McDermott International, Inc. announced today that one of its subsidiaries has been awarded a contract by the Discovery system for offshore facilities in the Gulf of Mexico. The value of this contract is included in McDermott’s second quarter 2012 backlog.
Williams Partners L.P.owns 60 percent of the Discovery system and operates it. DCP Midstream Partners, LP owns the other 40 percent of the Discovery system.
The project is to deliver new junction facilities for Discovery’s Keathley Canyon Connector™ pipeline system with a 3,300-ton, four-leg platform in 350 feet of water. The unmanned platform will provide pipeline junction facilities for incoming deepwater pipelines from the Hadrian South and Lucius fields and for outgoing shallow-water pipelines to shore.
Fabrication is expected to commence this summer at McDermott’s Morgan City facility in Louisiana. Offshore installation is expected to commence during the third quarter of 2013, and is intended to be ready for operational start-up before the end of the year.
McDermott’s deepwater combination heavy lift and pipelay vessel DB50 is expected to perform the installation. The DB50 has recently undergone extensive enhancement to its power and propulsion systems, and has a new deepwater lowering system.
- Noble’s New Drillship Enters Three-Year Contract in GoM (mb50.wordpress.com)
- USA-GOM: Galapagos Production Rates Above Forecast (mb50.wordpress.com)
- GoM Lease Sale: Apache Expands Presence in Gulf of Mexico (mb50.wordpress.com)
- Houston, Texas: Deep Down Receives Multiple Services Contracts (mb50.wordpress.com)
GMC and Horton Wison Deepwater confirmed their Joint Venture established to design and supply innovative Buoyant Towers for shallow water fields.
Kevin Chell, CEO of the joint venture, stated “The Buoyant Tower concept draws on the proven technology of the cellspar and the design provides multiple benefits for fields where other concepts would be problematic requiring high capital costs and expensive crane barges for installation. The buoyant tower can operate in water depths up to 600 feet and can be relocated allowing small marginal plays to be exploited in a cost effective manner. The design allows for hydrocarbon storage if needed, can eliminate separate shallow water drilling units and provides a high level of flexibility for the operator.”
The benefits of the design were recognized and adopted by BPZ Energy for their new platform at the Corvina field offshore Peru. The tower is composed of four cylindrical cells and is connected to the seabed by a single suction pile which is integral to the hull structure. The tower and decks with the production equipment will be transported from the fabrication yard to Corvina on a submersible heavy lift ship. After upending, fixed and variable ballast will be pumped into the hull to provide stability for the platform.
The CX-15 shallow water tower is well on track for a summer 2012 installation and will be the first application of this design. The platform is designed for 12,200 barrels of oil per day, gas compression capacity of 12.8 million standard cubic feet per day and produced water handling and injection capacity of 3,500 barrels per day. A total of 24 drill slots will be available, some of which will be used for gas and water reinjection wells. The CX-15 platform will be located about one mile from the existing CX-11 Corvina platform, with both platforms interconnected via a series of subsea pipelines.
The JV completed the FEED scope in 2011 which led to detailed design for the buoyant tower. Fabrication is underway at Wison Offshore and Marine’s yard in Nantong, China. GMC are also providing project management and installation services for the CX-15 platform.
Jim Maher, COO of the JV, commented “We are pleased to be working with BPZ Energy on this important project which draws upon deepwater technology and applies it in the shallow water arena.”
BP wants to sell its interests in what it describes as “non-strategic assets” in the Gulf of Mexico as part of its plan to focus its businesses worldwide on major assets and future growth opportunities.
Reflecting an increased focus on exploration, BP said it added significantly to its interests in promising South Atlantic equatorial margin plays during the quarter. The firm said it farmed in to four exploration concessions with Petrobras in Brazil, deepened its interests offshore Namibia and was awarded three new blocks offshore Uruguay. BP also gained access to the promising potentially liquids-rich Utica shale formations in Ohio, it added.
BP remains on track to start up six new major upstream projects in 2012, it said. These include Clochas-Mavacola in Angola and Galapagos in the Gulf of Mexico, both expected to start in the second quarter.
During the first quarter BP made an underlying replacement cost profit, adjusted for non-operating items and fair value accounting effects, of $4.8 billion. The figure (which is broadly comparable with net income under US accounting rules) was lower than the $5 billion earned by the firm in the previous quarter because of the adverse impact of a $541 million consolidation adjustment related to unrealized profits in inventory held within BP’s downstream business.
