-
09:00 - 10:20
Plenary - TBA
-
10:20 - 11:00
Track 1 - Peer Gynt
Coffee break & exhibition
10:20 - 11:00
11:00 - 13:00
Track 1 - Peer Gynt
Plenary - TBA
11:00 - 13:00
13:00 - 14:30
Track 1 - Peer Gynt
Lunch & exhibition
13:00 - 14:30
14:30 - 16:00
Track 1 - Peer Gynt
PARALLEL SESSION #1
14:30 - 16:00
14:30 - 15:00
Track 1 - Peer Gynt
Troll phase 3: A genuine Kinder Surprise
14:30 - 15:00
Rune Mode Ramberg, EQUINOR3. Brown field / tie-back technology
Track 2 - Klokkeklang
Large Connections for Norwegian gas Troll's
14:30 - 15:00
Ståle Størkersen, EQUINOR1. Field of the future
Track 3 - Troldtog
Worlds' Fastest Fail-Safe Wellhead Actuator
14:30 - 15:00
Espen Sten Johansen, TECHNI4. Green field / deep and ultra-deep subsea technology
15:00 - 15:30
Track 1 - Peer Gynt
Ormen Lange Phase 3 – Implementing Subsea Multiphase Compression
15:00 - 15:30
Arill S. Hagland, ONESUBSEA3. Brown field / tie-back technology
Track 2 - Klokkeklang
Reactive Flex Joint enabling cost effective satellite structures
15:00 - 15:30
Torunn Myhre, TECHNIPFMC1. Field of the future
Track 3 - Troldtog
A Winning Solution: Electrical BOP Technology
15:00 - 15:30
John Dale, ELECTRICAL SUBSEA & DRILLING4. Green field / deep and ultra-deep subsea technology
15:30 - 16:00
Track 1 - Peer Gynt
Subsea Boosting - 6 years of successful operating experience at Åsgard and Gullfaks fields
15:30 - 16:00
Caroline Roxane B. Harvengt, EQUINOR3. Brown field / tie-back technology
Track 2 - Klokkeklang
Wireless Sea Trial for Production Systems – A Seamless Integration with the AUV technology
15:30 - 16:00
Juliano Pimentel, AKER SOLUTIONS3. Brown field / tie-back technology
Track 3 - Troldtog
Toward Electrification in Oil & Gas Industry – The Role and Power of Engineering Simulation
15:30 - 16:00
Mostafa Valavi, EDRMEDESO4. Green field / deep and ultra-deep subsea technology
16:00 - 16:45
Track 1 - Peer Gynt
Coffee break & exhibition
16:00 - 16:45
16:45 - 18:15
Track 1 - Peer Gynt
PARALLEL SESSION #2
16:45 - 18:15
16:45 - 17:15
Track 1 - Peer Gynt
FASTsubsea - Topside-less "All Electric" Boosting System - Simple and Reliable
16:45 - 17:15
Alexander Fuglesang, FASTSUBSEA3. Brown field / tie-back technology
Track 2 - Klokkeklang
Improving Performance of Subsea Tie-in Operations by Means of Suitable Equipment Design Requirements
16:45 - 17:15
Victor Fonseca, PETROBRAS4. Green field / deep and ultra-deep subsea technology
Track 3 - Troldtog
Ready for Subsea Produced Water Treatment using Compact Flotation Technology
16:45 - 17:15
He Zhao, AKER SOLUTIONS1. Field of the future
17:15 - 17:45
Track 1 - Peer Gynt
Taking Hydrates Management to the Digital Age
17:15 - 17:45
Christophe Vielliard, ONESUBSEA3. Brown field / tie-back technology
Track 2 - Klokkeklang
Empig AS - The Cold Flow Enabler - Rethinking Flow Assurance
17:15 - 17:45
Lars Standal Strømmegjerde, EMPIG4. Green field / deep and ultra-deep subsea technology
Track 3 - Troldtog
New Technology – A DNV Type Approved solution of permanently repairing CRA Clad or Lined pipe with a mechanical connector
17:15 - 17:45
Chris Matthews, CONNECTOR SUBSEA SOLUTIONS1. Field of the future
17:45 - 18:15
Track 1 - Peer Gynt
Concept development for Next Generation subsea tie-backs in Equinor. Halten Øst project experience.
