases, production is set to rise fourfold to 1.2 Bcf/d, which will be maintained until the end of the contract in 2036.
Project Details: Perla
S. America – Other & Carib.
Borders & Southern Spuds Darwin East
Feb 1, 2012 – Borders & Southern Petroleum have spud exploratory well 61/17-1, which is designed to test the Darwin East prospect off the Falkland Islands. The prospect is a fault/dip closed structure with lower Cretaceous sandstone, reservoir target. Additionally, the exploration well will investigate geophysical attributes that include a flat spot, amplitude conformance to structure and an AVO (amplitude versus offset) anomaly. The Leiv Eiriksson (UDW semisub) is drilling the well and should take roughly 45 days to complete. Darwin East is located in the South Falklands Basin in the South Atlantic, about 87 miles (140 kilometers) south of the Falkland Islands.
Project Details: Darwin East
Bayfield Spuds Trinidad Well
Jan 27, 2012 – Bayfield Energy expects to spud the first well in its drilling campaign in its Galeota license offshore Trinidad. The operator is using the Rowan Gorilla (450′ ILC) jackup to drill the exploratory well EG8. The well lies in 135 feet (41 meters) of water and will be drilled to a total depth of 8,700 feet (2,652 meters). EG8 is a deviated exploration well intended to appraise the Lower Pliocene-to-Upper Miocene stacked, shallow marine sandstone reservoirs that were encountered in previous offset wells. Both of these earlier wells – EG2 and EG5, which were drilled in 1978 and 1985 respectively – encountered and tested gas at various levels and EG2 tested oil at a rate of 1,000 barrels of oil per day, reported Rigzone. The Galeota block spans 30,147 acres (122 square kilometers) in the shallow waters of the prolific hydrocarbon-rich Columbus Basin off the southeast coast of Trinidad. Bayfield operates the block with a 65 percent interest; while partner, Petrotin, holds the remaining stake.
Europe – North Sea
Subsea 7 Awarded Work for BP’s Clair Ridge Project
Feb 2, 2012 – BP granted Subsea 7 a contract for the Clair Ridge Project, west of Shetland. The Clair Ridge development will comprise two new bridge-linked platforms to be located in the northeast of Clair Phase 1. The contract scope includes the project management, engineering, procurement, fabrication and installation of a 3-mile-long (6 kilometer-long), 22-inch-diameter oil export pipeline and a 9-mile-long (14-kilometer-long), 6-inch-diameter gas export pipeline connected to the new production facilities and existing Clair Phase 1 export systems. The pipeline systems will allow production to be transported from Clair Ridge to Sullom Voe Terminal (SVT) via a dedicated gas export pipeline spur tied into the Clair Phase 1 pipeline. The associated gas will tie into the West of Shetland Pipeline System via the gas export pipeline. The scope also includes tie-ins of integrated subsea towhead structures, field testing and pre-commissioning activities. Offshore operations are due to commence in 2013.
Project Details: Clair
Total Launches Hild Development
Feb 2, 2012 – Total is launching the development of the Hild field in the Norwegian sector of the North Sea. The development, projected to cost $4.2 billion, is subject to the approval of the Norwegain Ministry of Petroleum and Energy and Norwegian Parliament. The partners submitted the PDO for approval on Jan. 25, 2012. Hild’s reserves amount to approximately 190 million boe. Production is expected to start in 2016 and will reach 100,000 boepd at peak.
Project Details: Hild
Nautical Farms-In to UK License Containing Hydra Prospect
Feb 2, 2012 – Nautical Petroleum has entered into an agreement with First Oil to acquire a 25 percent interest in UK License P1756, which contains the Hydra prospect. The license commitment calls for the acquisition of 155 miles (250 kilometers) of 2D and 24,711 acres (100 square kilometers) of 3D seismic plus a well to be drilled at the discretion of the participants. First Oil will continue to operate the license with a 75 percent interest.
Project Details: Hydra
Wintershall Spuds Maria Appraisal Well
Feb 2, 2012 – Wintershall has spudded the Maria appraisal well in the Norwegian sector of the North Sea. The operator is using the Borgland Dolphin (mid-water semisub) to drill well 6407/1-5S in PL 475BS. The main objective of the well is to prove oil in the northern part of the structure and to perform extensive data acquisition. “The results will help the Maria partnership to decide on the optimum development concept for Maria – either a subsea tieback or a standalone development,” said Maria Project Manager Hugo Dijkgraaf.
Project Details: Maria
Statoil Spins Bit at King Lear
Jan 31, 2012 – Statoil has spud the King Lear prospect in the Norwegian sector of the North Sea. The well should take about 166 days to reach total depth, and an additional 51 days if Statoil elects to sidetrack the well. The operator is using the Maersk Gallant (350′ ILC) jackup for the drilling operations.
Project Details: King Lear
Total Gets Consent to Drill in PL 102 C
Jan 30, 2012 – Total has been granted consent for use of the Borgland Dolphin (mid-water semisub) for drilling and completion of a production well in Production License 102 C. The operator will drill well 25/5-D-1-H as a sidetrack, which lies in a water depth of 390 feet (119 meters). Drilling is expected to start in February.
