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BHP Billiton: Funds Approved for Mad Dog Phase 2 (USA)

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BHP Billiton today announced approval for US$708 million (BHP Billiton share) in precommitment funding for the Mad Dog Phase 2 project in the deepwater Gulf of Mexico. The funding will facilitate detailed engineering and the procurement of long lead time items related to the hull, topsides and subsea equipment.

The Mad Dog Phase 2 project is based on successful appraisal drilling which confirmed significant hydrocarbons in the southern portion of the Mad Dog field. The proposed project includes the development of a second spar facility with all subsea production and injection wells. The new facility is estimated to have a design capacity of approximately 130,000 barrels of oil per day that will be exported via the Mardi Gras Pipelines under existing agreements. A final investment decision is anticipated in calendar year 2013 with first production scheduled for calendar year 2018.

BHP Billiton Petroleum Chief Executive Officer, J. Michael Yeager, said: “Mad Dog Phase 2 will join our extensive Gulf of Mexico portfolio that includes Mad Dog and Atlantis as well as the Shenzi and Neptune platforms that we operate. The extension of this field will underpin continued valuable liquids production from the Gulf of Mexico and further enhance our growth profile.”

Mad Dog is a partnership between BP (operator, 60.5 percent share), BHP Billiton (23.9 percent) and Chevron (15.6 percent).

Source

Australia: Tap Taps into Tallaganda

Australia: Tap Taps into Tallaganda| Offshore Energy Today

Tap Oil Limited (Tap) advises that at 0900 hours (AWST) today the Atwood Eagle semi-submersible drilling rig commenced drilling the Tallaganda-1 exploration well in the WA-351-P permit.

The Tallaganda-1 prospect straddles both the WA-351-P and WA-335-P permits in the Carnarvon Basin, offshore Western Australia. The well will target 0.8 to 1.3 Tcf (mean to P10) of gas within WA-351-P (Tap estimate).

The prospect will test the gas potential of sandstones in the prolific Triassic age, Mungaroo Formation, in a well defined horst block as imaged by high quality modern 3D seismic data. This is the primary play type of the North West Shelf.

The well will be drilled as a vertical well in a water depth of 1,141 m and is expected to take 37 days (trouble free) to drill with a projected total depth of 4,250 m. Weekly updates will be provided on Wednesdays during drilling operations.

Tap’s cost for the well will be carried up to a cap of $10 million following Tap’s farmout of 25% of its participating interest in the permit to BHP Billiton Petroleum (North West Shelf) Pty Ltd in 2011.

Tap’s Managing Director/CEO, Mr Troy Hayden, said:

 “We are pleased to have commenced the Tallaganda-1 well which has the potential to deliver a resource multiple times larger than Tap’s current 2P reserves.  Success at Tallaganda-1 will also give greater certainty as to the prospectivity of the Triassic potential on the permit.”

Background

The Operator completed a detailed assessment of the plays, prospects and leads in the permit in 2010 including the 3D seismic acquired in 2008. Further leads and prospects have been defined in the Triassic Mungaroo Formation which Tap has assessed as a 2-3 Tcf combined speculative resource on block.

Additional leads have been identified in WA-351-P in the Jurassic and Early Cretaceous, both of which are productive elsewhere in the Carnarvon Basin. Current indications are that this shallower potential is larger, but higher risk, than the Triassic in this permit. Further work will be done on these objectives.

 WA-351-P Joint Venture Participants

BHP Billiton Petroleum Pty Ltd (Operator)

BHP Billiton Petroleum (Northwest Shelf) Pty Ltd 55%

Apache Northwest Pty Ltd 25%

Tap (Shelfal) Pty Ltd 20%

Australia: Tap Taps into Tallaganda| Offshore Energy Today.

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 Jan 6 – Jan 12, 2012

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This week the SubseaIQ team added 13 new projects and updated 47 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.

