From Abu Dhabi: Al Dhafra Petroleum, 60% owned by ADNOC and 40% owned by Korea National Oil Corporation and GS Energy Group, is aiming to become the first onshore and offshore producer of oil in Abu Dhabi by bringing three hub fields onstream over the coming years

Onshore Area 1 on the border with Oman and Area 2 neighbouring Saudi Arabia will be brought into production first before offshore Area 3 is tapped.

Thuraya Al Ghafri, a geophysicist with Al Dhafra told ADIPEC, “In Area 3 we have three offshore fields, Bu Dana, Adnoc 1B and Adnoc 1C. The main target for these fields is Jurassic Carbonate. The structures are quite small compared to Area 1 and Area 2.

“New 3D seismic was acquired over the fields in 2015. It is currently undergoing processing and is expected to be completed by the third quarter 2016. First oil from these three fields is expected in the second quarter of 2025.”

A riser platform and a central separation platform will be built at Adnoc 1B and connected to an already existing platform which will be used for accommodation. Satellite wellhead platforms will be built at Bu Dana to the north and Adnoc 1C to the south.

Production from the fields is expected to ramp up to 15 Mb/d.

From Houston (BN): Regulators have given final approval to Hess’ development plan for Stampede (SEN, 32/8) in 1,078 m of water in Green Canyon blocks 468, 511 and 512 in the Gulf of Mexico, about 279 km south of New Orleans.

The plan includes a previously announced tension leg platform in GC 468 and six production wells and four water injectors along with associated subsea infrastructure.

Expected oil has a gravity of API 28.9 degrees. Hess’ partners are Statoil, Chevron (Union) and Nexen, each partner owning 25%.

LLOG has won approval of its initial development operations coordination plan for hookup and startup of Otis (32/7) in Mississippi Canyon block 79, in 1,178m about 210km southeast of New Orleans.

The plan calls for installation of an 18km gas line and a 19.8km umbilical linking the well to the Delta House (32/7) platform in MC 254.

The objective is API 34.9-degree oil. The startup is slated for February 2016. Ridgewood and ILX own 15% each, LLOG the rest.

Thermoplastic composite pipe (TCP) manufacturer Airborne Oil & Gas (AOG) will supply two noncollapsible flexible jumpers to Wild Well Control for the deepest riserless plug and abandonment in the Gulf of Mexico (GoM).

The two jumpers, 2-in. and 10-ksi rated, are collapse-resistant to 3,000 m water depth and are delivered in lengths of 91.5 m each.

They will provide the flexible fluid connection between a drillstring and Wild Well Control’s 7-series subsea intervention package.

Thomas Wilke, Wild Well’s general manager subsea, said, “Our primary client, Marubeni Oil and Gas, will be plugging and abandoning nine subsea wells, of which the deepest are at a water depth of some 2,226 m.

“We expect that some wells will be sub-hydrostatic, which may lead to significant differential pressures. Using AOG’s noncollapsible jumpers removes the risk of hose collapse and the related project delays. We have worked with AOG for some time on this project and concluded that their product provided a significant operational advantage.”

The job is AOG’s first in the GoM, and the two jumpers are expected to be mobilised in early December 2015.

The Norwegian Petroleum Directorate (NPD) has given the green light for startup of production on the Lundin-operated Edvard Grieg (32/15) Field in production licence 338 in the Norwegian North Sea.

Edvard Grieg is located on the Utsira High, about 35 km south of the Grane (32/7) and Balder (32/11) fields.

The Edvard Grieg Field consists of a platform with a full process facility, dry wellheads with external jackup drilling and living quarters. The platform has been successfully installed and commissioning is ongoing.

The Edvard Grieg platform is designed as a field centre and will receive and process hydrocarbons from other discoveries in the surrounding area.

A dedicated pipeline has been laid from the Edvard Grieg platform to the existing Grane oil pipeline for export to the Sture oil terminal.

A dedicated gas pipeline has been laid to the U.K. Scottish Area Gas Evacuation System (SAGE) on the U.K. shelf for export of rich gas to St. Fergus in Scotland.

Fugro has scooped a five-year contract for the provision of underwater services to Total in the U.K.

Under the contract, which has been running from July 2015 and includes extension options for a further two years, Fugro is providing a full range of ROV services to conduct inspection, repair and maintenance activities on Total’s pipelines, subsea assets and jackets in the region.

In July 2015, Fugro undertook the Central Graben area ROV inspection campaign utilising the ROV support vessel Atlantis Dweller and its two permanently mobilised ROV systems.

The workscope included cathodic protection, flooded member detection and high-pressure water-jetting services.

McDermott International has been awarded a large brownfield contract by RasGas for the engineering, procurement, construction and installation of a flow assurance and looping project consisting of 119 km of 6-in. and 8-in. pipeline and topside modifications offshore Qatar. Work is scheduled for completion by the end of third-quarter 2017.

Conductor Installation Services Ltd. (CIS) has successfully completed its second subsea piling campaign for Technip in Norway.

CIS used its remotely operated subsea piling system, which makes it possible to drive piles as large as 36-in. in diameter in water depths to 300 m.

In August, the piles were driven remotely to secure the subsea Boa (32/11) Extension Manifold, which makes up an integral part of the Alvheim (32/11) development, about 225 km west of Stavanger.

The development, which transports oil to the U.K. SAGE System, is designed to increase oil recovery by enhancing current production rates via three new subsea well step-outs at East Kameleon, Kneler A and Boa.

Sand control engineering specialist, Darcy, has signed a seven-year framework agreement to supply its hydraulic screen technology to Statoil’s assets on the Norwegian Continental Shelf.

Darcy designed and developed the technology in response to industry concerns about the high failure rate and costs of traditional gravel packing methods to control produced sand in well completions operations.

The agreement comes on the back of a world-first successful installation of Darcy’s technology on Statoil’s Statfjord (32/13) oil field in the Norwegian North Sea. This field faces challenges with continuous pressure depletion and reduced margins for pumping traditional openhole gravel packs. Integrating with Statoil’s completion equipment suppliers, the activation of the hydraulic screen took less than 1 hr of rig time.

Offshore