Project Details: Atla (David)
BP Shuts-in Production at Foinaven
Jan 30, 2012 – BP has halted production at its Foinaven field after a hairline crack was discovered in an underwater connecting pipeline. Production was immediately shut down and the leak was stopped, said the company. The field, which produces around 43,000 bopd, remains shut-in, and the company is unsure when production will resume. Foinaven was the UK’s first deepwater field and came online in mid-2000.
Project Details: Foinaven
Statoil Selects Spar Concept for Luva Development
Jan 30, 2012 – Statoil has selected a spar platform to develop the Luva field. Considered a deepwater pioneer in the Norwegian Sea, the Luva field may be the first to have a spar platform on the NCS. “This development may represent the start of deepwater production in the Norwegian Sea, and it will enable the tie-in of other discoveries in the same area,” said Ivar Aasheim, Statoil’s senior vice president for NCS field development. The spar platform will consist of a large-diameter, single vertical cylinder supporting a conventional deck with processing facility, accommodation quarters and other facilities. The installation will fix to the seabed. The development concept will include two subsea templates with four wells on each and one satellite template with one well. The platform will house accommodation quarters for a permanent crew, a storage unit for condensate, and a gas processing facility with a capacity of 812 MMcf/d. Gas will be exported through a 300-mile-long (483-kilometer-long), 30-36 inch diameter pipeline from the Luva field to the onshore processing facility at Nyhamna. The pipeline will also connect to the Linnorm field and tied-in to the Zidane field.
Project Details: Luva
Det norske Spuds Storebjorn Prospect
Jan 30, 2012 – Det norske has commenced exploratory drilling at Storebjorn in Production License 450. Well 7/12-13 S is the first well in the license, which was awarded in the 2007 APA licensing round. The Storebjorn prospect is located in the southern North Sea, in close proximity to existing infrastructure on the Ula and Gyda fields. The operator is using the jackup Maersk Guardian (350′ ILC) to drill the well.
Project Details: Storebjorn
N. America – US Alaska
Pioneer Divests Interest in Cosmopolitan Project
Feb 2, 2012 – Buccaneer Energy Limited has executed a Purchase and Sale Agreement for the acquisition of two main productive leases in the former Cosmopolitan Unit from Pioneer Natural Resources. The acquisition is being jointly made with BlueCrest Energy II. Buccaneer will acquire a 25% working interest and BlueCrest a 75% working interest with Buccaneer assuming operatorship of the project. Buccaneer plans to commence preliminary development planning on the Cosmopolitan project offshore Alaska. The operator plans to drill an offshore well using the Endeavour, Spirit of Independence (300′ ILC) jackup in late 2012 to further quantify both the oil and gas zones of the project. Development of the Cosmo project will begin in the northern hemisphere during the winter of 2012 and continue through to 2014. The preliminary development plan includes drilling oil wells from the existing onshore production site and drilling offshore water injection wells for reservoir pressure maintenance. Separately, offshore gas wells will be drilled and tied-back to the existing onshore site, which will be connected to ENSTAR’s recently completed gas transportation line.
Project Details: Cosmopolitan
N. America – US GOM
ATP Completes MC 942 No. 2 Well at Thunder Horse
Feb 2, 2012 – ATP has completed drilling of the Mississippi Canyon Block 942 No. 2 well to a measured depth of 21,400 feet (6,523 meters). As previously reported, three productive sands have been logged with a total of 239 feet (73 meters) of pay. ATP has set 7-5/8 inch casing across the B and C Sands and a 5-1/2 inch liner through the S Sand. The S Sand, at a depth of 21,010 to 21,090 feet (6,404 to 6,428 meters), has been perforated and completed. After completion of the next regularly scheduled BOP test, ATP will move to the completion of the C Sand which will be perforated at a depth of 17,560 to 17,730 feet (5,352 to 5,404 meters). As soon as the C Sand is completed, ATP will begin completing the B Sand which will be perforated at a depth of 17,410 to 17,480 feet (5,307 to 5,328 meters). An additional BOP test will be required before the completion of the B Sand. ATP estimates first production immediately upon completing these activities, scheduled for the first quarter 2012. Plans are to begin production in the S Sand. ATP intends to comingle the B and C Sands with the S Sand when the pressure equalizes between the three sands.
Project Details: Thunder Horse
Anadarko Spuds Spartacus
Jan 31, 2012 – Anadarko has spud the Spartacus prospect in 7,008 feet (2,136 meters) of water in the GOM. The operator is drilling the well using ENSCO 8500 (UDW semisub). Drilling should take roughly 60 days.
Project Details: Spartacus
Asia – SouthEast
Santos Commences Gas Production at Wortel
Feb 1, 2012 – Santos has commenced gas production at the Wortel field offshore Indonesia. The project includes two gas wells, a minimum facility wellhead platform and a 6-mile (10-kilometer) gas pipeline to the existing Oyong wellhead platform. Wortel???s gas production will then flow through the existing 37-mile (60-kilometer) pipeline to the onshore gas processing facility at Grati for processing and onward sale. Gross production rates from the combined Oyong and Wortel fields are expected to be about 90 MMcm/d.