Australia
Hess’ Drilling Ops Resume Offshore Australia
Jan 9, 2012 – Hess recommenced drilling operations at the Glencoe-2 appraisal well offshore Australia. The well was suspended in September 2011 when the semisub underwent problems. The well was drilled in 3,678 feet (1,121 meters) of water. Hess wholly owns and operates the WA-390-P permit, in which the discovery lies.
Project Details: Glencoe
Eni Acquires Bathurst 3D Seismic Survey over Blackwood Discovery
Jan 6, 2012 – Eni has completed the Bathurst 3D seismic survey covering the Blackwood East structure, acquiring 189,283 acres (766 square kilometers) of 3D data. This survey was acquired pursuant to a farm-in agreement with Eni to earn a 50 percent interest in the Blackwood gas discovery by acquiring a minimum 123,553 acres (500 square kilometers) of 3D seismic data over the Blackwood area and drilling on exploration well. Eni has up to a year to elect whether to drill the Blackwood-2 well. The Blackwood discovery is located in permit NT/P 38 offshore Australia in 200 feet (61 meters) of water.
Project Details: Blackwood
S. America – Other & Carib.
CGX Energy Commences Drilling Offshore Guyana
Jan 9, 2012 – CGX Energy has spud the Eagle-1 exploratory well offshore Guyana. The Ocean Saratoga (mid-water semisub) is drilling the well in the Corentyne license in about 270 feet (82 meters) of water.
Project Details: Eagle
Asia – SouthEast
PNOC, Nido Target Mid-2012 to Drill Commitment Well in SC 63
Jan 12, 2012 – PNOC Exploration Corporation and its partner, Nido Petroleum, have commenced pre-planning for the sub-phase three commitment well of Service Contract 63. The operator estimates that exploratory drilling on the Aboabo prospect will begin in mid-2012, subject to rig availability. The Service Contract 63 spans 2.6 million acres (10,560 square kilometers) in offshore Southwest Palawan, and includes the Aboabo A-1X gas discovery well.
Otto Planning to Drill Cinco in 2Q12
Jan 10, 2012 – The joint venture consortium of Service Contract 55 has elected to enter the fourth sub-phase of the drilling program, which requires a commitment well drilled prior to August 2012. The operator is planning to drill an offshore deepwater well at the Cinco prospect in 2Q 2012. Otto is working with farm-in partner BHP Billiton, who is carrying Otto’s share of expenditure on the drilling of Cinco well, to determine the 2012 work program. BHP Billiton has contracted Deepwater Expedition (UDW drillship) to drill the well. Otto Energy operates SC55, which is located offshore Palawan Island in the Philippines.
Talisman Sanctions HST/HSD Development
Jan 10, 2012 – Talisman has sanctioned the Hai Su Trang and Hai Su Den (HST/HSD) development within Block 15-2/01 offshore Veitnam. Production is expected to commence in 2013. The operator is planning to tie-back the development to the Hoang Long‘s facilities to the south of the block. The project is operated by Thang Long JOC, consisting of Talisman (60 percent) and PetroVietnam (40 percent).
N. America – US GOM
Aker to Provide Umbilicals for Lucius Development
Jan 12, 2012 – Anadarko granted Aker Solutions a contract for eight steel tube umbilicals for the Lucius field in the GOM. The scope of work includes project management, design, engineering, and manufacturing of two electro/hydraulic dynamic production umbilicals, two gas lift dynamic umbilicals, three electro/hydraulic infield umbilicals and one gas lift infield umbilical, including all associated ancillary equipment required for installation and interface with the existing development. Management, engineering and manufacturing of the umbilicals will be performed at Aker Solutions’ facility in Mobile, Ala. Final deliveries are slated for 3Q 2013. The Lucius field is located on Keathley Canyon Block 874, 875 and 919 in a water depth of about 7,000 feet (2,100 meters).
Project Details: Lucius
Hess Allocates $1.6B for Production Drilling on Shenzi, Llano
Jan 12, 2012 – Hess has allocated production expenditures of nearly US $1.6B for drilling production and water injection wells at Shenzi, and drilling production wells at the Llano field in the deepwater GOM. Situated on Green Canyon 609, Shenzi commenced oil/gas production on March 25, 2009, and currently has 11 production wells online. The Llano field, located on Garden Banks 385 and 386, came online April 29, 2004, via the Auger TLP.
Project Details: Shenzi
Alliance Engineering to Construct Topside, Deck for Tubular Bells FPS
Jan 11, 2012 – Wood Group’s Alliance Engineering received a detailed engineering and design contract of the topside facilities and deck, for Williams Partners’ Gulfstar FPS spar production platform. The platform, for installation in Mississippi Canyon Block 768, will produce oil and gas from the Tubular Bells field. The Gulfstar spar platform will be located in 4,300 feet (1,311 meters) of water and designed to process 60,000 bopd and 200 MMcf/d. The single-lift topsides will have three deck levels and include processing equipment, seawater injection equipment, utilities, an accommodation building with helideck, and pumping and compression equipment to export the treated oil and gas through departing pipelines. The completed deck will weigh approximately 7,000 short tons. Initial production is scheduled to commence in 2014.
