Bergen, Norway 11 – 13 June, 2019

Day 1 – June 12

Change day
  • 08:30 - 09:30

    Badge pick-up and coffee

  • 09:30 - 09:40

    Welcome

    UTC Program Committee Chairman:

    Jon Arve Sværen, ONESUBSEA

    UTC Conference Moderators:

    Wendy Lam, BHGE

    Kristin N. Berg, DNV GL

  • 09:40 - 10:00

    Smarter solutions for a future-fit portfolio

    Anders Opedal, Executive Vice President TPD, EQUINOR

  • 10:00 - 10:20

    BP Energy Outlook 2019 edition

    William Zimmern, Head of Global Macroeconomics, BP

     

    The global energy system is facing a dual challenge: to provide significantly more energy while at the same time reducing carbon emissions. The 2019 edition of BP’s Energy Outlook considers the future of global energy by exploring the forces shaping the energy transition out to 2040.

     

  • 10:20 – 11:00

    Coffee and exhibition

  • Track 1 @ Peer gynt

    Parallel session #1

    Track 1 @Peer Gynt

    Track 2 @ Klokkeklang

    Parallel session #1

    Track 2 @Klokkeklang

    Track 3 @ Troldtog

    Parallel session #1

    Track 3 @Troldtog

  • 11:00- 11:30

    11:00- 11:30, Track 1 @ Peer gynt

    Adapting to the new world: what’s next for the subsea market?

    Mhairidh Evans, WOOD MACKENZIE

    Adapting to the new world: what’s next for the subsea market?

    Through a challenging few years, the subsea industry has adapted and evolved. This paper will set out Wood Mackenzie’s insights on the current and future conditions for the subsea market.

    In the presentation, we will start with a short bit of context on some of the key talking points of the past couple of years (low activity, smaller contract sizes). Then we will focus very much on the future. We will discuss Wood Mackenzie’s view on the direction, pace and profile of future growth in the subsea market; which regions and types of projects are standing out, and why?; how have breakeven economics changed over the past few years and what’s the outlook?

    We will pose (and answer) the question ‘are mega-projects gone for good?’. And present on the changing motivations of operators when taking project FIDs (and what that means for the subsea market).

    There are some interesting new ways of working that the subsea industry is advancing – integrated solutions, standardisation and digitalisation. This paper will discuss our view of the opportunities and challenges for these innovations, and the potential impact of them on project economics.

    11:00- 11:30, Track 2 @ Klokkeklang

    North Sea Field Redevelopment - Using new subsea separation technology to de-bottleneck existing infrastructure and secure increased oil recovery. (OpCo Study)

    Asle Jostein Hovda, SEABED SEPARATION

    North Sea Field Redevelopment - Using new subsea separation technology to de-bottleneck existing infrastructure and secure increased oil recovery. (OpCo Study)

    In one of the central NCS fields the main FPSO and infrastructure is suffering severe issues from excess produced water. This is a common problem to most mature area development on the NCS/UKCS. This excess water is hampering the overall profitability by filling up the FPSO processing system and taking up a large part of the capacity in the pipeline infrastructure. The result is loss of new revenue opportunities from failure to onboard new fields, increasing operating expenditures, and in general non-optimum production philosophy for the area development.

    With new and more efficient subsea processing technology such as the Dual Pipe Separator system (DPS), operators can remove the produced water at the seafloor before releasing it to sea or injecting in a reservoir, and thus enable new business development opportunities. Removing the water at the seafloor, the operators will gain from increased oil recovery due to a reduced back pressure on the reservoir and accelerated production from existing and new reservoirs.

    The DPS technology is based on using a pipe separator principle with a set of inclined pipes in parallel, making the solution scalable to both capacity, reservoir pressure and water depths. Since the DPS consists of a number of inclined pipes in parallel, the number of pipes can be adjusted to the capacity requirement.

