UTC 2015 - Subsea Technology by UTC - Underwater Technology Conference

Hosted by the Underwater Technology Foundation

The 21st Underwater Technology Conference

Subsea under Pressure â&#x20AC;&#x201C; innovating for the next wave

www.utc.no

Bergen, Norway (16)17 â&#x20AC;&#x201C; 18 June, 2015

Main Sponsors:

Premium Media Partner:

Organising Partners:

INNOVATION FOR MORE EFFICIENT SUBSEA SOLUTIONS By developing and applying new subsea technologies we contribute to cost efficiency, enhance production and extend field life. Subsea 7 is a world-leading contractor in seabed-to-surface engineering, construction, inspection, repair, maintenance and services. We are dedicated to providing smarter, safer, more efficient and cost effective subsea solutions. www.subsea7.com

seabed-to-surface 2

CONTENTS Underwater Technology Foundation (UTF) 4| Welcome 5| Interview with Mrs. Margareth Øvrum, Statoil 6| Interview with Dr. Helge H. Haldorsen, 2015 President, SPE International 8| New UTF Subsea Project Award 11|

Technological Innovations - Control, Power and Instrumentation, 18 June 32| Technological Innovations - Materials, Mechanical and Marine Disciplines, 18 June 32| Academia (and Student Projects), 18 June 34| Simplification, Standardisation and enhanced industry collaboration, 18 June 34|

UTC 2014 attendee profile 12|

Backup presentations 35|

Interview with Mr. Keisuke Sadamori, IEA 14|

UTC Program Committee 2015 36|

Student projects at UTC 16|

Norwegian Centre of Expertise Subsea (NCE Subsea) 40|

Program 17 June 20|

Society for Underwater Technology 41|

Program 18 June 21|

Society of Petroleum Engineers, Bergen 41|

Parallel sessions 22|

UTC Exhibitors 2015 42|

Field Development Concepts and Experiences, 17 June 24|

Exhibition opening hours 43|

Improved Asset Value and Significant

UTC Field trips 44|

Cost Reductions, 17 June

25|

Technological Innovations - Materials, Mechanical and Marine

Trip 1: Workshop at MRC Solberg & Andersen 44|

45|

Disciplines, 17 June 26|

Trip 2: Nui Subsea Test and Hyperbaric Reception Facility

Simplification, Standardisation and enhanced industry

Trip 3: OneSubsea’ s assembly and test facility 46|

collaboration, 17 June 26| Technological Innovations - Control, Power and Instrumentation, 17 June 28| Improved Asset Value and Significant

Icebreaker at USF Verftet (New location!) 47| City of Bergen Reception and Banquet Dinner 48| Map of Bergen City Centre 49|

Cost Reductions, 18 June 31|

Registration and hotel reservations 51|

Field Development Concepts and Experiences, 18 June 31|

UTC 2015 Sponsors and Partners 52|

Simplification, Standardisation and enhanced industry collaboration, 18 June 31|

Ø M E R KE T ILJ

0 Trykksak 6

Organised by: Underwater Technology Foundation Editor / Project Management: Irmelin Grønevik, Possibility AS Layout: Lasse Hellen, Bembell AS Interviews: Eloise Logan Print: Haugesund Bok & Offset AS Frontpage photo: ©Xvision ©UTC 2015

UNDERWATER TECHNOLOGY FOUNDATION SINCE 1980, BERGEN HAS SERVED AS THE HOST CITY FOR THE WORLD’S OLDEST SUBSEA CONFERENCE, AND THE DRIVING FORCE BEHIND THE EVENT IS THE UNDERWATER TECHNOLOGY FOUNDATION (UTF). The Underwater Technology Foundation is a non-commercial entity established in 1980 when several large oil-related companies joined forces to arrange the first Underwater Technology Conference in Bergen. At that time, the subsea industry was in its infancy, and the foundation was the first in the world to put on a conference with sole focus on this sector. UTC – AN INTERNATIONAL NETWORKING ARENA Ever since the first UTC, the conference has been a regular event in Bergen. For the first 30 years, it was held biennially, but from 2010 onwards, it became an annual event. In addition to the large Norwegian oil and gas operators and suppliers, the proportion of international representatives is high – and is steadily rising. 22 different nations was represented in 2014. The conference attracts between 800 and 1000 participants annually. Hence, this June event in Bergen is an international meeting point for the world’s leading subsea technology companies. New technology is presented, challenges are discussed and UTF is the host and organiser.

THE FOUNDATION PROMOTES KNOWLEDGE UTF is, however, far more than just the Underwater Technology Conference – although focus on this event is high. The overall objective of the foundation is to promote increased knowledge of the subsea sector in the Bergen region. This is something the foundation will achieve through conferences such as UTC, which features an exhibition open to everyone interested in learning more about subsea. The foundation contributes to research and training at university level. GRANT The foundation offers a grant available to applicants in need of financial support for subsea related research or training projects. The foundation would like to see more applicants for the grant, and encourages anyone with a relevant project to apply.

Member organizations of the UTF are: Aker Solutions • Statoil • NUI • DNV GL CMR • Sparebanken Vest • Bergen kommune

UTF Board: Jarle Daae, Aker Solutions - Chairman Board UTF, Hans Erik Berge, DNV GL, Sonia Faaland, CMR, Tor Willgohs Knudsen, Statoil, Vidar Fondevik, NUI 4

www.utc.no/utf

WELCOME TO UTC 2015!

The Underwater Technology Foundation welcomes you to the Underwater Technology Conference (UTC), the 21st UTC since we started in 1980. This year we can welcome a broad selection of key note speakers, including Margareth Øvrum from Statoil and Keisuke Sadamori from the International Energy Agency, to capture the essence of this year’s theme.

As members of the subsea community we have a turbulent year behind us, and a challenging one ahead of us. To be best prepared to face this, UTC would like to invite you to connect, share and learn – all to enable yourself and your organization to be best possible prepared for the future.

The theme of this year’s conference ’Subsea under pressure innovating for the next wave’ acknowledges the situation that the industry is faced with today through the technologically challenging development of future fields but also the requirement to control and reduce cost through optimization, standardization and collaboration across industry.

Our theme ‘Subsea under pressure’ has many connotations, amongst these to profit margins, alternative energy sources, deep water and boosting. Some being challenges and some providing solutions. Many would say that they work best under pressure. Our subtheme ‘-innovating for the next wave’ is inspired by a firm belief that the market situation will improve and that innovation in its many forms will be important to future success.

UTF will commend the UTC 2015 Program Committee for their efforts in putting together a highly topical program that we very much look forward to. The cooperation in this great group of subsea professionals motivates us to further develop the conference to be a global and high-level arena for discussions for the future subsea solutions.

For the technical program we received a record of 136 abstracts providing the committee with the pleasure and challenge of selecting the 44 we believe will best inspire our innovation. Hard work has also secured us what we believe is an excellent selection of opening and key-note speakers who can enlighten us and point us in the right directions.

With great challenges ahead, it is important that individuals from major subsea operators from all over the world gather with suppliers and service providers to share initiatives, developments and solutions. We will provide the collaborative environment for you all to thrive.

Standardization would in the case of subsea be a facet of innovation, or to quote an IOGP (International association Oil and Gas Producers) vision: ‘Further industrialize and standardize Subsea Production Systems, through technical collaboration within the industry, to deliver significantly lower Capex and improved lead times. This will be achieved through promoting standard configurations, elements, processes, and industry standards. Inherent in this work is to maintain or enhance HSE performance and increased quality to deliver improved reliability and availability.’ Last year the industry succeeded with broad collaboration through a JIP on forgings resulting in DNV-GL RP0034. Forgings for the same type of application can now be manufactured to the same specification – use it. What will be the next step? Maybe welding and QA/QC/ITP (inspection and test plan).

UTC offers several facilitated and renowned networking arenas. This year we offer a variety of field trips that ought to be tempting and hard to choose from; attend a visit to Nui’s subsea test and hyperbaric reception facility, a workshop at MRC Solberg & Andersen aiming at increased industry-university collaboration or a visit to OneSubsea’s testing facility. This year we have changed the arena for the Icebreaker event – we will gather by the sea! Join us for an informal networking event at Bergens unique culture arena by the sea, USF Verftet. Meet fellow delegates, exhibitors and speakers, while enjoying tasty tapas and drinks at Bergens largest terrace. The focus this evening is to network in relaxed surroundings before the conference proceedings start Wednesday morning. Wednesday night you are invited to the City of Bergen reception in the exhibition before the banquet dinner and after party. UTC is a full-service conference. This means that all meals and drinks during the conference are included in the conference fee.

The future of our industry is being formed – by you – we hope to see you at UTC. Roald Sirevaag Chair UTC 2015 Program Committee VP Subsea Technology and Diving, Statoil

We look forward to a rewarding conference and welcome you to Bergen in June! On behalf of UTF Jarle Daae Chairman of the Board, UTF

Harald Pettersen - Statoil ASA ÂŠ

Harald Pettersen - Statoil ASA ©

The new technology we introduce today will become the industry standard Margareth Øvrum is Executive Vice President for Technology, Projects and Drilling for Statoil and a member of the company’s corporate executive committee. Having joined Statoil in 1982, she became the company’s first female platform manager, going on to hold central management positions, first Executive Vice President for Health, Safety and the Environment and then her present position. Here she discusses the challenges set for operators by today’s low oil price environment. Margareth Øvrum began by pointing out that although we are now in an oil market with large fluctuations, over the past 15 years the industry has seen oil prices ranging from $17 to $147 per barrel. “So while, like our competitors, we at Statoil are affected directly by oil prices, fluctuations are something we plan for. Our investment portfolio is flexible and we are constantly working to optimise it. We have a strong balance sheet and good liquidity”. She pointed out that Statoil also has flexibility in its project portfolio, because it is the operator for most of its projects. The uncertainty we see around us emphasises the importance of our efficiency programmes and measures to improve cost and capital efficiency. CO-OPERATION WITH SUPPLIERS Today’s low price operating pressures made it more important to come up with robust projects and boost efficiency, Øvrum said. Like cooperation with suppliers, so that both supplier and operator can deliver

cost-efficient developments throughout the value chain. She thought the entire industry needed to work hard on its competitiveness. For some years the investment has been at record levels, costs have been escalating and margins have been reduced. As a response, Statoil introduced an ambitious corporate efficiency agenda, starting when the oil price was still high, and current levels demonstrate how important this was. The best response to the challenge of today’s low oil price environment, Øvrum said, was to ensure future projects were robust enough to withstand future price fluctuations. That means that we must make our projects as profitable as possible even in such a scenario. Sometimes we have to develop new technology to achieve this, but most often we can use standardised solutions to reduce costs. If the break-even price per barrel gets too high, then the project is no longer sustainable, she said. IS SUBSEA THE ANSWER? Øvrum said that considering subsea technology solutions, there is a question mark over cost-efficiency. She said that subsea industry prices have increased significantly over the past years and more standardisation is needed. However, she stressed that Statoil would still use subsea wells in the future, when this was the best – and the most costefficient -- solution. Future resources are further from land, at greater depths and in colder and harsher environments. Subsea

processing technology and the subsea factory will be vital to realise Statoil’s business opportunities in these locations – and we are working on standardised module sizes and interfaces. STANDARDISATION IS KEY She said she thought low oil prices would encourage more standardised solutions. Statoil is promoting subsea standardisation through sharing technical specifications and participating in joint industry projects, Øvrum said. Standardisation is both cost-efficient and value-adding, reducing time and cost. As it is based on proven technology, it gives better regularity and safer operation. She noted that standardisation had contributed to accelerating the development of marginal fields through fast track-execution, enabling Statoil to cut costs (30%) and time (50%). At the same time the company needs to develop, qualify and implement new technology, since this can help reduce its capex and increase its operational efficiency. “Some of the new technologies that we introduce today will become the standardised solutions of tomorrow, so it is important to maintain technology development and implementation. For example, Statoil believes changing from 7’’ horizontal to 7’’ vertical subsea trees will produce a significant cost-reduction, taking both OPEX and drilling expenditure into consideration.”

Written by Eloise Logan

Business Region Bergen ©

There may not be a new normal stable oil price may not be a new normal stable oil price on the other side of this sub-50$/bbl period. The new normal may be an oil price mountain range from a valley of sub-50 to highs of 100+ $/bbl.”

Dr Helge Hove Haldorsen, the 2015 president of SPE International, will give the opening speech at UTC. SPE is a valued UTC partner organization and we look forward to an inspirational contribution from Dr Haldorsen in Bergen in June. In addition to his SPE position, Helge Haldorsen is Director General, Statoil Mexico. Dr. Haldorsen gave us his views on the outlook on our industry. Asked if he sees the current low oil price situation as being “the new reality”, Dr Haldorsen said: “Predicting the forward oil price has proved impossible for all. No company today is willing to bet the house on a certain oil price assumption -- and hedging is currently getting more difficult and more costly. The future looks very volatile, uncertain, complex and ambiguous, and many expect the E&P industry to continue its boom and bust behaviour, with perhaps price cycles becoming more frequent and of shorter duration”. “The bottom line is this,” he said, “There

Haldorsen pointed out that the past four stable high price years, when oil prices remained between 100-110 $/bbl, had been quite unique in terms of the stability and the associated price level. Sadly they left the industry with cost levels that were too high, since we felt we could afford anything. He said that at the CERA week 2014 conference, there was a consensus that costs must come down across the board. He went on: Since you can’t just cost-cut your way to greatness, new technology and new business models are needed to create the new and improved E&P2.0 that we so desperately need to stay competitive at a lower oil price. The conclusion of CERA week 2014, Haldorsen said, was that ‘100 is the new 20’, which means that IOCs need [a price of] 100$/bbl to deliver an acceptable return on investment. And now the oil price is 50% below ‘the new 20’ and a warning light is blinking for the industry’s competitiveness and return on investment -- unless we improve every element of what we do to restore E&P’s earnings per barrel, through cost-cutting and creative destruction, he warned.

IS THERE AN UPTURN IN SIGHT? The best cure for a low oil price is a low oil price, Haldorsen said. The highest cost marginal producers are forced to cut back activity and spending dramatically to be able to service their debt (and pay dividend), with a lower cashflow. And everybody else with flexibility will stop, delay and cut back on activity as well, albeit to a lower extent. Then oil price hedges run out and production starts declining. After a delay, demand grows, geo political events are thrown into the mix and slowly the oil price climbs. Due to the lower activity level, the cost of everything should come down, field development economics should again improve, projects should have a positive NPV again and activity levels and production should grow. WHAT ARE THE OPERATING PRESSURES? Everyone must adjust their sails when the wind changes; stricter project and activity prioritization, cut-backs in CAPEX, cutbacks in exploration, delays of development projects, re-negotiation of contracts, reduced travel, reduced R&D levels, reduced training, reduced attendance at SPE meetings, staff reduction, reduced hiring of new graduates and reduced summer intern position offerings. He quickly added: “I must say that not attending SPE meetings is wrong. Where are all the good ideas for beating the low oil price? Where great people in the business

meet and share experiences and ideas – at SPE meetings.”

manner and maintain a strong financial position to stay resilient.

IOCS AND SERVICE COMPANIES Looking at the difficulties for operating companies and oil service sector companies, Haldorsen said, the key for these two critical species in the E&P ecosystem is to collaborate and co-evolve, to become better together.

This means that they can handle an oil price downturn through increasingly stricter project and activity prioritization and delays-by-design. These will match the lower investment capacity resulting from their reduced cashflow.

Everyone must adjust their sails when the wind changes

His recommendation for operating companies is that they should X-ray themselves to separate unnecessary costs from nice to do HQ activities and then focus on simplification, standardization and improving the supply chain.

Then they should introduce incremental and radical improvements in everything they do, as frequently as possible. Their obsession should be with value creation and earnings per barrel, he said. Finally, since everything operators do they do in collaboration with suppliers, contractors and vendors, collaboration 2.0 with these business partners should be sought to eliminate wasteful processes, over-design, gold-plating, etc.. to achieve lower cost, improved deliveries and more value creation. REMAINING RESILIENT Asked what would be the best response to the current low oil price situation, Haldorsen said he believes the best companies navigate success in a disciplined

Delayed projects often are those with the highest break-evens and they are usually sent back to the drawing board for optimization and incremental and radical improvements, or the company may try to divest them. NEW DEVELOPMENTS Looking forward, Haldorsen identified deep-water oil production as meeting an increasing proportion of global oil demand. Brazil, West Africa, East Africa, the Gulf of Mexico (US and Mexico), Europe and the Arctic will ramp up. However, he noted that deep-water developments do however have a DNA that can be troublesome, in a low oil price scenario, if a company has all their eggs in this particular basket.

Then he considered onshore oil, which he said was more flexible because a company can vary the number of rigs operating in response to fluctuating oil prices. If the new normal for oil prices is rapid ups and downs, companies may be drawn in the direction of assets with capex flexibility, rather than to assets with long lead times, he concluded. NEW TECHNOLOGY Haldorsen agreed that as a result of the oil price situation a huge number of changes would be introduced to improve the industry’s cost base. “Incremental technology, business model, collaboration, improvements in everything we do in E&P. He continued: “Radical technology and business model improvements will be less frequent, but may include technology inflection points due to automated drilling, the internet of everything and big data, sub-sea factory, sub-sea compression, hydraulic fracturing without using water – possibly using CO2 instead -- more unbelievable wells offshore, for example 10,000 ft long, fractured every 500 ft. We will be taking the un- in unconventional offshore.

Written by Eloise Logan

The lead-time between discovery and first oil can be as much as 8-10 years. In deep water, you can invest $10 billion before the first drop of oil and income shows up on deck.

