Bergen, Norway 11 – 13 June, 2019

JUNE 14

Change day
  • 08:00 - 09:00

    Morning coffee in exhibition hall

  • 08:30 - 09:30

    Track 2 @Klokkeklang - Student Sessions

    Student presentations

  • 08:30 - 09:00

    Track 3 @Troldtog

    Global Centres of Expertice – GCE SUBSEA

  • 09:00 - 09:30

    Track 3 @Troldtog

    Scottish Development International – SDI

  • Track 1 @ Peer gynt

    FIELD DEVELOPMENTS / SYSTEMS SOLUTION

    Track 1 @Peer Gynt

    Track 2 @ Klokkeklang

    DIGITALIZATION, POWER, CONTROLS AND UMBILICALS - SUBTOPIC

    Track 2 @Klokkeklang

    Track 3 @ Troldtog

    SURF, SPS AND MARINE OPERATIONS

    Track 3 @Troldtog

  • 09:30 - 10:00

    09:30 - 10:00, Track 1 @ Peer gynt

    Subsea Water Treatment – A Unique Water Treatment Solution

    Torbjørn Hegdal, NOV

    Subsea Water Treatment – A Unique Water Treatment Solution

    Treating seawater at the seabed allows for a very effective disinfection and removal of particles, solving the traditional maintenance intensive topside solutions. Moving water treatment from topside to the seabed reduces weight and space requirements topside and simplifies the process significantly since weight and space are no longer an issue. At the seabed, Seabox™ is a system without any moving parts and filters, and is significantly simpler than the traditional topside systems.Treated seawater has many applications. Platform topside process systems require large volume of waters for cooling and traditional topside water systems are rather maintenance intensive. Treated seawater for water injection into the reservoir is another high-volume application. The Seabox™ is a unique system that ensures proper disinfection of water and removal of particles for different applications. Water quality for water injection into the reservoir may require further treatment of the water, like removing all suspended solids, removing sulphate or producing low salinity water. Part of the quality specifications are for protecting the reservoir and facilities, other parts are for changing conditions in the reservoir to increase production and oil recovery. No chemicals are added in the water treatment at seabed, the required chemicals for the disinfection are produced in the Seabox™. The subsea solution is more energy efficient, resulting in less cost and reduced CO2 footprint. Maintenance is limited to an intervention every fourth year. The focus of this presentation is the subsea water treatment and value proposition related to water intake.

    09:30 - 10:00, Track 2 @ Klokkeklang

    Condition monitoring and real-time digital twins for the Oil&Gas industry

    Stefan Schlömilch, SAP/FEDEM TECHNOLOGY

    Condition monitoring and real-time digital twins for the Oil&Gas industry

    Fedem Technology, a well-established supplier of advanced analysis services to the O&G industry, was acquired by SAP in 2016. Together, SAP/Fedem are digitalizing engineering know-how. The presentation will show how the IoT technology stack can be combined with real-time structural analysis (FEA) software and machine learning to enable the next generation of condition monitoring. Live projects from the area of wind power, infrastructure and manufacturing will be showcased. Detailed descriptions and demos of how the technology can be applied in the Oil&Gas industry will be outlined. The condition monitoring solution is relevant for any structures exposed to dynamic loads and rotating machinery. The highlighted projects will include examples of rigid static structures, flexible static structures and rotating machinery. The advantages to the end user include: Deeper knowledge of the structure, maintenance and inspection optimization, fatigue life documentation, early warning of failures, improved basis for life time extension, and potential upgrading of capacity. The technology will in combination with other Industry 4.0 applications enable the creation of new business models and technical solutions, which until now have been impossible such as unmanned and autonomous operations and advanced designs.

