Bergen, Norway 12 – 14 June, 2018

June 13

Change day
  • 08:30 - 09:30

    Badge pick-up and coffee

  • 09:30 - 09:40

    Welcome

    UTC Program Committee Chairman Jon Arve Sværen, Head of Business Strategy, ONESUBSEA and UTC Conference Moderators Wendy Lam, Business Development Subsea Product Systems, BHGE and Kristin N. Berg, Head of Section, DNV GL

  • 09:40 - 10:00

    Opening speech

    Karl Johnny Hersvik, Chief Excecutive Officer, AKER BP

  • 10:00 - 10:20

    Tech vision and international markets - from a subsea perspective

    Bjørn Kåre Viken, VP of Projects and Technology Collaboration,

    EQUINOR

  • 10:20 – 10:40

    New Ways of Cooperating

    Erik Sverre Jensen, Chief Operational Officer, LUNDIN PETROLEUM NORWAY

  • 10:40 – 11:00

    Hugo Dijkgraaf, Managing Director, WINTERSHALL

  • 11:00 – 11:45

    Coffee and exhibition

  • 11:45 - 13:00

    Panel debate: Subsea - Unlocking the potential!

    Introduction by UTC Conference Moderators Wendy Lam, Head of Market Development Subsea Production Systems, BHGE and Kristin N. Berg, DNV GL

    John Macleod, Chief Technological Officer, AKER SOLUTIONS
    Ben Charbit, VP Technology and Marketing, ONESUBSEA
    Brian G. Taylor, Technical Manager Well Control, TECHNIPFMC
    John Kerr, Chief Technological Officer, BHGE

  • 13:00 - 14:30

    Lunch and exhibition

  • Track 1 @ Peer gynt

    FIELD DEVELOPMENTS / SYSTEMS SOLUTION

    Track 1 @Peer Gynt

    Track 2 @ Klokkeklang

    SURF, SPS AND MARINE OPERATIONS

    Track 2 @Klokkeklang

    Track 3 @ Troldtog

    ASSET MANAGEMENT/INCREASED RECOVERY/LIFE-OF-FIELD SOLUTIONS

    Track 3 @Troldtog

  • 14:30 - 15:00

    14:30 - 15:00, Track 1 @ Peer gynt

    Johan Castberg - the cost reduction journey

    Benedicte Nordang, EQUINOR

    Johan Castberg - the cost reduction journey

    The Johan Castberg project delivered the plan for development and operation on December 5th, 2017 and is now in the execution phase. This presentation will give highlights from the development that resulted in the remarkable turnaround from a concept with a break-even of more than 80 USD/bbl to below 35 USD/bbl.A key concept has been design-to-cost where solutions have been ranked in steps from a minimum solution to a maximum solution. Each increment is required to add value to the project at a low break even. Close collaboration between Petec, Drilling&Wells and Subsea has reduced the required number of wells, templates and total pipeline and cable lengths. Tough KPIs on the subsea cost of each well (Perfect project) has been broken down to cost of the components. The vendors have been challenged with these targets and they have in turn been allowed to challenge all requirements, showing the potential savings. The feasible savings have been identified in close cooperation between contractors and Equinor. New methods and technologies have been utilized. A rigorous method for risk-based flowline protection has been applied to minimize the required rock-installation. New technology, DC/FO, has enabled a robust and simplified umbilical system while providing a significant capacity for future expansion and enabling future technologies. In addition, several new technology elements such as new wellhead design, 7” VXT, hybrid UTH and more have been applied.