     

    We will present a case study from a real NCS field where the DPS system will be integrated with already existing infrastructure to achieve significant IOR and open up the pipeline for new developments.

     

    11:00- 11:30, Track 3 @ Troldtog

    Subsea power distribution - Transforming field developments

    Knut Rongve, ABB

    Subsea power distribution - Transforming field developments

    ABB has since 2013 been running a 100MUSD 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 target environment is water depths up to 3000 meters, transmission distances up to 600 km, and power levels up to 100 MW.

    The first Subsea VSD was successfully tested in November 2018. This was an important milestone in the project. The subsea VSD operated for 1000 hours and demonstrated successful and reliable operation of the drive during different load conditions.

    In the final test campaign, the complete subsea power system will be tested together in a second shallow water in the summer of 2019. This will mark the end of this ground-breaking qualification project involving over 150 technical experts from 6 different European countries from ABB and our partners.

    After completion of final testing the products and systems will be available for commercial use, transforming future development of oil and gas fields.

    This presentation will give an insight into the latest progress and achievements. Further we will present the products and system aspects related to use of this technology and the benefits this could have on future field developments.

  • 11:30 - 12:00

    11:30 - 12:00, Track 1 @ Peer gynt

    Stones - the world’s first 15 ksi ultra-deepwater subsea pump

    Arill Småland Hagland, ONESUBSEA

    Stones - the world’s first 15 ksi ultra-deepwater subsea pump

    Stones is a phased development that began production in September 2016 from two flowing subsea wells tied back to an FPSO. Full-field development includes six more wells from two connected drill centers, and a subsea boosting system to increase production and extend the life of the field.

    This paper will describe the technology qualification program and execution experience from developing and delivering the world’s first 15 ksi ultra deepwater subsea pump, as well as lessons learnt from the project, through component qualification, engineering, manufacturing, testing and installation. In addition, experience from commissioning and start-up of the boosting system will also be described.

    Multiple technology gaps were identified to meet the HPHT design parameters for Stones. To close these gaps an extensive Technology Qualification Program (TQP) was executed together with OneSubsea Processing. This was the start of a cooperation between Shell and OneSubsea with a common goal; to deploy the world’s first 15 ksi ultra-deepwater boosting system. Following the TQP, an EPC contract was awarded in 2015 that included a pump station with two off 2.9 MW pumps and topside power drive system.

    The pump system has been through an extensive execution and test phase that has been completed without any injuries. The complete system has now been handed over to the operator and has partially been installed as part of the world’s deepest oil and gas project.

    The Stones boosting system will enable the operator to maintain and extend production in addition to significantly increase the recovery at the field.

    11:30 - 12:00, Track 2 @ Klokkeklang

    Vigdis Booster station – next generation booster project – why and how

    Ole Oekland, EQUINOR

    Vigdis Booster station – next generation booster project – why and how

    Vigdis Booster station project was sanctioned in November 2018. It is the first project in Equinor’ s project portfolio which has implemented the standardization principles for subsea booster stations.

    Equinor has since 2015 been defining and developing a standardized subsea multiphase boosting pump station with specified interfaces.

    The station will comprise of a foundation structure with trawl protection, a manifold module for connection to flow lines, a boosting pump module and an umbilical termination assembly. Key principles are a standardized manifold design with 2 off horizontal connections to the flow lines and 2 off vertical hubs (vertical bore) for connection of the pump module. The solution has been designed and engineered as a collaboration with SubseaDesign.

    Production on the Vigdis Field is currently limited by the capacity in the production lines and pressure drop across the topside chokes. Reservoir deliverability is limited by low reservoir pressure in some parts of the field, together with increasing water cut, leading to reduced energy into the system i.e. dropping wellhead pressures.

    OneSubsea will deliver both the pump system, including all-electric control, and the pump station.  VBS will apply a 8.7 KV HV motor and thereby eliminate the need for subsea transformer and reducing investment cost benchmarked to similar subsea projects.