    09:30 - 10:00, Track 3 @ Troldtog

    Automated Pigging Operations

    Marius Bjørn, NOV

    Automated Pigging Operations

    Operators are constantly looking for new solutions to improve the economics of new oil or gas fields. Specifically, Operators could see benefits in the development of subsea solutions for long distance tie-backs to existing platforms or on-shore facilities. Pigging is an important part of tie-back pipeline maintenance and inspection, and NOV proposes a new method for simplifying subsea pigging operations by reducing operation cost and improving safety operation (remove MSV intervention). In order to simplify pipeline systems, NOV, Total and Shell are developing the Subsea Automatic Pig Launcher (SAPL), a pigging system that can be permanently installed on the seabed. The SAPL draws on established topside pigging technology and promises a flexible and robust technology that allows for a range of pigging operations including intelligent pigging. It eliminates the need for a second flowline just to enable pigging and wax/slug handling and reduces the number of days required for vessel mobilization, consequently improving also the safety (less lifting operation). On the operational side, it minimizes the use of an ROV-equipped vessel and encourages the frequent pigging that can help avoid blockages and production shutdowns. The main idea is that you can sit onshore, or on a platform, and push a button to launch a pig and you perform the reloading once a year! NOV engineers will explain the technology and experience archived during the qualification testing performed on the west coast of Norway Q1 2018.

  • 10:00 - 10:30

    10:00 - 10:30, Track 1 @ Peer gynt

    Mapping Subsea All-Electric

    Kristin Moe Elgsaas, BHGE

    Mapping Subsea All-Electric

    Subsea electrification has gotten much attention over the last few years. Several companies – suppliers and operators alike – have publicly shared results from studies showing expected cost reduction and operational benefits. All-Electric solutions open for rethinking many current assumptions and design practices. Removing or reducing hydraulic lines and associated equipment impacts hardware from topsides to downhole, and all phases of project execution.During system definition, there is an almost endless combination of technologies and concepts with unique sets of benefits – or lack thereof. This is coupled with the desire to qualify structured and standard solutions that are applicable for the majority of fields and acceptable to the majority of operators. Hence, adopting a process that allows efficient screening and down-selection of options that realize the most system level benefits while ensuring safe operation – yet is both structured and flexible – is a complex, but critically important activity at the start of any development process to ensure qualification of the right solutions. One BHGE outcome of this process is the implementation of transmission system modularity which allows the combination of standard, modular core technologies and system level flexibility to meet different tie-back distances and field layouts. The result is an Envelope Map. This presentation will present a methodology for optimizing system level benefits including identifying the right balance between existing and novel technologies for All-Electric, describe the process for developing the BHGE Envelope Map, and finally give a view of current and future envelope needs and potential solutions.

    10:00 - 10:30, Track 2 @ Klokkeklang

    A Digital Solution for Subsea Production Management

    Carsten Russenes, ONESUBSEA

    A Digital Solution for Subsea Production Management

    As oil and gas operators invest in digital transformation, there is an increased expectation of supplier digital solutions that extend across the value chain and integrate with the digital philosophy of the operators. Advanced technology (sensors, controls, equipment, modelling engines, analytics and software) must connect to intelligent, automated and autonomous real-time systems to provide actionable information for the operator. Key challenges operators are facing are preventing production down time and at the same time maintaining the integrity, metrology and operability of the subsea production equipment, to reach their production targets. FRIENDTM Integrated Production Management Solution is a state-of-the-art OneSubsea solution that connects subsea equipment, sensors and actuators, via a Master Control System (MCS), to a secure hosted data environment. It is important to consistently interpret what is happening, why it is happening, what is likely to happen next and how to control it. The combination of advanced analytics, multiphase flow simulations and production assurance models make it possible to derive actionable information for operational support. Major achievements after using the system for more than a decade include increased up-time (availability), improved run hours for rotating equipment, and increased performance and accuracy of multiphase flow measurements. Having access to real time data has also made it possible to practice a consistent, proactive and integrated working methodology between the operator and supplier that safeguards best operational practices. This presentation will describe the overall solution and main components as well as how it provides value in daily operations for various categories of users.