17:45 - 18:15
Anna Arteeva, EQUINOR3. Brown field / tie-back technology
Track 2 - Klokkeklang
Bacalhau – SURF in Deepwater Brazil
17:45 - 18:15
Grethe Malene Sagerup, EQUINOR4. Green field / deep and ultra-deep subsea technology
Track 3 - Troldtog
New Building Blocks for Subsea Plant Solutions
17:45 - 18:15
Sigbjørn Daasvatn, SUBSEA 71. Field of the future
20:00
Conference dinner
-
08:30 - 10:00
PARALLEL SESSION #3
-
08:30 - 09:00
Track 1 - Peer Gynt
How Equinor aims to improve quality and save cost for qualification of a new subsea compressor for Åsgard by introducing and qualifying a new clampon gas flow meter
08:30 - 09:00
Kenneth Olsvik, XSENS1. Field of the future
Track 2 - Klokkeklang
Quality Assurance of Digital Twins
08:30 - 09:00
Ketil Firing Hanssen, DNV GL1. Field of the future
Track 3 - Troldtog
Meeting challenges
08:30 - 09:00
Helge Sverre Eide, BLUE LOGIC1. Field of the future
-
09:00 - 09:30
Track 1 - Peer Gynt
Building Blocks to the Subsea Field of the Future
09:00 - 09:30
Mark Ausborn, EXXONMOBIL UPSTREAM RESEARCH COMPANY1. Field of the future
Track 2 - Klokkeklang
Sand monitoring in the cloud – how digitalization can be a game changer for sand detection systems
09:00 - 09:30
Anja Bilsbak, CLAMPON3. Brown field / tie-back technology
Track 3 - Troldtog
A State-Of-the-Art on Reliable and Cost-Effective Solution for Active Heating Flexible Pipe
09:00 - 09:30
Hany Elosta, TECHNIPFMC1. Field of the future
-
09:30 - 10:00
Track 1 - Peer Gynt
Innovation in the new contracting landscape
09:30 - 10:00
Neil Brown, SUBSEA 71. Field of the future
Track 2 - Klokkeklang
Holistic Production Enhancement to Support Subsea Field Life Extension
09:30 - 10:00
Mike Avery, ONESUBSEA3. Brown field / tie-back technology
Track 3 - Troldtog
Flexible Pipe Technology Developments for HPHT and FLIP
09:30 - 10:00
Colin Russell, BAKER HUGHES1. Field of the future
-
10:00 - 10:30
Coffee break & exhibition
-
10:30 - 12:00
Track 1 - Peer Gynt
PARALLEL SESSION #4
10:30 - 12:00
10:30 - 11:00
Track 1 - Peer Gynt
Can subsea technologies reduce CO2 emissions?
10:30 - 11:00
Ina Ekeberg, ONESUBSEA2. Subsea energy solutions
Track 2 - Klokkeklang
Transforming underwater inspection through Fast Digital Imaging, Unmanned Surface Vessels and Integrated Underwater Vehicles. The BP 2025 vision.
