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Rigless suspended-well abandonment

Offshore Installation Services (OIS), an Acteon company, has successfully completed its 16th rigless suspended-well abandonment campaign involving multiple operators in the Southern North Sea. The multi-operator model for programmes of this kind can deliver significant customer benefits in terms of cost-effectiveness. A total of nine mudline wells in categories 1, 2.1, 2.2 and 2.3 were abandoned during the operation including four on behalf of GDF SUEZ E&P UK Ltd. and two for RWE Dea.

The scope of work for OIS, part of Acteon’s activity and resource management business, included the initial approval processes; formulating the contracting strategy; developing detailed procedures; procurement; appointing specialist service providers; overall logistics; and recycling and disposing of the recovered wellheads.

OIS conducted the two-phase abandonment operation from a chartered DP2-class anchor-handling tug supply vessel (AHTS). During phase one, a proprietary twin low-pressure packer tool from Acteon sister company Claxton Engineering Services Ltd. was deployed through the vessel’s moon pool to set cement plugs across all the casing annuli. The second phase involved abrasive severance of the wells using Claxton Engineering’s SABRE cutting tool.

“We have a strong track record in providing commercially efficient decommissioning solutions which are particularly important for non-revenue-generating assets,” said OIS vice president of commercial and business development Tom Selwood. “Multi-operator campaigns such as this, enable operators to share the associated costs which, when combined with the rigless nature of our offering, makes this the most cost-effective way to comply with UK oil and gas decommissioning legislation.”

Max Proctor, GDF SUEZ E&P UK drilling manager, added, “We are committed to fulfilling our responsibility to the environment as an operator and are leading the way in the North Sea with the decommissioning of redundant wells. We started this campaign immediately after the request came from DECC for operators to fully abandon suspended wells by reviewing the history of the wells and confirming the status of each with an independent well examiner. OIS is a valued partner of GDF SUEZ and the success of this project is testament to the team’s strong technical skills and experience.”

Since 1996, the OIS team has successfully completed more than 100 well decommissioning projects without a single lost-time incident.

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KBR to Design Bonaparte FLNG Vessel for GDF Suez

KBR has been selected by GDF SUEZ Bonaparte Pty. Ltd. (GDF SUEZ), operator of the Bonaparte LNG project, to execute floating liquefied natural gas (FLNG) production vessel design work for its project offshore Darwin, Australia.

This award is one of two contracts being let by GDF SUEZ as part of an initial concept definition design competition for the vessel. The award also pre-qualifies KBR as a contender for the EPC delivery phase of the project. The concept definition work is already underway in KBR’s London operations centre in Leatherhead, and is expected to last up to 12 months.

KBR has developed an extensive global FLNG engineering capability in recent years, and draws on its experienced resource pool with capabilities in FPSO and onshore LNG EPC delivery.

“KBR is delighted to be working with GDF SUEZ on this project. We look forward to working together in a new relationship which we hope will prove valuable for both companies as this project moves towards the EPC phase,” said Roy Oelking, Group President, Hydrocarbons.

This work follows KBR’s recent FLNG front-end projects in London, Houston and Perth. FLNG represents a new market for the industry and KBR’s engineering capability is already being utilized in several FLNG projects around the world.

KBR to Design Bonaparte FLNG Vessel for GDF Suez| Offshore Energy Today.

Offshore Lists Top 5 Offshore Field Development Projects

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by  David Paganie

Selecting the winners of this year’s Five Star Award – the Top 5 offshore Field Development Projects – was no easy task. The geographic distribution of candidates stretched from the Americas to Europe, Africa, Asia, and Australia. Technological innovation was widespread as well. After careful consideration, a consensus has been reached.

In no particular order, Offshore magazine’s Top 5 Offshore Field Development Projects of 2011 are:

Nord Stream

With the completion of Line 1, developers of the (EURO)7.4-billion ($10-billion) Nord Stream project have realized the ambitious goal of moving Russian gas to European markets directly through the Baltic Sea. First announced in 2001, the project calls for the construction of two parallel 759-mi, 48-in. pipelines that will move natural gas from Vyborg, Russia, to Lubmin near Greifswald, Germany. The Nord Stream consortium includes Gazprom, Wintershall, E.ON Ruhrgas, Gasunie, and GDF SUEZ.

Bruce Beaubouef, managing editor, gives the full details in his report “Nord Stream completes world’s longest subsea pipeline.”