Project Details: Oyong Project
Hess Comes Up Dry in Andalan
Jan 31, 2012 – Hess completed two of its three commitment wells on the Semai V Block offshore Indonesia, reported Rigzone’s RigLogix Database. Wells Andalan 1 and 2 were both dry. Andalan 1 encountered hydrocarbons and although non-commercial, it helps with understanding the basin, Hess said from a geological perspective.
Project Details: Andalan
AWE Prepping to Spud Atlas-1
Jan 31, 2012 – AWE Limited said planning for drilling the Atlas-1 well in the Titan PSC is accelerating following the execution of the drilling contract in November 2011. Site surveys are completed and based on the current rig schedule, the well is expected to commence drilling in April 2012.
Project Details: Atlas
PPP Reviewing CRD Development Plans
Jan 27, 2012 – Pan Pacific Petroleum is continuing to assess the potential of a commercial development of the CRD oil and gas/condensate discovery offshore Vietnam. The operator is deciding whether to further appraise the area or commence development plans. A decision is expected around the end of 1Q 2012, stated the company. In addition to the CRD discovery, Block 07/03 also contains several large undrilled exploration prospects which will be matured with the aim of establishing an exploration drilling program, subject to the approval of JV participants. The Ca Rong Do field is located on Block 07/03 in the prospective Nam Con Son Basin offshore Vietnam.
Project Details: Ca Rong Do (CRD)
Mediterranean O&G Increases Guendalina’s Gas Reserves
Feb 1, 2012 – Mediterranean Oil & Gas has revised the 2P recoverable reserves of the Guendalina field after conducting an independent review of gas reserves. The study was performed by RPS Energy, following the start of gas production in 4Q 2012 at the field. RPS’s CPR shows revised 2P recoverable reserves of 31.2 billion cubic feet (6.2 Bcf net to Mediterranean Oil & Gas), representing an increase of 42 percent relative to the previous pre-development valuation of 22 Bcf (4.4 Bcf net to MOG). RPS also estimates P3 reserves of 40.3 Bcf (8.1 Bcf net to MOG). The field, located 29 miles offshore the northeast coast of Italy, is producing roughly 21 MMcf/d.
Project Details: Guendalina
Tamar Development on Schedule to Commence Production
Jan 31, 2012 – Noble Energy reported that the Tamar development project remains on schedule for commissioning in late 2012, the company adds. Fabrication of the platform jacket and deck, and offshore pipeline installation, are 50 percent complete and onshore facility expansion is under way.
Project Details: Tamar
S. America – Brazil
New Subsea Guiding Frame Stabilizes Piles in Waimea Field
Feb 1, 2012 – The first offshore pile installation operation with the StabFrame, a newly developed subsea pile-stabilizing template, has been successfully completed at the Waimea field in Brazil’s Campos Basin. Jointly developed by Large Diameter Drilling Ltd. (LDD) and MENCK GmbH, the StabFrame stabilizes piles in all depths required for underwater pile driving. The operation was carried out in association with a contract that was awarded to MENCK by Wellstream International Ltd. The contract required MENCK to drive ten 84-inch mooring piles in water depths of up to 459 feet (140 meters) using an MHU 500T hydraulic hammer. The piles were required for installation of an FPSO mooring system on the OGX development of the offshore Waimea field.
OGX Confirms Hydrocarbon Find in Santos Basin, Swaps Rigs
Feb 1, 2012 – OGX has confirmed the existence of pre-salt microbiolite reservoirs with hydrocarbons in the shallow waters of the Santos Basin. As previously reported, the 1-OGX-63-SPS well had identified hydrocarbons both in the Aptian and Albian sections. When the well reached the Aptian section, it identified hydrocarbons through a high gas presence that resulted in a ‘kick’, indicating favorable permo-porosity characteristics and high pressure. As operations continued, the ‘kick’ was controlled and the analysis of rock fragments led to the confirmation of a microbiolite reservoir of Aptian age, which is the same type of reservoir rock found in the deep and ultra-deep waters pre-salt of the Santos and Campos Basins. The well has reached a depth of 20,128 feet (6,135 meters) and has thus far discovered a column of about 492 feet (150 meters) in the Aptian section. Due to the high pressures encountered, the drilling was temporarily suspended so that OGX can replace the current rig Ocean Quest (mid-water semisub) with the rig Ocean Star (DW semisub). The Ocean Star has the requisite specifications to continue the operation, which is expected to include logging and possibly conducting at least one drill-stem test.
Project Details: Fortaleza
OGX Opens First Well of OSX-1 FPSO
Jan 30, 2012 – OGX has initiated the opening procedure of the first producing well of OSX-1 FPSO, denominated OGX-26HP. The beginning of the production procedure initiated through the injection of chemical products into the well for the preliminary treatment of oil and gas, which will be processed by the vessel.
Clough Limited Gets Hook-Up, Commissioning Contract for Wheatstone Project
Feb 2, 2012 – Clough Limited received a contract for the offshore hook-up and commissioning component of the Chevron-operated Wheatstone project. The services will be provided over a 40-month period commencing immediately. The agreed scope of work includes the provision of labor, materials and an accommodation support vessel to assist Chevron with pre-commissioning, commissioning of integrated float over deck systems, offshore hook-up, and start-up assistance. Project management will be executed from Clough’s head office in Perth, while engineering and technical teams will be deployed to the fabrication yard in Korea and subsequently to the offshore platform located 140 miles (225 kilometers) from the Onslow coast.
