The £36 million contract was awarded under Amec Foster Wheeler’s global agreement with BP to provide engineering and project management services for BP's offshore developments around the world. 90 Amec Foster Wheeler people, including eight graduates, are working on the contract.

The additional living quarters will comprise 16 modules, creating space for an additional 26 beds. The modules will sit on a grillage support with sliding connectors, which are usually found on bridges and onshore refineries. The sliding connectors allow enough movement to accommodate for the flex and stress from the weight of the new structures, increasing efficiency by removing the need to drill through the deck and weld to deck support beams.

Alan Johnstone, Amec Foster Wheeler’s Managing Director for Upstream Asset Solutions, said: “We are delighted to be supporting BP’s rejuvenation of ETAP as they continue to invest in the North Sea. We’ve been working with BP for more than 35 years, delivering safe and efficient solutions and this contract award is another example of Amec Foster Wheeler combining our leading brownfield and EPC expertise and bringing new ways of working into the oil and gas industry.”

• Amec Foster Wheeler awarded new BP contract for Eastern Trough Area Project (ETAP) Additional Living Quarters

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This FSO will be deployed at the Culzean field approximately 145 mile (233 kilometers) off the coast of Aberdeen in water depth of around 295 feet (90 meters). The Culzean field is operated by Maersk Oil UK with co‐venturers JX Nippon Exploration & Production (UK) Limited and BP.
MODEC is responsible for the engineering, procurement and construction (EPC) of the FSO. SOFEC, Inc., a subsidiary of MODEC, will design and supply the Internal Turret mooring system. The FSO will have receiving capacity of 25,000 barrels of condensate per day and storage capacity of 350,000 barrels. The complete unit will be delivered to Maersk Oil UK in the first half of 2018.

"We are very honored to be awarded the contract for supply of the FSO by Maersk Oil,” said Toshiro Miyazaki, President and CEO of MODEC. “This new contract represents a significant milestone for MODEC in gaining entry into the important North Sea oil and gas industry.”

• MODEC Awarded Contract to Provide FSO for Maersk Oil’s Culzean Field; A Significant Milestone for MODEC in Gaining Entry into North Sea

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Culzean is a high pressure, high temperature ("HPHT") gas condensate field located in the Block 22/25a in the UK Central North Sea. Discovered in 2008 by Maersk Oil and its co-venturers, including JX Nippon, it has resources estimated at 250-300 million barrels of oil equivalent. It is both the largest field discovered in the UK North Sea in the last decade and is the largest gas field sanctioned since 1990*.

Production is expected to start in 2019 and continue for at least 13 years, with plateau production of 60,000-90,000 barrels of oil equivalent per day. At peak production, anticipated in 2020/21, the field is expected to produce gas equivalent to 5% of total UK demand.

The Culzean development has benefited from the recent introduction by the UK Government of the HPHT Cluster Area Allowance. The allowance supports the development of HPHT projects, which typically have high capital costs. The Allowance also encourages exploration and appraisal activity in the surrounding area or ‘cluster’.

The Culzean Field is the latest major JX Nippon investment and, along with the Mariner Field in the UK, will contribute significantly to JX Nippon’s corporate mid to long term global production.

• Field Development Plan approved for Culzean in UK North Sea

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The Anasuria Cluster is located approximately 175km east of Aberdeen in the UK Central North Sea and consists of a 100% interest in the Anasuria FPSO, Teal, Teal South, Guillemot A fields and a 38.65% interest in the Cook field. The cluster represents an attractive, geographically focused package of operated interests in producing fields and associated infrastructure. The assets have a proven and producing resource base which provides a platform for further development. A number of incremental development and exploration opportunities exist within the licence areas which are expected to generate significant incremental value in the medium term.

Ping and Hibiscus bring combined technical expertise and an exceptional track record in creating value in maturing basins in the Gulf of Mexico, Norwegian North Sea, Middle East, Australia and South East Asia. The partners are confident that the acquisition will create significant value for their respective shareholders and UK government.

The acquisition also brings two new entrants into the North Sea and reflects the support provided by the UK Government to encourage smaller independents to invest and revive the North Sea basin.