    10:00 - 10:30, Track 3 @ Troldtog

    Delivering effective well recompletion through team work

    Eric Risa, AKERBP

    Delivering effective well recompletion through team work

    Well failures in May and July 2017 resulted in removal of two Xmas Trees from operation and significant lost production. Recompletion was sanctioned, with a stretch target of production reinstatement within an opportunistic 61 day rig window in Q4 2017. Due to ambitious schedule targets rig intake, equipment preparation, procedure development and risk assessment were all placed on the critical path. Due to available equipment configuration bore depressurisation cycles required direction of fluids to the asset, increasing rig and asset simultaneous operations.A one team approach was used, with proactive engagement including asset, drilling, subsea and multiple suppliers. Process modelling of the planned operations provided an accurate execution framework for work to be performed within. Story board presentation of the key steps allowed optimization of the activity sequence, and clear basis for risk assessment. Changes to plan during execution were controlled through rigorous use of procedure updates, management of change and risk assessment. The operation also utilised an ROV piloted from shore to optimise offshore headcount. The workover was safely completed in December 2017, re-instating production from one of the wells and allowing onshore hardware investigation to be undertaken. The failed equipment was available for testing within a week of its recovery. Production was restarted within 5 months of failure. Around 100 lessons were captured during the work, to be used as basis for further well recompletion in 2018. This presentation will describe and explain how this success was achieved.

  • 10:30 - 11:00

    10:30 - 11:00, Track 1 @ Peer gynt

    Fast-Track Integrated Field Development: Optimizing and Accelerating Economic Project Returns

    Thomas Lindvig, ONESUBSEA

    Fast-Track Integrated Field Development: Optimizing and Accelerating Economic Project Returns

    Developing today’s subsea fields continues to grow in complexity. Most prospects are smaller yet located in deeper waters, with deeper well targets, located father from shore, and in colder regions. As a result, sanctioning projects in the current oil price environment is challenging, and adopting efficient field development plan (FDP) processes is essential to making projects viable. A fast-track FDP platform has been developed and used with great success on numerous projects worldwide. The platform integrates layout development and equipment selection with fully integrated pore to process simulation, establishes an excellent collaboration platform for the development team, and fully enables close collaboration between teams that traditionally do not work closely together. Subsea production system (SPS) and subsea umbilical, riser, and flowline (SURF) specialists can now work closely together with reservoir, production, and drilling engineers, ensuring the development of optimal solutions early in the FDP process while enabling the teams to overcome challenges that have previously been imposed by the segregation of the different technical disciplines. The key feature of this process is rapid, accurate scenario generation—that is, much shorter time from initial layout development to life-of-field production profiles that maximize overall economic performance for the project. The experience gathered to date clearly demonstrates that a fully integrated approach to field development is crucial for implementing the optimal development concept that maximizes returns on investment.

    10:30 - 11:00, Track 2 @ Klokkeklang

    Not all pipelines are made the same

    Lewis Kemp, WOODSIDE ENERGY

    Not all pipelines are made the same

    ‘Subsea pipeline design, construction and operational management has a long history, much of it associated with empirical formulae, analogue data and even ‘rule of thumb’. Specialist disciplines have been formed to capitalize on the computing power of day and enable detailed assessments of fatigue, bucking, stability and corrosion to be undertaken. Over the years there have been many incremental improvements in the design, construction and operation of subsea pipelines but where will we see the step change that the industry has been searching for? Can a digital twin approach to Subsea pipelines provide this step change? ‘Not all pipelines are made the same’ attempts to articulate the aspiration and, describe the journey that Woodside is currently undertaking to significantly change the way it builds and operates its subsea pipeline systems.’