Project Details: Wheatstone
Woollybutt Production to Cease in 1H12
Feb 1, 2012 – Woollybutt is an oil field in the Carnarvon Basin, Western Australia. Oil is produced from the field by a Floating Production Storage and Offtake vessel (FPSO), the Four Rainbow. Production at the Woollybutt field will end in April 2012 prior to the May 2012 termination of the FPSO contract. During the quarter, oil production rates at Woollybutt averaged 2,375 bopd gross for the period, with production lower production due to the mid-November shut-in of the Woollybutt-1 well, which was caused by a mechanical production.
Cliff Head Produces at Higher Rates following Field Maintenance
Jan 31, 2012 – Gross oil production at the Cliff Head oil field averaged 3,953 bopd for 4Q 2011. AWE said production remains at higher levels following the successful installation of a higher volume pump in the CH-12 well. Further field optimization studies are being undertaken.
Project Details: Cliff Head
AWE Updates Ops at Tui
Jan 31, 2012 – AWE reported that operational performance on the Tui oil field has performed well with production in line with budget forecasts. Furthermore, in early January 2012, a subsea project was undertaken to complete minor repair and maintenance work on various wellhead components on the producing wells. The field averaged daily gross production of about 5,600 bopd. Tui is located offshore New Zealand in 394 feet (120 meters) of water.
Project Details: Tui
GE to Supply Equipment for Ichthys LNG
Jan 30, 2012 – GE Oil & Gas will supply rotating equipment, subsea production systems, and connectors for the Ichthys LNG project offshore Australia. GE will provide rotating equipment, including gas turbines and compressors, for a new LNG plant at Blaydin Point, near Darwin, and associated floating production storage and offloading and a central processing facility in the Browse basin. In addition, GE will supply subsea production systems for the offshore portion of the project as well as subsea connectors for the pipeline to Darwin.
Project Details: Ichthys
Africa – West
Tullow Commences Phase 1A Development on Jubilee
Jan 27, 2012 – Tullow Oil reported that Jubilee’s Phase 1A of development has been approved by the Government of Ghana, and drilling is expected to commence in March 2012. The operator will use the Sedco Energy (DW semisub) to perform the drilling operations. This phase of development consists of drilling eight new wells (five producers and three additional water injectors) and expanding the existing subsea network. It will be conducted over an 18-month period. The total cost of Phase 1A is projected to cost around $1.1 billion. Commencing production in 4Q 2012, Jubilee is flowing at a gross rate of 70,000 bopd. The Jubilee field, located on two licenses, Deepwater Tano and West Cape Three Points, is situated in a water depth of 3,609 feet (1,100 meters).
Project Details: Jubilee


UK: Subsea 7 Bags Claire Ridge Project Contract


Subsea 7 S.A. has been awarded a contract valued at approximately $100 million from BP Exploration Operating Company Limited for the Clair Ridge Project, West of Shetland.

The Clair Ridge development will comprise two new, bridge-linked platforms to be located to the North-East of Clair Phase 1.

The contract scope includes the project management, engineering, procurement, fabrication and installation of a 6km 22” oil export pipeline and a 14km 6” gas export pipeline connected to the new production facilities and existing Clair Phase 1 export systems. The pipeline systems will allow product to be transported from Clair Ridge to Sullom Voe Terminal (SVT) via a dedicated gas export pipeline spur tied into the Clair Phase 1 pipeline, and the associated gas will again be tied  into West of Shetland Pipeline System via the gas export pipeline.

The 22” oil export pipeline bundle will be fabricated at Subsea 7’s Wester site facility in Wick, Scotland and will be installed using the Controlled Depth Tow Method. The 6” gas export pipeline will be fabricated at Subsea 7’s Vigra spoolbase. The scope also includes tie-ins of integrated subsea towhead structures, field testing and pre-commissioning activities.

Engineering and project management will commence from our Aberdeen office in early 2012, with offshore operations due to commence in 2013.

Steph McNeill, Subsea 7′s Vice President, UK said: “We are pleased to be awarded this major pipeline project by BP, which builds upon our unique bundle technology. Fabrication will take place at our Wick facility in Scotland, which has a  proven track record of successful bundle design, fabrication and installation, securing work for approximately 100 people. We look forward to helping bring on-stream the Clair Ridge Project in an efficient, timely and safe manner.”



Recap: Worldwide Field Development News (Jan 20 – Jan 26, 2012)


This week the SubseaIQ team added 10 new projects and updated 31 projects. You can see all the updates made over any time period via the Project Update History search. The latest offshore field develoment news and activities are listed below for your convenience.

Europe – North Sea
Duart Field Shut-In
Jan 26, 2012 – Bridge Energy stated that the Duart field is currently shut-in with production expected to restart in mid-March. The satellite field is located on UK Block 14/20 in the North Sea about 116 miles (186 kilometers) northeast of Aberdeen, Scotland.