Project Details: Tubular Bells
FMC to Supply Subsea Equipment for Lucius Development
Jan 10, 2012 – Anadarko awarded FMC Technologies a contract to provide subsea systems and life-of-field services for the Lucius project. FMC’s scope of supply includes five subsea production trees and two manifolds, with delivery slated for 4Q12. First oil is slated for 2014. Lucius is located in 7,100 feet (2,165 meters) of water on Keathley Canyon Block 875. Anadarko operates the field, holding a 50 percent interest; Co-owners in the discovery include Plains Exploration & Production with a 33.33 percent interest and Mariner Energy with 16.67 percent interest.
Project Details: Lucius
Africa – West
Hess to Drill Production Wells on Block G in 2012
Jan 12, 2012 – Hess plans to drill production wells on Block G in Equatorial Guinea in 2012. Block G houses the Okume Complex and the Ceiba field.
Project Details: Ceiba
Rialto to Commence Drilling Program Offshore Cote d’Ivoire
Jan 11, 2012 – Rialto Energy is prepping to commence a drilling program in Block CI-202, containing the Gazelle, Hippo and Bubale discoveries. The company has contracted the Transocean operated GSF Monitor (350′ ILC) jackup to drill a three-well program that will include two appraisal wells and the capability to test five independent structures. It is expected that the drilling program will commence in late February 2012. The Chouette well, which is part of the drilling program, will be the Company’s first exploration test in the CI-202 permit. Chouette has been assessed to have the potential to contain up to 212 million barrels of oil on a P50 base case. The block is located offshore Cote d’Ivoire, where Rialto Energy acts as operator.
Eni Divests Interest in Oyo Field
Jan 11, 2012 – Nigerian OML Agip Exploration, a subsidiary of Eni, has signed a definitive agreement to divest its 40 percent working interest in OML leases 120 and 121 (containing the producing Oyo field) to Allied Energy. The transaction is subject to customary conditions for closing and is expected to conclude during the first quarter of 2012. Once approved, Allied plans to expedite the development of the Oyo field by drilling two additional production wells commencing in 2012. These two wells are expected to significantly increase oil production over current levels. Allied also intends to accelerate exploration activities in the OMLs to fully exploit potential outside of the field, independently estimated at up to two billion barrels of unrisked prospective oil resources. The Oyo field is located on Leases 120 and 121, roughly 43 miles (70 kilometers) off the coast of Nigeria.
Project Details: Oyo
African Petroleum Grabs Block Offshore Cote d’Ivoire
Jan 10, 2012 – African Petroleum has entered into an agreement with the Societe Nationale d’Operations Petrolieres de la Cote d’Ivoire (Petroci) and the Republic of Cote d’Ivoire to acquire one offshore exploration permit covering Block CI-513. The block, situated in the Western Offshore area of Cote d’Ivoire, covers an area of 355,832 acres (1,440 square kilometers). The exploration program will target deepwater Upper Cretaceous submarine fans in the area, believed to have similar high impact potential as discoveries in the Jubilee field (in Ghana) and the Mercury discovery (in Sierra Leone). African Petroleum will operate the block with a 90 percent stake; while PETROCI will hold the remaining 10 percent stake.
Total Enters Mauritanian License
Jan 6, 2012 – Total has signed an exploration license with Mauritanian government to acquire a 90 percent interest in Block C 9, situated in ultra-deep waters. The National oil company, SMH, will hold the remaining 10 percent stake. The block is located about 87 miles (140 kilometers) offshore Western Mauritania, spanning more than 2.4 million acres (10,000 square kilometers), in water depths ranging from 8,202 to 9,843 feet (2,500 to 3,000 meters). The operator is planning a seismic acquisition campaign as the first phase of the exploration program.
African Petroleum Spuds Narina-1 Well
Jan 6, 2012 – African Petroleum has spud the Narina-1 well on Block LB-09 offshore Liberia. Narina-1 will primarily target a Turnonian prospect similar to previous discoveries. The company estimates the prospect has potential recoverable oil resources of 500 MMbbls to 1200 MMbbls for the Turonian reservoir, plus additional potential resources in both shallow and deeper reservoirs. The Maersk Deliverer (UDW semisub) is drilling the well.
Project Details: Narina
Europe – North Sea
Athena FPSO to Leave Dubai in Mid-February
Jan 12, 2012 – Ithaca Energy reported that the BW Athena FPSO is undergoing final conversion work at Dubai Dry Dock World. The vessel is scheduled to begin its transfer from Dubai to the UK in mid-February. The Athena field is slated for production in 1Q12 and flow at a rate of 10,000 boepd. The Athena field lies on Block 14/18b in 440 feet (134 meters) of water.