Business Region Bergen ÂŠ

Deadline April 20th

NOMINATE PROJECTS FOR THE NEW

UTF SUBSEA PROJECT AWARD The Underwater Technology Foundation (UTF) Subsea Award is designed to recognize the many outstanding achievements within the subsea industry. UTF would like to use our position in the industry to give some credit to the individuals behind new breakthroughs and innovation. We would like to share the stories not only with you but use our partners in Offshore Engineer Magazine to spread the story to the bigger audience outside the UTC conference halls. The UTF Subsea Project Award can be given to persons or groups that have contributed to knowledge and understanding in subsea technology through new products, services and/or processes. The objective is to tell everyone with a brilliant idea what it takes to succeed and what all the work resulted in for the industry. The jury has been appointed by the UTF board and consists of valuable UTF partners. Please nominate projects by April 20th.

The call for proposals is open to subsea projects only. Project teams can apply on behalf of their project. People related to the project is also encouraged to send proposals. In both cases, valid 3rd party references must be presented. The first UTF Subsea Project Award will be presented at UTC in Bergen 17 - 18 June 2015.

THE JURY:

Dr. Bob Allwood, Chief Executive of the Society for Underwater Technology (SUT) Dr. Helge Hove Haldorsen, President, Society of Petroleum Engineers (SPE) 2015 Bjørn Søgård, Segment Director, Business Development, Subsea and Floaters, DNV GL Elaine Maslin, Editor, Offshore Engineer Magazine Vidar Fondevik, Board Member, Underwater Technology Foundation (UTF)

GUIDELINES The program is available to both intra- and inter-company subsea projects that represent solutions to challenges where the project team has accomplished the task successfully with focus on project execution innovation, increased efficiency, HSE and a global commercial potential. GUIDELINES AND REQUIREMENTS

• The person(s) mentioned in the application is/are the rightful owner(s), or is an employee of the rightful owner of the project/ technology. • The nominee(s) is/are the appropriate individual(s) according to guidelines for the award

• This call for proposals is open to subsea projects only

• The project team is given the opportunity to present why the project was successful during the UTC conference.

• The project has to be recognized within the subsea industry and in operation with successful results. The award aims to recognize the individual(s) behind the project.

• Members of the panel of judges shall have access to the application, provided that statements of confidentiality are signed by the persons involved.

• Project teams can apply on behalf of their project. People related to the project is also encouraged to send proposals. In both cases valid 3rd party references must be presented.

• UTF shall be entitled to publicly announce all nominees and a to disclose a description of each project

Read more about guidelines and submit your nomination at www.utc.no/utf/utf-subsea-project-award

UTC 2014 ATTENDEE PROFILE Job function Executive Management

UTC 2014 Facts 11,6 %

Manager 25,4 % Chief Engineer

17,6 %

• 960 attendees • 26% international delegates • Delegates from 22 countries • 69 exhibiting companies

Engineer 11,0 % Business Development/Sales

19,1 %

Marketing/Administrative

2,4 %

R&D 7,2 % Student 2,7 % Other 3,0 %

Industry affiliation Operator 19,1 % EPCI 12,5 % System Supplier

18,8 %

Equipment Supplier

17,6 %

Subsea Services

17,6 %

Support Services

4,8 %

R&D 6,6 % Education and Training

3,0 %

EXHIBITION & SPONSORSHIP OPPORTUNITIES The UTC Exhibition is an exclusive arena for subsea related technology and services. We have a limited space available for the exhibition, making all stands visible for the conference delegates. Refreshments and lunches are served in the exhibition hall, in addition to social gatherings before and after the banquet dinner. The exhibition is the most important networking arena for the conference delegates. UTC offers two types of sponsoring packages, based on two levels of profiling, Main Sponsor and Sponsor Partner. We have chosen an egalitarian sponsoring strategy, not singling out any event or marketing item for sole publicity.

Find out more at www.utc.no/exhibition/information

13 Business Region Bergen ÂŠ

Business Region Bergen ©

More price downside before we see an upturn 2014 to defend market share as opposed to price. The process of rebalancing is underway, but there is likely to be more downside before the price rebounds for good, he cautioned.

Mr Keisuke Sadamori, is Director, Energy Markets and Security, at the International Energy Agency (IEA) in Paris and will be a keynote speaker at UTC Bergen. Among his IEA responsibilities are monitoring the global oil markets and responding to energy-supply disruptions. He gave us his view on the outlook for the world oil markets. Mr Sadamori was both pessimistic and optimistic about the likely course for the oil price. The market is in the middle of a correction that has yet to run its course, he said. Today’s low oil price environment was brought about by the relentless rise of North American supply, faltering demand growth and OPEC’s decision in November

Asked how long it might be until we can see any upturn, he replied, oil prices are likely to remain in a lower range until there are concrete signs of supply tightness. Lower prices have led oil companies -both international and national – to take an axe to spending, so production growth will slow eventually. The biggest question mark hangs over US light tight oil (LTO) – oil from shale -- which appears to be more responsive to price swings. He can see an improvement coming soon, though his optimism was qualified. The balances in our 2015 Medium Term Oil Market Report indicate that lower oil prices will translate into reduced supply growth later this year, resulting in a rebalancing that could support an uptick in prices. Higher prices, however, could stimulate increased spending and renewed supply growth – keeping in oil prices in check.

OPEC STILL A MAJOR MARKET PLAYER Sadamori noted that oil producers’ organisation OPEC would remain a dominant source of supply, despite robust growth in North America and elsewhere, pointing out that OPEC today accounts for some 40% of total oil output and the Middle East is -- and will remain -- the world’s largest exporting region for the foreseeable future. At the same time, he took the view that today’s oil market has changed fundamentally. He said, there have been oil price peaks and troughs roughly every decade since the price shocks of the 1970s, yet we have never seen a situation like we’re in now. US LTO has changed the rules of the game. It has made non-OPEC supply far more price-elastic and upended the traditional division of labour between OPEC and non-OPEC countries. OPEC’s move in November 2014 to let the market rebalance itself may have effectively turned LTO into the new swing producer. But it will not drive it out of the market. LTO might in fact come out stronger. On the other hand, demand has become significantly less price elastic. That suggests that the market response to the oil price collapse may be swifter than [we have

FACTS ABOUT IEA The International Energy Agency (IEA) is an autonomous organization which works to ensure reliable, affordable and clean energy for its 29 member countries and beyond. Founded in response to the 1973/4 oil crisis, the IEA’s initial role was to help countries co-ordinate a collective response to major disruptions in oil supply through the release of emergency oil stocks to the markets. While this continues to be a key aspect of its work, the IEA has evolved and expanded. It is at the heart of global dialogue on energy, providing authoritative statistics, analysis and recommendations. Today, the IEA’s four main areas of focus are: - Energy security: Promoting diversity, efficiency and flexibility within all energy sectors; - Economic development: Ensuring the stable supply of energy to IEA member countries and promoting free markets to foster economic growth and eliminate energy poverty; - Environmental awareness: Enhancing international knowledge of options for tackling climate change; and - Engagement worldwide: Working closely with non-member countries, especially major producers and consumers, to find solutions to shared energy and environmental concerns.

seen] to earlier price declines of a similar magnitude.

was to seek out the opportunities. While challenging, low oil prices also provide opportunities for companies to increase efficiencies and for the industry as a whole to focus on projects that are sustainable in a lower oil price environment.

CUTS MAY NOT HALT DEVELOPMENT Turning to the situation for companies, Sadamori said, firms were While challenging, low oil prices also tightening provide opportunities for companies However, he warned belts and to increase efficiencies and for the that fiscal cutting discipline and capital industry as a whole to focus on project spending projects that are sustainable in a lower careful management even before oil price environment would be the price of essential to oil began to ensure that fall. Due to adequate investment was made to bring on cost inflation and high break-even prices future supply in the short and long term. for projects, they are now re-evaluating investments. Projects are being delayed and Sadamori does not see the current price even cancelled. necessarily bringing forward alternative energy supplies. He observed, most But the outlook for oil development renewable energy that is competing with may not be so bleak after all. We have to fossil fuels is mandate-driven and as such remember, however, that industry costs will not be significantly impacted by a are also falling along with the price of oil. lower oil price. Furthermore, wind and So spending cuts will not in every case solar power do not compete directly with lead to a material impact on oil sector petroleum-based fuels when it comes to development. power generation. FIRMS SHOULD SEEK OPPORTUNITIES Written by Eloise Logan Sadamori’s advice to oil sector companies

FACTS ABOUT WORLD ENERGY OUTLOOK The annual World Energy Outlook (WEO) is now the world’s most authoritative source of energy market analysis and projections, providing critical analytical insights into trends in energy demand and supply and what they mean for energy security, environmental protection and economic development. The WEO projections are used by the public and private sector as a framework on which they can base their policy-making, planning and investment decisions and to identify what needs to be done to arrive at a supportable and sustainable energy future.

World Energy Outlook 2014

EXECUTIVE SUMMARY

STUDENT PROJECTS

For the second time UTC invite students from all parts of the world to deliver abstracts for consideration. We are interested in student projects at Master or PhD level (including 2014 graduates) in the field of subsea technology. The student presentations will be included in the technical presentations at the conference June 17th – 18th. The featured students will be included in the conference program, receive complimentary conference fee, and flight and hotel accommodation for the duration of the conference. To enable as many students as possible to propose an abstract we will accept contributions until April 25th 2015. Your student paper/presentation could be connected to one of the chosen topics for UTC 2015, or another topic connected to subsea technology: – Technological innovations – Control, Power and Instrumentation – Technological innovations – Materials, Mechanical and Marine disciplines – Field Development Concepts and Experiences – Simplification, Standardization and Enhanced Industry Collaboration – Improved Asset Value and Significant Cost Reductions Find out more at www.utc.no/conference/student-participation/submittal-requirements-and-guidelines

UTF INVITES STUDENTS TO UTC UTC is an international meeting point for the world’s leading subsea technology companies. New subsea technology is presented, challenges are discussed and students will be able to meet the companies face to face in the exhibition hall. The Underwater Technology Foundation sponsors students with delegate passes to UTC. Students can apply to get free attendance at the conference proceedings and lunches. Please send an e-mail to utc@possibility.no with the following information: Name Level: Bachelor, Master or PhD Institution: school with department/faculty The student admission does not give access to UTCs social events. It will not be possible to buy tickets to the events, this due to limited seats available. The Underwater Technology Foundation does not cover travel expenses.

17 Business Region Bergen ÂŠ

Leading the Subsea Revolution Aker Solutions is a leading developer in the subsea revolution and offers products, systems and services to maximize oil and gas recovery globally

akersolutions.com

Possibility AS – the technical organizer of UTC Possibility AS is conducting the practical and technical preparations and administrative functions for the conference, including: • Project management • Secretary for the Program Committee • Technical solutions and design • Concept development and production • Sales and coordination of sponsorships and exhibition • Marketing, design and information materials • Logistics • Registration and hotel reservations • Social events

The UTC team from Possibility

Irmelin

Jan Olav

Linn

Aase

Lene

Ståle

Olli

Kristoffer

OPTIMIZE FROM PORE TO PROCESS

AD01754OSS A4

A unique approach for optimized production and increased recovery INTEGRATE End-to-end solutions from reservoir to surface COLLABORATE Early engagement to anticipate challenges and improve decisions ENGINEER Optimal system architecture to increase life-of-field production CONTROL Continuous monitoring to manage changing reservoir conditions BOOST Production with scalable processing solutions ENHANCE Financial return over the life of the field LEARN more about our unique, unrivaled approach in

Stand 3

PROGRAM, DAY 1 @GRIEGSALEN

17 JUNE

08:30 – 09:30 Badge pick-up and coffee Welcome 09:30 – 09:40 UTC Program Committee Chairman Roald Sirevaag. Conference Moderator Simon Davies, Statoil 09:40 – 10:00

Opening speech, Dr. Helge H. Haldorsen, 2015 President, SPE International

10:00 – 10:20

Driving for value creation and industrialization Margareth Øvrum, Executive Vice President Technology, Projects and Drilling, Statoil

10:20 – 10:40

Handling pressure through technology Mike Garding, CEO, OneSubsea

10:40 – 11:00

Challenging project execution Geneviève Mouillerat, Vice-President Projects & Construction, Total

11:00 – 11:30

Coffee break and exhibition Panel discussion:

Subsea under pressure – are we innovating in the right way? 11:30 – 12:30

Moderator: Simon Davies • Hervé Valla, CTO, Aker Solutions • Pål Helsing, President and EVP, Kongsberg Oil & Gas Technologies • Sigurd Skogestad, Professor, Norwegian University of Science and Technology • Shawn Murphy, Center Director of Shell TechWorks - Boston, Shell • Per Sandberg, Vice President, Chief of Innovation, Statoil

12:30 – 14:00

Lunch and exhibition

14:00 – 15:30

PARALLEL SESSIONS, TRACK 1 - 4 – SEE DETAILED PROGRAM, PAGE 22-23

15:30 – 16:00

Coffee break and exhibition

16:00 – 17:30

PARALLEL SESSIONS, TRACK 1 - 4 – SEE DETAILED PROGRAM, PAGE 22-23

18:00 – 19:30

City of Bergen reception

19:30 – 01:00

Banquet dinner

Subject to change

PROGRAM, DAY 2 @GRIEGSALEN

18 JUNE

08:30 – 09:00 Morning coffee and refreshments in exhibition hall 09:00 – 09:10

Welcome Day 2 Simon Davies

09:10 – 09:30

Energy outlook Keisuke Sadamori, Director, Energy Markets and Security, International Energy Agency(IEA)

09:30 – 09:50

Standardization – the new innovation Elisabeth Tørstad, CEO Oil&Gas, DNV GL

09:50 – 10:00

UTF Subsea Project Award Award winner interviewed by Simon Davies

10:00 – 10:30

Coffee and exhibition

10:30 – 12:00

PARALLEL SESSIONS, TRACK 1 - 4 – SEE DETAILED PROGRAM, PAGE 22-23

12:00 – 13:15

Lunch and exhibition

13:15 – 14:15

PARALLEL SESSIONS, TRACK 1 - 4 – SEE DETAILED PROGRAM, PAGE 22-23

14:15 – 14:30

Coffee break Panel discussion:

Subsea under pressure - who is driving the cost? 14:30 – 15:30

15:30 – 15:45 Subject to change

Moderator: Jeremy Cresswell (Energy Editor, The Press and Journal) • Carl Andreas Holm, Partner and Managing Director, Boston Consulting Group • Rasmus Sunde, General Manager, FMC Subsea Eastern Region, FMC Technologies • Jannicke Nilsson, SVP STEP Project, Statoil • Odd Strømsnes, Managing Director, Technip • Per Arne Nilsen, Head of Subsea Technology, Total Summary and closing, Simon Davies, conference moderator

Parallel sessions Day 1 Track 1@Peer Gynt

17 June

Track 2@Spissen

Field Development Concepts and Experiences

Improved Asset Value and Significant Cost Reduction

14:00 – 14:30

Subsea Processing from Brazil to the Barents Sea. Jan-Olav Hallset, Team Lead - SURF Controls & Distribution, Norske Shell

Good oil & gas projects lost due to traditional design methodology? Tine Bauck Irmann-Jacobsen, Global SME WATCH Design, FMC Technologies

14:30 – 15:00

Johan Sverdrup Subsea Concept Development. Kristoffer Dahl, Subsea Engineer, Statoil ASA

CompactSep - compact subsea gas-liquid separator for high-pressure wellstream boosting. Olav Kristiansen, Principal Researcher Process Upstream Oil Production Systems, Statoil

15:00 – 15:30

Production Increase from Installation of Multiphase Boosting Solution Gavin Mann, Underwater Superintendent, Canadian Natural Resources International (UK) Ltd

Cost Reduction Opportunities in Deepwater Riser Systems. Hugh Howells, Principal Director, 2H Offshore Engineering Ltd

Session moderators Tom Eddy Johansen, FMC Technologies and Torkild Reinertsen, Reinertsen

Session moderators Nils Arne Sølvik, OneSubsea and Michael Starkey, Exxon Mobil

Coffee break and exhibition

15:30 – 16:00 Field Development Concepts and Experiences

Improved Asset Value and Significant Cost Reduction

16:00 – 16:30

Fast Track project execution: From speed to cost. Christina Schieldrop, Project Manager Fast Track Field Development, Statoil

Lean Contracting and Technologies for Cost Optomised Subsea Development. Hamish Button, CTO, Technip

16:30 – 17:00

All subsea? – The future of subsea production. Tore Irgens Kuhnle, Senior Researcher, DNV GL

Subsea Hand Tools - ROV Disassembly of THS. Will Price, Engineering Lead, Oceaneering

17:00 – 17:30

Managing Sand in Subsea Separation Systems. Ed Grave, Fractionation & Separation Advisor, ExxonMobil Upstream Research Company

Lifetime extension through condition based lifetime management. Sigurd Hernaes, Senior Field Development Engineer, FMC Technologies

Session moderators Torolf Hæhre, Shell and Henrik Medland Madsen

Session moderators Per Christian Eriksen, Aker Solutions and Johan Kristian Mikkelsen, Perestroika

Parallel sessions Day 2 Track 1@Peer Gynt

18 June

Track 2@Spissen

Improved Asset Value and Siginificant Cost Reductions Session moderators Per Christian Eriksen, Aker Solutions and Tim Crome, Technip

Technological Innovations – Control, Power and Instrumentation Session moderators Martin Dove, BP and Torkild Reinertsen, Reinertsen

10:30 – 11:00

Water Management for Subsea Gas Production. Christopher J Kalli, Team Leader: Flow Assurance and Production Systems Technology, Chevron

Subsea well stream compression development: a collaborative approach for an experience-based design optimization. Rune Vesterkjær, Manager Subsea Process Systems, Aker Solutions

11:00 – 11:30

Power under pressure- innovated solutions for the next wave of brownfield developments. Bjørn Rasch, Head of Subsea Power, Siemens Subsea

Coordination and standardisation of Completion/Workover systems in Statoil. Terje Holten, Project Manager, Statoil

11:30 – 12:00

Combining Seabed Boosting Pumps and Alternatively Deployed ESPs to Improve Recovery Subsea. Erik Torbergsen, Program Manager, OneSubsea

Sonsub Subsea Bus: Background and Roadmap for the future Subsea Factory Alessandro Radicioni, Manager Subsea Field Development, Saipem SpA

Lunch and exhibition

12:00 – 13:15 Field Development Concepts and Experiences Session moderators Terje Clausen, Subsea 7 and Torolf Hæhre, Shell

Simplification, Standardisation and Enhanced Industry Collaboration Session moderators Tonje Dahl, ClampOn and Tom Eriksen, NCE Subsea

13:15 – 13:45

Subsea to subsea live pigging. David R de Miranda (Gassco)/Keith Lathwell (DeepOcean), Asset Manager - UK Pipelines / Project Manager, Gassco / DeepOcean

Improving fault identification in subsea power systems. Kristin Moe Elgsaas, Senior Product Manager, Subsea Power, GE Oil&Gas

13:45 – 14:15

Subsea Factory - Standardization of the Brownfield Factory. Rune Mode Ramberg, Chief Engineer Subsea Technology and Operations, Statoil

Conductivity measurement for multiphase and wet gas flow conditions, for both oil and water continuous flows. Harald Solheim, PhD, project engineer, OneSubsea Processing

Subject to change

Parallel sessions Day 1 Track 3@Klokkeklang

17 June

Track 4@Troldtog

Technological innovations – Materials, Mechanical and Marine disciplines

Technological Innovations – Control, Power and Instrumentation

14:00 – 14:30

Remote Welding System - a new way of repairing critical deep water pipelines. Jan Olav Berge, Senior Advisor Pipeline Technology, Statoil

Capping Stack Connectors. John Charalambides, Director of Business Development, Oceaneering’s Specialty Connector Solutions Division, Oceaneering International, Inc.