Ken Pereira, Managing Director of Hibiscus commented, “This acquisition will complete our company’s strategy of acquiring a balanced portfolio of assets which includes exploration, development and producing assets within five years of listing our company. We will be able to cut our teeth as Operator in conjunction with Ping in one of the world’s foremost oil and gas production basins. The Anasuria Cluster has development potential for a company of the size of Hibiscus and provides us with an excellent foundation upon which we can build a significant North Sea presence.”

Acquisition Highlights

• Acquisition of interests in four producing fields (100% in Teal, Teal South, Guillemot A and 38.65% in Cook) with clearly defined upside opportunities and exploration potential
• Acquisition of the Anasuria FPSO and its associated processing infrastructure with potential for future

tie-ins

• Ping Petroleum and Hibiscus Petroleum To Acquire Operated Interest of Anasuria Cluster

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Dave Stewart, chief executive officer (CEO) of WGPSN said: “The collaborative approach we are taking with EnQuest and our ability to deliver cost efficiencies together in the provision of services to the Thistle, Heather and Northern Producer assets has secured us this contract, which extends an agreement in place since 2009.
”The strong partnership and understanding we have built with this key client positions us well to support them in optimising safety and productivity across these assets at this challenging time for the sector.”

The contract adds to Wood Group’s scope of work with EnQuest in the North Sea; Wood Group Industrial Services (WGIS) holds a contract to deliver topsides integrity work on the Thistle platform.

• Wood Group secures EnQuest contract

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Well 30/6a-A3Y (“A3”) is the fifth development well drilled on the Stella field. The well was drilled to a total measured depth subsea of 14,267 feet, with a 2,137 foot gross horizontal reservoir section completed in the Ekofisk chalk reservoir, the secondary reservoir underlying the primary Stella Andrew sandstone formation in which the first four Stella wells have been drilled. The Ekofisk well intersected a net reservoir interval of 2,073 feet, equating to 97% net pay.

A clean-up flow test was performed in order to remove the chemical stimulation fluids injected to enhance the natural fracture network of the chalk formation and improve the long term production performance of the well.

Following the initial clean-up period, a series of production flow tests were conducted on the well over approximately five days in order to obtain additional data and fluid samples to assist with future reservoir management. The well was flowed at rates up to 7,172 barrels of oil per day (“bopd”) on a 48/64 inch choke, with a gas/oil ratio of approximately 1,850 standard cubic feet per barrel (“scf/bbl”). The average flow rate over a 12 hour period was 8,080 boepd, comprising 6,191 bopd and 11.3 million standard cubic feet per day (“MMscf/d”). Fluid samples show that the oil gravity is approximately 39° API.

The A3 well is currently in the process of being suspended and operations are scheduled to be completed in the coming days. As with the previous Stella development wells, the suspension configuration is such that the well can be brought on to production without the requirement for any further well intervention activity once the “FPF-1” floating production facility is on location and hooked up.

Upon completion of operations on the A3 well the ENSCO 100 drilling rig will be demobilised from the field, marking the end of the Stella development drilling campaign. The five Stella wells that have been drilled have achieved a combined maximum clean-up flow test rate in excess of 53,000 boepd (100%). This well capacity significantly de-risks the initial annualised production forecast for the Greater Stella Area hub of approximately 30,000 boepd (100%), 16,000 boepd net to Ithaca.

Les Thomas, Chief Executive Officer, commented:
“We are very pleased to have delivered another successful flow test on the fifth and final well in the Stella development drilling programme. The results of the Ekofisk well further de-risk forecast cashflows from the Stella field and the high oil content of the well is encouraging for maximising liquids production during the period when the FPF-1 facilities will be operating at plateau gas production rates. We are also encouraged that there is further upside potential for reserves development in the Ekofisk formation.”

• Ithaca Energy successfully completes flow test operations on Stella A3 well

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As part of replacement of existing subsea assets, Technip’s scope of work covers project management and engineering, including:

• installation of two flexible risers: one of 9’’ and one of 6’’
• fabrication and installation of one dynamic umbilical riser,
• removal and recovery of existing assets at the FPSO vessel,
• additional installation, repair and maintenance works.

Technip’s operating center in Aberdeen, United Kingdom (UK), will execute this contract which is a continuation of similar work successfully completed in 2014.