Project Details: Athena
Chevron Spuds P2-10 in Dutch North Sea
Jan 11, 2012 – Chevron has spud the P2-10 well in the Dutch North Sea. The well is targeting an existing gas discovery on the P2 block aiming to evaluate commercial hydrocarbon flow rates within the Rotliegendes sandstone reservoir.
Technip to Supply Subsea Equipment for Golden Eagle Development
Jan 11, 2012 – Nexen awarded Technip a lump sum contract for the Golden Eagle development located in the UK sector of the North Sea. The contract covers the engineering, procurement, installation and commissioning of two export, one production, one mechanically lined water injection and one gas lift flowlines; one main umbilical and two subsea isolation valve umbilicals; subsea equipments; trenching and backfilling of all flowlines and umbilicals; tie-ins, protection, pre-commissioning and commissioning support. The project is scheduled for completion in the second half of 2014. The development plan for Golden Eagle includes a combined production, utilities and an accommodation platform linked to a separate wellhead platform. Golden Eagle is located on Block 20/1N in 374 feet (114 meters).
Project Details: Golden Eagle
BP, Odfjell Drilling Secure Contract for Quad 204 Project
Jan 11, 2012 – BP awarded Odfjell Drilling a pre-contract award for the provision of a new build, semisubmersible drilling unit for use in the West of Shetland area. The contract value is about US $1.2 billion, excluding options, and represents the largest contract in Odfjell Drilling’s 40 year history. The unit will be used in the development of the Schiehallion and Loyal fields, which lie within Quadrants 204 and 205 of the UKCS about 81 miles (130 kilometers) west of Shetland and 22 miles (35 kilometers) east of the Faroe-UK median line. The full contract will have a fixed duration of seven years and is slated to start in 4Q 2014. BP operates the project.
Project Details: Schiehallion (Quad 204)
Yme Slated for Production in 2012
Jan 11, 2012 – SBM Offshore says that productivity of work being performed on the MOPUstor platform for the Yme field has been impacted due to poor weather conditions in the North Sea. The operator and SBM Offshore are currently evaluating the related schedule and cost impacts of the development. Yme will be developed by 12 production wells and injection wells, of which five will be subsea completions. The wells will connect to a production platform for processing. Production from the field is expected to commence in 2012 and reach a peak production rate of 40,000 bopd. Yme is situated in Production License 316, which Talisman Energy operates, holding a 70 percent interest; Revus Energy holds 20 percent; and Pertra ASA holds 10 percent.
Project Details: Yme
Lundin to Spud Albert Prospect Soon
Jan 10, 2012 – Lundin plans to spud the Albert prospect, located in PL 519, in the 1Q of 2012. The operator will use the Bredford Dolphin (mid-water semisub) to perform drilling operations. The well is targeting a major fault bound north of the Tampen Spur hydrocarbon province. Lundin operates the license with a 40 percent interest; while Spring Energy holds 20 percent; Noreco holds 20 percent; and Bayerngas holds 20 percent.
Valiant Obtains Interest in Timon Prospect
Jan 10, 2012 – Valiant has farmed into Blocks 211/11b and 211/16b in the UK sector of the North Sea acquiring a 10 percent stake from Agora Oil & Gas. The blocks contain the Timon prospect, an Upper Jurassic stratigraphic trap. The consortium plans to spud the prospect in 1Q 2012 using the WilHunter (mid-water semisub). Valiant estimates prospective resources to total 30 mmboe.
Wintershall Gets Govt Nod to Drill in North Sea
Jan 10, 2012 – The Norwegian Petroleum Directorate has granted Wintershall a drilling permit for well 6407/1-5 in the Norwegian sector of the North Sea. Appraisal well 6407/1-5 will be drilled using the Borgland Dolphin (mid-water semisub). The appraisal well lies in Production License 475 BS/CS, where Wintershall is the operator with an ownership interest of 50 percent. The other licensees are Petoro AS (30 percent) and Centrica (20 percent).
Centrica Plugs, Abandons Butch Southwest
Jan 10, 2012 – Centrica has ended drilling of a sidetrack well on the Butch South West exploration prospect in Production License 405 B. After successfully drilling the Butch discovery and first sidetrack appraisal well, the partnership decided to drill a second sidetrack well from the same surface location. The objective of the well was to target additional oil volumes in an exploration prospect located to the south of Butch within a new segment containing the same reservoir. However, problems were encountered while drilling the section above the main reservoir. The partnership plans to drill a new well located closer to the prospect. The well was plugged and abandoned. The partnership includes Centrica (operator, 40 percent), Faroe (15 percent), Suncor Energy (30 percent) and Spring Energy (15 percent).