10:30 - 11:00
Eric Primeau, BP4. Green field / deep and ultra-deep subsea technology
Track 3 - Troldtog
Oscilay - New Technology for Umbilical and Power Cables
10:30 - 11:00
Ricardo Serafim, AKER SOLUTIONS2. Subsea energy solutions
11:00 - 11:30
Track 1 - Peer Gynt
Equinor - "Subsea ShuttleTM"
11:00 - 11:30
Kjell Einar Ellingsen, EQUINOR1. Field of the future
Track 2 - Klokkeklang
Development of an equipment centric subsea condition monitoring application - an operator's experience
11:00 - 11:30
Gregor Deans, TOTAL E&P4. Green field / deep and ultra-deep subsea technology
Track 3 - Troldtog
Technology Transfer Across Industries - a Case Study
11:00 - 11:30
Neil Douglas, VIPER INNOVATIONS2. Subsea energy solutions
11:30 - 12:00
Track 1 - Peer Gynt
Subsea Compression Powered by Renewables
11:30 - 12:00
Andrew Grant, AKER SOLUTIONS2. Subsea energy solutions
Track 2 - Klokkeklang
Locate subsea faults never found before using the C-Kore Subsea TDR
11:30 - 12:00
Mats Ekstrøm, C-KORE SYSTEMS4. Green field / deep and ultra-deep subsea technology
Track 3 - Troldtog
CO2SafeArrest – Cost efficient design requirements to avoid running fracture in CO2-pipelines
11:30 - 12:00
Bente Helen Leinum, DNV GL1. Field of the future
12:00 - 13:00
Lunch & exhibition
13:00 - 14:30
Plenary TBA
14:30 - 15:30
Meet & Mingle - TBA
Philippe Muguerra
SAIPEM
Subsea Factory System Engineer
Alex Rimmer
2H OFFSHORE ENGINEERING
Director
Eirik Duesten
PETROLEUM SAFETY AUTHORITY NORWAY
Principal Engineer
Karl Magnus Bengtsson
NEXANS NORWAY
Discipline Responsible XLPE Cables
Bente Helen Leinum
DNV GL
Senior Principal Engineer Operations Technology
Neil Douglas
VIPER INNOVATIONS
Director
Ricardo Serafim
AKER SOLUTIONS
Plm
Mats Ekstrøm
C-KORE SYSTEMS
Sales Manager Scandinavia
Gregor Deans
TOTAL E&P
Subsea Controls Specialist
Eric Primeau
BP
Senior Technical Specialist
Andrew Grant
AKER SOLUTIONS
Senior Process Engineer
Kjell Einar Ellingsen
EQUINOR
Lead Engineer
Ina Ekeberg
ONESUBSEA
Technical Sales Manager
Colin Russell
BAKER HUGHES
Flexible Pipe Product Line Manager
Hany Elosta
TECHNIPFMC
Surf Lead / Senior Specialist
Helge Sverre Eide
BLUE LOGIC
Business Manager
Mike Avery
ONESUBSEA
Sales Engineer
Anja Bilsbak
CLAMPON
Marketing Coordinator
Ketil Firing Hanssen
DNV GL
Principal Engineer
Neil Brown
SUBSEA 7
Innovation & Technology Manager
Mark Ausborn
EXXONMOBIL UPSTREAM RESEARCH COMPANY
Marine Technical Team Lead
Kenneth Olsvik
XSENS
VP Business Development
Anna Arteeva
EQUINOR
Project Manager
Christophe Vielliard
ONESUBSEA
Production Assurance Manager
Alexander Fuglesang
FASTSUBSEA
Founder & CEO
Grethe Malene Sagerup
EQUINOR
Project Manager
Lars Standal Strømmegjerde
EMPIG
CEO
Victor Fonseca
PETROBRAS
Subsea Engineer
Sigbjørn Daasvatn
SUBSEA 7
Strategic Technology Development Manager
Chris Matthews
CONNECTOR SUBSEA SOLUTIONS
Senior Design Engineer
He Zhao
AKER SOLUTIONS
Senior Specialist Engineer
Mostafa Valavi
EDRMEDESO
Senior Technical Consultant
John Dale
ELECTRICAL SUBSEA & DRILLING
CEO
Espen Sten Johansen
TECHNI
CCO
Caroline Roxane B. Harvengt
EQUINOR
Leading Advisor Subsea Processing
Arill S. Hagland
ONESUBSEA
Technical Sales Manager
Rune Mode Ramberg
EQUINOR
Project Manager
Juliano Pimentel
AKER SOLUTIONS
First Chief Engineer
Torunn Myhre
TECHNIPFMC
Engineering Manager
Ståle Størkersen
EQUINOR
Advisor
Philippe Muguerra
SAIPEM
Subsea Factory System Engineer
How Technology Enables a Lower Cost for Subsea Tiebacks
"This paper aims to present a number of new technologies, their qualification status, and how they can enable cost reductions for a dedicated field development. Technologies, developed in recent years, play a significant role not only in solving the technical challenges, but also in finding a cost-effective configuration. In order to appreciate these advantages, different configurations have been outlined starting from those allowed by the conventional technologies and comparing them to the ones enabled by the new technologies. These alternative configurations can be identified in a timely manner thanks to early Contractor involvement in design and pricing for subsea tie-backs. The paper will present a platform of technologies, their maturity status and how they can be integrated in novel architectures in an economic manner. Such technologies include: • Subsea chemical storage and injection • All electric control systems • Barrier fluidless pumps • Distributed and local flowline heating • Subsea water injection • Subsea separation • Floating windfarms"
Alex Rimmer
2H OFFSHORE ENGINEERING
Director
Riser Innovation And Influence on Future Subsea Fields in Norway