    The subsea pump interphase document described in the presentation is released as an open document allowing all companies, both operators and suppliers, to implement the proposals in their future field development where subsea booster pumps are part of the concept.

    11:30 - 12:00, Track 3 @ Troldtog

    Full scale testing of a game changing ultra-long step out power solution

    John Olav Fløisand, ONESUBSEA Andrea Sætre, SHELL

    Full scale testing of a game changing ultra-long step out power solution

    As part of the concept select phase, Shell has together with OneSubsea performed detailed power system analyses and executed several tests to validate the concept of providing power from shore on the Ormen Lange subsea compression development. The concept leverages pre-qualified and standard components in a proven power topology. Taking advantage of the testing facilities at Horsøy, a VSD has been operating various loads through a high voltage 120 km step out test arrangement replicating actual cable properties.  The testing has included start up, stops, trips, speed and load changes, and operation across the complete frequency range. Both the analyses and testing prove that the concept of operating a load via a 120 km cable is fully feasible and can be evaluated as part of the concept select phase.

    Increased recovery by applying subsea boosting in terms of boosting is a field proven solution. As the subsea field developments are evolving and becoming more extensive, the significance of the system realization bottleneck in terms of stepout length feasibility, is continuously increasing. A general perception has been that new offshore platforms or alternatively the use of the non-field proven subsea VSD’s is required for large and long stepouts for subsea boosting. However, based on this step change, power demanding greenfield and brownfield applications can be transformed to low-risk economically viable projects by extending the reach of the field proven power system topologies.

    This presentation shares insight to the evaluation and confidence steps taken, from concept idea and analysis, to system verification.

  • 12:00 - 12:30

    12:00 - 12:30, Track 1 @ Peer gynt

    Remotely Operated Factory (ROF™) – the Roadmap to Always safe, High value and Low carbon

    Cecilie Gotaas Johnsen, EQUINOR

    Remotely Operated Factory (ROF™) – the Roadmap to Always safe, High value and Low carbon

    Remote and unmanned operations including subsea tie-backs have been in the industry and Equinor’s portfolio for decades, i.e. Tordis boosting, Åsgard – and Gullfaks subsea compression and normally not manned platforms as Huldra and Valemon. From this knowledge and operational experience, combined with innovation and digitalization, Equinor’s Remotely Operated Factory (ROF™) has emerged and matured into several possible remotely operated and unmanned field development concepts.

    Unmanned Wellhead Platform (UWP™) has successfully been implemented and started at Oseberg H. From this lean design philosophy, UWP™ has further materialized to Unmanned Production Platform (UPP™) and Unmanned utility platform (UxP™), successfully targeting the corner stone of our business; Always Safe, High Value and Low Carbon. Field development solutions based on the UPP™ concept in combination with subsea technologies is assessed for several business cases. Beyond always safe which is designed into the unmanned and remotely operated facilities, stranded discoveries, marginal fields and new exploration plays can materialize using UPP™ with reduced capex and opex compared to standard PDQ greenfield solutions. Additionally, these concepts cater for further reduction in carbon intensity from our operations, enabled by simplified design solutions.  A range of solutions are shown in a ROF™ roadmap increasing the business opportunities and competitiveness for the future.

    12:00 - 12:30, Track 2 @ Klokkeklang

    Fast track EPCIC contract model to maximize economic recovery utilizing mature subsea processing system

    Jostein Tvedt, ONESUBSEA

    Fast track EPCIC contract model to maximize economic recovery utilizing mature subsea processing system

    In 2016 TAQA identified that continued production from the Eider platform was becoming uneconomic and instituted a wide-ranging review of options for the Eider field and its subsea tieback Otter.  It was determined that the maximum economic recovery (MER) would be achieved from bypassing production from the Otter field around Eider and flowing directly to North Cormorant, with the Eider platform undergoing cessation of production (CoP) and reverting to a utility platform for power and control for Otter.