The Group will leverage its unique integrated approach in the subsea business, as Technip Umbilicals will manufacture the umbilical at its plant in Newcastle, UK, while the Group’s diving support vessel Orelia will undertake the installation campaign.

Knut Boe, President of Technip North Sea Canada, commented: “We are delighted to have been awarded this contract which demonstrates clear collaboration and builds on the work we have already undertaken on Triton. Having successfully completed the initial project in 2014, we are in an ideal position to bring our extensive knowledge and experience of the asset, coupled with our flexible and umbilical expertise, to the next stage of the project.”

Bill Morrice, Managing Director of Technip in the UK, continued: “The scope of the 2015 campaign was defined by Dana and its Triton partners, as a result of a successful detailed riser life extension study executed by Technip in the UK late 2014. While Technip closely collaborated with Dana, this study provided the appropriate technical information to allow key decisions to be made and helped shape the 2015 project activity.”

Colin Taylor, Production Manager for Dana, said: “This scope is another example of Dana’s ambition to ensure the long term integrity and safety of the Triton FPSO in order to maximize the long term production recovery from the area.”

(1)Joint venture partners in Triton are Dana Petroleum (E&P) Limited (51.966%), Shell U.K. Limited (26.42%), Esso Exploration and Production UK Limited (20%) and Endeavour Energy UK Limited (1.614%).

• Technip wins subsea contract on Triton FPSO

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• BW Offshore: Contract extension for BW Athena

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The North Sea development which was discovered in 2001 has surpassed all expectations with its profilic production capability since it began producing in 2007.

At the time of field approval in 2003, the field was expected to produce 486 million barrels of oil in its lifetime, however 12 years later, the field has exceeded this volume and is now predicted to produce more than 850 million barrels of oil, until 2027.

Archie Kennedy, Managing Director of Nexen Petroleum UK said: “The Buzzard Field has been a success story from the beginning and has been a fantastic achievement for Nexen. Buzzard’s journey has provided ‘new oil’ in a mature basin which has undoubtedly enhanced the North Sea industry and will continue to do so.”

The field is the largest discovery in the North Sea in the past two decades and Buzzard’s production supplies almost 10 per cent of the UK’s energy needs. In 2013 the development produced 25 per cent of the total UK crude offshore. The field is also an important asset to the UK economy, and has contributed to significant and sustained economic and social benefits to the country, with the vast majority of its annual £300 million expenditure being spent locally.

Joel Turnbull, the Buzzard Area Development Manager added: “This is a wonderful achievement for Nexen. The field has surprised us all by showing it is considerably bigger than we originally thought and we are delighted with this accomplishment. However, this success is also testament to the great work put in by the people who have worked on Buzzard, all the way from discovery to now.” At its peak Buzzard was generating over 200,000 barrels of oil equivalent per day, however the field is just now starting to come off plateau rates and will move into a new phase of operations with the Buzzard partners committed to continuing to develop the field in the future to maximise production.

To mark the occasion, a cake cutting ceremony was held across the Aberdeen, Uxbridge Offices and all Nexen’s offshore assets – Buzzard, Golden Eagle, Scott, Rochelle and Telford installations.

The Buzzard Field is operated by Nexen Petroleum UK on behalf of partners Suncor Energy, BG Group and Edinburgh Oil and Gas.

Buzzard History
The Buzzard field came on stream in 2007 and was developed by three bridge-linked steel platforms supporting the wellhead facilities (W), production facilities (P), platform supporting living quarters and utilities (UQ) and a fourth oil-stripper platform (PS).

The wellhead platform, a four-leg jacket, features an integrated deck with conductors and wellhead trees. The production platform , also a four-leg jacket, has fluid processing equipment, water injection pumps and gas compressors. The UQ platform supports an integrated deck and living quarters, lifeboats, helideck and seawater lift pumps. In September 2010, a fourth platform was installed at the field. The platform features a 6,500t deck and bridge structure supported by a 3,500t jacket.