14:30 – 15:00

Development of a novel multiphase pump technology. Fredrik Moen, Business Development Manager, Aker Solutions

Tracerco Discovery Subsea Pipeline CT Scanner – Integrity and Flow Assurance Case Studies of Subsea Coated Pipeline Inspections. Lee Robins, Head of Subsea Services, Tracerco

15:00 – 15:30

Reducing life-cycle costs through the use of Electrically Trace Heated Enhanced Pipe-in-Pipe Neil Brown, Discipline Engineering Manager, Subsea 7

Subsea Controls – Network for the future. Odd Gilinsky, Product Line Manager, Aker Solutions

Session moderators Terje Clausen, Subsea7 and Per Arild Nesje, Kongesberg Oil&Gas Technologies

Session moderators Tonje Dahl, ClampOn and Henrik Meland Madsen, Siemens

Coffee break and exhibition

15:30 – 16:00 Simplification, Standardisation and Enhanced Industry Collaboration

Technological Innovations – Control, Power and Instrumentation

16:00 – 16:30

Standardization – will take the industry to the next level. Ingvar Grøtberg, Manager Field Development, FMC Technologies

Unique technology for 3D integrity monitoring of subsea pipes. Geir Instanes, Vice President, ClampOn

16:30 – 17:00

A new approach to a total field development assessment. Martin Sørensen, Director Subsea, Reinertsen Oil & Gas

Wireless subsea communication: the potential for utilization of general wireless broadband technologies. Ingvar Henne, Scientist, CMR Science and Technology

17:00 – 17:30

Subsea Processing JIP – Standardisation of Modules and Interfaces. Kristin Nergaard Berg, Principal Engineer, DNV GL

Subsea Laser profiling and Sequential imaging. Michael Flynn, CTO, Cathx Ocean

Session moderators Hans Kristian Sundt, GE Oil&Gas and Martin Dove, BP

Session moderators Tom Eriksen, NCE Subsea and Marie Bueie Holstad, CMR

Parallel sessions Day 2 Track 3@Klokkeklang

18 June

Track 4@Troldtog

Technological innovations – Materials, Mechanical and Marine disciplines

Academia and student papers

10:30 – 11:00

Dead legs innovative insulation design for subsea multiphase high-boost station, Julien Rolland, Flow assurance engineer, Total

SUBPRO: A new Norwegian research innovation center on subsea production and processing. Sigurd Skogestad, Professor, Norwegian University of Science and Technology

11:00 – 11:30

Duplex Stainless Steel - The choice for subsea components. Sophia Ekman, Development Engineer, Sandvik Materials Technology (Research and Development)

Student Paper TBD in May

11:30 – 12:00

Challenges related to equipment design and qualification to 20 ksi and 400° F. Paal Bratland, Principal Mechanical Engineer, OneSubsea Processing

Student Paper TBD in May

Session moderators Rune Høyvik Rosnes, Oceaneering and Marie Bueie Holstad, CMR

Session moderators Bård Espelid, DNV GL and Vidar Fondevik, Nui

Lunch and exhibition

12:00 – 13:15 Technological innovations – Materials, Mechanical and Marine disciplines

Simplification, Standardisation and Enhanced Industry Collaboration

13:15 – 13:45

Riserless Lightweight Well Intervention – ready for deepwater? Oddbjørn Bjerkvik, Chief Engineer, FMC Technologies

Standardization of umbilical – is that possible? Liv Molvik Lundegaard, Portefolio manager, North Sea projects, Nexans Norway AS

13:45 – 14:15

Autonomous Inspection Vehicle; A change in Conventional Thinking. Jim Jamieson, Technology Manager (Life-of-Field), Subsea 7

Cost from where? – Functional requirements versus detailed specifications. Ole Petter Hjelmstad, Department Manager Engineering, Subsea 7

Session moderators Tom Eddy Johansen, FMC Technologies and Per Arild Nesje, Kongsberg Oil&Gas Technologies

Subject to change

Session moderators Michael Starkey, ExxonMobil and Bård Espelid, DNV GL

BACKUP PRESENTATIONS Technological Innovations - Control, Power and Instrumentation

Technological innovations – Materials, Mechanical and Marine disciplines

Field Development Concepts and Experiences

Advances in Subsea Wet Gas Compression Technology A State of The Art Update. Mads Hjelmeland, Director Emerging Technologies, OneSubsea Processing

Field Gradient Sensor (FiGS) – New Innovative CP Inspection Technology. Jens Christoffer Werenskiold, Senior Engineer, FORCE Technology

Method for evaluation of technology impact on subsea system lifetime costs and risks. Keld Lund Nielsen, R&D Project Manager Deepwater Engineering, ENI spa

Simplification, Standardization and Enhanced Industry Collaboration

Improved Asset Aalue and Significant Cost Reduction

The “Good enough Philosophy” – material and manufacturing requirements at the right level for the subsea industry”. Hans Christian Ly, Head of Materials Technology, Subsea, Aker Solutions

Subsea Intervention and permanent technologies getting closer? Knut A. Nilsen, Technical Advisor, Innova AS

DAY 1 - PARALLEL SESSIONS FIELD DEVELOPMENT CONCEPTS AND EXPERIENCES - TRACK 1 @PEER GYNT 17 June, 1400-1430, Track 1@Peer Gynt Subsea Processing from Brazil to the Barents Sea

Jan-Olav Hallset, Team Lead - SURF Controls & Distribution, Norske Shell Norske Shell ‘s SURF department is involved in a number of subsea processing projects around the globe, projects which will enable effective exploitation of deep water fields worldwide. These projects all rely on development and delivery of novel technology and solutions. In this presentation we would like to share and discuss our experience so far, from Norway, via Gulf of Mexico to Brazil. It should be noted that all these projects are still in the execution phase and hence operational experience is limited. Regardless, we believe that it would be valuable to share our know-how with system design, technology qualification, execution, and installation. The presentation will show that subsea pumping is the key processing technology that enables unlocking of extra resources and that this happens over a wide range of water depths and reservoir pressures. It is tempting to discuss if processing technology is becoming a standard tool for subsea developments, although the technology is still novel and introduces a new level of complexity when compared to conventional subsea production systems. Lastly the presentation will point towards the future and discuss how Shell’s know-how and subsea processing technology are relevant for the development of resources in the Barents Sea. Subsea systems will have to handle the challenges in the Arctic, firstly the sensitive environment and secondly the sheer distances to any onshore supply facility.

17 June, 1430-1500, Track 1@Peer Gynt Johan Sverdrup Subsea Concept Development

Kristoffer Dahl, Subsea Engineer, Statoil ASA The Johan Sverdrup Field was discovered in 2010 and 2011 just 140 km from Stavanger in relatively shallow water depths of 110 meter. The reservoir located at 1900 meter below surface,

and has very good expected production rates and a high recovery rate. The first phase involves the establishment of a field centre consisting of four platforms. Three subsea templates for water injection will be connected to the field centre. No field is identical, and even in a well-known area of the NCS there are several surprises. The current frame conditions have also changed the way Statoil develops fields, with power from shore being the prime example. For the underwater scope there are also other less published key learnings. Some challenges are well known such as the increased dynamic loads on subsea wellheads in shallow water. Other challenges were less well known, such as the soft silty soil was discovered during geotechnical surveys that has posed a challenge for foundation design. The high focus on reducing produced water disposal to sea has led to produced water re-injection. This combined with risk of well clogging and fracking of the reservoir has again led to increased complexity in water management with corresponding impact on field lay-out and control system. Future flexibility and increased oil recovery initiatives are important even with high initial recovery. The subsea water injection system therefore has possibility both for traditional IOR such as infill wells, and nontraditional IOR such as Water Alternating Gas injection.

17 June, 1500-1530, Track 1@Peer Gynt Production Increase from Installation of Multiphase Boosting Solution

Gavin Mann, Underwater Superintendent, Canadian Natural Resources International (UK) Ltd In the summer of 2014, Canadian Natural Resources International (UK) Limited (CNRI) successfully installed and commissioned a OneSubsea manufactured and supplied, Multi Phase Booster Pump (MPBP) at its Lyell subsea production facility. At a water depth of 140m, the Lyell field is located around 386km Northnortheast of Aberdeen in the UK Sector of the North Sea. Hydrocarbons from Lyell are transported via subsea pipeline to CNRIs Ninian South Platform, from which water injection and facility control is provided. Control to the MPBP itself is provided by an 8km electrohydraulic umbilical running from the Ninian North Platform. The new MPBP replaced an older

pump originally installed in 2005 which became unserviceable a number of years ago. Installation of the new MPBP delivers value in two forms. The first is by enabling simultaneous production from wet and dry wells; without the MPBP the wet wells can only be produced when dry wells are closed. The second is the incremental production uplift provided by the pump when all wells are on-stream. Combined together, installation of the MPBP at Lyell has meant increased production and availability, and this is a significant benefit for CNRI. In addition to the above, the presentation will cover: - The drivers behind CNRIs choice of multiphase boosting versus other options, and why subsea boosting can be such a good fit for brownfield developments such as Lyell. - The challenges faced with the integration of new pumping equipment, into a mature subsea facility. - How ongoing pump performance is monitored and optimised. The presentation shall conclude by summarising the performance of the pump since installation, and based on this real experience, the projected value add for CNRI for the years ahead.

17 June, 1600-1630, Track 1@Peer Gynt Fast Track project execution: From speed to cost

Christina Schieldrop, Project Manager Fast Track Field Development, Statoil The Fast track mandate was given by Statoil’s Corporate Executive Committee (CEC) in November 2009. Average time for realizing subsea tie-back projects on the NCS was more than 5 years and increasing. Fast track was a measure to realize marginal discoveries and provide production growth in the short term. The ambition was clear: Reduce the execution time with 50%. Similar projects were clustered in one portfolio – to create a basis for scale and repetitiveness through standardizing and industrializing. 12 fast track projects have been sanctioned, whereof 10 are already in production. The fast track portfolio have a total capex of about 60 BNOK and recoverable reserves of about 500 mmboe. On such a large basis - systematic improvements makes a difference. The fast track portfolio has reduced the time from discovery to production with up to 40%, to close to 3 years, and has delivered

within the approved capital budgets. The capital efficiency and profitability is high compared to industry average, and the fast track portfolio delivers above average industry execution performance. It has moved Statoil’s and the industry’s perceptions of the potential within efficient project planning, front end loading and execution to a new level. Going forward we are committed to maintain and expand the fast-track activity. We want to achieve similar results on cost as we have obtained on the time dimension. Although we have many possibilities in the pipeline, the inflow of traditional fast track candidates varies, so we have to investigate and push for expanding the established Fast-track criteria. Our ambition moving forward is to “maintain speed – reduce cost”.

17 June, 1630-1700, Track 1@Peer Gynt All subsea? – The future of subsea production

Tore Irgens Kuhnle, Principal Researcher, DNV GL Where do we think the subsea technology is taking us with respect to pure subsea development concepts? We look into the business case of a pure subsea field development concept relative to existing floating field development concepts; determine to what degree it is an enabling versus enhancing alternative, and under what circumstances it is likely to become a preferred development concept in the future. While subsea technologies are advancing, there are still barriers to overcome related to cost and uncertain technology performance. The future of subsea technology must also be viewed in context of a business environment where the cash flow and profitability situation of the oil companies have made them more stringent on capital and risk averse. The business case of different subsea technologies is investigated both in isolation and how they impact each other as a part of a complete subsea concept to determine when moving production, power and processing subsea has positive versus negative consequences for the field economy. Main drivers and feasibility are discussed based on the positive and negative contribution from the different technologies. The conclusion is that while certain technologies are clearly enhancing or even enabling, other parts of the concept introduces new limitations. How to take advantage of the strengths of subsea technologies and multiphase flow capabilities while mitigating shortfalls related to power, complexity and availability? Field types especially suited for pure subsea developments are exemplified. Co-writers: Tore Myhrvold (Senior Principal Researcher), Frank Børre Pedersen (Vice President)

17 June, 1700-1730, Track 1@Peer Gynt Managing Sand in Subsea Separation Systems

Ed Grave, Fractionation & Separation Advisor, ExxonMobil Upstream Research Company ExxonMobil recently completed subsea technology qualification test programs, which included a multiphase subsea separation system for shallow-water applications using conventional, vessel-based separation technologies and another system for deepwater applications using compact separation technologies. As with any subsea processing application, reliability of the systems is extremely important, as intervention costs can be considerably high. One key reliability risk is related to managing the accumulation of sand in the subsea processing equipment. Another is the erosional limit of the process equipment due

to sand production. By properly designing and validating the performance of the various sand management technologies in these two subsea separation systems, these reliability risks could be reduced. For the shallow-water system, sand handling trials were conducted to evaluate the performance and to identify potential failure mechanisms of the sand fluidization/removal internals and/or the rest of the integrated sand handling system. In addition, the oil-water separation performance of the three-phase separator was measured during the trials to determine the effect of the various sand removal operations on the oil-water separation. For the deep-water system, an inline sand removal device was tested using model fluids over a wide range of inlet conditions to determine the sand removal performance. In other qualification test programs, the effectiveness of sand fluidization/ removal internals in the compact separation technologies, including the subsea slug catcher and pipe separator, was determined. This presentation will detail the design considerations with regards to sand management and disposal that impacted the final layout of these two subsea separation systems, the qualification test programs carried out on the various technologies of the integrated sand handling systems, and the results from these qualification test programs.

IMPROVED ASSET VALUE AND SIGNIFICANT COST REDUCTIONS - TRACK 2@SPISSEN 17 June, 1400-1430, Track 2@Spissen Good oil & gas projects lost due to traditional design methodology?

Tine Bauck Irmann-Jacobsen, Global SME WATCH Design, FMC Technologies During the last 40 years the subsea production systems have changed from platform developments on shallow water to deeper water, long tie-ins and need for subsea process systems. The conceptual design methodology has not developed in pace with the need for advanced subsea technology. When the disciplines traditionally involved in studying the potential of a new field do their estimates separately, they result is a set of conservative estimates. This translates to overly complex and costly solutions that are difficult to operate. This means that many interesting but challenging projects are put on hold because of uncertainty in feasibility and cost. To address this issue, a new type of conceptual design methodology has been developed. The methodology is based on long experience of online monitoring of subsea fields (from 1995), long experience of subsea delivery projects and equipment (from 1980), multiphase technology expertise, network modelling expertise and powerful optimization algorithms. The methodology looks at the entire life cycle of the field, from early design to the field’s operability, and provide decision makers with a more accurate and realistic picture of the fields’ potential. The methodology link the main disciplines early, make early design decisions knowledge based, hence reduce the risk of late changes and provide a smarter and leaner system solution which improve asset value and reduce cost. Case examples will be given to illustrate the new design methodology, compared with a traditional design approach. The impact on feasibility, reduction in uncertainty and operability, optimization of the subsea process

system and hence reduced CAPEX and OPEX will be illustrated.