Project Details: Butch
Valiant Gets Thumbs Up to Develop Causeway
Jan 10, 2012 – The Department of Energy and Climate Change has approved Valiant’s Causeway Field Development Plan. The Borgsten Dolphin (mid-water semisub) is booked to complete the existing production and water injection wells on the field with first oil targeted for the second half of 2012. Development plans call for the drilling of a new production well and a water injection well in the East and Far East fault panels. A production well will be completed with dual electrical submersible pumps. Hydrocarbons will be sent to and processed at the Cormorant North platform operated by TAQA Bratani Limited before being exported to the Sullom Voe terminal. Causeway is located on Blocks 211/22a and 211/23d in a water depth of 350 feet (107 meters) in the UK sector of the North Sea. Valiant operates the field.
Project Details: Causeway
Sterling Resources to Spud Cladhan South in 1Q12
Jan 10, 2012 – Sterling Resources issued a letter of intent to use the Sedco 704 (mid-water semisub) to drill the Cladhan South prospect in the first half of 2012. Cladhan South is an upper Jurassic channelized sand play immediately to the south of the existing Cladhan discovery. The Cladhan field is located on Blocks 210/29a and 210/30a in a water depth of 1,634 feet (498 meters). Serving as operator of the field is Sterling Resources, holding a 39.9% interest; EnCore holds 16.6%; Wintershall holds 33.5%; and Dyas holds the remaining 10%.
Project Details: Cladhan
Det norske Spuds Kalvklumpen Prospect
Jan 10, 2012 – Det norske has commenced drilling exploratory well, 25/6-4 S in license PL 414 in the Norwegian sector of the North Sea. The target for the well is the Kalvklumpen prospect, and drilling is being conducted by the Songa Delta (mid-water semisub). The partners in the license include Det norske (operator, 40 percent), Noreco (20 percent), Faroe Petroleum (20 percent) and Bayerngas (20 percent).
Project Details: Kalvklumpen
Drilling Ops to Bloom at Orchid Prospect
Jan 10, 2012 – Valiant plans to spud the Orchid prospect in the middle of the first quarter of 2012. The operator will use the Sedco 711 (mid-water semisub) to drill the well. Orchid is a dual target, four-way dip closure at Tertiary and Chalk level located in Block 29/1c in the UK sector of the North Sea. Valiant estimates gross prospective resources for the entire prospect to be 30 MMboe.
Project Details: Orchid
Statoil Makes Significant Discovery in Barents Sea
Jan 9, 2012 – Statoil has made a substantial oil discovery at the Havis prospect in Production License 532 in the Barents Sea. Well 7220/7-1, drilled by the Transocean Barents (UDW semisub), proved a 157-foot (48-meter) gas column and a 420-foot (128-meter) oil column. The operator estimates that the volumes in Havis are between 200 to 300 bbl of recoverable oil equivalents. The well reached a vertical depth of 7,218 feet (2,200 meters) in a water depth of 1,198 feet (365 meters). Statoil serves as the operator of PL 532 with a 50 percent stake; while Eni holds 30 percent and Petoro holds 20 percent.
Project Details: Havis
First Oil Acquires Stake in Kraken Discovery
Jan 9, 2012 – EnQuest has agreed with Canamens Limited to acquire two of its companies, whose assets include a 20 percent stake in the Kraken oil discovery. EnQuest will pay an initial consideration of US $45 million dollars in cash and a further $45 million in cash, contingent upon approval of the Kraken field development plan by the Department of Energy and Climate Change. Through this transaction, EnQuest will acquire a 20 percent interest in Blocks 9/2b and 9/2c, including the Kraken discovery. Kraken is estimated to hold gross contingent resources of 160 MMboe for Block 9/2b and 9/2c. EnQuest also acquired further potential exploration upside in Blocks 3/22a and 3/29 and in Blocks 9/6a and 9/7b. Kraken is a large heavy oil accumulation in the UK North Sea, located in the East Shetland basin, to the west of the North Viking Graben. It is being progressed to the development stage. Kraken FDP approval is anticipated in H2 2012. The operator of Kraken, Nautical, has a 50 percent interest, with the remaining 30 percent interest held by First Oil.
Project Details: Kraken
NPD Grants Statoil Drilling Permit for Well 30/6-28 S
Jan 9, 2012 – The Norwegian Petroleum Directorate granted Statoil a drilling permit for well 30/6-28 S in the Norwegian sector of the North Sea. The drilling permit for well 30/6-28 S relates to the drilling of a wildcat well in Production License 053. The area in this license consists of parts of Block 30/6 on the Oseberg field, between Oseberg A and Oseberg C. The Oseberg Center is located on Blocks 30/6 and 30/9 in the northern part of the North Sea at a water depth of 328 feet (100 meters). Statoil serves as the operator of the Oseberg Center and holds a 49.30 percent interest.
Project Details: Oseberg Center