Buzzard Facts

• 190km – the total distance drilled. This distance is from Uxbridge, UK to Calais, France.
• Every day Buzzard’s daily energy output could charge the entire world’s smart phones 19 times over.
• The weight of the platform is equal to that of 350 blue whales.
• 500 million barrels – this volume is equivalent to 706,622 double decker buses; 31,798 Olympic swimming pools.
• 500 million barrels of oil could power a car from here to the sun and back

• Buzzard Soars High Marking 500 Million Barrels Production

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The well was drilled by GDF SUEZ E&P UK Limited as operator, with the Transocean Galaxy II drill rig.
The well is now being side-tracked to appraise the extent of this discovery.
JX Group has been conducting oil and gas exploration, development and production in the UK Continental Shelf (UKCS) for nearly twenty years. It is committed to expanding further its activities in the UKCS, which is one of the core areas of JX Group’s worldwide upstream business. JX Nippon Exploration & Production (U.K.) Limited acquired block 22/16 in 2011 through the 26th license round.

• New Oil Discovery in Block 22/16 in the UKCS

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The Glenlivet specific scope includes:

• fabrication and installation of 12" production pipeline and 6" MEG(1) pipeline complete with a 2" piggy backed service line,
• supply and installation of steel tube umbilical, manufactured at Technip Umbilicals facility in Newcastle, UK,
• supply and installation of flexible tails from Flexi France, the Group’s manufacturing plant in Le Trait, France,
• fabrication and installation of pipeline end manifold, flowline end terminations, flexible tails and rigid well tie-in spools, as well as the installation of CPI(2) templates and manifolds,
• rock dumping and pre-commissioning.

The Group will leverage its unique vertical position in the subsea business:

• Technip’s operating center in Oslo, Norway, will execute the project in full synergy with the previously awarded Edradour project.
• Vessels from the Group fleet will perform the installation in the summer seasons of 2016 and 2017.
• The pipelines will be fabricated at Technip’s spool base at Evanton, UK, and installed by Technip’s vessel Deep Energy.
• Umbilicals will be manufactured at the new Technip umbilicals facility in Newcastle, UK.

Knut Boe, President North Sea Canada, stated: “It is very good to see the benefits of the synergies between these two projects being realized by Total’s award of this extra scope to Technip.”

• Technip awarded subsea contract for the Glenlivet project, West of Shetlands, UK

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“With the start-up of the West Franklin Phase 2 project, Total consolidates the production capacity of its operated Elgin/Franklin hub. The hub holds significant reserves as well as promising exploration opportunities”, outlined Michael Borrell, Total’s Senior Vice President Exploration & Production, Europe and Central Asia.

West Franklin Phase 2 will develop reserves of 85 million barrels of oil equivalent. The project includes the drilling of three new production wells and the installation of two new platforms, the West Franklin wellhead platform and the Elgin B platform which will be also used to drill new wells on Elgin.

Located approximately 240 km east of Aberdeen, West Franklin was discovered by Total in 2003 and Phase 1 production started in 2007 with two wells drilled from the Franklin platform.

Total operates Elgin/Franklin, including West Franklin, with a 46.2% interest alongside co-venturers Eni (21.9%), BG (14.1%), E.ON (5.2%), ExxonMobil (4.3%), Chevron (3.9%), Summit (2.2%) and Dyas (2.2%).

Total Exploration & Production in the United Kingdom

Total has been present in the United Kingdom since 1962. The Group is one of the country’s leading oil and gas operators, with equity production of 105,000 boe/d in 2013.

More than 90% of Total’s production in the UK comes from several operated fields located offshore in two major zones: the Alwyn/Dunbar area in the Northern North Sea and the Elgin/Franklin area in the Central Graben.

In 2015, Total will commence production from its new third hub located in the West of Shetland area, with the start-up of the Laggan-Tormore project.

• UK: West Franklin Phase 2 brought on stream in the North Sea

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“This is a very significant agreement for the Mariner project, and the result of an innovative, new procurement approach, where the supplier will work as an integrated part of the Statoil team delivering most of the drilling and well services on the Mariner field,” says managing director for Statoil Production UK, Gunnar Breivik.

From its Aberdeen base, Schlumberger will deliver all the main drilling and well services for Mariner, including drilling, completion, electrical submersible pumps (ESPs), cement and fluids.