    14:30 - 15:00, Track 2 @ Klokkeklang

    First use of new technology enables development of field in Norwegian Sea

    Arne Skeie, SUBSEA 7

    First use of new technology enables development of field in Norwegian Sea

    The Ærfugl field is a gas condensate field located in the Norwegian Sea to the West of Skarv and Idun fields. Heat input into the flow line system will be required during both plateau and off-plateau production periods. The enabling technology Electrically Heat Traced Flowline (EHTF) will be utilized to enable system start-up and shut down, and to maintain the production fluids outside of the hydrate envelope during steady state operation. The Ærfugl EHTF consists of a 10” flowline inside a 16” carrier pipe (Pipe In Pipe). The large annulus between the 10” and the 16” allows for good insulation, and combined with reduced annulus pressure, a U-value of less than 0.5 W/m²/K is achieved. Such a low U-value allows for a quite passive system, requiring limited power from the heating system. The Ærfugl EHTF system is based on a topside transformer which transforms 11 KV to 1.1 KV. The power cables goes directly from the bus bar to the In-Line Power Inlet Structure (ILPIS) on the Electrically Heat Traced Flowline (EHTF) via a continuous dynamic and static power umbilical. There is as such not any sophisticated components subsea to transform or split the current. All components that may need maintenance and repair are located topside.

    14:30 - 15:00, Track 3 @ Troldtog

    New concept for long distance subsea tie-back

    Karl Jørgen Kristiansen, EQUINOR

    New concept for long distance subsea tie-back

    One conventional development of green field off-shore oil is by using local fixed platforms or floaters/FPSOs, oil processing and off-shore loading. These are costly and complex facilities to be installed and manned by expensive logistics with inherent safety challenges. In very remote areas, and/or hostile climatic/weather environments, local surface processing may not be considered acceptable on a range of parameters.In more developed, mature areas, subsea tie-back solutions to existing processing facilities are usually applied. The maximum tie-back distance to existing infra-structure is often limited by conventional concepts struggling with range limitation, and expensive complex solutions for pipeline heating, to provide acceptable flow assurance. The Thermoil™ concept aims to provide for full subsea development, of oil dominated fields, and facilitate long distance tie-back to a central processing facility or to an onshore oil terminal. It consists of ultra-long insulated pipe-in-pipe flow segments with subsea pumping and heating facilities which can expand into a flexible infrastructure serving multiple fields simultaneously or in sequence.

  • 15:00 - 15:30

    15:00 - 15:30, Track 1 @ Peer gynt

    The world's deepest subsea boosting system: Stones, a global delivery model.

    Riad Wardani, SHELL

    The world's deepest subsea boosting system: Stones, a global delivery model.

    In a global market defined by lower oil prices and fewer, farther discoveries, it is crucial to adapt innovative field development solutions delivered through efficient, collaborative and integrated project execution models. Shell were early to react to the changing conditions and evaluated alternative project delivery models for the Stones field development offshore GoM. The field, solely owned and operated by Shell, is located 320km Southwest New Orleans and is one of the most challenging high pressure / temperature subsea developments undertaken to date. Achieving first oil in September 2016, it is the world’s deepest subsea development at a water depth of over 2900m and Shell’s first FPSO in the GoM. In response to the challenging field conditions, many industry firsts were successfully implemented including the world’s deepest, highest pressure and temperature mudline boosting system. After early engagements on the technology maturation and qualification front with an integrated Shell and OneSubsea team, it was selected to build on the relationships, learnings and experience gained on the Draugen subsea boosting delivery. An execution model based on local presence with integrated focus lead to Shell in Norway taking a leading role in the delivery of the subsea boosting system for the GoM. Relying largely on the same delivery teams as for Draugen, both within OneSubsea and Shell, a standardized, more streamlined and integrated delivery model resulted in efficient project execution. With a target loadout date in February, this presentation aims to share some of the learnings from the Stones subsea boosting system delivery.

    15:00 - 15:30, Track 2 @ Klokkeklang

    Installation of the world's first subsea Thermoplastic Composite Flowline for Hydrocarbon Service

    Jan Van Der Graaf, AIRBORNE OIL AND GAS

    Installation of the world's first subsea Thermoplastic Composite Flowline for Hydrocarbon Service

    Thermoplastic Composite Pipes (TCP) are successfully applied in Subsea conditions in the past few years. Firstly for Water injection and MEG injection applications. The next step is the use of TCP for Hydrocarbon flowlines and risers.This presentation will discuss the installation of the world’s first subsea Thermoplastic Composite Flowline for hydrocarbon service that provides a solution for today’s challenges in two vital ways: Thermoplastic Composite Pipe (TCP) ensures the lowest total installed cost and ensures the lowest operational cost as it does not corrode. The installation took place at the end of 2017 off the coast of Sarawak, Malysia in 50 m of Waterdepth.The TCP flowline is connected to a TCP riser retrofitted to an existing Wellhead Jacket.The installation required the simultaneous handling of the riser and flowline part.The installation was successfully executed in december 2017.The flowline is currently producing oil through this 6″ ID riser and flowline system.

