AGR wins NCS frame agreement with Premier Oil

AGR has been assigned by Premier Oil to deliver a range of services within the Norwegian Continental Shelf (NCS).

The contract period is for five years plus an additional three years. The scope of the agreement covers well management and well planning services for exploration drilling and field developments. The work scope will encompass delivery of resources, competence and methodology by AGR’s well management team in Norway.
 
Sjur Talstad, AGR’s E.V.P, Norway and Russia, said: “We are pleased to continue the close working relationship with Premier Oil on the Norwegian Continental Shelf (NCS). The activity will be carried out from our fast growing Stavanger office which has an excellent track record of delivering well management and operational HSE support."
 
AGR recently celebrated drilling over 500 well projects in 25 countries for 106 clients - an average of one drilling project commenced every 10 days since 2000. On the NCS, the company has managed over 80 drilling projects on 14 rigs on behalf of 21 operators. Last year, AGR’s Norway team was involved in 15% of exploration wells drilled on the NCS.

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Baker Hughes acquires software technology company Perfomix

Baker Hughes stated the acquisition of Perfomix, a Texas-based oilfield software technology company focused on solutions to enhance oil and gas operations' performance. Perfomix will operate as a wholly-owned subsidiary of Baker Hughes and will be integrated into the company' s remote operations services organization.

Perfomix offers a data and advisory services delivery platform to support drilling, pressure pumping, completions and production operations, and regulatory reporting requirements. The addition of Perfomix will expand the Baker Hughes portfolio of field devices integration, real-time data management, visualization, and analytics software, thus complementing existing capabilities with a modern, elastically scalable and standards-based technology platform.

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Delineation of the 6407/1-6 S gas/condensate discovery near in the Norwegian Sea

Wintershall Norge, operator of production licence 475, has concluded the drilling of appraisal wells 6407/1-7 and 6407/1-7 A.

The wells were drilled about 8 km northeast of the Tyrihans field and 5 km northeast of the 6407/1-6 S gas condensate discovery in production licence 475. The reservoir in this discovery consists of thin sandstone layers from the Lange formation in the Lower Cretaceous. The discovery was made in January 2013. The resource estimate for the discovery was then between 3 and 20 million standard cubic meter of recoverable oil equivalents.

The objective of well 6407/1-7 was to delineate the 6407/1-6 gas/condensate discovery higher up in the structure. A new appraisal well, 6407/1-7 A, was therefore drilled downflank to investigate reservoir thickness and lithology.

Well 6407/1-7 proved gas/condensate in two sandstone intervals with a net vertical thickness of 12 m and a gross reservoir thickness of 16 m. Well 6407/1-7 A proved gas/condensate in two sandstone intervals with a vertical thickness of 7 m and a gross reservoir thickness of 13 m.

The difference in pressure measurements between wells 6407/1-7, 6407/1-7 A and the discovery well 6407/1-6 S indicates that there is no communication between the appraisal wells and the 6407/1-6 S discovery. Well 6407/1-7 has therefore proven a separate discovery, and will be reclassified as a wildcat well.

Preliminary estimates of the size of the new gas/condensate discovery range from 1 to 4 million standard cubic meter of recoverable oil equivalents.

The resource estimate for the 6407/1-6 S gas/condensate discovery has now been downgraded to between 1 and 6 million standard cubic meter of recoverable oil equivalents. The licensees will consider the discoveries in conjunction with other nearby discoveries as regards future development.

This is the second and third exploration well in production licence 475. The production licence was awarded on 29 February 2008 (APA 2007).

Wells 6407/1-7 and 6407/1-7 A were drilled to vertical depths of 3,345 and 3,311 m, respectively, below the sea surface, the latter with a measured depth of 3,571 m. Both wells were terminated in the Lange formation in the Early Cretaceous. Water depth at the site is 280 m. The well has been permanently plugged and abandoned.

Wells 6407/1-7 and 6407/1-7 A were drilled by the Borgland Dolphin drilling facility, which will now proceed to production licence 550 in the northern part of the North Sea to drill wildcat well  31/2-21 S, where Tullow Oil Norge is the operator.

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Magnolia LNG, SKEC Group sign technical services agreement

Liquefied Natural Gas Limited has reported that Magnolia LNG, LCC (MLNG), its wholly-owned subsidiary, has executed a technical services agreement (TS Agreement) with SK E&C USA, Inc., a wholly-owned subsidiary of SK Engineering and Construction Co. Ltd., of Korea (SKEC Group).

The TS Agreement relates to the ongoing engineering, procurement and construction (EPC) activities for MLNG’s planned 8 mtpa Magnolia LNG Project, in Lake Charles, Louisiana.

SKEC Group has already completed a satisfactory detailed review of Liquefied Natural Gas Limited’s OSMR process technology, which will be employed in the Magnolia LNG Project, and provided the company with an initial estimated EPC cost of $1.57 bn, which was consistent with the company’s budget estimate, including appropriate contingencies.

Liquefied Natural Gas Limited’s Managing Director, Maurice Brand, said that the EPC activities remained on schedule with the SKEC Group and will be managed going forward by the recently appointed COO, John Baguley, who will commence on May 1, 2014.

“We also remain on schedule to lodge our application for Filing with the Federal Energy Regulatory Commissions on the 30 April 2014,” Brand said.

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