    As part of this process and in May 2017 a contract was entered for the engineering, procurement, construction, installation and commissioning (EPCIC) of a subsea multiphase boosting system for the Otter Field.

    The Otter field is located at Block 210/15a, East of Shetland, and commenced production in 2002.

    The need to maximise recovery in subsea fields has driven the advancement of subsea processing technologies.

    This project has been executed, delivered, installed, commissioned and started up in just 16 months.

    This paper will focus on the key challenges in ensuring successful integrated project execution and highlight the success factors critical to delivering a long subsea tieback boosting project.

    Lessons learned for a fast track EPCIC long tie-back boosting project execution model will be provided, together with challenges and lessons learned re-using existing hardware in order to minimize capital expenditure.

    Early operational experience will be provided, as well as key features in terms of production assurance and drawdown capabilities. The fundamental benefits of subsea boosting by enabling stable well backpressures will be provided.

    12:00 - 12:30, Track 3 @ Troldtog

    Hybrid Multiphase Modelling – Predictive and Digitalized before first steel is cut

    Henrik Alfredsson, AKER SOLUTIONS

    Hybrid Multiphase Modelling – Predictive and Digitalized before first steel is cut

    Subsea Compression offers a low carbon footprint compared to topside offshore gas installations. Now and into the future we will use energy from an array of sources where gas will continue to play an important part. Producing this with the best available technology in the cleanest possible way should be our priority. Following the success of the Åsgard Subsea Compression Project Aker Solutions are going deeper, further and more compact creating the second generation Subsea Compression Systems. The drive to predict, understand and digitalize already in project phase intensifies as flow rates and pressures increase and installed size decreases.

    This paper will present how novel digital tools are used to predict complex multiphase / multi physics events crucial to the functionality of the Subsea Compression System. Next generation Hybrid Multiphase Models have been used in cooperation between Aker Solutions and Siemens to predict multiphase liquid distribution and gas/liquid separator performance. The outcome is compared to real environment, high pressure, low surface tension measurements. This forms a validation benchmark showing how what was previously deemed “simulation wise impossible” now has evolved into a trust worthy engineering tool. In the Subsea Compression framework this enables perceived risk to be challenged and cost to be reduced way ahead of the test and integration phase. This drives down size and increases the safe operability envelope of the Subsea Compression System effectively getting more gas out on the market.

  • 12:30 - 14:00

    Lunch and exhibition

  • 14:00 – 14:20

    Engineering the future: The role of engineers in transforming our industry

    Graham Henley, Vice President Engineering, SHELL

  • 14:20 - 14:40

    Keynote

    Erna Solberg, Prime Minister of Norway

  • 14:40 - 16:00

    Panel Debate - Subsea technology's role in the future sustainable energy picture

    Moderators:

    Wendy Lam, BHGE

    Russel McCulley, UPSTREAM

    Panelists:

    Egil Bøyum, AKER SO

    William Zimmern, BP

    Anders Opedal, EQUINOR

    Graham Henley, SHELL

  • 16:00 - 16:30

    Coffee and exhibition

  • Track 1 @ Peer gynt

    Parallel session #2

    Track 1 @Peer Gynt

    Track 2 @ Klokkeklang

    Parallel session #2

    Track 2 @Klokkeklang

    Track 3 @ Troldtog

    Parallel session #2

    Track 3 @Troldtog

  • 16:30 - 17:00

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

    A 3D-printed subsea tool used for Egina development (Nigeria)

    Hugues Greder, TOTAL

    A 3D-printed subsea tool used for Egina development (Nigeria)

    The 330 meter long Egina FPSO started to produce offshore Nigeria last December 2018. During the Egina development phase, Total  successfully used Additive Manufacturing (3D-printing) to provide a subsea tool within seven days and avoid a shut-down of the nearby producing Akpo FPSO.