    10:30 - 11:00, Track 3 @ Troldtog

    Low Cost Pipelines: unlocking the affordability of Long Subsea Tie-Backs

    Martin Davies, WOODSIDE ENERGY

    Low Cost Pipelines: unlocking the affordability of Long Subsea Tie-Backs

    As subsea tie back lengths increase, the cost of a pipeline systems becomes a significant portion of the capital expenditure for a long subsea tie backs. Our Long Subsea tie back technology program has predominately focused its attention on subsea electrification, flow assurance, subsea processing and boosting technologies. However, as step out distance to existing facilities increases the pipeline infrastructure dominates the affordability of the Long Subsea Tie-backs (LSTB). This begs the question – How do we move the dial to reset pipeline cost norms to enable commercialisation of remote and marginal field opportunity in the current economic climate? We believe to achieve a truly transformational result we must address every element of the pipeline activity set both individually and in an integrated system manner. This presentation describes a number of step change and disruptive cost reduction opportunities across the whole pipeline supply chain (engineering, procurement, Installation).

  • 11:00 - 11:25

    Coffee and exhibition

  • 11:25 - 12:25

    Panel debate: What does a digitalized future look like for subsea?

    Introduction by UTC Conference Moderators Wendy Lam, BHGE and Kristin N. Berg, DNV GL.
    Otso Juntunen, Regional Manager, GOOGLE CLOUD NORDICS
    Petter Jacob Jacobsen, Director of Customer Success, COGNITE
    Jeff Jensen, Chief Technical Officer, ARUNDO
    Mattew Guest, Head of Digital Strategy & Innovation EMEA, DELOITTE

  • 12:25 - 12:30

    Award for Best student presentation

  • 12:30 - 14:00

    Lunch and exhibition

  • Track 1 @ Peer gynt

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

    Track 1 @Peer Gynt

    Track 2 @ Klokkeklang

    DIGITALIZATION, POWER, CONTROLS AND UMBILICALS - SUBTOPIC

    Track 2 @Klokkeklang

    Track 3 @ Troldtog

    SURF, SPS AND MARINE OPERATIONS

    Track 3 @Troldtog

  • 14:00 - 14:30

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

    Equinor Strategy for Underwater Intervention Drone (UID™)

    Marianne Bryhni Asla, EQUINOR

    Equinor Strategy for Underwater Intervention Drone (UID™)

    The Equinor Underwater Intervention Drone (UID™) strategy describes the future use of remotely operated, semi-autonomous and autonomous underwater vehicles for subsea operations. The impact for Equinor will be higher production efficiency (PE), lower operational expenditure (OPEX), lower HSE risk and lower carbon footprint for new and existing oil and gas producing fields with subsea facilities and installations. The underwater intervention drone technology will be an enabler for more cost efficient field development for marginal fields and fields located in challenging conditions. A UID™ is a new collective term used for all types of underwater vehicles performing tasks under sea surface related to the oil and gas industry. The industry has many specific abbreviations for this type of vehicle e.g.; WROV, ROV, RROV, EROV, AUV, AIV, etc. UID™ is in this context a common name for all these abbreviations. The future UID™ is believed to be merging of the traditional ROVs and AUVs towards a vehicle manoeuvring in all directions and with hover capabilities in the sea column with remote control and/or autonomous programming. The future UID™ will be powered by an integrated battery and/or power source, that can be charged from a subsea docking station or by tether or umbilical to a structure that enables power and communication back to shore/control room/Operator. Typically, the UID™ can be operated from offshore (platform/vessel/rig) or onshore and can be submerged over longer periods (>one year). The paper will present a description of the UID™ concept and strategic approach to the industry.

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

    All-electric for well barrier elements

    Bjørn Søgård, DNV GL

    All-electric for well barrier elements

    Subsea all-electric has been discussed for at least 25 years, but has not yet been implemented to an industrial scale for well barrier elements. With the introduction of subsea compression stations, the default control and actuation principle is all-electric. However, for the simpler control system used for well barrier elements, the default selection is still electro-hydraulic where the actuation is provided by hydraulic power and the fail-safe close mechanism is obtained through energized springs. The introduction of all-electric systems challenges traditional thinking with respect to safety functions as well as day to day operation. Before going all-electric, equal or improved safety level, cost and uptime must be demonstrated. Benefits with all-electric control and actuation systems are less limitations for the step out distance, as well as being more robust for deep and ultra-deep waters. The current studies done by the industry reveal that the regulations are not necessarily well suited for this technology. This has also lead to a new NFR founded project (Safety 4.0) being launched with contribution from PSA, NTNU, UiS, DNV GL and several industrial partners. The outcome of this study is to provide new guidelines including requirements acceptable to the authorities. The presentation will compare all-electric to traditional electro-hydraulic design, discuss how all-electric challenges traditional safety principles, how the safety and operability of the (battery powered) system can be ensured (not least through improved monitoring features) and how to compare and evaluate prediction models of all-electric with existing field data for traditional design.