"Field developments in Norway with floating platform facilities are dominated by Flexible riser systems. Of riser systems installed from floating platforms in Norway, only a handful of rigid risers have been installed. The choice and dominance of flexible risers is driven by the combination of the shallow to moderately deep water depths, harsh environmental conditions, and established supply route and ease of installation. A number of riser innovations may, however, change this landscape for future field developments and address some of the limitations in size, operating pressures and maintain integrity of flexible risers. Namely advances in the design and configuration of rigid steel risers and progress in the use of composite materials as an alternative to flexible risers. In the case of rigid risers, solutions have been developed (including distributed buoyancy) that can compete on structural performance in moderate water depths typical of offshore Norway, install-ability and cost. With thermoplastic composite pipe, there has been progress towards getting the right characteristics from composite pipes to enable their use in riser systems, subject to qualification. In this paper, an overview will be provided of the typical types of riser systems used in field developments worldwide, the factors driving selection of the risers and the current landscape of risers in Norway. Further, the new riser technologies and enabling alternative configurations will be presented along with the influence on reducing costs and future field developments in Norway"
Eirik Duesten
PETROLEUM SAFETY AUTHORITY NORWAY
Principal Engineer
Requirements for subsea leak detection
"Section 57 Detection and mapping of acute pollution in the Activity Regulations was updated last year. The purpose of the change was to clarify the operators' responsibility for detecting acute pollution. In 2020 Norwegian Environment Agency and Petroleum Safety Authority Norway will conduct a joint campaign auditing the operators' compliance with section 57. The requirements for detection are described in the guideline to Section 57 of the Activity Regulations. E.g. “… The requirements for detection and acute pollution monitoring include all types of pollution (oil, cuttings, oily water, chemicals, etc.) and all parts of the environment (sea surface, water column, seabed, air). Monitoring of injection activity is also covered by this provision…” “…The operator must assess the types and amounts of pollution that can be detected / mapped using the barriers and safety funtions…” “…Continuous monitoring may include all or part of the facilities and areas around. For example, through radar systems on the surface and leak detection systems that cover parts of facilities on the seabed…” In the presentation the Norwegian Environment Agency and the Petroleum Safety Authority Norway will address the background for the requirements in section 57, and our the expectations with regards to the industry's systems to detect acute pollution. Furthermore, representative RNNP data for acute spills will be included, and the main topics for the audit campaign will be highlighted. "
Karl Magnus Bengtsson
NEXANS NORWAY
Discipline Responsible XLPE Cables
High voltage wet designed XLPE submarine cables
"The objective of this work is to qualify high voltage power cables of wet design i.e. a design allowing water vapour to permeate into the crosslinked polyethylene (XLPE) insulation system during service. Today medium voltage power cables (up to and including 36 kV) are usually of wet design while a radial metallic water barrier, often a lead sheath, is used for higher voltages operated at higher electrical stresses. There is a need in the offshore wind and in other renewable segments for cost effective and reliable static and dynamic high voltage power cables. High voltage cables of wet design will meet the requirement of a cost-effective design and will also be an attractive solution for dynamic cables where the metallic water barrier can be an issue regarding mechanical fatigue. A wet designed power cable will also reduce the weight of the cable. This will be advantageous regarding the needed number of installation campaigns, which are a major time and cost element for long subsea power cables. In addition, omission of lead, which is the most common metallic water barrier for static high voltage cables, will reduce the environmental impact. A new Cigré recommendation TB722 has been released in April 2018 with a qualification program for wet including high voltage dielectrics (Um = 7.2–72.5kV) to be operated in sea water. In short terms, the qualification is based on electrical ageing of cable cores soaked in a sea water substitute at 40°C. The ageing performance is characterised by electrical breakdown voltage testing. "
Bente Helen Leinum
DNV GL
Senior Principal Engineer Operations Technology
CO2SafeArrest – Cost efficient design requirements to avoid running fracture in CO2-pipelines