17 June, 1430-1500, Track 2@Spissen CompactSep - compact subsea gasliquid separator for high-pressure wellstream boosting

Olav Kristiansen, Principal Researcher Process Upstream Oil Production Systems, Statoil Subsea separation has successfully been implemented on the Troll, Tordis and Pazflor fields. One feature of subsea separation is to separate gas and liquid to optimize working conditions for subsea pumps enabling high recovery factors. The later years focus has been on qualifying more compact separation units than conventional gravity based separators. If the requirement is high pressure and highcapacity boosting, the only option is singlephase or gas-tolerant/hybrid pumps. A gas tolerant pump can typically handle 10% actual volume gas contents. A higher gas volume fraction will require degassing upstream the pump. This can be done using a conventional two-phase separator. In ultra-deep waters or at high shut-in pressures, separators with large diameters will require thick walls which can be challenging or even impossible to produce. Lifting operations of such subsea modules will be challenging and costly. Reducing the weight and size of the separator module is important both from a construction, installation and intervention perspective. CompactSep, a compact, inline gas-liquid bulk separator consists of already proven hardware components assembled in a two-stage separator system. The CompactSep system has been developed and qualified in a Joint Industry Project with Statoil as operator and Chevron, Petrobras, TOTAL and FMC as participants. Comprehensive, large-scale tests were performed with realistic fluids and at realistic conditions. The main results of the test campaign are presented. The key learnings were that CompactSep has a wide operating range and that it is possible to stabilize the process with relatively slow subsea control valves. A comparison between conventional subsea modules and CompactSep shows significant cost and weight reductions. Authors: Olav Kristiansen (Statoil), Gene Kouba (Chevron), Fabricio Soares da Silva (Petrobras), Jérôme Anfray (TOTAL), Mattias Gillis Winge Rudh (FMC Technologies)

17 June, 1500-1530, Track 2@Spissen Cost Reduction Opportunities in Deepwater Riser Systems

Hugh Howells, Principal Director, 2H Offshore Engineering Limited Riser systems can form a major component of the total cost of deepwater production systems. Whether the selected riser arrangement is a steel catenary, lazy wave or freestanding hybrid, the high costs result from a combination of stringent or complex fabrication and inspection requirements and the installation methods and vessels involved. Through some relatively minor design changes or re-configuration, manufacturing and fabrication requirements can be simplified and installation complexity and installation vessel requirements reduced, resulting in smaller overall costs. This paper describes target areas for cost reduction in deepwater riser systems and some methods by which this objective can be achieved.

17 June, 1600-1630, Track 2 @Spissen Lean Contracting and Technologies for Cost Optomised Subsea Development

Hamish Button, CTO, Technip The paper will present strategies for lean field development and project delivery. Highlighting areas where ‘offshore industry culture’, excessive specification and functionality currently can lead to inflated costs in the construction of subsea facilities. It will also review the integration of SPS and pipeline infrastructure technologies with topsides for optimising performance and installed cost.

17 June, 1630-1700, Track 2@Spissen Subsea Hand Tools – ROV Disassembly of THS

Will Price, Engineering Lead, Oceaneering During the decommissioning of a deepwater well in the Gulf of Mexico the removal of the Tubing Head Spool (THS) was unsuccessful after multiple attempts using the existing disconnect options built into the THS. Taking a couple months to regroup and discuss potential solutions the operator and Oceaneering decided to partner together to disassemble the THS subsea using the ROVs and modified tooling. To ensure the success of this operation the two companies worked together to simulate the entire operation with a similar THS prior to mobilizing for the campaign. Leading up to and during the campaign it was determined a vast array of non conventional ROV tooling would be required. Some of these tools included pipe wrenches, ROV installable 1/2” NPT fittings, hydraulic tubing overshot tools to reconnect control tubing, and large socket high torque wrenches. The intervention was successful offshore but was not as straight forward as planned. During the intervention it was visually determined that hydrates had formed inside the lock piston of the THS and was the reason for the malfunction. After four days of continuous ROV operations to remove bolts, nuts, install hydraulic fittings, and pump MEG into the connector the THS was able to be successfully removed in three pieces. This intervention prevented years of delays in decommissioning and helped eliminate significant costs and risks to develop tooling to cut the THS off.

17 June, 1700-1730, Track 2@Spissen Condition and Performance Monitoring – an Extended Lifetime Enabler

Sigurd Hernaes, Senior Field Development Engineer, FMC Technologies Lately it has been performed several Lifetime Extension evaluations for the subsea fields on the NCS. Commonly the output of such evaluations will be some form of mitigating actions. A common mitigation is a reduction in the operational envelope, e.g. reduced maximum allowed pressure, production rate or intervention limitations. This can often be unwanted constraints to the system. The basis for this conclusion will often be theoretical analysis of the system and these can be quite conservative as the information that forms the basis for these is limited. As a result unnecessary constraints can be implemented to the system. This presentation will present an approach where condition and data monitoring is actively used to extend the lifetime for an existing field based on true and more realistic data for the assessment of the condition, and hence the integrity of the system.

Further, aspects with regards to maintenance and integrity management will be discussed. Also positive side effects of having a Condition and Performance Monitoring system will be mentioned. The presentation will conclude that Condition and Performance Monitoring is a good tool for extending the lifetime of an existing field as it makes it possible to continuously monitor critical parameters with regards to degradation mechanisms which are potential threats to hydrocarbon containment and the operational integrity of the equipment.

TECHNOLOGICAL INNOVATIONS – MATERIALS, MECHANICAL AND MARINE DISCIPLINES - TRACK 3@KLOKKEKLANG 17 June, 1400-1430, Track 3@Klokkeklang Remote Welding System - a new way of repairing critical deep water pipelines Jan Olav Berge, Senior Advisor Pipeline Technology, Statoil Offshore oil and gas pipelines are important assets for maintaining stable energy supply as well as being critical for maintaining cash flow to the owners and shippers. Emergency repair response time is in focus by all major pipeline operators, and the need for remote repair technology have been addressed since the mid 1990’ies. Statoil have, on behalf of the Pipeline Repair and Subsea Intervention (PRSI) Pool in Norway, developed new technology allowing remote controlled repair by hyperbaric welding of large diameter subsea pipelines in water depths down to 1300 meters. The new Remote Welding System consist of three main modules; a habitat providing a dry gas filled work location at the tie-in location, a power and control unit launched separately providing all essential services needed for the job and the remote welding tool performing the welding operation itself. The system is built and qualified for pipelines from 30” to 42” diameter, but may be expanded to smaller diameters and deeper waters.

17 June, 1430-1500, Track 3@Klokkeklang Development of a novel multiphase pump technology Fredrik Moen, Business Development Manager, Aker Solutions As the oil industry continuously moves to deeper waters and harsher environments, the need for enabling technologies is increasing. Subsea pumping in general, and multiphase pumping specifically, has for several years been a leading technology in obtaining increased recovery both from greenfield and brownfield developments. In order to take part in this expanding market, Aker Solutions has developed a range of subsea pumps for all applications. The most recent addition to the family is the multiphase pump which has been developed as part of a joint industry project (JIP) with several oil companies participating. Key focus will be given to the new technology developed for the multiphase pump, differentiating it from products already existing in the marketplace. The pump integrates a newly developed semi-axial impeller design tailored to raw well stream pumping. The hydraulics is designed for maximum pressure generation while avoiding separation and gas locking in the pump. Organized in a

back-to-back arrangement, the hydraulic configuration is self-balancing and optimized for long intervention intervals. Coupling the pump with an Aker Solutions 6MW – 6.000 RPM motor has shown promising results in testing to date. Furthermore, the pump will be equipped with a newly developed health monitoring system enabling a more proactive operational strategy. With this new insight into performance parameters, the operator is able to run the pump in optimal conditions. Moreover, the presentation will include disclosure of the multiphase pump’s performance achievements obtained during the joint industry program currently in its final stages.

17 June, 1500-1530, Track 3@Klokkeklang Electrically Trace Heated Enhanced Pipe-in-Pipe: Unlocking Reserves through Low Power and Thermal Efficiency

Neil Brown, Discipline Engineering Manager, Subsea 7 It is estimated that eleven prospects on the NCS will require pipeline systems with enhanced thermal performance, including high performance insulation and / or active heating. This requirement is driven by ever more challenging produced fluid composition, production profiles and the need to optimise process design. The subsea industry is facing the same trend in most active hydrocarbon producing regions. Enhanced Pipe-in-Pipe (PiP) technology utilises high performance insulation material in a reduced pressure environment to provide an order of magnitude improvement in total heat transfer compared to traditional PiP systems. Electrical Trace Heating (ETH) technology is a solution to direct heating of pipelines that provides enhanced redundancy, significantly reduced power requirements, an “always-on” capability and ease of installation compared to existing Direct Electrical Heating (DEH) technology. This paper describes the application of enhanced PiP technology with an ETH system. The technology provides a stepchange in the performance of highly insulated and heated pipeline systems. Such a step-change enables extended reach in cold climates as well as the potential to unlock reserves in brown field areas. ETH PiP technology is being actively developed for deployment by major operators such as Total, ConocoPhillips and Statoil. A summary of the design implications and an overview of ongoing technology qualification work will also be presented in this paper.

SIMPLIFICATION, STANDARDIZATION AND ENHANCED INDUSTRY COLLABORATION - TRACK 3@KLOKKEKLANG 17 June, 1600-1630, Track 3@Klokkeklang Standardization – will take the industry to the next level Ingvar Grøtberg, Manager Field Development, FMC Technologies In the mature oil and gas provinces the majority of the opportunities consist of smaller and more marginal discoveries requiring tie-back to existing infrastructure, while the development cost has increased over time due to a number of reasons. On top of this the oil price is under pressure. The challenge is then to develop

solutions that can make these discoveries profitable. Historically solutions were copied from one project to the next. This does no longer give the expected efficiency gains, since the requirements have increased in quantity and complexity which again leads to changes that is detrimental to the effect of copy. Even small changes may lead to large engineering rework. It seems like there is an agreement in the industry that there are two key enablers to solve the challenge for our industry to improve the economics in the marginal discoveries. (A) Standardization through the value chain to be able to handle the complexity in requirements and consequences of changes. (B) The industry needs to work together to align, simplify and reduce the amount of requirements. The question is how we do it. Standardization needs to take place on components, products, subsystem and system level in order to take out the full potential. At the same time we need to agree on solutions that are fit for purpose, we need to simplify and challenge the requirements. In this presentation FMC will demonstrate how standardization provides efficiency gains, improvement in schedule, quality performance and ensures that lessons learned is captured. We will present a configurable standard with flexibility to accommodate functional requirements and project specific needs.

17 June, 1630-1700, Track 3@Klokkeklang A new approach to a total field development assessment Martin Sørensen, Director Subsea, Reinertsen Oil & Gas In order to cope with the market demand for

new and cost effective subsea field development solutions, the Oil & Gas subsea industry is now at a very important and exiting crossroad. After decades of technology-driven subsea project developments, the subsea equipment has reached a level of maturity which enables the industry to swop towards cost-driven project developments. It is time to look into the toolbox and make a sanity check – do we have all we need in order to develop the next generation subsea project? With all these tools actually at hand, it is time to take advantage of the technologies and put focus on standardization, common standards & specifications, reuse, open architecture, configurable systems etc. To proceed into the future we must look at alternative and better ways to execute complete subsea projects. This implies a need to reconsider the subsea contract models and accept new and alternative ways of handling concept studies, FEEDs, system engineering, hardware supply and installation, and consequently the industry can take advantage of equipment independent system engineering players entering the subsea arena. In addition we believe that subsea development projects can be executed along the same contractual and competitive principles as in other segments of the Oil & Gas industry, e.g. topside and landbased projects. The subsea main suppliers and customers need to come to a consensus in order to change the route into the future. The presentation will put focus on main drivers and what steps to take in order to achieve field developments that are simple, robust, reliable and cost effective.

17 June, 1700-1730, Track 3@Klokkeklang Subsea Processing JIP – Standardisation of Modules and Interface

Kristin Nergaard Berg, Principal Engineer, DNV GL Over the last decade, CAPEX costs per well have increased considerably. Industry players are discussing the root cause and possible solutions. Tailor making and company specific requirements are mentioned as part of the picture. Subsea processing is an enabler for exploiting resources in marginal fields. However, with the current cost level, profitability can be challenging to prove. On this background, DNV is leading an industry cooperation to find standards within subsea processing - based on initiative from Statoil. To achieve cost efficient technology, industry collaboration is being established to define standards that can be used in subsea processing projects. Cooperation between operators is important to secure a coordinated and predictable approach to the supplier industry and to identify in which areas standardization may be achievable and beneficial. Although subsea processing is seen as relatively new technology, there is experience to draw from between operating companies. Subsea pumps have been taken into use in several fields. Subsea separation is used in Total’s Pazfloor project, Petrobras’ Marlim project and Statoil’s Troll Pilot and Tordis. In 2015, the first systems for subsea compression will start boosting the gas production at the Åsgard and Gullfaks fields. All of these represent significant efforts that can be re-used through operator collaboration, in terms of e.g. working methods, engineering and technology qualification. Being a young

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technology, there is a window of opportunity to set directions for standardization before practices have become too integrated to turn around. Standardization is a buzzword today and it is expected from our industry that we make efforts to achieve this. In this presentation, DNV GL will explain the approach and ambition for the JIP and give a status update of the work.

TECHNOLOGICAL INNOVATIONS – CONTROL, POWER AND INSTRUMENTATION - TRACK 4@TROLDTOG 17 June, 1400-1430, Track 4@Troldtog Capping Stack Connectors

John Charalambides, Director of Business Development, Oceaneering’s Specialty Connector Solutions Division, Oceaneering International, Inc. During a loss of well control offshore, emergency intervention requires vertical access to the wellhead. Vertical access is currently available via a MODU positioned directly over the wellhead and BOP, but this access may not always be an option if other floating production facilities such as a Spar or TLP are used. To ensure emergency intervention is possible when the wellhead is damaged, debris is in the way, or vertical access is not available, a contingency means to attach the capping stack directly to the well is required. The well capping method involves using a specialized connector to attach a BOP directly on a flowing production riser approximately 100 ft. above the mudline. The connector will have a top connection consisting

of an API 18 ¾” - 15 KSI flange. A BOP wellhead mandrel will be bolted to the top flange of the connector. This allows the connector, when latched to the riser, to be a contingency wellhead for the BOP. The connector is controlled and operated via an externally mounted ROV panel. Proven hydraulic pipeline repair concepts have now been applied to capping stack applications and re-engineered to accept high internal pressures, large pressure end loads, and bending and torsion loads. Once the connector has been set on the flowing riser, the only controls needed are via the ROV, which supplies the control pressure and operates the valve functions.

17 June, 1430-1500, Track 4@Troldtog Tracerco Discovery Subsea Pipeline CT Scanner – Integrity and Flow Assurance Case Studies of Subsea Coated Pipeline Inspections

Lee Robins, Head of Subsea Services, Tracerco Tracerco Discovery provides high-resolution wall integrity data plus detection and characterization of deposits. Case Study 1 – Pipeline integrity Discovery was deployed to determine the remaining wall thickness of several coated single wall jumpers and pipein-pipe flowlines of an unpiggable pipeline system. Wall thicknesses and other features were measured to within 1mm accuracy, confirming the integrity of the pipelines. Case Study 2 – Flow Assurance Discovery was deployed to determine the location and type of unknown deposits in a blocked pipe-in-pipe system. As well as sizing and locating the extent of the deposits, they were also characterised so that different deposit types were differentiated

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(wax, hydrate, asphaltine, scale). This enabled an efficient remediation and cleaning campaign to be planned to bring the pipeline back into production. Discovery Technology is ROV deployed and the inspection is carried out from the outside of the pipeline. It is the only non-invasive technology capable of inspecting unpiggable coated pipelines. Discovery benefits are: • Production can continue and normal operations are not affected • A high resolution tomographic image of wall thickness and pipe contents is provided to 1mm resolution • Coating does not need to be removed • Suitable for gas, liquid or multiphase flow • Suitable for inspection of rigid and flexible lines, including pipe-in-pipe pipe bundles • Real time communications allow instant assessment of pipeline conditions Flow Assurance specialists can now obtain an accurate characterisation of pipeline deposits and confirm what they are (i.e. hydrate, wax, asphaltine or scale) Integrity Engineers now have an externally deployed reliable method of accurately measuring any defects and the remaining wall thickness of any type of pipeline (coated or uncoated).

17 June, 1500-1530, Track 4@Troldtog Subsea Controls – Network for the future

Odd Gilinsky, Product Line Manager, Aker Solutions Subsea controls has evolved over the decades, starting with rather basic hydraulic control functions, then adding a growing portion of electronics and eventually data communications. The principal architecture has however not

17 June, 1600-1630, Track 4@Troldtog Unique technology for 3D integrity monitoring of subsea pipes

Geir Instanes, Vice President, ClampOn Corrosion and erosion on subsea installations is a big challenge for oil and gas operators and can carry significant cost and risk. Better monitoring of seabed installations will lower maintenance costs, provide greater control and reduce risk to installation integrity. For topside installations, there are several methods of inspection and monitoring available, but subsea, the challenge has been to find technology that works and provides real value. The growing number of aging subsea installations increases the need for good retrofit solutions. Research and development of guided-wave methods for asset monitoring and screening has been ongoing for several years and over this time ClampOn has developed a non-invasive instrument which can be used on new subsea installations or retrofitted by ROV to existing installations. While developing this guided wave based system, ClampOn’s research team has worked in parallel to develop and implement more technology in the system which will provide high-resolution

3D data for the area being monitored. Tomography is already used elsewhere, such as in medical applications, but has never before been used as part of a fixed subsea system to monitor wall thickness loss in pipelines. This paper provides background information about ClampOn’s development of its subsea corrosionerosion monitoring system, an explanation of the measuring principles used, and explains how combining several technologies and principles allows us to accurately monitor changes in wall thickness loss in subsea installations and fulfil operators’ need for continuous condition monitoring of subsea pipes.