    The Egina Gas Export Line was to be tied back to the existing Akpo Gas Export line when it was found out that the connection pressure cap located on the subsea connection module was blocked and could not be removed. This was due to a blockage by gas hydrates. It was decided to remove all the nuts from the plunger flange, remove the flange and introduce a “methanol soaking tool” to get rid of the hydrates. The external shape of the tool was designed locally and then digitally sent to TOTAL 3D-printing center. The tool design was reviewed to optimize the shape of the methanol channels within the tool. A so-called “topological optimization” was performed to reduce the weight of the tool. A stress and strain analysis was conducted to make sure the tool would sustain deep-water injection conditions. The tool was then printed using a powder bed laser sintering technology. The retained material was polyamide-12. The 32cmx32cm tool was printed in 37 hours and weigths 11kg (ca. half of a machined tool). The tool was sent within 48hours to Port Harcourt and run subsea in 1250m water depth. After 2 hours of continuous soaking, the pressure connecting cap was successfully freed from hydrates.

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

    Field experience from the world's first subsea process cooler for wet gas compression

    Kristine Solberg, ONESUBSEA

    Field experience from the world's first subsea process cooler for wet gas compression

    Equinor and OneSubsea Processing have cooperated in developing and qualifying the world’s first subsea wet gas compression system which was installed at the Gullfaks field in the North Sea in late 2015. The system has been in continuous operation since July 2017.

    Early in the compressor technical qualification program it became obvious that subsea cooling was mandatory for the success of a subsea wet gas compression system. Development of a wet gas process cooler was essential and required focus on several aspects such as cooler performance, fluid distribution, pressure loss, sand accumulation, hydrate formation, and marine growth. Reliability, robustness, size and weight were of high priority, as marine interventions are costly, especially for large equipment.

    Three years after installation, and 1.5 years in operation have provided extensive operational experience for the process coolers in the Gullfaks subsea wet gas compression system. It is of high interest to evaluate and compare operational experience from field with test data and calculations. The purpose of this paper is to summarize the experience gained from field with respect to cooler performance and flow assurance issues and compare with initial calculations and assumptions.

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

    Test site in Trondheimsfjorden for Underwater Intervention Drone (UID™) - subsea docking station

    Pål Atle Solheimsnes, EQUINOR

    Test site in Trondheimsfjorden for Underwater Intervention Drone (UID™) - subsea docking station

    Test site in Trondheimsfjorden for Underwater Intervention Drone (UID™) – subsea docking station.

    NTNU and Equinor are collaboration regarding developing and installation of a UID docking station test-site. During the spring 2018 NTNU and Equinor have installed world first pilot of UID docking station in Trondheimsfjorden at 365 meters depth, northwest of Munkholmen. The docking station is powered and controlled from Trondhjem Biological Station (NTNU) about 2,2 km from site. The users of the docking station will be Academia (NTNU), UID suppliers, Operators and others.

    The aim for the pilot is to have possibility of testing and verification of new technology within UID technology and will be offered to the marked with a non-profit rental cost to customers. From NTNU and Equinor view it is important to have this type of low threshold test site available to increase the speed of the UID technology research and development.

    The test site has inductive power and communication system from Blue Logic, Wisub and Siemens.

    The paper will present a technical description of the test site in Trondheimsfjorden and an experience transfer of the first users of the dockings station. The first user will start operation during spring 2018 (Eelume). Presented by Asgeir Sørensen (NTNU), Martin Ludvigsen (NTNU) Jan Christian Torvestad (and Equinor) and Pål Atle Solheimsnes (Equinor).

  • 17:00 - 17:30

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

    Large modifiable underwater mothership MUM – Operational and technical concepts for complex unmanned tasks

    Willem Hendrik Wehner, THYSSENKRUPP MARINE

    Large modifiable underwater mothership MUM – Operational and technical concepts for complex unmanned tasks

    Aim of the “MUM– Large Modifiable Underwater Mothership” Project is to explore near-future technology unlocking the potential of large UUVs within the next decade. We present a highly modular and variable unmanned underwater vehicle family, providing novel operational and technical concepts for efficient and economic subsea tasks and works under harsh conditions.