"Results from large-scale running ductile fracture tests have been used to propose new design requirements for crack arrest in CO2 pipelines and updates of DNVGL-RP-F104. Transport of CO2 in pipelines from capture site to storage site forms an important link in the overall CCS scheme. However, the costs of pipelines are significant, where material costs are a major part. The thermodynamic properties of CO2 are different from those of e.g. natural gas that are transported in pipelines and recent full-scale burst tests from the projects SARCO2 and COOLTRANS point to significant difference in terms of fracture arrest behaviour. The CO2SafeArrest Joint industry project (JIP) aims to investigate the fracture propagation and arrest characteristics of CO2 carrying steel pipelines with the purpose to establish cost efficient design requirements. Full-scale fracture propagation testing is essential to understand ductile fracture propagation/arrest behaviour of pipelines and to provide input to models and requirements for crack arrest. The ductile fracture propagation and arrest is studied on 24” X65 pipe strings with a predominant nominal wall thickness of 13.5 mm and 14.5 mm, respectively. This presentation provides an outline of the overall CO2SafeArrest project including videos showing a full scale running ductile fracture. The outcome from the JIP will be made available in a new updated DNVGL-RP-F101 ‘Design and operation of carbon dioxide pipelines’. An outstanding issue is development of procedures for evaluation of possible re-use of existing pipelines. DNVGL Co-Authors: Sigbjørn Røneid; Principal Specialist - Pipeline Technology, Erling Østby Principal Specialist - Fracture Mechanics "
Neil Douglas
VIPER INNOVATIONS
Director
Technology Transfer Across Industries - a Case Study
"Degradation of electrical insulation resistance in subsea cables, connectors, and umbilicals is an industry problem on a global basis. Between 2013 and 2018 Viper Innovations completed a JIP development that was sponsored by five Super Major Operators. The technology has subsequently been utilised in subsea applications to monitor electrical integrity and to locate electrical failures and degradation. Between 2016 and 2019, the core monitoring technology has been adapted to create an electrical integrity monitoring product for the railway industry, which has been successfully trialled by Network Rail in the UK. The route to diversification into another industry has demonstrated that the processes, quality systems, and expertise that are demanded by the subsea oil and gas industry facilitate the move into other highly engineered business sectors. The purpose of the paper is to share some of the key decisions and initiatives that have been cruicial to the success of the diversification. In addition, continued technical developments that have been made for the railway applications will be transitioned back into the oil and gas sector to further benefit those Operators who initially supported the JIP. This is a success story of a cross-industry technology transfer. "
Ricardo Serafim
AKER SOLUTIONS
Plm
Oscilay - New Technology for Umbilical and Power Cables
"The conventional way to manufacture umbilicals is to use planetary reels that rotates about center of the umbilical during closing operation. Having to rotate, planetary reels are subjected to weight and volume limitations. That means the reels have to be replaced regularly and the umbilical spliced. This hamper the productivity as splicing takes time and has associated quality risks. Aker Solutions has solved this problem by developing an innovative manufacturing technology dubbed Oscilay. By having the reels statically placed on the ground – with no rotation – Oscilay represents a new bundling principle. This principle is based on an alternating helix made possible by periodically changing the lay direction during the bundling operation. The benefits are many; however a main benefit is that we can allow no splicing of electrical power cores during the bundling process given no weight restriction usually associated with horizontal or vertical planetary machines. This provides a step change in delivery time while reducing risk since any number of elements could be assembled into a power cable in a single pass through the machine. To give an example, Aker Solutions has manufactured and qualified according to API 17E a umbilical prototype for use in 3 000 m water depth that included 3 variations of the same cross section with no splicing. Such lengths would also require sophisticated armoring provided by Aker Solutions' patented carbon fiber rod technology. In this presentation we will show results from the latest testing together with relevant KPIs on the production performance."