17 June, 1630-1700, Track 4@Troldtog Wireless subsea communication: the potential for utilization of general wireless broadband technologies

Ingvar Henne, Scientist, CMR Science and Technology The development of new technologies for mobile broadband communication has produced efficient solutions for high capacity wireless communication based on the combination of adaptive modulation, OFDM (Orthogonal Frequency Division Multiplexing) and MIMO (Multiple Input Multiple Output). These technologies reduce the impact of varying transmission conditions, and should have a potential for use in wireless subsea communication in order to improve communication capacity and robustness. OFDM has proven to be robust, particularly in transmission conditions with severe intersymbol interference caused by multipath reflections or refractions. MIMO is used for spatial diversity to improve communication channel robustness during transmission conditions that are predominant in wireless communication close to subsea installation like templates, pipelines and risers. Complex structures create a very challenging environment for acoustic communication, which OFDM and MIMO can handle efficiently with adaptation to the medium. Simulations have been carried out for the transfer function of an acoustic transmit and receive system. This simulation setup emulates a simplified model of the measurement setup, and parametric sweeps simulate timevariations for the transmission medium. A prototype system based on a software-defined radio with acoustic transducers was built,

and measurements have been carried out. The transducers were placed in a rectangular tank with plane surfaces that creates distinct reflections, which resembles the propagation conditions close to or within subsea installations. The initial study shows that mobile broadband technologies have potential usage for underwater communication, and that the combination of adaptive modulation, OFDM and MIMO can improve system performance compared to fixed single-carrier solutions.

17 June, 1700-1730, Track 4@Troldtog Subsea Laser profiling and Sequential imaging

Michael Flynn, CTO, Cathx Ocean The integrity and operation of subsea assets requires regular survey and inspection using highly accurate survey tools and processes. Subsea Survey today uses a combination of video imaging and acoustic data which is limited in resolution. This makes some features such as anodes and cracks difficult to identify. Traditional video data and even HD, on a moving subsea vehicle, is captured over long exposure times and so details are heavily blurred even where the video stream is adequate for piloting. A combination of Laser profiling and co-registered still images provides sharp high resolution images and accurate 3D point cloud enabling detailed asset inspection. The industry is now entering a phase where five knot vehicles are being successfully trialled. These bring new challenges to all forms of optical data capture. The limiting factor for increased speed and range is exposure times, which is determined by high camera sensitivity and optical power. Laser images are best shot in darkness and stills cameras require intense burst of light therefore a key requirement is the ability to sequence the various imaging scenarios. Recent laser profiling trials over subsea assets in the North Sea have had very positive results. In varying turbidity conditions the 3D laser data with coregistered still images enabled clear identification of features on a pipeline. The simplicity and accuracy of these data collection methods makes identification of features and faults much simpler. Matched with modern data storage and retrieval tools automation of the inspection process is the natural progression.

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changed dramatically; after all we are an extremely conservative industry, not without reason. The pressure for new solutions is driven by increasing process complexity (the “Subsea Factory”) and a requirement to reduce cost. Two elements may accelerate this change; optical fibre and electrical actuation, already well known technologies, but the real impact on how we build subsea controls is yet to be seen. The traditional hydraulic-electrical SCM is designed for tree/well control, however for the separation, processing, and boosting subsea plant we have the opportunity to solve this with a much more modular, distributed architecture, changing the principles on how we separate traffic and address redundancy; at a lower cost. The subsea control system is there to facilitate the production process; it is a “necessary evil”, but is also the glue in an advanced subsea production system. The current standards are all targeting well/tree control, limiting the necessary evolution. We will show concepts for a control infrastructure that will have a significant impact on how we could connect the subsea factory, using principles from the telecom industry. Not a revolution, but give the evolution a necessary push forward.

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3. Do you recommend or approve the 1. What is your main job function? purchase of equipment or services? (check one box only) (check all that apply) 01 Executive & Senior Mgmt (CEO,CFO, is your main job function? 3. Do you recommend or approve the 1. What COO,Chairman, President, Owner, 700 Specify purchase of equipment or services? (check box only) VP,one Director, Managing Dir., etc) 701 Recommend (check all that apply) Executiveor& Engineering Senior MgmtMgmt. (CEO,CFO, 702 Approve 02 01 Engineering COO,Chairman, President, Owner, 703 03 Operations Management 700Purchase Specify VP, Director, Managing Dir., etc) 701 Recommend 04 Geology, Geophysics, Exploration 4. Which ofApprove the following best describes 702 02 Engineering or Engineering Mgmt. 05 Operations (All other operations personnel, your703 personal area of activity? Purchase 03 Operations Management Dept. Heads, Supv., Coord. and Mgrs.) (check all that apply) Geology, Exploration 99 04 Other (pleaseGeophysics, specify) 4. Which of the following 101 Exploration survey best describes 05 Operations (All other operations personnel, your area of activity? 102 personal Drilling Dept. Heads, Supv., Coord. and Mgrs.) (check all that apply) 2. Which99 of the best describes 103 Sub-sea production, construction Otherfollowing (please specify) 101(including Exploration survey your company’s primary business activity? pipelines) 102 Drilling (check one box only) 104 Topsides, jacket design, fabrication, 2. Which of the following best describes 103 Sub-sea production, construction 21 Integrated Oil/Gas Company hook-up and commissioning your company’s primary business activity? (including pipelines) 22 Independent Oil & Gas Company 105 Inspection, repair, maintenance (check one box only) 104 Topsides, jacket design, fabrication, 23 21 National/State Oil Company 106 Production, process control Integrated Oil/Gas Company hook-up and commissioning 24 22 Drilling, Drilling Contractor instrumentation, power generation, Independent Oil & Gas Company 105 Inspection, repair, maintenance 25 23 EPCNational/State (Engineering,Oil Procurement., Company 106etc. Production, process control Construction), Main Contractor 24 Drilling, Drilling Contractor 107 Support services, power supplygeneration, boats, instrumentation, 26 25 Subcontractor EPC (Engineering, Procurement., transport, support ships, etc etc. 27 Engineering Company Construction), Main Contractor 108 supply supply boats, 107Equipment Support services, 28 26 Consultant Subcontractor 109 Safety prevention protection transport, supportand ships, etc 29 27 Seismic Company Engineering Company 110 108Production Equipment supply 30 28 Pipeline/Installation Contractor Consultant 111 109Reservoir Safety prevention and protection 31 29 Ship/Fabrication Yard Seismic Company 99 (please specify) 110 Other Production 32 30 Marine Support Services Pipeline/Installation Contractor 111 Reservoir Ship/Fabrication Yard 33 31 Service, Supply, Equipment Manufacturing 99 Other (please specify) Marine Support Services 34 32 Finance, Insurance Service, Supply, Equipment Manufacturing 35 33 Government,Research, Education, 34 Finance, Insurance Industry Association Government,Research, Education, 99 35 Other (please specify) Industry Association 99 Other (please specify)

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DAY 2 - PARALLEL SESSIONS IMPROVED ASSET VALUE AND SIGNIFICANT COST REDUCTIONS - TRACK 1@PEER GYNT 18 June, 1030-1100 Track 1@Peer Gynt Water Management for Subsea Gas Production

Christopher J Kalli, Team Leader: Flow Assurance and Production Systems Technology, Chevron Remote offshore gas fields are commercially challenged by a lack of infrastructure. Subsea production is generally seen as the solution but comes with numerous challenges of its own that often results in significant costs offsetting the potential savings of a subsea development. A substantial proportion of these costs are associated with management of the key flow assurance risks; corrosion, hydrates, scale, liquids hold up and solids. These risks arise directly from the challenge of transporting unprocessed gaseous production fluids over long distances. This presentation describes a vision of success and a number of technology opportunities and approaches that together offer the possibility of managing these flow assurance challenges with much reduced cost. However, success will most likely depend on the industry sharing a common vision and the creation of meaningful alliances and collaborations involving operators, the service industry and research organisations.

18 June, 1100-1130 Track 1@Peer Gynt Power under pressure – innovated solutions for the next wave of brownfield developments

Bjørn Rasch, Head of Subsea Power, Siemens Subsea AS Siemens Subsea develops and qualifies a full subsea power distribution solution where we plan to finalize main qualification tests already in 2015. Final test in water will take place early 2016. The Subsea Power Grid is a flexible toolbox which enables more subsea processing with intelligent power solutions. This presentation will focus on cost effective and compact stand alone solutions which optimal serves single consumers in brownfield developments. Standalone subsea variable speed drives directly fed from a topside switchgear enables subsea boosting with a minimum of topside infrastructure required. In this way marginal discoveries can effectively be tied in to existing facilities independently from available space on the vessels. Optimized subsea VSD technology especially for smaller subsea power consumers also supports future production technologies like “dual boost” or “cable installed ESP” in a cost-effective manner.

18 June, 1130-1200 Track 1@Peer Gynt Combining Seabed Boosting Pumps and Alternatively Deployed ESPs to Improve Recovery Subsea

Erik Torbergsen, Program Manager, OneSubsea Paleogene fields in the Gulf of Mexico face well-documented production challenges, such as low permeability, weak drive, deep reservoirs, and deep water. In order to achieve economically attractive levels of recovery, many operators are exploring artificial lift systems. One such option is to pair seabed boosting

pumps with high reliability in-well electric submersible pumps. A program to evaluate the feasibility and benefits of such a system has been launched: DualLiftTM The primary objective of this study was to document the feasibility of a DualLift system and compare its performance to standalone seabed boosting pumps. Work included developing a full-field system layout and simulating production for a range of reservoir and system assumptions using Petroleum Experts GAP. Another major objective of the study was to document the impact of ESP reliability on the production availability of a DualLift system given the historically inconsistent performance of ESPs. A comprehensive availability model was developed using reliability data for individual system components; ESP reliability, ESP intervention time, and rig deployment time were varied to determine their impact on overall system availability. The results of the availability model were then combined with the steady-state production results to calculate a range of net present values. Primary findings from the study were that DualLift was able to recover 20% 50% more oil than seabed multiphase boosting alone by significantly lowering bottom hole flowing pressures. Additionally, the DualLift concept was found to add positive net present value and achieve industry-standard production availability targets by utilizing moderately reliable alternatively deployed ESPs. In total, the combination of seabed boosting pumps and in-well ESPs should be considered as a viable method of enhancing recovery from challenging offshore oil fields.

FIELD DEVELOPMENT CONCEPTS AND EXPERIENCES - TRACK 1@PEER GYNT 18 June, 1315-1345 Track 1@Peer Gynt Subsea to subsea live pigging

David R de Miranda (Gassco) / Keith Lathwell (DeepOcean), Asset Manager - UK Pipelines / Project Manager, Gassco / DeepOceanAS The Gjøa Gas Pipeline live pigging campaign is considered to be the first diverless intelligent pigging operation to be done subsea to subsea using production gas and maintaining full export operations. The Gjøa Gas Pipeline transports rich gas from the Gjøa/ Vega fields through the Gjøa platform on the NC S to the UK FLAGS pipeline. The 28”pipeline has a length of ca 131 km and has been operated by Gassco since 2010. The cleaning and inspection of the pipeline was conducted in November 2014. A MFL (Magnetic Flux Leakage) intelligent pig was used. Diverless launch and receipt of MFL had not been done before. Onshore pig launch tests were conducted to provide comfort that it was possible to launch the pigs with Naphtha and to receive them safely subsea without significant risk to production operations. Experience from the successful offshore operations will be used for development of future generation of subsea pig launch and receipt equipment and pigging procedures. The successful completion of the diverless Gjøa live pigging project demonstrates the operational feasibility of subsea to subsea diver-less pigging opening up opportunities for subsea connection of pipelines through subsea tie-in projects. It thus also negates the need to connect new pipelines to existing riser platforms,

significantly improving field development economics for greenfield and brownfield developments.

18 June, 1345-1415 Track 1@Peer Gynt Subsea Factory - Standardization of the Brownfield Factory

Rune Mode Ramberg, Chief Engineer Subsea Technology and Operations, Statoil ASA Objectives/Scope: As part of the corporate technology strategy Statoil has launched a technology plan for the Subsea Factory concept. The plan describes how to combine subsea production and processing technology elements with key business cases and define enabling and cost-efficient field development concepts. Methods, Procedures, Process: While there has been a gradual increase in the complexity of the subsea processing systems we have also advanced our analytical and modelling approach to subsea processing concept evaluation and selection. In our recent concept evaluation we have used an integrated modelling approach, in which subsea processing options are directly linked to reservoir models, flow lines and surface facilities. This enables us to see value added in terms of increased reservoir productivity, but also overview of entire system behaviour from reservoir to the topside, throughout the expected field life. Results, Observations, Conclusions: The cost level within subsea has increased by a factor 2.5 over the last 10-12 years. Statoil aims at establishing a Business agreed standardisation on subsea processing interfaces and modules. This standardisation strategy will allow suppliers to compete within modules/ technology elements, but standardise on module size and open interfaces to achieve plug-andplay functionality. The goal is to reduce costs and improve competitiveness of subsea solutions: • More profitable subsea developments • Increased subsea processing volume Statoil believes that alignment with the other operators is vital to succeed in establishing a global, open standard. This will be a “Win-win solution” for O&G Industry • Standardisation enabling cost reduction through simplification • More profitable subsea developments • Increased subsea processing volume (=> winwin-solution for the O&G industry)

SIMPLIFICATION, STANDARDIZATION AND ENHANCED INDUSTRY COLLABORATION - TRACK 2@SPISSEN 18 June, 1030-1100 Track 2@Spissen Subsea well stream compression development: a collaborative approach for an experience-based design optimization Rune Vesterkjær, Manager Engineering, Process & Design, Emerging Subsea Technologies, Aker Solutions Subsea gas compression has been recognized as a real opportunity to maximize return for brownfields as well as new discoveries, with a significant potential for reduced CAPEX and OPEX compared to traditional topside

solutions. In addition, cash constraints with the oil companies’ and reduced oil prices have resulted in a strong focus on cost reduction and standardization for better predictability in project execution and risk minimization. The objective of this presentation is to share the latest developments for an optimized and cost-effective subsea well stream compression system, combining the robustness and maturity of qualified technologies with the need for economically feasible solutions in challenging market conditions. Extensive engineering work and several technology qualification programs have been completed as part of Åsgard Subsea Compression and Ormen Lange Pilot projects; a large number of key components have been qualified for subsea service. Valuable experience and lessons learned gained by the teams involved in the execution of these projects – from conceptual design to actual delivery of the equipment - have formed the basis for the development of a minimum viable subsea well stream compression solution. Examples on how competence acquired through design, fabrication and extensive testing of subsea compression systems has been used to challenge requirements, whilst keeping qualified core functionality, will be shown. This has allowed achieving major reductions in size, CAPEX and OPEX for the optimized well stream compression solution. Finally examples of tight collaboration throughout the supply chain, with close cooperation with key sub-suppliers for specific design optimizations will be presented.

18 June, 1100-1130 Track 2@Spissen Coordination and standardisation of Completion/Workover systems in Statoil

Terje Holten, Project Manager- AOR Workover System’s, Statoil Workover systems are used on subsea wells, but not all the time. They are needed for well completion, repairs (intervention), or permanent plugging. The rest of the time they are stored in warehouses, and many of the licenses with subsea wells have their own system. Not so in the future. Workover systems are expensive, between NOK 600 million and NOK one billion per system. This represents several billions worth of equipment that is standing by most of the time. Therefore Statoil has allocated the units in our tool pool management system, and the strategy is by optimizing the different tool groups Statoil will include new licensees in existing tool groups: The licenses that need such systems may buy into existing packages, and licenses that already have such systems will be paid for their deposits. Maintenance cost and storage cost will be reduced accordingly. Prerequisite is the new planning tool for allocation of equipment towards operational needs. In the future we will also see more standardisation both of subsea systems and workover systems, and we expect to reduce the costs significantly for future needs by adding sub-systems to the equipment groups instead of buying new complete packages. Statoil is also mapping which systems that are best suitable towards our rig portfolio to: Secure safe and efficiently handling on the rig, reduce rig modification cost, optimize systems to ensure operability, HSE , dynamic positioning (DP) vs anchored operations and reduce WoW.

18 June, 1130-1200 Track 2@Spissen Sonsub SUBSEA BUS: Background and Roadmap for the future Subsea Factory

Alessandro Radicioni, Manager Subsea Field Development Engineering, Saipem SpA The anticipated adoption of subsea processing technologies in the future subsea field developments entails an increased level of functional complexity to be deployed on the seabed. The introduction of a higher level of functional complexity in subsea systems shall be supported by a total system availability which will not be only dependent on individual technologies and associated equipment reliability but also on a set of key drivers which shall govern the overall Subsea System configuration and that shall include elements such as Interchangeability, Re-Configurability, Expandability, Installability Inspectability and Retrievability To this end, the standardization of subsystems/modules and the standardization of interfaces among subsystems/modules and with Subsea Production Systems or other facilities shall be key. For the above, the philosophy to develop “open sources architectures” through standardized Functional Building Block and standardization of the relevant interfaces is being pursued by Sonsub (Saipem brand name and industrial platform for the Subsea Factory) for its subsea processing technologies and proprietary solutions including the Subsea Gas/ Liquid Separation System (Multipipe Separator), Liquid/Liquid Separation System (SpoolSep), and The Sea Water Treatment and Re-Injection System (SPRING). The paper illustrates the “open source architectures” conceived by Sonsub for its proprietary technologies along with the proposed standardization principles to allow the integration of a system independent from any proprietary products or equipment and exclusive interfaces.

TECHNOLOGICAL INNOVATIONS – CONTROL, POWER AND INSTRUMENTATION - TRACK 2@SPISSEN 18 June, 1315- 1345 Track 2@Spissen Improving fault identification in subsea power systems

Kristin Moe Elgsaas, Senior Product Manager, Subsea Power, GE Oil&Gas This presentation explains how an innovative high voltage connector design can be used to efficiently locate faults in subsea power systems. Downtime in subsea production systems causes significant economic losses and quick fault identification and rectification is a key to reduce life of field costs. In systems that also include subsea power & processing, the number and types of modules that must be checked for failure increases. While some power modules might be monitored, smaller equipment such as connectors and jumpers are typically not. In case of failures in these interconnections or un-monitored equipment, it is critical to understand what has failed to ensure the right module is retrieved. A connector capable of acting as an insulation switch can ease and speed up this identification. The MECON is a clean environment connector emphasizing reliability and process control. Mechanical mating of the connector halves and electric

engagement has been split in two independent actions separated by a flushing process that ensures proper dielectric properties inside the connector prior to electric engagement. The connector is designed to withstand full system voltage when mechanically mated but electrically dis-engaged without any insulation breakdown. These characteristics allow for systematic fault searching. Such a method could significantly reduce the cost of failures in subsea power & processing systems. The presentation will introduce both the unique design concept for the high voltage connector and the process for rapid fault location.

18 June, 1345-1415 Track 2@Spissen Conductivity measurement for multiphase and wet gas flow conditions, for both oil and water continuous flows

Harald Solheim, PhD, project engineer, OneSubsea Processing On-line measurement of water salinity is important for many applications in multiphase and wet gas flow metering. Applications range from detecting formation water breakthrough for flow assurance purposes to updating water density input to gamma-densitometry-based flow meters. In this paper, the employment of an open-ended coaxial reflection probe for estimating water salinity in three-phase flow will be described. The limited sensitivity depth of the reflection probe, based on microwave technology, means that it is sensitive to the bulk electrical property of the fluids in its close vicinity. When placed in a liquid-rich location of a blind T pipe spool, the reflection probe is suitable for both the multiphase and wet gas flow conditions. This is providing comparable salinity-estimate accuracy for the full range, from low to very high GVF. While a microwave transmission system will fail to estimate water salinity for many oil-continuous flows, the intermittent presence of water in the close vicinity of the reflection probe flush at the pipe wall helps achieve a reasonable salinity estimate.

TECHNOLOGICAL INNOVATIONS – MATERIALS, MECHANICAL AND MARINE DISCIPLINES - TRACK 3@KLOKKEKLANG 18 June, 1030-1100 Track 3@Klokkeklang Dead legs innovative insulation design for subsea multiphase high-boost station Julien Rolland, Flow assurance engineer, Total The Oil & Gas industry is facing new subsea challenges as existing deep offshore fields are now depleting and some new coming fields present difficult development or production challenges like limited reserves, remote areas, complex fluids. Installation of subsea boosting systems enables to balance the reservoir depletion with time and thus to extend the production plateau and increase total recovery of fields. With the qualification of the first high boost multiphase pump (developed by OneSubsea), Total achieved a major new milestone in subsea pumping of fluids from a deep offshore reservoir, using a high pressure pump (150 bar) with the ability to handle fluids containing a large volume of residual gas. The multiphase pump module is thermally insulated

in order to prevent hydrates formation during production and shutdown. A recirculation line enhances the pump operating envelope and provides minimum flow protection. Depending on the operating conditions, the recirculation line may be closed at times, creating long dead legs where temperature can drop rapidly. The use of appropriate thermal bridge transferring heat from a warm location of the pump module enables to maintain the temperature above the hydrate formation temperature. The insulation design has been fully qualified and thermal performances have been successfully confirmed with a full scale thermal test of the multiphase pump module.

18 June, 1100-1130 Track 3@Klokkeklang Duplex Stainless Steel – The choice for subsea components

Sophia Ekman, Development Engineer, Sandvik Materials Technology (Research and Development) During the last decade, hydrogen induced stress cracking (HISC) has caused a number of failures for super duplex subsea components exposed to cathodic protection. One common factor for these failures has been that the failed duplex stainless steel had been exposed to high stresses in combination with a coarse microstructure or presence of intermetallic phases, which is a result of manufacturing processes. Because of this guidelines have been developed to avoid future problems. This paper summarizes results from laboratory tests performed on different product forms in duplex stainless steels simulating materials subjected to cathodic protection. Different loads have been applied relating to the material´s yield strength (Rp0.2)

at a temperature of 4°C. Results show that fine grained tube and bar material (10-30µm austenite spacing) can withstand 120% of the yield strength without crack initiation, while material with a coarse microstructure (austenite spacing > 30µm) show risk for HISC at 90% of the yield strength. A case story of a retrieved super duplex tube that has been subjected to cathodic protection for 6 years without failure is also discussed. The results for material with a coarse microstructure are in line with the guidelines developed to avoid HISC while fine grained material do not suffer HISC at stress levels up to the specified minimum yield strength (SMYS). The paper also discusses a proposed mechanism for the occurrence of HISC in duplex stainless steels.

elastic plastic analysis as per the 2013 edition of ASME VIII-2 or fracture mechanic analysis as per ASME VIII-3 to determine suitability of equipment design. To provide sufficient design data, material qualification for the new HPHT equipment will involve fatigue testing and crack growth testing in an actual anticipated process environment. This presentation will describe how the new requirements of design, material, and verification are used in the development of a new HPHT subsea multiphase flowmeter for conditions exceeding API 17D. It will also identify gaps in the new design guidelines, where it will be up to the manufacturers to define an appropriate way of verifying and validating special components’ ability to provide integrity at the severe design conditions.

18 June, 1130-1200 Track 3@Klokkeklang Challenges related to equipment design and qualification to 20 ksi and 400° F

18 June, 1315-1345 Track 3@Klokkeklang Riserless Lightweight Well Intervention - ready for deepwater?

Paal Bratland, Principal Mechanical Engineer, OneSubsea Processing There is a trend in the oil and gas industry to develop high-pressure and high-temperature (HPHT) reservoirs up to 20 ksi/1378 bar and 400° F/203° C. API 6A and API 17D, which are the most commonly used design standards for HPHT equipment, ends at 15 ksi/1034 bar and 350° F/177° C. New design standards to address the conditions beyond API 6A and API 17D have not been released yet; however, test programs based on the API 17TR8 ‘HPHT Design Guideline for Subsea Equipment’ draft(s) have begun. Due to the expected loads and failure modes, API 17TR8 is based on use of

Oddbjørn Bjerkvik, Chief Engineer, FMC Technologies Riserless Lightweight Well Intervention (RLWI) is full year service in shallow water expected to be robust and delivered safely and efficiently. In deep water the service is almost non-existent. The presentation will give a brief description of the service provided, equipment used and how operations are run offshore today before addressing the biggest challenges with deepwater operations. This is challenges related to hydrate prevention while running wireline, storage of hydraulic energy in deepwater, transportation of fluid between the subsea stack and the vessel, riser back-up and handling of downlines (umbilical, wireline and ROV).

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18 June, 1345-1415 Track 3@Klokkeklang Autonomous Inspection Vehicle; A change in Conventional Thinking

Jim Jamieson, Technology Manager (Life-of-Field), Subsea 7 The introduction of new technology by Subsea 7 has led to the development of the AIV Mk1 system. A targeted program to deliver an enhanced service offering, a program that started in 2010 with a vision statement, “To deliver a robust, reliable commercially viable autonomous hovering vehicle to achieve a new method of subsea inspection”. The program builds on the experience of Subsea 7 with ROV systems and a decade of autonomous systems research and development. The Mk1 AIV represents the first milestone in Subsea 7’s autonomous vehicle roadmap where the meaning of the “I” will evolve from Inspection to Intervention. Through a commitment to enhancing performance and value to our customers, Subsea 7 has actively pushed forward the technology needed to deliver this autonomous vehicle.

ACADEMIA AND STUDENT PAPERS - TRACK 4@TROLDTOG 18 June, 1030-1100 Track 4@Troldtog SUBPRO: A new Norwegian research innovation center on subsea production and processing

Sigurd Skogestad, Professor, Norwegian University of Science and Technoliogy The objective of the SUBPRO center at NTNU is to become a leading international subsea research center that provides top quality candidates, knowledge, innovations and technology in partnership with the most important industrial players in the field. The center receives over an 8-year periode about 30 million NOK annually, of which the resarch council contributes 12 million NOK and the industrial partners the rest. Based on discussions with the industry, the SUBPRO project will therefore focus on two main areas: 1. Subsea systems engineering - Modelling and simulation of subsea components and systems - System design: Design for more available and robust subsea systems -Safety: Barrier philosophy for subsea facilities - Operation: Monitoring and prediction of equipment and system state - Control: Development of robust and selfoptimizing control strategies 2. Subsea separation - Fundamentals of heterogeneous systems - Solid/liquid separation -Liquid/liquid separation and water management - Gas-liquid separation - New process concepts The center will at any time have about 20 PhD candidates and 7 researchers (post. Docs included). 40 PhD degrees (in average 5 each year) are planned over the whole 8-year period. In addition, 50 master degrees are planned annually within the field. Expected areas of industrial application and commercialization are: • Improved design of subsea process/production equipment, primarily water separators. • New methods for optimal design of control systems optimal operation of subsea systems.

• Better systems engineering/design for development of subsea solutions for new oil and gas fields with respect to processing and production performance, reliability, maintainability, reduced investment and reduced operating costs. • Methods for assessment of mechanical condition and remaining useful life.

SIMPLIFICATION, STANDARDIZATION AND ENHANCED INDUSTRY COLLABORATION - TRACK 4@TROLDTOG

Contractors are encouraged to be innovative within their core business. The presentation will focus on the various cost elements in SURF field developments and how cost reductions can be achieved through Functional requirements versus detailed specifications. The cost of Subsea field developments have increased significantly in recent years and combined with falling oil prices this has led to an increased focus on how to reduce cost. This paper will focus on how this could be achieved through specifications of “Functional requirements” rather than standardisation only.

18 June, 1315-1345 Track 4@Troldtog Standardization of umbilical – is that possible?

Liv Molvik Lundegaard, Portefolio manager, North Sea projects, Nexans Norway AS In cooperation with Statoil, and during project execution of the first Statoil Standard Project 2013-2014, Nexans has developed a Standardized delivery of umbilical. Project execution, work procedures, documents, engineering, single elements and product are simplified and standardized. Nexans has a tradition to deliver technically challenging custom made products in complicated and engineering extensive projects. During the execution of these standard projects, the same organization and engineers had to change mindset; think simplification, cost saving and have a strong focus on future reuse of their work, documents or designed items. Standard design had to take into account also future use in coming projects, cost saving, increased predictability or flexibility for our customer. A pragmatic approach and open, good communication with Statoil and strict discipline on both sides made this possible. The experience from the project execution in five Statoil Standard project shows that standardization is absolutely possible, not 100 %, but to an extent that is a good start and beneficial for both parties. Further development of the standardized deliveries could be obtained by a more extensive cooperation across interfaces and between operators with regards to their technical requirements.

18 June, 1345-1415 Track 4@Troldtog Cost from where? – Functional requirements versus detailed specifications

Ole Petter Hjelmstad, Department Manager Engineering, Subsea 7 Opposite to the Drilling market, the traditional Subsea SURF market is mainly driven by a cost plus approach. I.e. when the technical solution is defined, the final cost only vary with the margin on top. A well-defined and standardised SURF field development guarantee a consistent bidding process, track record and cost, but not always the best technical and most cost effective solution since the competition is limited to the “top margin” only. By allowing Contractors to compete on their innovative technologies, specific asset base, competence, track record etc., Contractors have a wider arena to compete on. Simply allowing Contractors to compete on their full capabilities and not only what an Operator or Design house assume is the most favourable solution. This approach may lead to significant cost reductions in the short term and further cost reductions in the long term since

Business Region Bergen ©

The presentation will explain how RLWI can become an attractive service in deep water and status on the technological challenges listed above. Co-author: Andreas Mohr

BACKUP PRESENTATIONS FIELD DEVELOPMENT CONCEPTS AND EXPERIENCES Keld Lund Nielsen, R&D Project Manager Deepwater Engineering, ENI spa

Method for evaluation of technology impact on subsea system lifetime costs and risks.

Subsea systems engineering has come to a situation where costs, time and risks are of major concern. It is proposed to move beyond classical “document based engineering” and to assess a “model based engineering” approach. It is inspired by “Lean and Six-Sigma” methodologies. The “Lean” aspect concerns the overall systems view. It must enable global evaluation of several phases of the subsea plant life, such as: construction and installation, operation and maintenance, scenario analysis for resilience assessment etc. The “Six Sigma” aspect relates to risk and uncertainty. The idea has been adapted by deploying a Markov-ChainMonte-Carlo method (MCMC). It permits to assess operational scenarios of test cases. Our work demonstrates that economics and risks can be explicitly connected to the technical design. It has been obtained by a multi-physics approach. Mainly the Modelica modelling language is deployed. A case with a FPSO and 40 km tieback is proposed. Different designs are compared, e.g. one with active heating layout and one with hybrid loop design. The active heating approach is technically very innovative, i.e. risks and uncertainties are relatively high. Conversely, there are interesting features in terms of handling during shut-in cases. The hybrid loop is more conventional. The shut-in simulation shows longer time to recovery of production due to the replacement with diesel, i.e. system characteristics are radically different. The testcases are compared in terms of costs and risks.

IMPROVED ASSET VALUE AND SIGNIFICANT COST REDUCTIONS Knut A. Nilsen, Technical Advisor, Innova AS

Subsea Intervention and permanent technologies getting closer?

Brownfield rejuvenation, lifetime extension, increased recovery and the development of marginal fields results in increased demand for subsea instrumentation, processing, power conversion and communication. This leads to development of new subsea technology and the transfer of technology from surface to subsea. Examples of this are electro hydraulic power systems (subsea HPU systems) for local generation of hydraulic power and control functions; use of acoustic technology (sonars, hydrophones) and cameras e.g. for leak detection; and use of fibre optic communication technology. At the same time, these technologies have been applied subsea by the ROV/intervention industry for several years, but based on the ability to recover the equipment. Technology that is considered “new” for permanent applications, such as subsea HPU systems, is “old” (and field proven) in intervention applications. Development has been done largely by taking existing or new technology from other areas and applying this subsea. I.e the companies working with

intervention technology already have massive experience with the transfer of technology from surface to subsea. At the same time, increased demands for regularity and reliability means that requirements for “traditional” intervention technology is slowly merging with the requirements for permanent subsea equipment. Some ROV-equipment is undergoing the same qualification tests regime that is used for permanent equipment (e.g. to ISO 136286). These facts open up for a wider potential for using the experience and already existing technology from the intervention industry in the development of new technology for permanent applications.

SIMPLIFICATION, STANDARDIZATION AND ENHANCED INDUSTRY COLLABORATION Hans Christian Ly, Head of Materials Technology, Subsea, Aker Solutions

The “Good enough Philosophy” – material and manufacturing requirements at the right level for the subsea industry”

The requirements in the oil and gas industry need to be improved and aligned in several areas. The key to success is the communication between the parties involved, oil companies, equipment manufacturers, and the sub-suppliers performing the manufacturing. Most oil companies have a variety of requirements added to industrial standards, like the ISO 13628 series, ASTM, API, Norsok, etc. In order to standardize, the equipment manufacturers make specifications with a mix, covering requirements from all oil companies, resulting in longer lead time and increased cost. The current industry consensus is control, quality surveillance and assurance systems, with approvals of documents in ERP-systems as the key to success. Few have focus on the critical processes where the properties of our products are set, for instance during forging, heat treatment or welding. We have all learnt that good quality can never be inspected into a product already made. It seems that we have forgotten this lesson learned. In order to cut cost and lead times, we need to focus on how we can re-use manufacturing process specifications (MPS) and standardize qualifications for the whole industry. This will result in products with lower cost, precise quality and predictable delivery time. Improvement potentials can be found in all parts of the industry. In addition, the window of opportunity is here as everyone are looking for cost reductions.

TECHNOLOGICAL INNOVATIONS – CONTROL, POWER AND INSTRUMENTATION Mads Hjelmeland, Director, Emerging Technologies, OneSubsea Processing AS

Advances in Subsea Wet Gas Compression Technology A State of The Art Update Subsea boosting represents a technology domain which may contribute to simplifying and enabling challenging developments of

marginal, but also, remotely located oil & gas fields. The industry has over the past 20 years seen numerous subsea implementations of the multiphase technologies, in ever increasing water depths in the main deep water regions of the world, but also in more shallow water prone provinces such as the North Sea. The fact that the multiphase technology area has gained experience through successful operation over the past 20 years, coupled with the fact that natural gas has increased in value in many parts of the world, has driven the innovation to the next step; subsea compression. However, typically there are two different approaches to this challenge;  True Wet Gas Compression – subsea rotating machinery working directly on the unprocessed wellstream, or Subsea Gas Compression – marinized dry gas compressors with upstream wellstream processing and associated control systems. This technical presentation will describe the evolution of a MultiPhase Compressor, which is working directly on the unprocessed well stream. A description of how this technology can simplify complex offshore field developments will be given, as well as an overview of the operating characteristics and features of the compressor. Furthermore, specific challenges related to the application of subsea compression systems will be addressed, among other items the criticality of a robust and reliable total system, including subsea distribution of power & controls.

TECHNOLOGICAL INNOVATIONS – MATERIALS, MECHANICAL AND MARINE DISCIPLINES Jens Christoffer Werenskiold, Senior Engineer, FORCE Technology

Field Gradient Sensor (FiGS) – New Innovative CP Inspection Technology

In order to ensure technical integrity and safety on offshore assets, the Field Gradient Sensor FiGS is a solution that accurately measures the current state of anodes, pipelines and critical structures. Its sensitivity surpasses all other sensors available today, and allows you to make more qualified decisions regarding lifetime extension and anode consumption. The FiGS has already proven its success on a buried pipeline survey for one of the leading Oil companies on the Norwegian continental shelf, with a quality and accuracy of readings and results as never seen before. The survey resulted in substantial retrofit cost savings for the client. Among its capabilities, the sensor can be used to detect coating defects on pipelines that are exposed, buried and rock-dumped. Its ability to detect very small FG values (0,1µV/cm) means that even small coating defects can be detected and measured accurately. The FiGS has two sensing electrodes rotating around a common axis at 4Hz, measuring the relative field gradient in the seawater. Due to the physical shift between the two reference cells, the system is not influenced by cell drift, and filtration of noise fields from the ROV improved. The sensor measures both the strength and the direction of electric fields, enabling accurate calculation of anode and cathode current densities with pinpoint accuracy. Its efficacy and efficiency is beyond comparison, leaving you confident in the results provided to you, swift and effortlessly.

UTC PROGRAM COMMITTEE 2015 ROALD SIREVAAG (CHAIR) Chair UTC 2015 Program Committee/ VP Subsea Technology and Diving, Statoil Roald Sirevaag has 30 years’ experience from Norsk Hydro and Statoil. He entered the industry as a drilling engineer and moved to subsea with the TOGI project in the late 80’s. Within subsea he has held various project positions in early phase (Norne), execution (Kristin), operation (Sleipner) as well as line management and chief engineer positions. He has an MSc in Petroleum Production and a Diploma in Economics. He believes the effectiveness and efficiency of the subsea industry needs to be improved through enhanced connectivity and collaboration between the different disciplines (reservoir, drilling, subsea, process etc.) and the equipment and service industries. NILS ARNE SØLVIK Deputy Chair UTC 2015 Program Committee/ Vice President, Emerging Technologies, Processing Systems, OneSubsea Nils Arne graduated as a Master of Science in Electrical Power Engineering from the Norwegian Institute of Technology (NTH) in 1991. He started his career as a Consultant with Norwegian Contractors in the area of the large concrete platforms, such as Sleipner, Draugen, Troll A and Heidrun. In 1994 he joined ABB as a Technical Trainee and after several periods with different ABB companies he joined ABB Corporate Research and became involved in subsea processing and power distribution development programs. In 1997 he joined ABB Offshore Technology AS as Project Manager and later Department Manager before he went on to become Sales Manager, Subsea Processing for ABB Offshore Systems Inc. in Houston from 2001. In 2003 he joined Framo Engineering AS and now holds the position as Vice President, Emerging Technologies, Processing Systems, OneSubsea. PER CHRISTIAN ERIKSEN Vice President Technology Strategy, Aker Solutions Per Christian holds 12 years’ experience in the industry and has been part of Aker Solutions organization since 2002. He has been part of the full value chain in subsea ranging from studies, tenders, projects and services. More specifically he has been in Angola for the Dalia project, and further he built up the Global Lifecycle Services Support department as a support entity for the regional onshore and offshore operations. Currently he is heading the Technology Strategy in Aker Solutions’ Subsea area, setting the technology direction for the Aker Solutions subsea products in the years to come. Per Christian graduated as Master of Science in Petroleum Engineering from the Norwegian University of Science and Technology in 2002. MARTIN DOVE Project Director, BP Martin Dove holds the position of Project Director in the GOO Subsea Production team, and is based in BPs Sunbury offices. Martin has responsibility for ensuring that subsea operational experience input is provided to the BP projects organisation ‘GPO’, assuring subsea operational readiness and start-up efficiency on major subsea projects and facilitating the common process implementation for smaller subsea projects across the Regions. Martin joined BP in 1988, working most recently as the Subsea Production Operations Manager in Norway. Prior to this Martin has worked as the Subsea Team Leader for Greater Plutonio in Angola where he set up the subsea operations organisation and led the team through start-up into operations. Earlier in his career Martin has undertaken subsea and facilities roles in Azerbaijan, Aberdeen, Sullom Voe, Southern North Sea and Grangemouth. Martin has an M.Eng from London University in Mechanical and Electrical Engineering. TONJE DAHL Marketing & Communications Manager, ClampOn Tonje has been with ClampOn since 1997 and has been a vital part of the company’s marketing strategies and activities. She graduated from the University of Stavanger with a bachelor degree in business administration, with a specialization in export marketing. Tonje has been a volunteer on the Board of SPE Bergen Section for several years and has just concluded a two years position as Chairman of the section. Over the years, she has gained extensive knowledge of instrumentation, and subsea instrumentation in particular.

MARIE BUEIE HOLSTAD Department Manager Measurement Science, Christian Michelsen Research(CMR) Marie graduated as Dr. Scient in industrial instrumentation from the University of Bergen in 2004. She started working as a development phycisist for Tracerco, supplier of measurement systems and diagnostics services for subsea and topside offshore industries. Marie has been working for Christian Michelsen Research AS for the last 7 years, mainly focusing on measurement technology R&D for the oil and gas sector, including subsea measurement concepts and studies . Marie currently heads the CMR Measurement Science Department.

BÅRD ESPELID Head of Department, DNV GL Bård Espelid holds a M.Sc. in electrochemistry from the Norwegian Institute of Technology (NTNU). He has been working for DNV GL within materials technology and integrity management the last 32 years. Today he holds a position as business development leader within “Subsea and Wells”. In DNV GL he also execute the role as customer service manager for some prioritized customers. The last years Espelid has been especially involved in DNV GL services related to re-certification of well control equipment. Bård Espelid is an active member of different national and international corrosion societies. VIDAR HORNELAND Regional Engineering Manager, DOF Subsea Vidar holds a M.Sc. in Marine Technology from Universities of Glasgow and Strathclyde from 2002 and started his career as Technical Superintendent on offshore drilling rig prior to joining Stolt Offshore/Acergy in 2003. He has varied project engineering and offshore experience ranging from structure installation, IMR, flexible installations and diving operations from several projects in the North Sea and West Africa. More specifically, he has worked on Skirne Byggve, ERHA, Benguela Belize projects and several tie-back projects at Norne, Heidrun and Vigdis fields in addition to the Tordis IOR and Tyrihans projects. In 2009 he started in DOF Subsea as Engineering Manager and has been responsible for technical execution of several projects, tenders and FEED studies while building the engineering departments both in Bergen and in Aberdeen. Vidar is part of the Senior Management Team in DOF Subsea Atlantic Region.

MIKE STARKEY Subsea Engineering Advisor – Global Engineering, ExxonMobil Mike Starkey graduated from Strathclyde University, U.K. in 1984 with a BSc in Mining and Petroleum Engineering. He has worked for ExxonMobil for 30 years and has spent time in the Production, Development and Research Companies. He started working in the North Sea spending time as a Completions Engineer and in Operations prior to becoming a Subsea Engineer. During time in Houston and Stavanger he has worked on numerous subsea projects around the globe and at various phases from pre-FEED through execution. He is now based in the U.K. and provides Subsea Engineering support to the production units in W. Africa, Europe and N. America.

TOM EDDY JOHANSEN Senior Chief Engineer | Subsea System, FMC Technologies Tom Eddy has been working in the subsea business since he graduated in 1982 and with FMC technologies for more than 25 years. He is educated mechanical engineer and has a degree in marine/offshore engineering. Tom Eddy has worked in most of the product lines within the subsea business and in the last 15 years as engineering manager and chief engineer in several major international subsea development projects for various customers. His current position is senior chief engineer subsea systems for FMC Technologies eastern region.

HANS KRISTIAN SUNDT Product Manager Subsea Boosting & Compression, GE Oil & Gas Hans Kristian graduated from the Norwegian University of Science and Technology in 2000 with a Master of Science in Chemical Engineering. He has more than 10 years of experience within technology development and sales in the oil and gas industry. He started his career as a topside process engineer and has since followed new products from the initial idea, through the development and finally to the market. In 2008 he left dry land and joined the subsea community. Hans Kristian currently works with GE Oil & Gas as Product Manager for Subsea Processing.

COLIN JOHNSTON Director, SeaNation Colin Johnston has been working in the offshore industry for over 25 years. He started offshore in the North Sea and has spent the last 14 years in the Gulf of Mexico with Helix Energy Solutions Group. His area of specialization is subsea well operations covering completions, intervention and decommissioning as well as drilling and coiled tubing drilling technology applications. Colin is a regular contributor to industry forums on subsea well operations and sits on the board of the Underwater Technology Conference, Deepwater Intervention Forum and Society for Underwater Technology Houston branch. Colin has a Mining Engineering degree from University of Newcastle upon Tyne, a master’s degree in Subsea Engineering from Heriot Watt University, Edinburgh and an MBA in finance from the University of St Thomas, Houston.

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PER ARILD NESJE Business Area Director, Special Solutions, Kongsberg Oil & Gas Technologies Per Arild currently works as Director for the business area Special Solutions at Kongsberg Oil & Gas. He was one of the founders of Nemo Engineering AS back in 1989. The company changed name to Kongsberg Oil & Gas Technologies in 2013. He holds a B.Sc. degree in Mechanical Engineering from the University of Newcastle Upon Tyne, England from 1982. His entire career has been devoted to pipeline and subsea design, and development and delivery of subsea equipment and tooling for temporary and permanent use. Today his field of responsibility within Kongsberg Oil & Gas Technology cover business development and special responsibilities for repair tools and systems; modifications to subsea pipelines and structures; intervention and handling systems; and development of special products to cover challenges and requirements subsea in a new and/or improved manner.

TOM ERIKSEN Senior Subsea Innovator, NCE Subsea Tom Eriksen started his underwater career as combat swimmer in the Royal Norwegian Navy in 1969. Graduated as officer serving as diving instructor and Operational officer at the Navy’s Special Forces unit. He is an Engineer in Sub Sea Technology from Bergen University College in 1982. In 1987 he graduated as Business Candidate from Norwegian School of Management, BI, where he also qualified as Project Manager in 1996. 1991-1992 he served as UN-Observer, Middle East (UNTSO) and 1992 -1993 in former Yugoslavia (UNPROFOR). From 1999, he worked at Bennex Transmark AS as Manager Sub Sea Solutions, responsible for selling ROV systems and related equipment. When Siemens AS acquired Bennex AS he led the internal NITO group, managing the employed engineer’s rights in the takeover. From February 2013, he has been working for NCE Subsea as Senior Subsea Innovator.

VIDAR FONDEVIK Senior Advisor, NUI Vidar Fondevik holds a M.Sc. in Underwater Technology and Subsea Engineering from Heriot-Watt University. He has bachelor degrees in Naval Architecture and Business Economics. His underwater career started in 1969 as combat diver in the Navy. Then he served as diving surveyor for DNV in the Oil and Gas industry. He was involved in early experimental diving at NUTEC and in the development of submarine manipulators and tools. He became pilot and manager for the acrylic submarine ‘Check Mate’- now displayed at NOM. Since then he had different jobs, including seven years as a General Manager. He is a Board Member both in UTF and in SUT Norwegian branch. He was Board Member in NUI AS until the change of ownership in January 2014.

RUNE HØYVIK ROSNES Program Development Manager, Oceaneering Rune started his career in the Oil & Gas Business working for the NCA Group where he held the position as Sales & Business Development Manager Eastern Hemisphere for many Years. Followed by the Oceaneering acquisition of NCA in 2011, he has been involved in crossdepartment technology development ranging from Subsea All Electric Hardware to Space Systems. Constantly paving the way for disruptive innovation in various industries has led him to work with innovative partners such as ESA, NASA, Exxon Mobil, Shell, Statoil, GE, UiS, NTNU and others. A member of the board in the Space & Energy Technology Network and Forening for Fjernstyrt Undervannsteknologi (FFU), in addition to taking an active role in educational initiatives such as UiS Subsea, MATE, First Lego League and academic partnerships. Studied Mechanical Engineering at the University of Stavanger and holds a certificate in Metier Project Management from SKEMA Business School in France.

JOHAN KR. MIKKELSEN Chief Technology Officer, Perestroika AS Johan Kr Mikkelsen has 40 years experience from Norsk Hydro and Statoil. He entered the oil and gas industry at the Mongstad refinery in 1974 as process engineer and a couple of years later as Production Manager at the refinery. In 1983 he moved on as Production Director for Oseberg field and in 1992 as SVP for Norsk Hydro drilling. In 2000 he continued as SVP for Oseberg asset and in 2003 as SVP for the Troll asset. In 2005 he became Country manager for Norsk Hydro Canada before he moved on as Peregrino Project Director and later Production Director for the field in Brasil. In 2012 he returned to Norway as VP for the Statoil Subsea Improvement Project until early 2014 when he retired from Statoil. At present he is the Chief Technology Officer with Perestroika AS. He holds a Master degree from NTH from 1973 in Industrial Chemistry and a Master degree in Chemical Engeneering from University of Wisconsin, USA in 1979.

TORKILD REINERTSEN Ph.D, Managing Director, Reinertsen AS Responsible for the oil&gas activity in the family owned company, REINERTSEN AS for more than 30 years. Reinertsen is an Engineering and EPC contractor working within Subsea and Process Facilities.

TOROLF F. HÆHRE Subsea Team Lead, Shell Technology Norway Torolf graduated as a Master of Science in Civil & Structural Engineering (1974) from the Norwegian University of Science and Technology (NTNU). He has extensive experience in offshore and subsea field developments since 1980. He joined Shell in 1989 and was leading the Draugen Subsea Facilities EPC contract from 1990 – 94.Therafter he worked as Operations Manager in Rockwater before he again joined Shell in 1996 as the Shell representative on the Technology Agreement between Kongsberg Offshore (now FMC), Statoil, Elf, Mobil and Shell. During 1998-2001 he was responsible for the deepwater manifold and tie-in systems on the Shell Philippines Malampaya development and he was working on the Sakhalin II development project from 2001-2003. Since 2003 he has been working with Shell Technology Norway.

HENRIK MELAND MADSEN Vice President & Head of Subsea Systems, Siemens H. M. Madsen has been part of the Siemens Subsea organisation since 2010, and has held various positions in sales and marketing and is now holding the position as head of Subsea System. This organisation is responsible, amongst others, for the development of the Siemens Subsea Power Grid. H. M. Madsen has more than 10 years of experience in the subsea industry and prior to working for Siemens he held various positions with Framo Engineering AS, a renown supplier of subsea boosting systems. In this company H. M. Madsen worked with subsea installations, system integration tests for various projects, was responsible for development and deliveries of subsea control systems prior to working in sales and marketing. H. M. Madsen holds a degree of SivilingeniĂ¸r (Master of Science) from NTNU the Norwegian University of Science and Technology in Marine Engineering. As part of this study, one of the years was spent at ESIM in France. TERJE CLAUSEN Business Development Director, Subsea 7 Terje holds a MSc in Marine Technology from the Norwegian Institute of Technology (NTNU), specializing in Marine Hydrodynamics and Marine Operations. He has over 20 years experience within the offshore industry, within marine operations, pipelines, mooring, deepwater risers systems and field development. The last 10 years he has held several management roles in Subsea 7 within Technology & Business Development. He was previously employed by Aker, DNV, Global Maritime and Brown & Root. TIM CROME Director Sales & Business Development, Technip Tim Crome has worked in the offshore pipeline / subsea industry since graduation from Imperial College, London, in 1980. For the last 30 years his work and home has been in Norway. He joined Technip in 1997, was Engineering Manager for the Oslo office from 2001 until 2007 and is now Director for Sales and Business Development for Technip in Norway. Prior to joining Technip he worked for JPKenny, DNV and Norsk Hydro.

PER ARNE NILSEN Head of Subsea Department, Total S.A France Per Arne has for many years held Senior Management positions internationally (Norway, US, Canada, UK, Singapore, Australia, France). He has been employed by several Oil & Gas operators globally, with roles spanning from asset management, via project management and delivery management to R&D/Technology management. Specialties: International negotiations, project execution management, change management, professional leader with multicultural skills and experience. Professional in Subsea technologies.

SONIA FAALAND board member UTF/ Head of R&D , CMR Prototech Sonia Faaland is member of the UTF board and Head of R&D in CMR Prototech. Sonia has been involved in projects related to fuel cells, energy conversion, energy optimization and space research for the Oil & Gas, Maritime, Green Energy and Space industries. Main focus now is establishment of a project related to subsea power using fuel cells. During her five years as senior engineer for Det Norske Veritas she worked with testing and failure analysis of offshore and subsea components. In addition to UTF, Sonia is a member of the board of Maritime CleanTech which recently was given the status as Norwegian Center of Expertice (NCE). RICK KOPPS Subsea Specialist, Chevron

Visit us at UTC 2015 Booth #2

Siemens Subsea Enabling large-scale subsea processing by connecting innovation with experience

The future of oil and gas recovery involves accessing increasingly complex reserves. Operators are moving into deep and ultra-deep waters, expanding their oil and gas production into remote regions.

Siemens is helping to make these field developments technologically and economically possible with an extensive portfolio of subsea products and systems, as well as with exemplary service and support.

www.siemens.com/energy/subsea

BERGEN AREA ORGANISING PARTNERS FOR UTC 2015

SUBSEA SOLUTIONS MADE IN NORWAY

NCE Subsea is an initiative by the subsea industry for the strengthening and internationalization of business, R&D and education. We bring together and promote the Norwegian subsea industry, which constitutes a world leading environment for subsea solutions. Organizations established in Norway that provide products or services in or to the subsea industry, or aim to do so, can be a member in NCE Subsea. Partnership is awarded R&D and educational institutions, authorities and companies considered particularly important for the development of the subsea industry. NCE Subsea contributes to research, innovation, competence building and international business development. Our focus is on stimulating increased collaboration and experience sharing between our partners and members and with national and international collaborators. We initiate and organise joint industry projects for our partners and members, as well as with other national and international actors. One of our objectives is to strengthen the Norwegian supply chain for subsea solutions through close collaboration between companies and R&D institutions.