Det norske to Drill Geite Prospect 2Q 2012
Jan 26, 2012 – Det norske announced plans to commence exploratory drilling in licenses PL 497/497B, in the Norwegian sector of the North Sea. Geite, located in a water depth of 262 feet (80 meters), is considered a large 4-way fault dependent closure. The operator plans to drill the prospect in 2Q12.
Project Details: Geite
Valiant, Antrim to Develop Fionn Field
Jan 25, 2012 – Antrim Energy and Valiant Petroleum have signed an agreement to proceed with early installation of subsea facilities for the development of the Fionn field in the UK sector of the North Sea. Fionn, located in Block 211/22a, was formerly called Central Causeway fault block. In December 2011, the UK Department of Energy and Climate Change assigned separate field designations to the Fionn field and the Causeway field, the latter containing the two fault blocks previously referred to as the East Causeway and Far East Causeway fault blocks. A Field Development Plan for the Causeway field was approved by DECC, with first oil expected in mid-2012. Under the terms of the Fionn Agreement, various subsea facilities will be installed during the first half of 2012 in conjunction with the installation of facilities for the Causeway field as a pre-investment for the future tie-in of Fionn to minimize development costs. Valiant will finance Antrim’s share of these costs. For three months following first oil from Causeway, Antrim has the option either to either withdraw from the Fionn project, or confirm its participation by paying its 35.1 percent share of the pre-investment outlay. Operator Valiant Causeway will likely submit a development plan for Fionn to DECC during the current quarter. It is planned that Fionn production will be combined with Causeway production, transported for processing to the Cormorant North platform, and exported to the Sullom Voe terminal for sale. First oil from Fionn is anticipated in mid-2013.
Project Details: Causeway
Total Submits Hild PDO to Norwegian Authorities
Jan 25, 2012 – Total has submitted a Plan for Development and Operation to the Norwegian Petroleum Directorate for the Hild field in the Norwegian sector of the North Sea. The field has estimated recoverable reserves of 1 Bboe. The development calls for an integrated wellhead, living quarters and production facility with a life expectancy of 30 years. The facility will be designed for remote control from an onshore base in Stavanger via an undersea cable from Kollsnes. It will also receive power from land. Oil will be sent by pipeline to a contracted storage vessel for processing before loaded onto shuttle tankers. The ship, which is planned to receive power from the production facility, can store up to 620,000 barrels of oil. Production is slated to commence in 2016. Hild is located in a water depth of 328 to 394 feet (100 to 120 meters).
Project Details: Hild
Nautical Divests 25% Stake in Kraken to EnQuest
Jan 24, 2012 – Nautical Petroleum will divest a 25 percent stake in the Kraken discovery (Petroleum License P1077) to EnQuest. Subject to the approval of the joint venture partners and the Department of Energy and Climate Change (DECC), EnQuest will become the operator of blocks 9/2b & 9/2c. The deal will involve Nautical receiving a carry on in its future expenditure on the Kraken field of up to $240 million, consisting of $150 million firm carry and a contingent carry of up to $90 million. The value of the contingent carry will be calculated by reference to a determination of the gross 2P reserves in blocks 9/2b and 9/2c. The reserve determination will take place during the development drilling phase. In addition to the disposal of a 25 percent interest in Kraken, Nautical will also divest interests in exploration blocks in the Greater Kraken area. EnQuest will receive a 10 percent interest in the P1575 license (Blocks 9/6a and 9/7b) and a 15 percent interest in the P1573 and P1574 licenses (Blocks 3/22a and 3/26). Krakan spans Blocks 9/2b and 9/1a in the UK sector of the North Sea.
Project Details: Kraken
E.ON Comes Up Dry at PL 350
Jan 23, 2012 – E.ON Ruhrgas has completed the drilling of wildcat well 6507/6-4 S and is in the process of completing the drilling of wildcat well 6507/6-4 A. Both wells are dry. The objective of wells 6507/6-4 S and 6507/6-4 A was to prove petroleum in Upper Triassic and Permian reservoir rocks, respectively. Well 6507/6-4 S encountered Upper Triassic reservoir rocks with reservoir quality as expected, while well 6507/6-4 A did not encounter the expected reservoir rocks. Extensive data acquisition has taken place at both wells and sampling was carried out. This is the first time drilling has occurred in PL 350. The wells will now be permanently plugged and abandoned.
Staoil Gets Govt Nod for Skuld Fast-Track Development
Jan 20, 2012 – The Ministry of Petroleum and Energy has greenlighted the plan for development and operation of Skuld, a fast-track development tied-in to the Norne field in the Norwegian sector of the North Sea. The field will be developed by three subsea templates with six production wells and three water injectors connecting to the Norne FPSO through a 14-inch-diameter production flowline and umbilical. The field is scheduled to come online by late 2012. Recoverable reserves in Skuld are estimated at 90 MMboe, primarily oil.