A total of 22 drilling and well services are included in the scope, including a logistics support responsibility that goes beyond the normal scope for similar Statoil contracts.

The contract will commence in January 2015 and has a duration of four years, plus options for several additional four-year periods.

The Mariner field, located approximately 150 kilometres east of the Shetland Isles, is currently under development by operator Statoil and its co-venturers JX Nippon and Dyas.

Mariner is the largest field development on the UKCS in more than a decade, and will be in production for at least 30 years. Drilling is planned to start in 2016 with production start-up following in 2017.

The main Mariner platform will have one drilling rig and one well intervention and completion unit. In addition, a new-build jack-up rig will be located next to the Mariner installation, working through well slots on the platform for the first four years. Over the field’s lifetime as many as 130 well targets are planned.

“The aim for this contract is a long-term partnership with a performance-based compensation format rewarding actual performance — metres drilled and completed — rather than usage of time and material. Together we will now establish an integrated operations team in our Aberdeen office, working closely with both the service supplier and the drilling contractor Odfjell and rig contractor Noble to plan and optimise operations. We will work side by side to meet the challenges in the market, driving performance, creating value and dividing risk,” says Breivik.

The contract with Schlumberger also includes options for Bressay, another Statoil-operated field on the UKCS, currently in the concept evaluation phase. Furthermore, it will also work as a framework agreement for exploration drilling on UKCS where Statoil has the option to use Schlumberger for any of the drilling and well services covered by the scope of the contract.

Facts:

– The Mariner Field is located on the East Shetland Platform of the UK North Sea, approximately 150 kilometers east of the Shetland Isles.

– The Mariner heavy oil field consists of two shallow reservoir sections – the deeper, Maureen Formation at 1492 metres and the shallower Heimdal reservoir at 1227 metres.

– The development of the Mariner field will contribute more than 250 million barrels reserves with average plateau production of around 55,000 barrels per day.

– The field will provide a long-term cash-flow over a 30-year field life. Production is expected to commence in 2017.

– The concept chosen includes a production, drilling and quarters (PDQ) platform based on a steel jacket, with a floating storage unit (FSU). Drilling will be carried out from the PDQ drilling rig, with a jack-up rig assisting for the initial years.

– The Mariner field development entails a gross investment of more than USD 7 billion.

– Following the final investment decision in December 2012, Statoil in 2013 established its UKCS operations centre in Aberdeen.

– Statoil is the operator of the Mariner field with 65.11% equity. Co-venturers are JX Nippon Exploration and Production (U.K.) Limited (28.89%) and Dyas Mariner Ltd. (6%).

• Statoil awards Mariner drilling and well services contract to Schlumberger Oilfield UK

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Effective January 2015, the contract will create 150 new jobs and secure more than 700 existing positions. This is WGPSN’s largest contract award in 2014 and includes an option for two, one-year extensions.

WGPSN already provide engineering, procurement and construction services for six BP offshore assets - Clair, Magnus, ETAP, Andrew, Bruce, and its new Glen Lyon FPSO which is currently being constructed and is due to come online in 2016. This is the first time WGPSN has secured a contract for the FPS onshore facilities and adds to the company’s current contract to support BP’s Sullom Voe Terminal in Shetland.

Dave Stewart, UK managing director of WGPSN said: “Wood Group has more than 40 years of experience working with BP globally and this new contract is testament to the partnership and understanding we have developed.

“Providing this combined service across upstream and midstream operations for the first time positions us well for continued excellence in delivering safe, collaborative and innovative services directed at maximizing productivity and efficiency across BP’s assets in the UK.

In the UK, Wood Group now employs more than 10,000 people working onshore and offshore.

• Wood Group secures major BP contract

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The agreement is worth more than GBP 120 million. It comes in addition to a five-year maintenance and modifications services contract awarded in June by Statoil for the Mariner field, which is set to start production in 2017.

"We are very pleased to be expanding our already significant role in developing the Mariner field and to be working with Daewoo and Statoil," said Tore Sjursen, head of Aker Solutions' maintenance, modifications and operations (MMO) business. "This is a testament to the strength and know-how of our UK operations."

The work will be managed by Aker Solutions' UK MMO unit through an integrated construction and completions (ICC) organization with Daewoo and Statoil.