SUBSEA INDEX We own and operate Subsea Index, a bi-lingual matchmaking tool in English and Portuguese. The intent of the database is to create business opportunities by providing accessible and searchable high quality, business relevant data about companies and organizations related to the subsea industry. Subsea Index is open for registration of all companies and organizations delivering products and services in the world wide subsea industry. Use the database to find your partner in business, R&D, education and training WWW.SUBSEAINDEX.NO. NORWEGIAN CENTRE OF EXPERTISE NCE Subsea is one of twelve national centres of expertise. The Norwegian subsea industryâ&#x20AC;&#x2122;s world leading position and the established interaction between industry actors formed the basis for the Norwegian governmentâ&#x20AC;&#x2122;s appointing of a Norwegian Centre of Expertise (NCE) for subsea technology in 2006. NCE is a national program supported by Innovation Norway, the Industrial Development Corporation of Norway and the Research Council of Norway. WWW.NCESUBSEA.NO

Society for Underwater Technology SUT is a worldwide, multi-disciplinary, learned society that brings together organisations and individuals with a common interest in underwater technology, ocean science and offshore engineering. SUT was founded in 1966 and has members from more than 40 countries, including engineers, scientists, other professionals and students working in these areas. The organisation has comprehensive expertise within its area of activity, whereby it influences the development of new techniques to further explore and exploit the world’s oceanic resources, such as through annual prize-giving ceremonies. Today the association is established in London with branches in Bergen, Aberdeen, Houston, Rio de Janeiro, Perth, Melbourne, Kuala Lumpur and Lagos, where they carry out learned courses and programmes for members and others who are interested in subsea technology and their wide range of other ocean-related activities. The latest branch, SUT Norway (Bergen) was established in 2009. SUT Norway is a non-profit organisation, to be developed through networking and interaction between individuals and companies working professionally with underwater technology. Its objective is to facilitate the exchange of knowledge and information, e.g. by arranging courses and seminars with agendas relevant to subsea activities. WWW.SUT.ORG.UK

SPE Bergen Society of Petroleum Engineers (SPE) is a professional association whose 100,000-plus members worldwide are engaged in energy resources development and production. Local sections of the SPE are established around E&P communities all over the world. SPE Bergen Section is one of five sections in Norway. We host a variety of activities and events, focusing on networking and knowledge. SPE Bergen hosts regular member meetings, the annual SPE Sailing with the Statsraad Lehmkuhl in late spring, SPE Bergen Lutefisk in early winter and the SPE Bergen YP.lnk hosted by our YP program. Our largest event during the year is the annual SPE Bergen One Day Seminar in April. This international E&P conference and exhibition attracts some 500 participants and approximately 45 exhibiting E&P companies. SPE recognizes the importance of those who one day will be leaders of the E&P industry. Along with many SPE sections, the SPE Bergen Section has developed a Young Professionals (YP) programme, to support and assist those in the industry with fewer than ten years of experience. SPE also offers student memberships. The SPE Bergen Student Chapter counts several hundred members and is the most important link between students and the petroleum industry in the Bergen area. The SPE Bergen Section is proud to support and sponsor one of the world’s largest and most vibrant SPE student chapters. The chapter hosts its own events, and students also participate on regular section events. BERGEN.SPE.NO

GO DEEPER AIM HIGHER Refuse to let higher pressures, temperatures and corrosion block your deepest ambitions. Stop by Booth 41 and find out how we help you get there.

SMT.SANDVIK.COM/OILGAS

UTC 2015 EXHIBITORS 35

34 46 33

47 49

48 50

32 3 31 4

Reserved

Vacant

Stand # 3 1 Stand # 4 22

One Subsea

Exhibitors

12 18

13 15

Statoil

Cathx Ocean

SubSea 7

ClampOn

DeepOcean

EAB Engineering

FMC Technologies

PG Pump Solutions

Force Technology

Phaze Technologies

Freudenberg Oil & Gas Technologies

Plexx

PLM Technology

Quest Offshore

Roxar Flow Measurements

Sponsor Partners Aker Solutions DNV GL

GE Oil & Gas

Oceaneering

41 2

Hydro Group

Sandvik Materials Technology

IK Stavanger

Siemens

Innospections

Innova

Media Partners

Offshore Engineer

Kongsberg Oil & Gas

Teknisk Ukeblad

MacArtney Underwater Technology

Organising Partners

MacDermid Offshore Solutions

Mechman

Stand #

Exhibitors

ScanSense

SEACON (europe) Ltd

Sense Offshore

Sim Evolution

Subsea Design

Summit Systems

Svafas

MRC SolbergÂ & Andersen

Techni

Namtvedt Sealmaker Services

Technip

Exhibitors

National Instruments

Tracerco

ABB

Nexans

Transvac

Advantec

NLI Subsea

Trelleborg

Benestad

Norway2UK

Water Linked

Blue Logic

Offshore Media Group

Xvision

Castrol Offshore

Olvondo Industries

Zetechtics

Stand # 14

NCE Subsea

SPE

SUT

Stand #

Main Sponsors

DOF Subsea

Stand #

EXHIBITION OPEN TO THE PUBLIC

With 60 companies the UTC Exhibition will be a vibrant and important arena for subsea updates and information. At UTC you will meet executives, managers, engineers and other strategic and planning personnel related to the subsea field of the petroleum industry. Students are also especially invited to the UTC exhibition. The exhibition hall will accommodate lunches and refreshments buffets. The exhibition will be open for other professionals, not participating at the conference, at these hours: Wednesday 17 June: Thursday 18 June:

10:30 â&#x20AC;&#x201C; 16:00 09:00 â&#x20AC;&#x201C; 14:30

Guests have to register at the entrance, no entrance fee will apply. Guests will be given the opportunity to buy lunch tickets at registration. We encourage all exhibitors to invite their business partners to visit the UTC Exhibition.

ACHIEVING THE POTENTIAL OF THE SUBSEA SECTOR From the drawing board to decommissioning, DNV GL supports operators, suppliers, governments and industry associations in solving complex subsea challenges through tailored solutions and global best practice. Driven by a curiosity for technical progress, our worldwide network of experts provides independent advice and a neutral ground for collaboration, enabling customers to implement technology safely and efficiently. For more information on how we help the subsea sector achieve its potential through our services, standards and recommended practices, visit: dnvgl.com/oilgas

SAFER, SMARTER, GREENER

FIELD TRIPS - 16 JUNE True to tradition, UTC invites delegates to site visits in the Bergen region. This year we offer three trips with different focus and agenda. We hope you will use this opportunity to get demonstrations, see the technology, learn more about the products or discuss how our business could benefit from increased industry- university collaboration.

TRIP 1: WORKSHOP AT MRC SOLBERG & ANDERSEN IN ÅSANE Bergen University College and UPTIME Centre of Competence present

THUNDER FROM DOWN UNDER! - a workshop aiming at increased industry-university collaboration The cooperation between industry and R&D environments in Australia has been successful. The Australians have established a best practice for utilizing the competence and possibilities available in the R&D sector demonstrating that it is possible for high cost countries to be competitive in the world market. In this workshop we challenge Norwegian R&D institutions and industry to share their experiences and identify opportunities. Professor Brian Evans challenges us with his experience and perspectives from Australia. - Scientists need to understand industrial problems and define projects addressing these. On the other hand the industry needs to see the competence and possibilities available in the R&D sector. This is one important foundation for business development: New solutions and methods can be developed and enable more optimal operations and maintenance, says Prof. Geir Anton Johansen, Dean, Faculty of Engineering and Business Administration, Bergen University College, and Knut Vindenes, CEO at UPTIME Centre of Competence. PRELIMINARY PROGRAM Experiences from the Australian oil and gas sector, Prof. Brian Evans, Head Dept of Petroleum Engineering, Curtin University, Australia The key to innovation: Crossovers, relatedness and undiscovered opportunities, Prof. Stig-Erik Jakobsen, Head of Innovation Center, Bergen University College The Global Subsea University Alliance - Prof. Geir Anton Johansen, Dean, Faculty of Engineering and Business Administration, Bergen University College Bringing two cultures together to innovate - not just talk, Knut Vindenes, CEO at UPTIME Centre of Competence Taking technology forwards - with expectations to the university, interviews with the companies Goodtech and MRC Solberg & Andersen Product demos from Goodtech and MRC Solberg & Andersen The workshop is hosted by the company MRC Solberg & Andersen at their location in Åsane in Bergen. Technology samples from both MRC Solberg & Andersen and Goodtech will be demonstrated at the workshop. Please join us for an interesting and nice June afternoon at MRC Solberg & Andersen - warming up for the UTC Conference. WHEN: June 16th 13:30 – 17:00 MEETING POINT: Grieghallen square, outside the Peer Gynt entrance. Look for the MRC Solberg & Andersen sign for registration.

TRIP 2: NUI AT LAKSEVĂ&#x2026;G

NUI SUBSEA TEST AND HYPERBARIC RECEPTION FACILITY WELCOMES UTC 2015 PARTICIPANTS TO A FIELDTRIP TO NUI PREMISES. The fieldtrip will give you an introduction to the NUI Subsea Test and Hyperbaric Reception Facility test areas and resources, including the indoor test pool and NUI chamber complex . It will also be possible to visit and conduct a test dive in our chamber system. Since 1976, we have delivered competence and subsea services to the oil and gas industry. With our expertise and unique facility, we are a solid partner for both national and international subsea operations and subsea testing. For further info please visit www.nui.no

WHEN: June 16th 13:30 - 17:00 MEETING POINT: Grieghallen square, outside the Peer Gynt entrance. Look for the NUI sign for registration.

TRIP 3: ONESUBSEA AT HORSØY

ONESUBSEA TESTING FACILITY AT HORSØY You are invited to visit OneSubsea’s assembly and test facility at Horsøy. This state of the art facility, which was opened in 2012, allows OneSubsea to perform testing of Pump Systems, Swivel Systems and Multiphase Metering Systems to ensure efficient field installation and safe operation. This tour gives you the opportunity to see Subsea Processing equipment such as Booster Pumps, the Multiphase Compressor and Station for Gullfaks, assembly line for Multiphase flowmeters and the SIT test facility including the test pit. WHEN: 16th June 13:30 – 17:00 MEETING POINT: Grieghallen square, outside the Peer Gynt entrance. Look for the OneSubsea sign for registration.

NEW LOCATION BY THE SEA!

ICEBREAKER AT USF VERFTET - 16 JUNE

Join us for an informal networking event at Bergens unique culture arena by the sea, USF Verftet. Meet fellow delegates, exhibitors and speakers, while enjoying tasty tapas and drinks at Bergens largest terrace. The focus this evening is to network in relaxed surroundings before the conference proceedings start Wednesday morning. The United Sardine Factory (USF) is located at the Georgernes Verft in Bergen. This old factory was once the largest cannery in Norway. Now, USF is a multiple cultural arena, unique in size and variety. This is the home for arts and culture productions in its various forms and genres. DRESS CODE: Smart casual VENUE: Georgernes Verft 12 (see map at page 49) WHEN: 16 June, 19:00 – 22:30 Please pick up your accreditation inside upon arrival, you need this to access the premises and the bars.

FIND YOUR WAY TO USF VERFTET

GUIDED TOUR: Join the guided tour through this scenic part of Bergen – with small wooden houses and narrow streets. The guide and local historian Mr. Mons Kvamme, who lives in the area, will walk you through the narrow streets and share a few local stories on the way. START: Radisson BLU Hotel Norge, hotel lobby at 18:00 END: USF Verftet, UTC Icebreaker event UTC is a full-service conference. This means that all meals and drinks during the conference are included in the conference fee. PLEASE SIGN UP FOR THE ICEBREAKER WHEN YOU REGISTER FOR THE CONFERENCE.

Main sponsors:

USF Verftet is located by the sea only a quick kilometer from the city center/Radisson BLU Hotel Norge. It will only take about 15 minutes by foot, - that is, if you do not get stuck taking photos of the picturesque wooden houses and narrow streets on the way. You can of course take a taxi, but then you are likely to miss out the narrow charming streets.

Premium Media sponsor:

RECEPTION AND BANQUET - 17 JUNE

CITY OF BERGEN RECEPTION - 17 JUNE OFFICIAL RECEPTION HOSTED BY THE CITY OF BERGEN - IN THE EXHIBITION HALL The City of Bergen invites the UTC delegates to hors d’oeuvres and drinks in the Exhibition Hall prior to the banquet dinner. Entertainment and award ceremony. DRESS CODE: Business VENUE: Exhibition hall (Dovregubben), Grieghallen WHEN: Wednesday 17 June, 18:00 – 19:30 PLEASE SIGN UP FOR THE BERGEN CITY RECEPTION WHEN YOU REGISTER FOR THE CONFERENCE.

BANQUET DINNER - 17 JUNE As the perfect ending to the first day of the conference, you areBergen invited to a banquet tekniske fagskole dinner in “Spissen”, the grand foyer in Grieghallen. You will experience great entertainment and a three course meal. After dinner we will move back to the exhibition hall for an after party with avec and drinks. The evening will provide an excellent setting for discussions and networking for both delegates and speakers. DRESS CODE: Business VENUE: Foyer Spissen, Grieghallen WHEN: 17 June, 19:30 – 01:00

PLEASE SIGN UP FOR THE BANQUET WHEN YOU REGISTER FOR THE CONFERENCE.

Øygarden kommune

MAP OF BERGEN CITY

LOCATIONS AND RECOMMENDED HOTELS 1

USF Verftet – Icebreaker

Radisson Blu Hotel Norge

Grieghallen – Conference venue

Scandic Bergen City

Scandic Ørnen Hotel

Walking route from Radisson Blu Hotel Norge to USF Verftet

Photo: Ole Jørgen Bratland

Great innovations

come from great challenges

Statoil is an international energy company with operations in more than 30 countries. Our focus is to accommodate the world’s energy needs in a responsible and sustainable way. It’s not an easy task, but nothing gets our engineers going like a challenge. After all, the greatest innovations are often spurred by the greatest challenges. It’s what inspires us to keep pushing boundaries and finding better solutions. No challenge, no change. Learn more at statoil.com Statoil. The Power of Possible

REGISTRATION AND HOTEL RESERVATIONS

DATES 16 June: Field trips and Icebreaker 17 June: Conference and Exhibition, Official Reception, Banquet Dinner 18 June: Conference and Exhibition CONFERENCE FEE NOK 9.750 ($1.170 - March 2015) + 25% VAT INCLUDED IN THE CONFERENCE FEE: UTC is a full-service conference. This means that all meals and drinks during the conference are included in the conference fee. • Participation at the conference both days • Access to download the conference presentations after the conference • Lunches and all day refreshments • Field trip • Icebreaker event at USF Verftet • City of Bergen Reception in the Exhibition Hall • Conference Banquet (Specified registration is required for attendance at the social events) Please register before 1 June 2015 PAYMENT We accept Amex, Diners, MasterCard and Visa. You will receive a detailed receipt as soon as your credit card has been charged. Payment by invoice: Many companies require a purchase order and a specified invoice address to receive an invoice. If this is applicable for your company, please contact the organizer by e-mail. You will receive an “Invoice reference code” needed for your registration. Contact information technical organiser: lene.vikre@possibility.no/ +47 916 94 214 25% VAT will be added to the invoice in accordance with Norwegian tax regulations.

ACCOMMODATION To ensure accommodation for our delegates and speakers we have pre-ordered a large number of rooms at hotels in walking distance from the conference venue. Please make hotel reservations when you register for the conference. After 10 May we cannot guarantee the availability of rooms. All prices are per room per night incl. breakfast and VAT. Please settle your bill on departure Radisson Blu Hotel Norge NOK 1945,- (Available 15 – 19 June) Scandic Bergen City NOK 1550,- (Available 15 – 19 June) Rica Ørnen Hotel NOK 1995.- (Available 15 – 19 June. only 60 meters from conference venue)

REGISTRATION AT WWW.UTC.NO YOUR CONFERENCE BADGE You can pick up you conference badge at these hours: Tuesday 17 June: 17:00 - 19:00 Wednesday 18 June: 08:30 - 09:30 Location: Entrance Peer Gynt, Grieghallen Late arrivals: All day Wednesday and Thursday at the conference information desk at the entrance Peer Gynt. CANCELLATIONS Registration is binding. Cancellations must be received in writing by 15 May 2015, and will be subject to a cancellation fee of NOK 1000,- ex vat, unless a substitute delegate is offered. After this date, a full registration fee will apply; however, substitutions will be accepted. Substitution for registered delegates may be made at any time prior to the conference, but we would appreciate prior notification. All cancellations and substitutions must be in writing. AIRPORT AND TRANSPORTATION Bergen Airport Flesland There will be buses to the airport after the conference 18 June, free of charge to conference delegates.

CONTACT PERSONS: TECHNICAL ORGANISER Possibility AS Kanalveien 11 NO-5068 Bergen Norway

REGISTRATION, HOTEL RESERVATIONS AND ACCOUNTING: Lene Vikre, Registration and Accounting Manager E-mail: lene.vikre@possibility.no Phone: +47 916 94 214

E-mail: utc@possibility.no

UTC EXHIBITION: Ståle Eiken, Exhibition Manager E-mail: stale.eiken@possibility.no Phone: +47 928 05 779

MEDIA: Irmelin Grønevik, Project Manager UTC E-mail: utc@possibility.no/ irmelin.gronevik@possibility.no Phone: +47 922 37 093

Return address: Possibility AS Kanalveien 11, 5068 Bergen Norway

Main Sponsor

Premium Media Partner

Media Partner

Sponsor Partner

Organising Partners:

UTF THANKS ALL PARTNERS FOR THEIR SUPPORT IN 2015! The Underwater Technology Foundation (UTF) is a non-commercial entity established in 1980 when several large oil-related companies joined forces to arrange the Underwater Technology Conference in Bergen. The foundationâ&#x20AC;&#x2122;s goal is to promote increased knowledge of the subsea sector. This is achieved by hosting the conference and giving contributions to research and training at university level. UTF offers a grant available to applicants in need of financial support for a subsea related research or training project. The foundation would like to see more applicants for the grant, and encourages anyone with a relevant project to apply.