Pazflor

The Pazflor field offshore Angola boasts a number of firsts. Foremost among them is that it is the first-ever project to deploy a development plan based on gas/liquid separation at the mudline spanning several reservoirs. This technological innovation is what will make it possible to produce the heavy, viscous oil contained in three of the four reservoirs in this gigantic development in the Angolan deep offshore. Pazflor, operated by French oil company Total, lies 93 miles (150 kilometers) off Luanda in water depths ranging from 1,968 – 3,937 feet (600 to 1,200 meters) and has estimated proved and probable reserves of 590 MMbbl.

The project is described in detail by Eldon Ball, senior editor, technology & economics, in his report “Pazflor development relies on subsea separation system handling four reservoirs.”

Karan

Saudi Aramco’s $8-billion Karan gas field project offshore Saudi Arabia is the first-ever non-associated gas development in the country. Currently, five wells are flowing 120 MMcf/d on the way to a design capacity of 1.8 bcf/d by 2013. The field produces gas via a 68-miles (110 kilometers) long subsea pipeline to the onshore Khursaniyah process facility. Plans call for approximately 20 total wells spread over four production platforms that tie in to a main platform with associated electrical power, communications, and remote monitoring and controls.

The project report by Gene Kliewer, technology editor, subsea & seismic, is provided in full detail in “Karan marks first-ever non-associated gas project offshore Saudi Arabia.”

Peregrino

The achievement of first oil from the Statoil-operated Peregrino heavy oil field in Brazil in April marked a major milestone for the operator. It is the first field to be brought onstream by the company in Brazil and its largest operated field outside of Norway. And by bringing Peregrino’s 14°API crude to the surface, Statoil provided convincing testimony of its heavy oil expertise.

See the full report by Nick Terdre, contributing editor, in “Peregrino producing heavy oil for Statoil offshore Brazil.”

Who Dat

Discovered in December 2007, the LLOG Exploration-operated Who Dat field lies in an average water depth of 3,200 ft (975 m) in Mississippi Canyon blocks 503, 504, and 547, in the Gulf of Mexico. Three wells – two in MC 503 and one in MC 547 – have been completed, with 10 more infill wells to be drilled and completed in the coming months using the semisubmersible rig Noble Amos Runner. Notable achievements for the field development include the first use of the OPTI-EX design; the first use of an FPU built “on spec;” and the first use of a privately owned FPU.

Jessica Tippee, assistant editor, gives a detailed report in “Who Dat initiates production in GoM in post-Macondo era.”

Congratulations to all of Offshore magazine’s winners for their contribution to the successful application of new and innovative technology. More information on the award-winning projects is available in a special webcast hosted on Offshore magazine’s website.

The projects are selected on the basis of best use of innovation in production method, application of technology, and resolution of challenges, along with safety, environmental protection, and project execution.

Copyright 2011 PennWell Publishing Company. All Rights Reserved.

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GDF Suez Sees Strong China LNG Demand

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China’s demand for liquefied natural gas (LNG) is expected to surge five-fold to 44 million tonnes per annum (mtpa) by 2020, while the emergence of 10 new importing countries in Asia could add another 27 million tonnes of new demand each year, an executive from GDF Suez SA told an industry conference on Wednesday.

Booming Asian demand, combined with uncertainty over the pace of new supplies, could create lasting opportunities for supplies as far afield as the United States to flow into the Pacific, said Nicholas Zanen, vice-president of trading at U.S. energy company Cheniere Energy Inc .

Philip Olivier, president of GDF Suez’s LNG unit, said LNG demand in Asia and the Middle East was expected to grow by 95 million tonnes per year from 2010-2020 and although there was enough flexible supply in the medium term to sate Asian demand, new plants urgently needed to be build to meet long-term growth.

We cannot underestimate LNG demand in China and India, and there is little additional volume available from the Atlantic Basin,” Olivier said.

GDF’s bullish forecast on China was in line with forecasts by state-owned China National Offshore Oil Corp, which estimated the country’s 2015 imports at 30 mtpa, driven by a surge in LNG-fuelled vehicles and development of LNG storage facilities.

China imported 9.4 million tonnes of LNG in 2010.

To ride on Asia’s growth, Olivier told Reuters that the company was focused on building a supply base in Australia via its proposed Bonaparte floating LNG project.

Australia is our No.1 priority at the moment because of its stability and proximity to Asian markets,” he said.

Although Australia’s gas exports are set to triple by 2017 to overtake Qatar as the world’s top LNG exporter, Olivier said the supply growth would not be enough to take away the premium in Asian prices.

(reuters)

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