USA: Saratoga, McMoRan in Vermilion 16 Field JV Talks

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Saratoga Resources and McMoRan Oil and Gas LLC (McMoRan) are in advanced talks regarding a potential joint venture on Saratoga’s Long John Silver Prospect at Vermilion 16 field.

While specific terms of the proposed joint venture are still being discussed and subject to confidentiality obligations, Saratoga anticipates contributing its deep rights (approximately 20,000 feet and below) to approximately 4,000 acres and access to Saratoga’s production and pipeline facilities in Vermilion 16 with McMoRan expected to contribute approximately 6,000 acres to the joint venture. The joint venture objective is expected to target ultradeep shelf Lower Tertiary (Wilcox) and Cretaceous objectives at depths of 23,000-30,000 feet subsea. All of the subject acreage is in Louisiana state waters in Vermilion Parish with water depths ranging from 5-10 feet.

The Long John Silver Prospect is situated in one of the main Lower Wilcox depositional fairways that fed McMoRan’s Davey Jones discovery on the Gulf of Mexico Shelf and the Walker Ridge Wilcox discoveries in Gulf of Mexico Deepwater.

Saratoga will retain its existing rights to all shallower objectives in the subject acreage, including all proved, probable and possible reserves, consisting of 8.7 million barrels of oil equivalent (MMBOE) of proved reserves and 18.6 MMBOE of total reserves at January 1, 2011. Additionally, Saratoga will retain the right to process its production from such shallower objectives at Saratoga’s production and pipeline facilities. Saratoga owns and operates a central production facility in Vermilion Block 16 with production capacity of 100 million cubic feet per day and a two mile pipeline to shore. Saratoga intends to continue its current development plans with respect to its shallower reserves in Vermilion 16, including drilling of development wells commencing in the first quarter of 2012.

Saratoga President, Mr. Andy Clifford, said “We are excited at the prospect of partnering with McMoRan in our ultradeep shelf play. McMoRan’s management team, under the visionary leadership of James Moffett, has established its position as a pioneer and the preeminent player in the ultradeep shelf play. We have gained valuable insights into the ultradeep Wilcox play through our involvement in the University of Texas Deep Shelf Consortium and through my years at BHP Billiton, a participant in the original Blackbeard well and a participant in the Cascade and Chinook Wilcox discoveries in Walker Ridge. We believe our Long John Silver Prospect has similar characteristics to recent high profile Wilcox successes, including McMoRan’s highly acclaimed Davey Jones well. Our 3D mapped deep shelf plays in Vermilion 16 and Grand Bay add exciting potential to our ongoing developmental drilling program.”

Source

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UAE: Drydocks World Wins Tanker-to-MVC Conversion Deal from AET

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Drydocks World has signed a contract with Singapore based AET, for two Tanker-to-Modular Capture Vessel (MCV) conversion projects. AET is converting these vessels as part of the Marine Well Containment Company’s (MWCC) well containment system.

MWCC is a not-for-profit, stand-alone organization with 10 member companies ExxonMobil, Chevron, ConocoPhillips, Shell, BP, Apache Anadarko, BHP Billiton, Statoil and Hess. The conversion will be implemented at the Drydocks World – Dubai facility.