    15:00 - 15:30, Track 3 @ Troldtog

    Deep Water Boosting Design in an Operational Perspective

    Gandi Rahmawan Setyadi, TECHNIPFMC

    Deep Water Boosting Design in an Operational Perspective

    Deep water oil developments often require the use of artificial lift. Subsea boosting technologies provides robust performance, and the installed base of subsea boosting pumps is steadily increasing. The need for better understanding of how more cost-efficient systems can be designed and operated has led to the development of improved operational design methodologies that also can be transferred to online advisory systems. By investigating the interaction of parameters in the full system and identify which key parameters to monitor it is possible to make a less conservative design, hence both investment and operational costs are reduced. Use of an online flow advisory system including all physical parameters relevant for the subsea boosting station will enable further optimization of the production and equipment utilization during life-of field.Specific examples will be presented. By designing the system with temperature monitoring, requirements for insulation and preservation can be reduced. By designing the system to operate at best efficiency, requirement for power and performance can be reduced. Hence, significant cost savings are obtained, while robustness and safety remain.

  • 15:30 - 16:00

    15:30 - 16:00, Track 1 @ Peer gynt

    Smart solutions in Maria ensuring safe and cost efficient project execution

    Kay Irmscher, WINTERSHALL

    Smart solutions in Maria ensuring safe and cost efficient project execution

    The Maria development project was executed in an economically challenging time and the operator Wintershall had to turn every stone to make the development a success. The project was delivered almost a year ahead of schedule and significantly below budget. The presentation will explore some of the work that was undertaken to “undercut” the usual cost in development, construction and installation. Some examples are; the use of a dual derrick rig despite a heavy BOP, which was made possible due to smart fatigue reduction solutions; and a remote controlled well-commissioning from onshore saving time, cost and the environment. The above and several additional efforts, combined with outstanding collaboration with the suppliers, contributed to making the Maria development project a success.

    15:30 - 16:00, Track 2 @ Klokkeklang

    Installation of the world's first floating wind park

    Yngve Børstad, TECHNIPFMC

    Installation of the world's first floating wind park

    The Hywind technology was conceived in 2001 and by 2009 the concept had matured enough to install the world’s first floating wind turbine. In 2017 the Hywind concept was deployed at a large scale for the first time in the Hywind Scotland Pilot Park. The park is the world’s first floating wind park and powers over 20 000 UK homes. Floating wind power is still in its early stages, but has great potential in most areas of the world. Turbine size and technology is rapidly developing and it is likely that we will see much larger floating wind parks in the future.In the Hywind Scotland project TechnipFMC was responsible for transport of tower and substructure, inshore operations related to assembly in Norway, vertical towing of the completed turbines to Scotland, installation of the anchoring system as well as the hook up of the turbines to the mooring lines in the field. The presentation outlines the main technical challenges faced in the planning of TechnipFMC’s operations at Hywind Scotland, as well as an overview of the experience gained during project execution.