At the peak of the offshore phase, the contract will secure as many as 950 jobs in the UK.

Separately, Aker Solutions' Norwegian MMO unit secured a two-year contract extension worth NOK 360 million for asset integrity management work at 11 offshore and three onshore locations in Norway. The extension is part of a four-year contract awarded in October 2010 by Statoil.

• Aker Solutions Wins Hook-Up and Commissioning Contract for Mariner Development

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The Golden Eagle Area Development includes the Golden Eagle, Peregrine and Solitaire fields and is located 70km north east of Aberdeen, with an average water depth of 89-139 metres. The main facilities include producing wells and a production platform. Currently there are two Golden Eagle wells with potential to produce approximately 18,000 barrels of oil per day. The project is expected to reach its peak production of approximately 70,000 barrels of oil per day (boepd) in 2015, with Maersk Oil net production expected to be c 20,000 boepd.

Martin Rune Pedersen, Managing Director of Maersk Oil UK said, “Today’s announcement represents a great achievement by the Golden Eagle project teams. A project of this scale is important for the UK North Sea and for Maersk Oil - to deliver it safely, on time and on budget is an excellent performance.”

Nexen Petroleum U.K. Ltd. (“Nexen UK”), a wholly-owned subsidiary of CNOOC Limited, is the operator of the Golden Eagle Development Area and has 36.54% interest. The remaining interests are held by Maersk Oil North Sea UK Ltd. (31.56%), Suncor Energy UK Ltd. (26.69%) and Edinburgh oil and Gas Ltd (5.21%).

Note: The fields are located in blocks 20/1S, 20/1N and 14/26a of the UK North Sea

• First oil from Golden Eagle development

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The refinery is currently in a period of shut-down, and will be decommissioned and operated solely as a petroleum storage and distribution terminal. The Company will seek a buyer for the terminal facility along with three inland terminals. The sale of the Company's retail assets is unaffected by the inability to sell the refinery.

• Murphy Oil Corporation Announces Failed Sales Process For Milford Haven Refinery

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DONG Energy and Total have decided on a joint development of the Edradour and Glenlivet fields, by way of tie-in to the Laggan and Tormore infrastructure, with both fields expected to contribute to production in 2018.

Mike Smith, Managing Director for DONG Energy's oil and gas activities in the UK said:

"This is a great step forward for our business in the West of Shetlands. The agreement to move forward with the joint development of Edradour and Glenlivet underpins our long term gas hub strategy and strengthens our production base in the region."

• DONG Energy to divest 5% of West of Shetland Edradour field to Total - DONG Energy and Total to develop the Glenlivet and Edradour gas fields jointly

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The contract covers various project management engineering and installation works, which include:

• fabrication and pipelay of approximately 50km of rigid pipe - 25km of metallurgically clad pipe and 25km of HDPE lined,
• installation of 3 umbilicals totaling 14km,
• installation of 7km of flexible risers and jumpers ,
• template and manifold installation at three drill centers,
• diverless tie-ins to pipelines and manifolds,
• pipeline flooding, hydro testing and leak testing.

Technip’s operating center in Aberdeen, United-Kingdom, will execute the contract.

The Group will leverage its unique vertical position in the subsea business. The Group’s spoolbase in Evanton, United-Kingdom, will weld and load-out the rigid pipe and Technip Umbilicals, Technip’s wholly-owned subsidiary in Newcastle, United-Kingdom, will manufacture the umbilical. All construction work on the project will be undertaken via diverless construction methods.

A number of vessels from the Technip fleet will be utilized for the offshore campaign, including Technip’s Deep Energy, one of the largest pipelay vessels ever built.

Bill Morrice, Managing Director of Technip in the UK, said: “We are delighted to have been awarded this contract which builds upon our excellent relationship with EnQuest. Our vast experience in the delivery of efficient, cost-effective solutions for our clients has been recognized once again and we look forward to supporting EnQuest to maximize production from the Kraken field, currently one of the largest developments in the UK North Sea.”

• EnQuest selects Technip for a large subsea contract

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Endeavour has a 44% working interest in the Rochelle field.

• Endeavour Announces Rochelle Field Has Returned to Production

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