Project Details: The Greater Norne Area
Asia – SouthEast
AWE Acquires Acreage in Natuna Sea
Jan 26, 2012 – AWE Limited has executed a sale and purchase agreement with a Genting Berhad subsidiary to acquire a 100-percent interest and operatorship in two production sharing contracts offshore Indonesia for $39 million. Under the terms of the agreement, a wholly owned subsidiary of AWE will acquire assets that include an undeveloped oil field with an estimated 76 MMbbl of recoverable oil. The two PSCs, the North West Natuna PSC and the Anambas PSC, are located in the Natuna Sea in 230 to 295 feet (70 to 90 meters) of water. The NWN PSC contains the undeveloped Ande Lumut oil field, which is estimated to contain 76 MMbbl of recoverable heavy oil, and three exploration and appraisal wells. The Anambas PSC contains the Anambas gas field, discovered in 2006, together with a number of additional exploration prospects within an offshore area containing significant gas development and pipeline infrastructure. The transaction is effective from Jan. 1, 2012 and is anticipated to be complete by February 2012. The purchase will be funded by cash reserves and proceeds from part of AWE’s stake sale in the BassGas Project.
Nido to Acquire 2D Data over Service Contract 58
Jan 25, 2012 – Searcher Seismic, on behalf of the Service Contract 58 Joint Venture, is acquiring 621 miles (1,000 kilometers) of new 2D seismic data over the greater Bikuda ??? Bulador prospect area in the northern sector of the area. The prospects were high-graded by subsurface work performed in 2011. The survey will help to mature these prospects to drillable status, so they can be considered as candidates to meet the sub-phase 3 commitment well due before January 2014. The survey is expected to commence in the near future. Service Contract 58, operated by Nido with a 50 percent stake, is a large deepwater block covering approximately 3.3 million acres (13,440 square kilometers) that lies immediately outboard of the giant Malampaya gas field. No wells have been drilled in the block to date. Water depths are in excess of 3,281 feet (1,000 meters) over most of the block.
MEO Australia Creating POD for Seruway PSC
Jan 24, 2012 – MEO Australia says it is working on a variety of activities aimed at maturing a Plan of Development (POD) for the Gurame gas discovery within the Seruway PSC offshore Indonesia. This POD maturation, coupled with the Kuala Langsa discovery and the improved definition of the Ibu Horst exploration prospects will underpin its future plans to attract a farm-in partner for the Seruway block. MEO has committed to acquiring 172,974 acres (700 square kilometers) of 3D seismic and to drill a well by the end of 2012. The Seruway PSC covers an area of 898,228 acres (3,635 square kilometers) and contains two gas discoveries – Gurame and Kuala Langsa – including several exploration opportunities.
Asia – Far East
ConocoPhillips Reaches Settlement Agreement Related to Peng Lai Oil Spill
Jan 25, 2012 – ConocoPhillips and the China National Offshore Oil Corp. have reached an agreement with China’s Ministry of Agriculture to resolve issues related to the June 2011 incidents at the Peng Lai 19-3 field in Bohai Bay. The company will make a compensation payment of $160 million to settle public and private claims of potentially affected fishermen and bay communities from the oil spill. ConocoPhillips will also designate a portion of its $16 million environmental fund to improve fishery resources. Peng Lai is located on the Bozhong Block 11/05 in approximately 75 feet (23 meters) of water.
Project Details: Peng Lai
N. America – US GOM
Marlin Primes Eugene Bit
Jan 26, 2012 – Marlin Energy is preparing to spud the A-2DST01 well, a sidetrack of the existing A-2 well, targeting reserves in the Tex X2 sandstones. The operator is using the Ocean Columbia (250′ ILC) jackup to drill the well at the Eugene Island Field in the GOM. Two sidetrack wells are planned to access new reserves, said partner Leni. Potential pay zones have been identified in the Tex-X2 and X3 reservoirs, and if completed successfully, will lead to an immediate increase in production. The A#2 sidetrack is targeting a downthrown fault block which Marlin considers to have good seismic amplitude. The fault block has an estimated mean recoverable reserve of 0.5 million barrels of oil within the primary, Tex-X2, target level at a depth of approximately 13,000 feet (396 meters) subsea. The slightly deeper Tex-X3 reservoir will also be tested by the well.
Pyrenees Slated for Production in 1Q12
Jan 24, 2012 – The Pyrenees field is in its final stages of flowline and umbilical installation. Liquids-rich gas and condensate production is expected by February 2012 at a gross rate of 60 MMcf/d. Pyrenees is located on Garden Banks 293 in 2,100 feet (640 meters) of water.
Project Details: Pyrenees Discovery
Stone Acquires Stake in Wideberth Development in GOM
Jan 24, 2012 – Stone Energy has acquired a 25 percent non-operated working interest in the deepwater Wideberth development project. The company says that first production from this gas satellite tie-back is expected in 2Q12. Wideberth is located in 3,700 feet (1,132 meters) of water on Green Canyon Block 490.
Project Details: Wideberth
Shell to Appraise Vito in GOM
Jan 20, 2012 – Shell is on location at Mississippi Canyon Block 940 to drill the No. 2 appraisal well on the Vito prospect. The operator is using the Noble Danny Adkins (UDW semisub) to drill the well. Drilling should take about 145 days. The discovery is located in 4,206 feet (1,282 meters) of water.