    15:30 - 16:00, Track 3 @ Troldtog

    Multiphase Flow Splitting in Åsgard SCMS

    Henrik Alfredsson, AKER SOLUTIONS

    Multiphase Flow Splitting in Åsgard SCMS

    Åsgard Subsea Compression was successfully brought on stream in September 2015 boosting the gas pressure from the Midgard and Mikkel fields. Going forwards, the Åsgard Subsea Compression Phase 2 project will further increase the pressure ratio for the station extending the life of the field. A possibility to increase the pressure ratio has been identified by means of introducing wet gas compression which is achieved by purposely injecting liquid upstream of each compressor. Since early 2017 the flow from the four import lines are co-mingled in the upstream manifold and unevenly split towards each train. This increases compression efficiency but causes a challenge as liquid distribution across the two trains can’t be controlled. The situation is made more complex as the liquid content is expected to change with reducing pressure and new wells coming on stream.For this purpose a co-operation between Statoil and Aker Solutions was initiated with the goal of determining how a multiphase flow split can be predictively modelled in the subsea framework. This paper covers the work performed and how it translates into life extension on Åsgard. Measurements from operations will be compared to built CFD models showing how fidelity simulations today can be used to predict the complex mechanisms behind a three phase uneven flow split. The same modelling techniques are then used to predict the multiphase flow split for lower operating pressures, enabling life extension without risk of running trains dry.

  • 16:00 - 16:30

    Coffee and exhibition

  • 16:30 - 17:00

    16:30 - 17:00, Track 1 @ Peer gynt

    Value mapping – from design to end of field life, maximising assets

    Stian Sande, SUBSEA 7

    Value mapping – from design to end of field life, maximising assets

    The Alliance between AkerBP, Aker Solutions and Subsea 7 is based on a few simple but fundamental principles. Some of these are early engagement, openness and information sharing, working together in integrated teams and sharing of commercial upsides and downsides. In practical terms this means that a joint project team is established already at DG1 and works together to maximize the value of the project through the Select, Improve and Execution phases and all parties benefit from finding and developing the overall most cost effective solutions. This close collaboration allows for maximizing the value of a field development considering the initial development cost, operation and decommissioning. By combining the competence and experience of operator, SURF and SPS suppliers early in the project phase, before key decisions are made, the impact of alternative solutions on both CAPEX and OPEX can be better assessed. The intent of continuity through pre-FEED, FEED and into execution also allows the suppliers to present their overall best solutions without reservations and without a concern that technology and intellectual property will be disclosed to others. Last but not least, a combined team allows for much better optimization and reduced interface risk between SPS and SURF scopes. Certain techniques can be used to map the value stakeholders and specific elements can add to a field development from design to end of life and give valuable insight into opportunities for creating value.

    16:30 - 17:00, Track 2 @ Klokkeklang

    Subsea Power Distribution - Tool kit for subsea processing

    Knut Rongve, ABB

    Subsea Power Distribution - Tool kit for subsea processing

    ABB has since 2013 been running a Joint Industry project together with Statoil, Chevron and Total to develop technologies for subsea power transmission, distribution and conversion at greater distances, in deeper waters, and in harsher environments. The project is targeting a 3000-hour shallow-water system test in 2019, including the qualification of pressure tolerant medium voltage switchgear, medium voltage drives, as well as supporting controls and auxiliary supplies. The target environment is water depths up to 3000 meters, transmission distances up to 600 km, and power levels up to 100 MWThis presentation will show the latest progress and achievements on the technology developments for high/medium voltage subsea power distribution main building blocks. The successful test of the subsea VSD performed in November 2018 is an important milestone in the project and the subsea VSD operated continuously for approx. 6 weeks under water. The subsea VSD operated in back-to-back configuration directly with the grid. The focus of for the completed test was on thermal performance of the subsea VSD. The test demonstrated the successful and reliable operation of the drive during different load conditions.Main topics for the presentation will be:
    • Introduction to Subsea Power Distribution Technology
    • Presenting main power building blocks for Subsea Power Distribution
    • Latest status and achievements from the Subsea Power JIP
    • Presenting findings and lessons learned from shallow water testing

    16:30 - 17:00, Track 3 @ Troldtog

    The Norwegian Petroleum Safety Authority’s perspective on the HSE status and challenges for the subsea industry.

    Geir Løland, PETROLIUM SAFETY

    The Norwegian Petroleum Safety Authority’s perspective on the HSE status and challenges for the subsea industry.