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

    Remote Operated Subsea Lifting Operations

    Asmund Saetre, AXTECH

    Remote Operated Subsea Lifting Operations

    Operating equipment on offshore vessels from a remote location has been a well-debated topic for many years. For long, this was just a wild idea, but the later year’s focus on digitalization and the introduction of a stable high-speed 4G mobile network in the North Sea suddenly brought it within range. The introduction of this technology and its opportunities made AXTech start an R&D project to develop different concepts for Remote Support and Operation. To test the concepts, AXTech set up a remote control room connected to one of our Module Handling Systems, enabling us to perform tests in a real life environment. The scope was not only to verify technology, but also to get hands-on experience on operating advanced lifting equipment from a distance as well as providing offshore operators audio and video support from onshore expert operators. We paid special interest in the user experience, thus audio and video became important topics, considering both traditional CCTV as well and use of modern technologies such as Augmented Reality and Body Cameras. We made some unexpected experiences but all in all the tests were successful and we believe that the tests are some of the first steps on the way to fully remote operations. We would like to present the findings we have made so far and share some of our experiences around Remote Operation and Support, Body Cameras and Augmented Reality in Subsea Lifting Operations

  • 14:30 - 15:00

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

    The Transformation of Underwater Vehicles; key to reducing IRM costs

    Wayne Sherry, SUBSEA 7

    The Transformation of Underwater Vehicles; key to reducing IRM costs

    Subsea Inspection Repair and Maintenance (IRM) services have traditionally been vessel-based, relying on Remotely Operated Vehicles (ROV) or Diver operations. The industry challenge to reduce costs is driving the development of new working practices, leveraging the latest in communications, system electrification and autonomous technologies to enhance underwater vehicle capability. The initial focus on qualification of ROVs operated from shore based control rooms and high speed survey vehicles is now being followed by investigations into seabed resident hybrid vehicles. The targeted benefits are Cost reduction, enabling Digitalization and condition based monitoring, reduced Environmental impact (eg. low carbon footprint), reduced HSE Risk and increased production efficiency. This paper comments on the current status of development and presents an overview of the equipment and technologies (both existing and to be developed) required to be in place to deliver the service benefits targeted.

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

    Functional Safety in All-Electric Subsea Control Systems

    Carsten Mahler, ONESUBSEA and Markus Glaser, AALEN UNIVERSITY

    Functional Safety in All-Electric Subsea Control Systems

    Objectives/Scope:

    This paper discusses a novel all-electric control system architecture that uses batteries instead of mechanical springs to provide the required energy for fail-safe valve actuation. To evaluate the reliability of the safety instrumented system, the functional safety principles are explored.

     

    Methods, Procedures, Process:

    The paper covers the analysis of functional safety principles when implemented in an all-electric control system. The paper considers the principles of probability of failure on demand (PFD), diagnostic coverage, hardware fault tolerance, component type, and functional safety management as well as the system’s capabilities in regards to these principles.

     

    Results, Observations, Conclusions:

    Functional safety and the related safety integrity level (SIL) are based on PFD, systematic capability, and functional safety management. The all-electric control system systematic capability is directly related to the redundancy concept, which can be used for safety, availability, or both. Because of its built-in diagnostics, the system offers an enormous degree of diagnostic coverage. Based on the component failure rates, the PFD can be calculated. The functional safety management requires dedicated activities throughout the development process. This is ensured by independent review personal. Depending on the desired SIL (e.g., SIL3), an independent review of the development ensures the compliance with the functional safety standard.