“We have made a good start against our strategic priorities for 2012. During the quarter we gained access to significant new deepwater and US shale exploration acreage, our ongoing divestment programme has reached $23 billion, and we have five deepwater rigs at work in the Gulf of Mexico. This operational progress will underpin the financial momentum we expect to come through as we move into 2013 and 2014,” said Group Chief Executive Bob Dudley.
During the quarter BP made payments of $1.5 billion into the $20 billion Trust that it set up in the wake of the Deepwater Horizon disaster. At the end of the quarter, BP had made total payments into the Trust of $16.6 billion and it expects its payments to end in Q4 2012.
At the end of Q1 2012, BP had paid a total of $8.3 billion in individual, business and government entity claims, advances and other payments. The firm also expects to pay a further $7.8 billion as settlement for private economic loss and medical claims stemming from the Deepwater Horizon accident and oil spill after it reached a definitive agreement with the Plaintiff’s Steering Committee on April 18.
BP revealed on Friday the agreement to sell its interests in the Pompano and Mica fields in the deepwater Gulf of Mexico to Stone Energy Offshore, LLC, a subsidiary of Stone Energy Corp. for $204 million in cash.
The agreement includes the sale of BP’s 75 per cent operated working interest (WI) in the Pompano field and assets and 50 per cent non-operated WI in the Mica field, together with a 51 per cent operated WI in Mississippi Canyon block 29 and interests in certain leases located near the Pompano field.
Completion of the sale is subject to the pre-emption rights of various co-working interest owners. The companies expect to complete the sale in 2012.
BP group chief executive Bob Dudley said: “We continue to make progress in our divestment programme as we focus on BP’s areas of strength around the world. The sale of these mature assets will allow us to concentrate our efforts on the major production hubs and significant growth opportunities that BP has in the Gulf of Mexico.”
On completion of the transaction BP will continue to operate seven production platforms in the Gulf of Mexico, producing from some of the largest deepwater oil and gas fields ever discovered. Among BP’s Gulf of Mexico assets are the giant fields Thunder Horse, Atlantis and Mad Dog, each of which have long production profiles and development programs.
The Pompano Field is eight miles long, located within water depths ranging from 1,100 feet to 2,200 feet. Given the distance and depth range, the Pompano owners elected to use proven technology and placed a fixed platform in shallow water at the northern end of the field.
Both the Pompano and Mica fields produce oil and gas through the Pompano platform, approximately 120 miles southeast of New Orleans. First oil was produced from the Pompano field in October 1994 after being discovered by BP and Kerr-McGee in 1985. The Mica field, tied back to the Pompano platform some 29 miles to the north west, began production in 2001.
- USA: BP Confirms Significant Resource Extension for Mad Dog Complex (mb50.wordpress.com)
- USA: EMAS Wins Gulf of Mexico Subsea Contract from BP (mb50.wordpress.com)
- USA: Shell Sets World Record for Deepest Subsea O&G Well at Perdido Development (mb50.wordpress.com)
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.
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.
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.
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.
- Statoil: Riserless light well intervention (mb50.wordpress.com)
- Mexico: Cal Dive to Install Subsea Pipeline in Abkatun Offshore Field (mb50.wordpress.com)
- Gulf of Mexico: Vector Lands Cascade Chinook Field Job (mb50.wordpress.com)
- Shell Perdido: The first full field subsea separation and pumping system in the Gulf of Mexico. (video) (mb50.wordpress.com)
- Perdido Subsea System (video) (mb50.wordpress.com)
Apache Corporation said a subsidiary has received Australian government environmental approval for development of the Julimar and Brunello offshore natural gas fields that will supply natural gas to the Chevron-operated Wheatstone LNG project.
The Julimar and Brunello gas fields, discovered by Apache and Kuwait Foreign Petroleum Exploration Co. (KUFPEC) in 2007, are located offshore in exploration permit WA-356-P, approximately 180 kilometres (km) (112 miles) west-northwest of Dampier in Western Australia.
In 2009, Apache and KUFPEC joined with Chevron to develop the Wheatstone LNG hub. Apache and KUFPEC agreed to supply gas from their Julimar and Brunello fields and to become foundation equity partners in the Chevron-operated Wheatstone LNG project.