Project Details: Vito
Chevron Hands Technip Wheatstone Contract
Jan 26, 2012 – Technip Oceania, an Australian subsidiary of France’s Technip Group, has received a contract by Daewoo Shipbuilding and Marine Engineering for the detailed design of Chevron’s Wheatstone offshore gas-processing platform. The offshore portion of the project compromises the development of gas fields in the WA-17-R and WA-253-P petroleum titles located on the northwest shelf offshore Western Australia in water depths of 230 to 655 feet (70 to 200 meters). Subsea gas gathering systems will transport production to the processing platform where the gas and condensate will be treated. It will then export to the onshore gas plant at Ashburton North. Work is scheduled for completion in the second half of 2012. The Chevron-operated Wheatstone project compromises the Wheatstone and Iago gas fields, located in water depths between 330 and 850 feet (100 to 260 meters).
Project Details: Wheatstone
McDermott Makes Big Splash with Ichthys Surf Contract
Jan 25, 2012 – Inpex has granted McDermott International a letter of award for the Ichthys gas/condensate field offshore Australia. The surf contract, with a value of $2 billion, is the largest subsea contract McDermott has received to-date. This project includes engineering, procurement, construction, installation and pre-commissioning of production flowline systems, a MEG injection system, plus start-up condensate transfer and fuel gas transfer flowline systems, control systems, as well as other associated SURF elements in water depths of up to 902 feet (275 meters). McDermott will also install mooring systems for the FPSO and central processing facility, as well as, installation engineering for future flowlines, risers and umbilicals. Engineering work has commenced with fabrication slated for 2013. Gas from the Ichthys field, in the Browse Basin approximately 124 miles (200 kilometers) offshore Western Australia, will undergo preliminary processing offshore to remove water and extract condensate. The gas will then be exported to onshore processing facilities in Darwin via a 552-mile-long (889-kilometer-long) subsea pipeline.
Project Details: Ichthys
ConocoPhillips to Drill Boreas in February
Jan 24, 2012 – ConocoPhillips is gearing up to commence a drilling program in the Browse Basin Australia. The first well, Boreas-1 in WA-315-P, is located 2.7 miles (4.2 kilometers) east of the Poseidon discovery. The well will be drilled in a crestal position on a previously untested fault block with significant gas potential. ConocoPhillips is funding 80 percent of Boreas-1 to fulfill its farm-in commitments. The operator will use the Transocean Legend (mid-water semisub) to drill the well in February 2012.
MEO to Acquire 3D Data over Permit WA-454-P
Jan 24, 2012 – MEO Australia has performed a technical evaluation of the Marina-1 gas and liquids discovery in permit WA-454-P in the Bonaparte Gulf. MEO says that the evaluation has provided sufficient encouragement to warrant an early investment in 3D seismic, as well as information on the nearby Breakwater prospect. Design of and tendering for the Floyd 3D seismic survey targeting Marina, Breakwater and two other leads were completed during the quarter. The contract for acquisition of the Floyd 3D seismic survey was awarded in early January. Acquisition is expected to commence in February and to be completed in March.
Eni to Drill Heron Appraisal Well 3Q12
Jan 24, 2012 – Eni will use the jackup ESNCO 109 (350′ ILC) to drill the Heron-3 appraisal well. The vessel is expected to arrive late in second quarter 2012 with drilling to occur during the third quarter. Heron is located in NT/P68 permit in the Bonaparte Basin offshore Australia.
Project Details: Heron
MEO Commences 3D Seismic Survey in AC/P 50 and AC/P 51
Jan 20, 2012 – MEO Australia Limited has commenced acquisition of a 125,282 acre (507 square kilometer) Zeppelin 3D seismic survey in AC/P 50 and AC/P 51 in the Ashmore Cartier region of the Timor Sea. The survey is scheduled to take about 23 days to record. The permits are in permit year three of the primary exploration term. The Zeppelin 3D seismic acquisition will fulfill the current year work obligation subject to receipt of regulatory approvals for a work program variation for AC/P51.
Statoil Acquires Acreage Offshore Greenland
Jan 23, 2012 – Statoil has acquired a 30.625 percent working interest at the Pitu license in Baffin Bay. The license was awarded to Cairn Energy during the first Baffin Bay licensing round in December 2010. Cairn will continue as operator and will retain a 56.875 percent working interest while partner Nunaoil will retain its carried interest of 12.5 percent. The work program includes the interpretation of recently acquired seismic data. The partnership will evaluate the seismic data prior to making a decision on drilling an exploration well. Cairn will retain operatorship at this stage, while Statoil will operate any future development.
N. America – Mexico
Pemex Confirms Veracruz Hydrocarbon Find
Jan 24, 2012 – Pemex says exploratory well Puskon-1 has proved the existence of an active petroleum system off the coast of Tuxpan, Verazruz, recording a series of hydrocarbon demonstrations. The well, drilled in a water depth of 2,122 feet (647 meters), was designed to evaluate the potential of a possible formation of the Mesozoic, which extends over an area of about 4.9 million acres (20,000 square kilometers). Pemex says the well was set to reach a total depth of 26,657 feet (8,125 meters) but confirmed the presence of wet gas at 23,622 feet (7,200 meters).Recorded temperatures and pressures were higher than predicted at 25,039 feet (7,632 meters). It also updated the geological-geophysical interpretations in order to propose a new future exploration location to assess the potential of this oil objective.