     

    Novel/Additive Information:

    The paper provides a detailed study of the functional safety principles of, their impact on, and a capability analysis of the all-electric control system.

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

    Creating efficient manufacturing requirements for subsea equipment.

    Gustav Heiberg, DNV GL

    Creating efficient manufacturing requirements for subsea equipment.

    The ability to produce oil and gas in the most cost-effective way will be an important going forward. To support this DNV GL have driven several standardization initiatives related to manufacturing og subsea equipment. One key initiative is a joint industry effort to prepare requirements for parts manufactured by additive manufacturing. We have found that additive manufacturing can open vast opportunities for customized parts and new supply chain setups. An important prerequisite is clear requirements for parts ensuring quality in the most cost effective way possible. For mature manufacturing processes like welding and forging DNV GL we have found that harmonized requirements can generate significant value. DNV GL have facilitated and industry wide undertaking to create harmonized requirements. For welding of subsea equipment significant progress has been made in the last 12 months. The DNV GL recommended practices for subsea forgings DNVGL-RP-0034 and DNVGL-RP-B202 has gained wide recognition and is being adopted throughout the industry. DNV GL have made valuable learnings from involvement in the implementation phase.

  • 15:00 - 15:30

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

    Freedom vehicle - The subsea transformer!

    Arve Iversen, OCEANEERING

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

    Subsea Digitalization – next generation of a control system for subsea processing and power distribution

    Karstein Berge Kristiansen, SIEMENS

    Subsea Digitalization – next generation of a control system for subsea processing and power distribution

    Demands for deterministic behavior, low latency, and high bandwidth would be the main requirements for the next generation of a subsea control systems. This paper presents a topology and a principal solution for a subsea control system fulfilling functional requirements for subsea processing and control of subsea power distribution networks. This paper aims to describe a setup for a control system for subsea usage based on open and available industrial communication and interface standards used in regular topside automation industry. No interfaces or communication methods are vendor specific. The next generation control system connects topside interfaces to the seabed, removing existing boundaries which will drive towards a system simplification and a communication infrastructure that allows connecting controls devices from different vendors. Removing the present boundary between topside and subsea control systems gives the opportunity to use the same digitalization portfolio for both topside and subsea installed parts/components. Diagnostic tools based on AI (Artificial Intelligence) are already available in regular topside automation portfolio from several different vendors and would be available for monitoring and diagnostic on subsea installed equipment in the proposed solution. Physical locations (subsea or topside) of data inputs/objects are irrelevant regarding functionality for the setup in the proposed solution. Introducing open industry standards in subsea control systems makes the proposed setup independent of company specific standards and interfaces, thus removing requirements for one vendor only setup. Subsea part of proposed setup could be interfaced to any topside control system utilizing standard communication protocols.

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

    Reactive Flex-Joint – a qualified and field proven solution for Wellhead fatigue challenges

    Knut Olav Sønåsen, TECHNIPFMC

    Reactive Flex-Joint – a qualified and field proven solution for Wellhead fatigue challenges

    Awareness of lower available Wellhead fatigue life increases as the industry gains more knowledge through analysis and tests. Loads on Wellhead are affected by vessel movements transferred through Marine Riser and Blow Out Preventer. These loads cause cyclical bending moments and Wellhead fatigue degradation. TechnipFMC has developed and qualified a unique technology to decrease cyclical bending moments for significant reduction of Wellhead fatigue damage. The presentation covers how TechnipFMC together with a main customer developed and qualified the Reactive Flex-Joint technology. The presentation contains results from the first subsea operation performed during an ongoing rig campaign.

  • 15:30 - 15:40

    Award for Best Abstract Presentation

  • 15:40 - 15:50

    @PEER GYNT - Summary and closing

    UTC Program Committee with Chairman Jon Arve Sværen and UTC Conference Moderators Wendy Lam, BHGE and Kristin N. Berg, DNV GL