Mats Ekstrøm
C-KORE SYSTEMS
Sales Manager Scandinavia
Locate subsea faults never found before using the C-Kore Subsea TDR
"With subsea oilfields aging and becoming increasingly complex, operators need new technologies to quickly and cost efficiently locate faults in their subsea networks. This talk will discuss how C-Kore Subsea TDR technology can be used to rapidly pinpoint faults in subsea electrical systems. Traditional TDR testing employs deck-based equipment connected to the subsea infrastructure via down-lines, a procedure with many disadvantages. A significant issue is that downlines introduce additional attenuation and reflections in the measured data making test results hard to interpret. It can be impossible to differentiate between the end of the downline and a near-end fault inside the subsea structure, as the reflections have been delayed, flattened and attenuated by the downline. The deck-based TDR also requires a highly skilled operator. Working under difficult conditions, saved data usually only consists of a low-resolution screenshot or photograph of the TDR display. The C-Kore Subsea TDR solves these problems in two ways: by taking all TDR measurements directly at the subsea interface and by automating the testing process. This eliminates impedance mismatches and additional attenuation normally introduced by downlines. With the gathered data, near-end faults can be clearly identified. Thanks to the automation, offshore personnel do not need to have expertise on how to perform TDR measurements. The C-Kore Subsea TDR also always saves full length high-resolution traces for subsequent analysis using the simple C-Kore software. Case studies will be presented where operators have located subsea faults using the C-Kore Subsea TDR that could not be found using traditional techniques. "
Gregor Deans
TOTAL E&P
Subsea Controls Specialist
Development of an equipment centric subsea condition monitoring application - an operator's experience
"Currently the vast volume of subsea data cannot be monitored manually by Operations teams offshore and onshore which makes prediction, detection and analysis of subsea integrity issues difficult. Identifying problems with subsea equipment prior to failure can result in a reduction in deferred production and significant savings in offshore repair campaigns, sparing philosophies and reduce damage to subsea infrastructure. Automated condition monitoring is essential to maintain equipment availability and therefore production availability and a project was launched within the Total Deepwater Product Line to develop a suite of generic, equipment-centric monitoring tools (SUBCM) which could be used across all Total subsea assets. This paper will detail the development process for the SUBCM tools within Total, experience with data management and data quality, examples of the tools developed and analysis results and feedback from the final users in the field , the Operations teams. The paper shall also cover the pros and cons of the development of these tools internally rather than using 3rd party tools."
Eric Primeau
BP
Senior Technical Specialist
Transforming underwater inspection through Fast Digital Imaging, Unmanned Surface Vessels and Integrated Underwater Vehicles. The BP 2025 vision.
"Configuring Fast Digital Imaging (FDI) sensor packages onboard underwater vehicles has delivered inspection data up to 8 times faster than traditional inspection methodologies. This impacts time at sea, hence reduction in carbon emissions, risk and cost. FDI techniques replace video with high definition stills imagery / laser points cloud and contact cathodic protection measurement with field gradient. FDI is a technique, not an inspection criterion, delivering Fast General Visual Inspection (FGVI) or General Visual Inspection (GVI) dependent upon system configuration. BP has implemented FDI techniques since 2017 in the North Sea, Trinidad & Tobago and Azerbaijan. FDI technology is a gamechanger for the underwater inspection industry and is progressively being adopted by other operators and asset owners. FDI is also an enabling technology for Unmanned Surface Vessels (USV) and remotely operated underwater vehicles, controlled from shore based Remote Operations Centres (ROC). BP has utilised USV technology in the North Sea for data harvesting and shallow water pipeline inspection, and in Azerbaijan with 900 kilometres of acoustic pipeline inspection completed employing USVs. BP is committed to FDI and integrated USV technology for underwater inspection and has a stated goal that by 2025 all inspections will performed by unmanned remotely operated systems. This presentation outlines BP experience in brokering these technologies, how new data formats feed into the inspection cycle and how FDI and USVs with integrated underwater vehicles will transform the inspection industry in the coming years. "
Andrew Grant
AKER SOLUTIONS
Senior Process Engineer
Subsea Compression Powered by Renewables
"Subsea Compression is undoubtedly a low-carbon alternative to onshore/topside compression. In addition to the fact that placing the compressor(s) closer to the source results in less compressor shaft power being required, the fact that a subsea compressor is always electrically driven means that if energy used to power the compressor can be drawn from a renewable source, there will be no ongoing CO2 emissions associated with the gas produced. