Oil production has started under budget and ahead of schedule at the Julia oil field in the Gulf of Mexico, Exxon Mobil Corporation (NYSE:XOM) announced on April 19. The first production well is now online and a second well will start production in the coming weeks.

The Julia development is located approximately 265 miles southwest of New Orleans in water depths of more than 7,000 feet. The initial development phase uses subsea tie-backs to the Chevron-operated Jack/St. Malo production facility, reducing the need for additional infrastructure and enhancing capital efficiency. Technology has also played a key role in the Julia development including the use of subsea pumps that have one of the deepest applications and highest design pressures in the industry to date.

“Successful deepwater developments like Julia, located more than 30,000 feet below the ocean’s surface, benefit from ExxonMobil’s disciplined project execution capabilities and commitment to developing quality resources using advanced technology,” said Neil W. Duffin, president of ExxonMobil Development Company.

The Maersk Viking drillship is currently drilling a third well, which is expected to come online in early 2017. Credit: Maersk

Production results will assist in the evaluation of additional wells included in the initial development phase, which has a design capacity of 34,000 barrels per day of oil.

“This initial production will provide ExxonMobil with insight into the potential future development of the reservoir,” said Duffin.

Discovered in 2007, the Julia field comprises five leases in the ultra-deepwater Walker Ridge area of the Gulf of Mexico. ExxonMobil, the operator, and Statoil Gulf of Mexico LLC each hold a 50 percent interest in the Julia unit. Over the past decade, ExxonMobil has drilled 187 deepwater wells worldwide in water ranging from 2,100 feet to 8,700 feet.

ExxonMobil is on track to start up 10 new Upstream projects in 2016 and 2017, adding 450,000 oil-equivalent barrels per day of working-interest production capacity. The company is enhancing resource value through production optimization, technology application and cost management.

Statoil together with operator Repsol Sinopec and partner Petrobras has completed the Gavea A1 well in the ultra-deep pre-salt block BM-C-33 in the Campos basin in Brazil.

The well encountered a hydrocarbon column of 175 meters in a good-quality reservoir of silicified carbonates of the Macabu formation.

The well reached a total depth (TD) of 6,230 meters and was successfully tested producing around 16 million standard cubic feet (scf) of gas and 4,000 barrels per day of oil (32/64” choke).

Map image courtesy: Statoil

This is the fourth appraisal well in the license, which comprises the Seat, Gavea and Pão de Açucar (PdA) discoveries. In 2013-2015 the consortium drilled and tested the Seat-2, PdA-A1 and PdA-A2 appraisal wells.

With Gavea A1 the consortium has finalized the appraisal activities in BM-C-33 and will now evaluate the sub-surface data and assess lean and cost-effective development concepts.

Repsol Sinopec Brasil (35%) is operator of BM-C-33 with Statoil (35%) and Petrobras (30%) as partners.

As announced in December 2015, Statoil will take over operatorship of the license. This is expected to happen in the third quarter of 2016, subject to the approval from Brazilian authorities (ANP).

Seanic Ocean Systems Inc. (Seanic) and CSA Ocean Sciences Inc. (CSA) are responding to challenges faced by the oil industry to address increasing regulations and environmental stewardship concerns. This strategic partnership merges technology and environmental expertise with the goal of improving oil spill response equipment and services. Innovative solutions developed by Seanic and CSA will provide much-needed support to the oil industry, which is under increasing pressure to maximize efficiency while minimizing risk and environmental impact.

Both companies already support the oil spill response needs of the energy industry, providing a range of specialized equipment and services, from engineered solutions to oceanographic sensors and from testing and maintenance to developing dispersant monitoring plans. Forging this partnership integrates the skills and experience of each company, resulting in better service to both industry and the environment.

“Seanic’s Remote Systems Technology combined with CSA’s experience in Environmental Sciences will allow us to approach oil spill response, particularly the application and monitoring of dispersants, in a unique and innovative manner,” stated Kevin Peterson, President of CSA Ocean Sciences Inc. “As environmental regulations evolve, water depths increase, and locations become more remote, cost-effective solutions based on solid science and technology become more important than ever.”

Seanic brings expertise in ROV tooling, engineered solutions, and the maintenance and improvement of oil spill equipment. Their corporate headquarters in Katy, Texas offers state-of-the-art facilities for manufacturing, testing, storage, and maintenance of equipment, including stabilized yard space, a tool pool, storage warehouse, and a 500,000-gallon in-ground wet test tank. Overseas facilities in Scotland, Norway, Australia, and Singapore support international operations.

CSA brings 46 years of specialized experience in marine environmental consulting, serving the energy industry worldwide through offices in the United States, the Eastern Mediterranean, Qatar, Trinidad, Singapore, and Australia. CSA’s expertise in coastal, marine, and deep ocean surveys, sampling, monitoring, assessment, and mitigation is built on the integration of science, operations, and an understanding of environmental data collection, management, and analysis within geospatial domains.

Well management and performance improvement specialist Exceed has bolstered its decommissioning credentials through a strategic alliance with international oil and gas service company, Weatherford.

The collaboration will offer an end-to-end solution for well decommissioning, using an integrated team which brings together extensive technical and commercial capabilities.

Exceed brings a proven track record in well management to the partnership which will ensure lessons are learned, knowledge is shared and the performance improvement curve is significantly accelerated, whilst Weatherford boasts extensive global plug and abandonment experience, field proven tools and technology and a global footprint.

John Anderson, Exceed commercial director

The expertise brought from both companies means that commercial models can be flexible and tailored to meet client requirements. Significant value is added through cost savings to operator groups through bulk purchases, shared equipment and resources, and improved safety and operational performance through an incentivised approach.

The collaboration also opens up potential to create a project-wide EPC approach through the appointment of further partners. Global agreements have already been established with a number of internationally recognised service providers to expand the service portfolio as and when required.

The collaboration follows Exceed’s recent plug and abandonment contract win with Fairfield Energy, which will see the firm support a campaign which covers 45 platform wells and 16 subsea wells, and recognises the Exceed team’s strong track record in decommissioning.

John Anderson, commercial director at Exceed, said: “This alliance is a major step forward in demonstrating what collaboration in the decommissioning sector should actually look like.

“Integrating the supply chain, sharing resources and drawing upon a knowledge base which extends beyond one company will mean major savings, quicker project execution and effective risk management. There is great potential for this joint approach both now and in the future.”

Statoil has set tough targets to reduce costs in their project portfolio. During the last decade subsea costs have increased significantly and the industry needs to move from tailor-made solutions to more industry standards.

At the Barents Sea Conference in Hammerfest, Norway, a new subsea concept developed by Statoil was presented by Margareth Øvrum, executive vice president for technology, projects and drilling in Statoil.

The new subsea solution is called Cap-X.

Image courtesy: Statoil

"Once again we aim to drive subsea technology development on the Norwegian continental shelf together with our industry partners. The potential for increased efficiency and reduced costs can make this the next standard within subsea templates," says Margareth Øvrum. "With Cap-X, Statoil is one step closer to a “plug and play” solution on the seabed."

Cap-X is a combination of existing and new technology. It is ¼ the size of today’s subsea templates and enables more operations from vessel instead of rig.

The technology increases the efficiency of horizontal drilling in shallow reservoirs. The main structure of the technology can be produced in shorter time by a larger number of suppliers, with potential for local production.

The development of Cap X was initiated in 2013 to increase commerciality of potential resources in the Barents Sea.

“We as explorers need to find resources that can be developed at a lower cost and with lower emissions. Cap-X can potentially have a significant impact on developing the resources in the Barents Sea and in other areas with shallow reservoirs”, says Jez Averty, senior vice president for the exploration Norway and UK cluster in Statoil.

In a period of cost constraint and increasingly complex oil & gas production, finding solutions that increase efficiency and production has never been more important. To address the industry’s need for smart solutions that reduce complexity, DNV GL is funding 43 new joint industry projects in 2016 in addition to launching a new Step Change innovation program to help customers leverage opportunities from digitalization.

Both initiatives are based on closed interaction and collaboration with industry partners. Key focus areas for DNV GL in 2016 will be to address challenges on standardization, operations (OPEX services), safety, environment, regulations and performance.

“DNV GL led JIPs aim to provide insights into future trends and technologies. Many of the projects result in new industry standards and practices that support innovation and flexibility in design while managing costs and maintain safety levels,” says Rolf Benjamin Johansen, Technology Manager, DNV GL – Oil & Gas.

The value of standardization is recognized by the industry with 61% of senior oil & gas professionals agreeing that operators will increasingly push to standardize their delivery globally1. The most common strategy for maintaining innovation with lower budgets is to increase collaboration with other industry players (45%) and nearly one in three (30%) plans greater involvement in joint industry projects in the year ahead.

DNV GL’s new Step Change innovation program is focused on digitalization. Only one in five oil and gas companies see themselves as highly digitalized today. However, close to half of senior oil & gas professionals (45%) already see solid or high potential for big data and analytics to transform the operating efficiency of the industry in 2016. DNV GL’s program involves the end-users, e.g. oil companies, drilling contractors and suppliers, in the innovation process. The first pilot projects have already created significant value for these end-users from using new forms of data analytics in combination with domain knowledge and technical insight.

“Step change is exactly what it says – a paradigm shift in how we drive innovation to quickly test out data smart solutions and new business models with strong customer involvement at an early stage. In the current price environment, innovation is even more critical. It can both help the industry to reduce complexity short term by standardizing parts and processes and enable new technological developments long-term that will drive efficiencies. At DNV GL, we are continuing to invest 5% of our revenue in R&D because it enables us to provide long-term foresight for our customers,” says Kjell Eriksson, Regional Manager Norway, DNV GL - Oil & Gas.

Currently in the initial phase, DNV GL welcomes industry players to join the JIP projects or contact us if they are interested to be involved in our Step Change program.

Aker Solutions' maintenance, modifications and operations (MMO) business in Norway will as a subcontractor of Kværner provide engineering services for upgrading the semi-submersible platform at the Statoil-operated Njord A oilfield. 

Statoil-operated Njord A oilfield. Photo: Øyvind Nesvåg / Statoil.

The company signed a subcontractor agreement with Kværner, which was awarded the framework agreement for the Njord Future project by Statoil. Aker Solutions' initial delivery will be front end engineering design (FEED) work. The contract with Kværner also includes engineering work in the engineering, procurement and construction (EPC) phase of the project should the operator decide to proceed with this, as well as an option for prefabrication work.

"We look forward to working with Kværner to find the most robust and cost-effective solutions for Statoil on this project, which draws on our experience in complex modifications," said Per Harald Kongelf, head of Aker Solutions' Norwegian operations.

The MMO unit in Bergen will execute the FEED work with support from Aker Solutions' engineering business in Oslo, working as an integrated team with Kværner. The work will start immediately and at its peak involve 120 employees of Aker Solutions.

Aker Solutions has previously delivered concept and feasibility studies on upgrading Njord to Statoil.

Materia, Inc. (Materia), in conjunction with Aegion Corporation (Aegion), has been selected by Shell Offshore, Inc., a wholly-owned subsidiary of Royal Dutch Shell plc (Shell), to supply pipeline insulation materials for the Appomattox development in the deepwater Gulf of Mexico.

Materia’s Proxima® resin technology delivers a broad range of products that increase reliability and performance for high pressure, high temperature applications in deepwater oil and gas exploration and production.

The insulation system is unique among existing polymers in its ability to provide an effective thermal barrier between flowlines and seawater. The thermosetting cross-linked hydrocarbon polymer maintains structural integrity in deepwater operating environments as an incompressible solid at water depths greater than 10,000 feet. This advanced insulation technology can also be rapidly and safely applied in the factory or the field.

Chuck R. Gordon, Aegion’s president and chief executive officer, said, “The collaboration with Materia will leverage their leading polymer insulation technology, Bayou’s world class coating, logistics and prefabrication capabilities, and Bayou Wasco’s pipe insulation technology for the safe and efficient transportation of crude oil from deepwater oil field developments in the Gulf of Mexico.”

Dr. Michael Giardello, co-founder and senior advisor to Materia, said, “Shell’s safety and performance requirements were rigorous. We were charged with supplying pipeline insulation materials that met their performance requirements, while greatly reducing the complexity of the system.”

Nitin Apte, Materia’s president and chief executive officer, stated, “Materia’s thermal insulation provides a simple and cost-effective solution to the challenges of deepwater oil and gas production. We greatly value this relationship with Shell and Aegion, and look forward to solving the thermal insulation challenges for future deepwater projects.”

Fabrication of the billion dollar topsides destined for the Maersk Oil operated USD 4.5 billion UK North Sea megaproject, Culzean has begun. The steel-cutting ceremony for the first of the three topsides modules took place at the Sembcorp Marine Offshore Platforms (SMOP - formerly known as SMOE) Admiralty Yard in Singapore on April 7th.

Culzean is the largest hydrocarbon discovery in the UK North Sea for over a decade. The field is approximately 145 miles east of Aberdeen and is expected to produce between 60,000 - 90,000 boepd at plateau production, producing for at least 13 years. The project was sanctioned in August 2015. Maersk Oil’s coventurers in Culzean are JX Nippon Exploration & Production (UK) Limited (34.01%) and BP (Britoil) (16%).

Jakob Thomasen, CEO of Maersk Oil, igniting the flames for the steel-cutting ceremony. This is the first sheet of steel cut for the Culzean megaproject. Credit: Maersk Oil

“Starting the fabrication of the topsides is an important milestone. When the field begins to produce in 2019, Culzean will become a key contributor to Maersk Oil’s ambition to become a Top 5 operator in the North Sea in the 2020s, and provide around 5% of UK gas demand at peak production. Maersk Oil and coventurers’ investment will also support employment in both the UK and Asian supply chains,” said Maersk Oil Chief Executive Jakob Thomasen, speaking at the ceremony in Singapore.

“Our focus for the next three years is working with our partners and suppliers to deliver the project from fabrication right through to commissioning safely, on time and within budget,” says Thomasen.

The contract with SMOP, worth over USD 1 billion including long lead items, was awarded in September 2015. The contract includes the building of the Central Processing Facility plus two connecting bridges, Wellhead Platform and Utilities & Living Quarters Platform Topsides for the Culzean Field Development.

The platforms will be built with enhanced digital and monitoring capability.

“We will be harnessing technology to develop a 21st century facility with the ability to remotely monitor critical equipment 24 hours a day, and enable offshore colleagues to access real time data and immediate technical evaluation and onshore support. The technology will minimize time spent on plant and enhance safety and efficiency. Maersk Oil estimates this digital toolkit can save more than USD 10m annually,” says Martin Urquhart, Culzean Project Director.

Aker Solutions secured an agreement to provide maintenance and other services for subsea facilities at Petrobras-operated oil and gas fields offshore Brazil.

The contract is for a fixed term of three years valued at BRL 435 million net of taxes (NOK 1 billion) and may be extended by another three years. It covers maintenance, storage, supply of parts and technical assistance for all subsea equipment delivered by Aker Solutions to Petrobras in Brazil.

"Brazil is a key global offshore market," said Luis Araujo, chief executive officer of Aker Solutions. "We have a nearly four-decade presence in the country and are committed to finding solutions to help Petrobras develop its petroleum resources in the most efficient and sustainable manner possible."

Aker Solutions is in April opening a new subsea manufacturing center in Curitiba, doubling its local production capacity. The company is also upgrading its subsea services unit in Rio das Ostras to better meet customer demand.

The contract will be managed at the base in Rio das Ostras in Rio de Janeiro, at a local content rate of 87 percent. This builds on a commitment to develop partnerships with national suppliers.

"We are pleased to be able to continue providing top-notch services and technologies to support Petrobras' production and growth plans in the pre-salt deepwater fields," said Maria Peralta, head of Aker Solutions in Brazil.

The agreement is similar to one signed in 2011 for maintenance of equipment and other offshore services. Currently, Aker Solutions' subsea lifecycle services unit has about 360 employees in Brazil, of which 150 are part of the technical team working offshore. The company has about 1,300 employees in the country.

The contract is booked as part of Aker Solutions' first-quarter order intake.

New subsea technologies and systems must be qualified before use to build confidence that they will function as intended. However, current subsea technology qualification (TQ) processes can be inefficient, time consuming and variations in methodology impede industry players from leveraging on each other’s results. Now DNV GL is calling for a standardized system qualification approach and joint industry effort to drive faster take-up of new technology and value creation in subsea.

A new position paper ‘Subsea system qualification: Towards a standardized approach’ by DNV GL’s Strategic Research & Innovation unit aims to answer two questions: How can confidence in new subsea systems be demonstrated in a faster and more efficient way? How can already qualified technologies be re-qualified in an effective manner for reuse in similar systems or under slightly different operating conditions?

Subsea illustration Credit: DNV GL

The position paper proposes a joint industry effort in three steps to enable more effective technology development and implementation in the field: 1) Establish common industry principles, and consolidate a common framework for system qualification founded on existing industry procedures; 2) Develop a methodology to standardize system qualification for common use across the upstream oil and gas industry and 3) Pilot and demonstrate the developed methodology and roll-out a Recommended Practice.

“The subsea industry needs to overcome key challenges such as cost reductions, enabling increased recovery, and complex field developments. At the same time, the future trend still points towards more complex systems which require integrating process, power, and control systems subsea. Assuring safety and reliability on a system level is critical when interfaces become more complex and system integration failures are harder to identify,” says Tore Myhrvold, researcher and lead author of the paper, DNV GL.

“Developing a standardized approach to subsea technology qualification will enable companies to leverage on each other’s qualification efforts and results, reduce the overall development time and ultimately enable faster innovation in the subsea sector,” continues Myhrvold.

Previous experience has shown that focus on qualification in the early phases of development reduces risk of failures in late phase testing. Failures and errors in tests that are run in later development stages, such as factory acceptance tests (FAT) and system integration tests (SIT), are expensive to fix since they may result in costly rework and re-iteration of the design process. DNV GL’s position paper recommends increasing the qualification efforts in the early phases of development to enable faster and more effective development and implementation of novel subsea technology systems.

The position paper also proposes that numerical or analytical methods (models) could prove to be cost effective and safe alternatives to current expensive physical testing or be used in conjunction with existing methods. These alternative methods can explore the effects from parameter variations and how different sub-systems or single components affect the entire system performance. By using non-intrusive numerical modelling tools to establish a common modelling platform, a wide variety of validated models can be used in the system qualification to virtually test system operational ranges and failures.

“The Norwegian Petroleum Directorate (NPD) reports that subsea tie-back represents the most relevant solution for 68 out of 88 discoveries on the Norwegian continental shelf. To sanction many of these projects, fast and cost effective technology development is vital,” says Elisabeth Tørstad, CEO of DNV GL – Oil & Gas.

“Our efforts to drive standardization in the subsea sector aim to reduce cost, lead times and to increase confidence in new technologies to enable faster innovation. Our collaboration with the industry on subsea documentation and subsea forging for example have resulted in guidance that is being implemented in projects and now delivering benefits for operators,” adds Tørstad.

To download the position paper visit www.dnvgl.com/download-subsea-position-paper.

The MAY 2016 MTS Houston Section luncheon will be held on May 26 2016 and will feature a presentation by Cory Weinbel, Senior VP Development Projects, Venari Resources. Mr. Weinbel will discuss Improving Deepwater Project Outcomes through Enhanced Collaboration.

The current low oil-price environment makes the safe and efficient execution of Deepwater Projects more important than ever as companies look for ways to grow with decreasing project resources. The Oil & Gas industry has traditionally used partnerships to spread the cost burden and reduce risks associated with large projects but in general has not fully taken advantage of the resources and synergies offered by greater involvement of Partners in the Deepwater Development. This presentation uses Cory Weinbel’s experience as well as examples from the Deepwater Oil & Gas industry and other industries to characterize the enhanced collaboration mechanisms and show the tangible benefits and the limited downside to embracing and more-effectively exercising this collaboration. While the changes required for enhancing collaboration are simple, straightforward, and common-sense, they will require many companies and their employees to embrace a new cultural paradigm. The benefits to our industry can be significant and potentially include reduced project costs and schedules, standardization of key technical elements, and the training of new generations of project personnel.

Mr. Weinbel spent over seven years working for Helix Energy Solutions Group as Deepwater Project Manager and General Manager of Production Facilities where he spear-headed the development of the first ship-shaped disconnectible oil production unit in the Gulf of Mexico at the Phoenix Development. His work has allowed him to work on multiple types of deepwater floating production units including Spars (Gunnison), TLP’s (Marco Polo), Semisubmersibles (Independence Hub), and Ships/FPSOs (Phoenix, Jubilee.)

Earlier in his career, Mr. Weinbel worked as a project engineer/project manager for Kvaerner Oil & Gas, Kerr-McGee Oil & Gas, and Kerr-McGee Chemical. Cory holds a Master of Science degree in Metallurgical Engineering and Bachelor of Science degree in Materials Engineering from Columbia University School of Engineering and Applied Science.

UPCOMING MTS HOUSTON PRESENTATIONS AND EVENTS

Hereema Marine Contractors Nederland SE will remove the platform and transport it to shore, while AF Offshore Decom AS has been awarded the contract for disposal and recycling of the platform.

Photo credit:  Statoil

The Huldra field is a Statoil- operated gas and condensate field on the Norwegian Continental Shelf, North East of Bergen. The field came on stream in November 2001 and on plateau the field produced 10, 3 MSm3/day.  

The gas and condensate production was closed down 3. September 2014. Previously the jack up rig West Epsilon has been awarded the contract for plugging the six wells at Huldra during 2016. On behalf of the partners Statoil has now awarded two new contracts for removal, transportation, disposal and recycling of the Huldra platform.