    The new vehicle class brings unconventional ideas to the table towards solving the needs of the offshore oil and gas industry regarding cost efficiency and reduced manning:

    The design of modular building block systems allows a focused mission-dependent module assembly. A scalable fuel cell based energy system, based on proven submarine technology will power the MUM throughout even long-term deployments. New developments in autonomy, navigation, and communication enable autonomous missions which usually require permanent operator control. With payloads or toolboxes up to ten tons, the MUM system will largely extend the possible tasks for UUVs.

    This concept design is going to be validated through model tests of vehicle variants in summer 2019 and real scale tests of critical components.

    Underlying operational concepts, mission module designs as well as vehicle configurations for the tasks were validated by industry experts e.g. from Equinor and PGS.

    Exemplarily, we present two relevant missions; i.e. the exchange of subsea control modules (SCM) by the vehicle and the deployment and retrieval of ocean bottom seismic nodes.

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

    GRAND - the next big tie-back

    Hilde Reme, EQUINOR Erik Brandt, SURF manager GRAND project

    GRAND - the next big tie-back

    The GRAND development unlocks significant volumes, utilizes and extends the capacities of the Grane platform and revitalizes the area. This presentation will review the concept maturation and selection process – Unmanned Wellhead Platforms versus 4-slot templates versus 6-slot templates – and how the reservoir characteristics and well requirements influenced on the decision. The characteristics of the selected subsea solution will be described – how standard building blocks are utilized – how a new standard building block is added to the standard catalogue – and how the selected solutions will accommodate the requirements of the characteristic reservoirs and objectives of the project. The planned development will have capacity for up to 24 wells.

    Co-authors: Helge Rivelsrud and Erik Brandt

     

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

    A new generation of self-contained subsea valve actuators combining reliable fail-safe springs with interchangeable electric drives

    Alexandre Orth, BOSCH REXROTH

    A new generation of self-contained subsea valve actuators combining reliable fail-safe springs with interchangeable electric drives

    1. Objective

    All electric subsea actuators have been developed to provide solutions for the limitations of the traditional hydraulic actuators, such as demand for top side hydraulic power unit, need for hydraulic flow lines in umbilical’s. However, when it comes to the high actuation forces like 5’’ or 7’’ gate valves, the all electric solutions demand a large dimension and weight. However, the power density (force per size) is one of the advantages of hydraulic actuators.

    2. Method

    Is it possible to create a hybrid solution which combines the advantages of both existing technologies, i.e. to get the best out of electrics and hydraulics?

    This work presents a novel approach for actuation of subsea valves which combines the strengths of an electromechanical actuator with a hydrostatic transmission. The paper will provide a prototype of a hybrid actuator for subsea production based on successful industrial solutions.

    3. Results

    The main achievements are: 1. Cost-effective modular design (lean production management), 2. Environmental-friendly set up (no leakage of hydraulic fluid), 3. High power savings (up to a reduction of 75%), 4. High safety level (up to SIL 3), 5. High availability and condition monitoring, 6. Integration of a mechanical override, 7. Interchangeable electric drives (optional driven by ROV torque tools).

    The results are demonstrated by qualification test of a 2’’ gate valve for 3,000 m water depth. Hence, a 5’’ concept design shows the potential to build a complete actuator in the same space used today by a pure hydraulic cylinder.

    4. Novel

    The designed Subsea Valve Actuator is more reliable as existing solutions without hydraulic umbilicals and emission of fluid into seawater, by offering a standard electric interface with integrated condition monitoring and safety. It is an important step to close the technological gap to accomplish the all-subsea factory, especially to replace existing hydraulic actuators.