The conversion shall allow the tankers to continue to operate normally as tanker in the US Gulf of Mexico, with capability to be deployed as MCV within shortest possible time. The first vessel is expected to arrive at the yard in December 2011 and the second vessel in February 2012. Each project will be completed within a period of nine months. Each vessel will handle about 100,000 barrels of liquid and about 200 million standard cubic feet of gas per day. The MCVs are capable of operating at depths of 10,000 feet.

The vessels will be equipped with new state-of-the-art containment system provided by Marine Well Containment Company. Conversion scope includes installation of 4 off power generators, 4 off retractable type azimuth thrusters one tunnel thruster, Dynamic Positioning, Pipe racks on deck and supports for Process Module, Flare tower, turret etc..

“We are extremely happy to sign this prestigious Contract with AET, a well-known global service provider, as part of our well-articulated strategy of building our presence in the oil, gas and energy industries. We already have an established reputation and strong expertise in carrying out sophisticated vessel conversion projects for world-leading companies. Our thrust on expanding our knowledge base and creating a technology-driven state-of-the-art facility has borne fruit and we are able to effectively serve the industry,” said Khamis Juma Buamim, Chairman of Drydocks World.

Source

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Telemark

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Mirage/Morgus
Phase I of the project focuses on the northern part of the greater Telemark area, which includes the Mirage and Morgus fields.
Located on Mississippi Canyon Block 941 in a water depth of 3,800 feet (1,158 meters), the Mirage field was discovered in 1998 when a well encountered roughly 87 feet (27 meters) of hydrocarbons in two sands. The Morgus field is located on Mississippi Canyon Block 942 in 4,304 feet (1,312 meters) of water, and was discovered when drilling encountered approximately 55 feet (17 meters) of net pay.
In an effort to cut costs, ATP decided to jointly develop these fields due to their close proximity. Combined, Mirage and Morgus hold estimated recoverable reserves of 190 Bcf (5 Bcm).
In 2008, the West Sirius semisub drilled three wells on the Mirage and Morgus fields and reached a total depth of 5,900 feet (1,798 meters) in 3,927 feet (1,197 meters) of water.
To develop the Mirage field, Technip received a contract for the flowlines, risers, jumpers and subsea structures. The contract covered engineering for the installation, welding and installation of two steel catenery risers and two oil and gas export flowlines; fabrication and installation of subsea structures and jumpers and pre-commissioning of the project.
Mirage is operated by ATP, which owns a 25% interest; Statoil owns the remaining 75% interest. Morgus is operated by ATP, but Statoil owns 100% of the interest.
Telemark
Phase II of the project focuses on the Telemark field. Telemark is situated in a water depth of 4,300 feet (1,311 meters) on Atwater Valley Block 63. ATP acquired the field in 2006 and owns 97% interest; BHP Billiton holds 1% interest; Chevron holds 1% interest; and Eni holds the remaining 1% interest.
The field was discovered in 2003 in the southern part of the greater Telemark area when exploratory drilling encountered 140 feet (43 meters) of hydrocarbons in the Miocene sands. The Telemark field was deemed commercially viable shortly after, and ATP began field development preparations.
Situated 7 miles south of the Mirage and Morgus fields, Telemark originally was designed to have its own production hub, a MinDOC II, but the company decided to tie-back the field’s subsea well to the ATP Titan, as well. This development will result in an increase in production rates through ATP Titan in 2010 and 2011.
In May 2009, Bluewater Industries received a contract for the field’s development. The contract covers the design and manufacture of one high-pressure flexible riser measuring 2 miles (3 kilometers) long, and engineering for the installation and welding of one oil and gas production flowline approximately 13 miles (21 kilometers) long. The contact also includes installation of a flowline and associated riser with an option to install an umbilical; fabrication and installation of subsea structures and a jumper; and pre-commissioning of the project.
ATP Titan
In 2007, ATP decided to develop the Telemark area with a floating, drilling and production triple-column spar, the ATP Titan, since accessible infrastructure wasn’t nearby. The MinDOC, a deep draft floating platform, is comprised of three columns linked by pontoons, boasting a higher load capacity and enhanced stability than previous designed semisubmersibles or spars.
In 2007, construction of the ATP Titan MinDOC commenced with construction slated to end in the third quarter of 2009. The facility has a design capacity of 25 Mbopd and 60 MMcf/d (2 MMcm/d) and incoporates six dry tree wellheads with three pairs of future subsea flowlines. Mustang Engineering received a contract to provide detailed engineering and procurement support for the topsides production facilities on the ATP Titan.
Towards the end of 2009, ATP Titan was moored at the Mirage and Morgus fields to complete the drilling of three wells to vertical depths of 14,500 to 17,250 feet (4,420 to 5,258 meters). The vessel will serve as the production platform for the life of the fields’ reserves. Then, ATP Titan will move to the Telemark field to recover its remaining reserves once the vessel has finished producing from the Mirage and Morgus fields.
First production from the Telemark Hub commenced on March 28, 2010, and the vessel has an estimated life span of 40 years.
Future Exploration
A fourth field that is 100% owned and operated by APT — Oasis — is located on Mississippi Canyon Block 943, and may be tied-back to the platform, pending exploration results.