• The Engineering, Preparation and Removal (EPR) contract has been awarded to Heerema Marine Contractors Nederland SE.

• The contract for disposal and recycling of the platform has been awarded to AF Offshore Decom AS, a subsidiary of AF Gruppen ASA.

The total weight of the platform is approximately 10.000 tons, distributed over a 5, 000 ton topside and a 5, 000 ton steel jacket. It is expected that more than 95 percent of the platform will be recycled.

The plan is to remove the Huldra platform during 2019 with the subsequent disposal and recycling work taking place at AF Offshore Decom’s environmental base in Vats, Norway within the first half of 2020.

The platform is being removed according to the Ospar convention, stating that oil installations no longer being used as a main rule shall be removed.

Secretary of the Interior Sally Jewell and Director of the Bureau of Safety and Environmental Enforcement Brian Salerno have announced final well control regulations to reduce the risk of an offshore oil or gas blowout that could result in the loss of life, serious injuries or substantial harm to the environment. The regulations represent one of the most significant safety and environmental protection reforms the Interior Department has undertaken since Deepwater Horizon, and builds upon a number of reforms instituted over the last six years to strengthen and modernize offshore energy standards and oversight.

- Final Well Control Rule

- Final Well Control RIA

- Reforms Since Deepwater Horizon

- Well Control Final Rule Fact Sheet

Fugro has been awarded a contract by Indian oil and gas company, ONGC, for the provision of ROV services on board the drillship Sagar Vijay. The contract, which was signed at ONGC’s offices in Mumbai, involves providing support for deepwater drilling operations off the east coast of India, in depths up to 900 metres.

A range of tasks will be performed by Fugro’s FCV ROV, including seabed surveys, monitoring of subsea drilling operations, guideline cutting and reinstallation, remote intervention and AX/VX ring gasket installation. Services also include setting up regular fluid injection, drilling re-entry, bullseye checks and routine video monitoring, inspection and cleaning on and around the BOP.

Fugro will also provide drill support tooling during the 18-month project, which is expected to commence in May 2016.

Apprentice Jens Erik Eriksen in Kværner and Norway’s minister of petroleum and energy Tord Lien marked the construction start on the Johan Sverdrup utility and living quarters platform on the island of Stord, north of Stavanger on Thursday, March 31, 2016.

“Johan Sverdrup is the biggest industrial project in modern times in Norway, and will create considerable value for society for generations to come. Today we are kicking off the construction of the utility and living quarters platform, which is the second of four platform currently under construction in the first project phase,” says Kjetel Digre, Statoil’s project director for Johan Sverdrup.

Johan Sverdrup platform. Credit: Statoil

Statoil awarded a joint venture between Kværner and KBR the contract for engineering and construction of the topside for the utility and living quarters platform for the Johan Sverdrup field in June 2015.

Stord is central in a comprehensive Johan Sverdrup project. Kværner Stord will fabricate parts of the topside steel frame, and will also assemble all parts for the utility and living quarters platform before the platform is installed on the field in 2019. At peak around 2000 Kværner employees will be involved in Johan Sverdrup deliveries.

Kværner’s sub-supplier Apply Leirvik on Stord will construct the accommodation module for the living quarters platform, which will be the biggest on the Norwegian continental shelf (NCS).

The other modules for the utility and living quarters platform will be constructed at the Energomontaz Polnoc Gdynia (EPG), Mostostal Pomorze Gdansk (MPG), Mostostal Chojnice and Crist Offshore in Poland, as well as in Gothenburg, Sweden. Detailed engineering is performed at KBR’s office in Leatherhead, London, and at Apply Leirvik on Stord. The fabrication work was also kicked off today at two of the yards in Poland and at Apply Leirvik’s yard.

“The Johan Sverdrup project is growing every day. It is a complex puzzle with activities spread all over the world. We are 14,000 people working on the project every day in 2016, and together we will perform 100 million working hours. We depend on everyone delivering as required, and all pieces of the puzzle falling into place at the right time and with the right quality. Our top priority is a safe working environment. We do not want any injuries among personnel working for the Johan Sverdrup project,” says Digre.

The utility and living quarters platform will accommodate the crew working on the Johan Sverdrup field during the field life of 50 years. The platform will have the largest living quarters on the NCS with a capacity of 560 people. The platform will also accommodate the field’s control and emergency center, and some utility systems covering the whole field center.

The platform will be completed in the first quarter of 2019, before it is installed on the Johan Sverdrup field by use of the world’s largest heavy-lift vessel, the Pioneering Spirit.