     

  • 17:30 - 18:00

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

    Innovative Local Heating Technology Provides Design Optimization and Operation Flexibility to Long Subsea Tie-backs

    Stephane Anrès, SAIPEM

    Innovative Local Heating Technology Provides Design Optimization and Operation Flexibility to Long Subsea Tie-backs

    Several heating solutions are already field proven, they are based on distributed heating technologies like DEH and Heat tracing and are mainly considered for hydrate management under transient operations  such as start-up, shutdown and preservation. Local heating is a different solution, intended to be used continuously during production.

    Heating the flowlines during production is a way to overcome  thermal constraints, mitigate hydrate and wax risks, provide operating flexibility and optimize Capex. Indeed in the case of long distance tie-backs, very deepwater applications or when the fluid temperature at the wellhead is too low, conventional flow assurance solutions might be very expensive or even not applicable.

    A local heating device can be integrated into a subsea station, installed inline or in parallel of the main flowline and which can be retrieved for maintenance or be relocated. The technology is compact thanks to the use of induction which allows for the transfer of a high power (several MW) over a relatively short pipe length. The technology can be implemented either on new fields or on the extension of existing lines, is fully compatible with preservation by flushing and allows for pigging in case of deposits.

    This paper will present an overview of the local heating technology including a preliminary design and will then provide information on the small-scale prototype tests (100 kW heating) that have been performed and have confirmed heating levels and heating efficiency.

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

    Subsea sea water treatment and injection – A cost efficient and flexible solution to increase recovery

    Eirik Dirdal, NOV

    Subsea sea water treatment and injection – A cost efficient and flexible solution to increase recovery

    With the downturn fresh in mind, oil and gas operators are challenging the market to come up with innovative low-cost solutions to increase recovery and improve their margins. This is particularly important in mature areas like the North Sea.

    Water injection is a common way of increasing recovery from reservoirs. Moving water injection subsea provides a cost-efficient solution and ensures safe operation, making field development economically viable.   Utilizing the seabed to treat and energize surrounding seawater provides the long sought-after flexibility for both Brown- and Greenfields.

    Two oil service majors have joined forces and developed a complete water treatment and injection package solution based on Seabox™ and LiquidBooster™ technologies.  With significantly reduced topside scope and utilizing standardized products, it is a cost-efficient solution to provide high-quality water to subsea wells for reservoir pressure support.

    One important aspect of the solution is that the sea water treatment and injection process is moved subsea, reducing the need for topside modification, which makes it easier to control cost, reduce the overall uncertainties and provide significant value creation to a field development.   The water injection strategy can be decoupled from the host and provides a flexible approach to phase in water injection capacity when and where required, based on reservoir dynamics and/or synergies between a cluster of nearby fields.

    This presentation will give an introduction to a subsea sea water injection application, the associated benefits by moving this technology subsea and the advantageous synergies of a joint integration approach.

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

    Ensuring safety and reliability of all-electric systems

    Aslaug Melbø, BHGE

    Ensuring safety and reliability of all-electric systems

    Subsea electrification has been a recurring industry theme for more than 20 years, but adoption has been limited. Recently, there has been renewed interest in this concept, driven mainly by a reaction to cost pressures in the industry and an increased acceptance of enabling technologies for subsea electrification including electric actuation.

    One reason for the limited adoption has been that only standalone parts of the system have been qualified, meaning that not all benefits of a fully electric system can be reached. Another reason is conservatism in the industry and concern that an all-electric system will not have the same safety and reliability as a conventional electro-hydraulic system.

    BHGE will present our systems approach to the all-electric development, ensuring all aspects are covered. Safety and reliability are key focus areas in the development. Important design decisions around the functional safety approach, fail-safe mechanisms and retrievability have been made early in the project to ensure the all-electric system maintains all aspects of safety and reliability that are expected from a conventional system. In addition, all-electric systems use more advanced monitoring and digital tools that further improve the reliability and integrity of the system.

  • 19:30 - 00:00

    Conference Dinner

    @Dovregubben