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Bayfield Spuds Another Well Offshore Trinidad

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Bayfield Energy, an independent oil and gas exploration and production group with key assets in Trinidad and Tobago, has announced the spud of the second well in its exploration and appraisal programme in the offshore Galeota Licence Area, designated EG7.

The well spudded on 4 April 2012 and is being drilled by the Rowan Gorilla III jack-up rig, following on from EG8, which was suspended as an oil and gas discovery in March following successful drilling results.

The well is located in 112 ft (34 m) of water and lies approximately 800m east of well EG1, which encountered oil in 1964. EG7 is planned to be drilled to a total depth of approximately 8,485 ft (2,586 m, measured depth below rotary table) and will be deviated to the south-east from the surface location to investigate the Lower Pliocene to Upper Miocene stacked shallow marine sandstone reservoirs encountered in the previous discovery wells EG1 (1964) and COS1 (1985).

As in well EG8, several primary exploration targets have been identified by direct hydrocarbon indicators highlighted through reprocessing of 3D seismic data acquired by Bayfield in 2010.

Following completion of EG7, as previously agreed the jack-up unit will revert to Bayfield’s alliance partner in the rig contract. This will allow time for Bayfield to integrate the results from EG7 and EG8 into its evaluation of the Galeota Licence, prior to proceeding with the next phase of drilling.

Bayfield is the operator of the Galeota Licence area holding a 65% interest, with Petrotrin holding the remaining 35%.

Source

Range Resources Reports Further Success at North Chapman Ranch

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by  Range Resources – Press Release – Friday, March 09, 2012

Range Resources reported Friday further success in the appraisal and development of the North Chapman Ranch Field onshore Texas (Range 20-25 percent interest), with the successful drilling of the Smith #2 and Albrecht #1 wells.

Initial gross flow rates from the uppermost pay zone, which is one of four principal pay zones, in the Smith #2 well reached more than 3 million cubic feet per day and 125 barrels of oil per day, with more than 7,500 pounds per square inch flowing casing pressure on a 10/64-inch choke. Work is being conducted now to remove all of the plugs below the upper pay zone and combine the remaining lower pay zones to achieve maximum rate and recovery, Range said.

The Smith #2 well was drilled approximately 1,350 feet southeast of the Smith #1 discovery well, further extending the Company’s Proved Reserves in that direction.

The Smith #2 was followed immediately by the Albrecht #1, drilled more than 1,500 feet southeast of the Smith #2. The Albrecht #1 confirmed the presence of the Howell Hight reservoir in that area and is also expected to add significant Proved Reserves to the Company’s portfolio.

With four wells now drilled in the field, Range estimates that over 80 percent of the structural closure at the Howell Hight reservoir falls into the proved and probable (2P) category. Work is currently underway to revise the reserve estimates at North Chapman Ranch, and is expected to be finalized once The Albrecht #1 well comes online. The Albrecht well is scheduled for completion and fracture stimulation within the next four to six weeks.

Once the Smith #2 and Albrecht #1 wells are both online, Range estimates that its net production and cash flow from the project will increase by more than 200 percent over current levels.

Company: Range Resources
more info

- Range Resources Reports Further Success at North Chapman Ranch (Mar 9)
- Range Resources Reports Continued Drilling Success in Trinidad (Jan 27)
- Range Charges Ahead at Trinidad (Dec 9)

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Trinidad to Offer Six Blocks in Deep Water Bid Round

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Trinidad and Tobago’s Ministry of Energy and Energy Affairs (MEEA) has announced that the 2012 Deep Water Competitive Bid Round is tentatively set to open on the 29th of March.

Leading up to the opening of the round, the MEEA will participate in road shows 21st – 24th of February at NAPE 2012 in Houston, 28th – 29th of February at Trinidad and Tobago Energy Trade Mission in the JW Marriot Houston, and the 8th of March at the MEEA delegation to the High Commission for the Republic of Trinidad and Tobago in London where the six selected deep water blocks nominated will be announced.

The six offshore blocks that are to be nominated and offered will come from locations in the East Coast Marine Area and Trinidad and Tobago Deep Atlantic Area (See Concession Map). This acreage offers a mix of water depths, hydrocarbon play-types and production potential.

Available Data

PGS, in conjunction with the MEEA, has acquired 6,766 km of marine MultiClient 2D data over approximately 43,000 sq. km of the Trinidad and Tobago offshore area.

PGS TOBAGO TROUGH MC2D 2008: 2,448 km of ultra-long offset, dual-sensor GeoStreamer 2D data located across 9 blocks in the West Tobago Sub-basin and Tobago Platform.

PGS DEEPWATER ECMA MC2D 2008: 1,966 km of ultra-long offset, dual-sensor GeoStreamer 2D data located across 26 blocks in the Barbados Accretionary Complex on the Trinidad and Tobago Deep Atlantic Area.

PGS NCMA-4&5 MC2D 2008: 2,352 km of high resolution 2D located across the Patao High across 2 blocks in the West Tobago Sub-basin and Southeast Tobago Sub-basin between the Tobago Platform and the Araya-Tobago metamorphic basement.

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Trinidad expects $3 Bln in energy exploration in 2012

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By Linda Hutchinson-Jafar

PORT OF SPAIN, Feb 6 (Reuters) – Upstream companies operating in Trinidad and Tobago will invest $3 billion in oil and gas exploration activities this year, Energy Minister Kevin Ramnarine said on Monday.

“2012 exploration drilling will spring to life after low to moderate activity,” he said at the opening session of the Trinidad and Tobago Energy conference.

Some 15 exploration wells will be drilled this year, mainly by Canada-based companies Parex Resources and Niko Resources and by BP, he said.

Five drilling rigs are currently operating in the country while six seismic programs were continuing or starting in 2012.

Trinidad and Tobago is highly dependent on the energy sector, which contributes close to 40 percent of GDP, 40 percent of revenues and is the largest source of foreign direct investment.

Updating the status of negotiations for deep water blocks in the Atlantic, Ramnarine said discussions have concluded with BP Trinidad and Tobago and he expects sign-off soon, while talks were continuing with BG Trinidad and Tobago and BHP Billiton for deep water acreage.

Ramnarine said the country’s continuing decline in oil production was a “most worrying aspect of the energy sector.”

Oil production, which averaged 92,000 barrels per day in 2011, was hampered by a plant shutdown at the state-owned oil company Petrotrin and by maintenance activity by other small oil producers.

“Any gains in government revenue that could be realized as a result of increased oil prices were negated by falling oil production. It’s hurting the national economy and the country at a time when we should be benefitting from high oil prices,” he told the energy conference.

Oil production has declined to 100,000 barrels of oil per day (bpd) from 145,000 bpd over the last 10 years.

Ramnarine said his ministry is preparing for a road show at the end of the month in Houston to meet with representatives from 200 oil and gas companies that have expressed interest in Trinidad and Tobago.

The ministry will also promote the next deep water bid round, which will be launched next month, he said.

Source

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

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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
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.
Australia
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

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