    The Norwegian Petroleum Safety Authority (PSA Norway) HSE regulations applies to the petroleum activities in Norway, including subsea production systems. Incidents including acute spills must be reported to PSA, and we have thus a comprehensive overview of incidents, accidents and other challenges the subsea industry experience. Furthermore, our supervision activities contribute to the continuous improvement of the safety of the petroleum activities, and is an important source for assessing the safety status. We will in our presentation show statistics for incidents related to subsea production systems. Furthermore, the challenges the subsea industry has today and will meet in the future will be addressed from PSA’s perspective.By working together, the combined knowledge of suppliers, operators and authorities, can be utilized to improve the safety level and achieve reduced costs. Openness and sharing of previous experience are key success factors, and the objective of PSA’s presentation is to share our experience and knowledge with you.

  • 17:00 - 17:30

    17:00 - 17:30, Track 1 @ Peer gynt

    Snorre Expansion Project - facilitating large IOR volumes

    Sverre Espedal-Selvåg, EQUINOR

    Snorre Expansion Project - facilitating large IOR volumes

    The Snorre Expansion Project delivered the plan for development and operation on December 21st, 2017 and is now in the execution phase with all contracts awarded. This presentation will give highlights from the concept development extending the lifetime of the Snorre Field to 2040 and possibly beyond. The following will be addressed:
    • The journey from Platform Solution to Subsea Concept
    • Benefits of Subsea concept unlocking large Snorre IOR volumes
    • Cooperation between Operation, Subsurface, Facilities and Drilling & Well

    17:00 - 17:30, Track 2 @ Klokkeklang

    Siemens Subsea Power Grid – now ready to unlock the potential of more subsea processing

    Bjørn Rasch, SIEMENS

    Siemens Subsea Power Grid – now ready to unlock the potential of more subsea processing

    Siemens has over the last years worked dedicated to develop and qualify a subsea power distribution system. The goal has been to create and qualify a complete and deployable power distribution system including all required subsea connection solutions as well as an overall power control & communication system to realize full subsea digitalization with high performance standardized interfaces. This system is now ready for the final phase of qualification where the performance parameters of the system are verified in a subsea environment. All system units will be qualified for operation at 3000 m water depth. The qualification has been performed in close collaboration with 4 major operators in order to ensure compliance with the future requirements. This presentation will focus on the complete journey from idea through component qualification, material compatibility and pressure testing to system verification and final full load testing in intended environment. The Subsea Power Grid is now a unique tool for unlocking the potential of more subsea processing in order to increase recovery and boost production in sustainable and environmental friendly way.

    17:00 - 17:30, Track 3 @ Troldtog

    A revised DNV-GL, RP-E101 "Recertification of well control equipment" reflecting new business models within subsea maintenance

    Torbjørn Espeland, DNV GL

    A revised DNV-GL, RP-E101 "Recertification of well control equipment" reflecting new business models within subsea maintenance

    DNV-GL has been involved in verification of maintenance activities on critical subsea well equipment for many years. In 2017 a new revision of our Recommended Practice DNV-GL-RP-E101 was issued, based on continuous interaction with market partners that supported a revision of this service document. The purpose of the revision was to harmonize different RPs addressing the same topic and make the document applicable globally, but most importantly to reflect the changes in the market. DNV-GL see that the drop in oil price has led to new business models within subsea maintenance with significantly lower volume and cost levels. We also see that the non-OEM side of the market has grown. The balancing act is now to keep a quality control level that secures technical integrity, and at the same time demonstrate an acceptable service cost. The revised DNV-GL-RP-E101 underlines the benefits of a risk based or condition based approach in terms of scoping only the critical components and processes for verification. With the revised document DNV-GL as an independent party has taken the market changes into account and facilitated for the new business models, in order for all players to succeed with the goal of having safe and operational well control equipment.

  • 17:30 - 18:00

    17:30 - 18:00, Track 1 @ Peer gynt

    Condition monitoring of subsea production control systems

    Phil Eckford, AKER SOLUTIONS

    Condition monitoring of subsea production control systems

    Subsea Production Control System (SPCS) in-service faults, failures, deterioration and degradation can impact the normal operation of Safety, environmental and Production Critical Elements. The potential financial, Health, Safety and Environmental consequences of failure of these critical elements can be significant. This paper presents a proactive monitoring and measurement solution based on real time data to verify against defined performance and operating envelopes using a digital platform. This enables effective visualization of anomalies, diagnosis, prognosis and overall cost efficient, safe and sustainable management of the subsea production control system.An intelligent SPCS integrity management digitalization system that focusses on unlocking the value from the existing data rather adding any extra sensors to the legacy fields will be presented. Through a combination of domain subsystem knowledge and advanced data analytics applied to controls data; the ability to predict certain types of faults is becoming a reality. The outcome of this approach leads to: improved production availability
    • through on-going analysis of system performance with effective trouble shooting leading to faster turnaround reduction in unplanned events
    • through understanding of the precursors leading to the key anomalies and how they impact the system.. condition based approach to the management of subsea operations
    • through taking an informed approach to subsea operational planning based on current system status spares holding optimization
    • through understanding the key risks via anomaly management multi customer knowledge sharing for improved service
    • through learning from other customer systems with similar products and performance issues

    17:30 - 18:00, Track 2 @ Klokkeklang

    Cost and value engineered power system with a High Voltage subsea electrical induction motor – A simplification of the subsea power distribution system

    Kay Kristiansen, ONESUBSEA

    Cost and value engineered power system with a High Voltage subsea electrical induction motor – A simplification of the subsea power distribution system

    The power drive system of a subsea boosting application consists of a Variable Speed Drive supplying power to the subsea booster pump through an umbilical. Transformers may be used to elevate the transmission voltage for longer step outs (typically >15km). The induction motor for OneSubsea Processing applications have for more than 20 years had a voltage rating at max 6.6kV based on standard motor classing. It was designed for continuous operation with a single earth fault in compliance with IEC voltage class 6/10(12) kV (IEC 60502). As a result of our comprehensive and successful track record, operation with earth fault has been removed as a firm requirement for some applications, allowing the rated operating voltage to be increased. Elevating the rated motor voltage and hence the transmission voltage, enables subsea boosting applications with longer step out, eliminating the need for step-up/-down transformers. In 2016 OneSubsea launched and successfully executed a fast track development- and qualification program including design activities, analyses, test and manufacturing of a prototype 10.5kV High Voltage Motor unit. The qualification of an induction motor with increased voltage rating was since then been the enabler for the award of two major boosting system projects. The possibility of a simplified layout can now contribute to a significant reduction in installation cost, complexity and risk associated with the deployment of systems with subsea transformers. However a holistic system approach needs to be considered to determine the best cost and value engineered solution.

    17:30 - 18:00, Track 3 @ Troldtog

    Askeladd and Troll Phase 3 – high rate subsea production system with 7” VXT

    Anna Arteeva, EQUINOR

    Askeladd and Troll Phase 3 – high rate subsea production system with 7” VXT

    Statoil has increased the effort to maximize the recovery from oil and gas fields. The development of gas fields and long tie-backs is gaining higher priority. Lean development poses technical challenges within flow assurance and system design. A large production pressure envelope and high production rates require optimisation of the system design related to the pressure drop, production velocities, fluid content, sand erosion, vibrations and acoustic fatigue. Risks such as formation water break-through and hydrate management raise additional requirements for the subsea equipment for the long tie-back projects. Those issues are addressed in the common studies between Statoil projects Troll phase 3 (gas off-take to Troll A) and Askeladd (gas export to Hammefest LNG via Snøhvit, world’s longest tie-back) performed in cooperation with Aker Solutions, TFMC and OneSubsea. A high rate 7” subsea production system (SPS) has been developed based on an updated Vertical Xmas Tree (VXT) where the wing section and piping is increased from 5’’ to 7’’ and a Choke Bridge Module (CBM) is implemented. The CBM also includes functionality for fluid control, water monitoring and erosion monitoring. This paper will address how the new SPS design enables 10% production recovery increase, delayed investments for the next phases, lower CO2 intensity at the processing facilities, reduced production velocities and increased robustness with regards to vibration and erosion potential in the subsea equipment.