Africa – Other
Afren Plans to Spud Orpheus Prospect in 2012
Jan 24, 2012 – Afren plans to drill the Orpheus prospect in 2012 from an offshore location, and is in the process of securing a jackup drilling rig capable of undertaking this work. During Q4 2011 over 559 miles (900 kilometers) of deepwater 2D seismic was acquired, which is currently being processed. Final results are expected at the end of the 1Q 2012. The Orpheus prospect is situated in the Tanga block mainly offshore northeast Tanzania in coastal to shallow marine waters.
Project Details: Orpheus
Anadarko to Conduct Extensive Testing Program at Barquentine
Jan 20, 2012 – Anadarko is preparing to spud the Barquentine-3 well offshore Mozambique. The Deepwater Millennium (UDW drillship) is currently on location where it will commence an “extensive” testing program, reported Rigzone’s RigLogix Database. The operator plans to install observation gauges and conduct several flow tests. The discovery lies offshore Area 1 of Mozambique’s Rovuma Basin.
Project Details: Barquentine
Africa – West
Afren Plans to Drill Additional Development Well at Okoro
Jan 26, 2012 – Production at the Okoro field has averaged at 15,800 bopd on a gross basis during the period, reported Afren. In the first quarter of 2011, two infill wells were brought onstream, and debottlenecking work was also undertaken in order to increase the production handling capacity of the Okoro FPSO. Afren expects to drill a development well from the existing unmanned wellhead platform at the Okoro field. The Okoro field is located in OML 112 in shallow water offshore Nigeria.
Afren Mulling Okwok Development Plans
Jan 26, 2012 – Afren completed an Ocean Bottom Cable 3D seismic survey over the whole Ebok/Okwok/OML 115 area in 3Q11. The operator is currently processing the new data, which is slated for completion by 2Q12. One of the primary purposes of the new data is to assist in development planning for the Okwok field, and to pinpoint an additional appraisal well that the consortium will drill in the second half of the year, ahead of formal submission of a FDP to the Nigerian authorities. Afren is leaning towards a development plan that incorporates a separate dedicated production processing platform tied-back to the existing Ebok FSO, located about 8 miles (13 kilometers) to the west. The Okwok field is situated on OML Block 67 in 131 feet (40 meters) of water offshore Nigeria.
Project Details: Greater Ebok-Okwok Complex
Oriental Ramps Up Ebok Production
Jan 26, 2012 – Oriental Oil reported that initial phases of the Ebok development have been completed, following the commissioning and ramping of all 14 production wells. Reservoir performance and well deliverability recorded at the field to date are in-line with prognosis, with production processing and regular crude oil offtake operations running smoothly. The Transocean High Island VII (250′ ILC) jackup remains on location at the west fault block area of the field. The consortium plans to drill up to four horizontal production wells from the west fault block location targeting oil-bearing reservoir zones that were not drilled during the initial phases of field development work. The field partners also plan to drill an exploratory well on the Ebok north fault block during the first half of the year. Ebok is located on Block OML 67 offshore Nigeria in a water depth of 135 feet (41 meters).
Project Details: Greater Ebok-Okwok Complex
CAMAC Energy Enters Gambia
Jan 23, 2012 – CAMAC Energy has entered into an agreement with the Gambian Ministry of Petroleum on the provisional award of two offshore exploration blocks, A2 and A5, in water depths ranging in 1,969 to 3,281 feet (600 to 1,000 meters). CAMAC Energy will operate the blocks with an 85 percent interest, which cover a total surface area of 658,783 acres (2,666 square kilometers). Gambia National Petroleum Company will be carried at 15 percent through first oil. The two exploration blocks are located in the highly prospective West African Transform Margin, home to several recent major discoveries in Ghana (Jubilee, Odum) and Sierra Leone (Venus, Mercury). Additionally, in 1979 Chevron drilled the Jammah-1 well on the basis of sparse 2D data in Block A2. The well had gas shows, thereby establishing the presence of hydrocarbons in the area. Extensive 3D seismic shot on the two Gambian blocks A1 and A4, immediately west of the blocks A2 and A5, has revealed a number of material prospects and leads according to the operator African Petroleum Corporation Limited. One of the identified prospects, Alhamdulilah, has potential mean unrisked resources of approximately 500 million barrels.
Hyperdynamics Suspends Sabu-1
Jan 23, 2012 – After encountering equipment problems, Hyperdynamics has suspended drilling operations on the Sabu-1 exploratory well offshore Republic of Guinea. Repairs will be made and the delay is estimated to take about a week. The well reached a total subsea depth of 7,297 feet (2,224 meters), putting the well near the top of Cretaceous age sediments, and the next string of 13-3/8 inch casing was successfully set. Following retesting of the blowout preventer, the well reached a depth of 7,559 feet (2,304 meters). The operator expects to test prospective upper Cretaceous sandstone reservoirs while it drills the Sabu-1 well to a total subsea depth of about 11,811 feet (3,600 meters).
Project Details: Sabu


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