Source

BP Announces Significant Resource Extension of Mad Dog Field in Gulf Of Mexico

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Release date: 07 September 2011

BP announced today the drilling of a successful appraisal well in a previously untested northern segment of the Mad Dog field in the US Gulf of Mexico.

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The well results confirm a significant resource extension for the Mad Dog Field complex, which includes the existing field, in production since 2005, and appraisal drilling of the Mad Dog South field in 2008 and 2009. Pending confirmation through future appraisal drilling, the total hydrocarbons initially in place in the Mad Dog field complex are now estimated to be up to four billion barrels of oil equivalent.

The well, drilled by BHP Billiton on behalf of the unit operator BP, is located on Gulf of Mexico Green Canyon block 738 approximately 140 miles (225 kilometres) south of Grand Isle, LA., in about 4,500 feet (1,371 metres) of water. The well encountered about 166 net feet (50 metres) of hydrocarbons in the objective Miocene hydrocarbon-bearing sands and discovered an oil column of more than 300 feet (91 metres).

“With these additional hydrocarbon resources north of the main field, Mad Dog has been firmly established as a giant field in BP’s Gulf of Mexico portfolio, rivalling Thunder Horse in size of resource,” said Bob Dudley, BP group chief executive. “Working with the industry and regulators, we will apply our enhanced standards of safety, reliability and compliance to all of our Gulf activities as we continue to provide important jobs and energy to the nation.”

BP maintains a 60.5 per cent working interest in Mad Dog. BHP Billiton has a 23.9 per cent interest, Chevron Corporation, through its subsidiary Union Oil Company of California, has a 15.6 per cent interest.

Due to the materiality of the Mad Dog South finds in 2009, BP has been advancing development options to increase production from Mad Dog by adding another spar production facility with a production capacity of 120,000–140,000 barrels of oil equivalent per day (boed).

“Coupled with the recent exploration success at the discovery at the Moccasin prospect, located in Keathley Canyon, the Mad Dog result re-emphasizes the exploration and development potential of the Gulf of Mexico and the region’s ability to continue to deliver material projects for BP,” Dudley added.

On Sept. 6, 2011 Chevron Corporation announced the Moccasin discovery in the Lower Tertiary play on Keathley Canyon block 736. BP has a 43.75 per cent working interest in the Moccasin prospect. The prospect is operated by Chevron U.S.A. Inc., also with a 43.75 per cent interest, and the co-owner is Samson Offshore Company with 12.5 per cent interest.

Notes

  • The Mad Dog Field started production in 2005 and utilizes a truss spar platform, equipped with facilities for simultaneous production and drilling operations. The facility is designed to process 80,000 barrels/day of oil and 60,000 standard cubic feet/day of gas.
  • Oil and gas is transported to existing shelf and onshore interconnections via the Mardi Gras Transportation System.
  • BP is one of the largest producers of oil and gas in the US Gulf of Mexico with net production of over 250,000 boed. BP is progressing eleven Gulf of Mexico projects: Atlantis Phases 2 and 3, Kaskida, Mars B, Galapagos, Na Kika Phases 3 and 4, Freedom, Mad Dog Phase 2, Mad Dog North and Tiber.
  • Major BP developments in the deepwater Gulf of Mexico include: Pompano, 1994; Marlin, 2000; Horn Mountain, 2002; Na Kika, 2003; Holstein, 2004; Mad Dog, 2005, Atlantis, 2007, Thunder Horse 2008.

Original Article

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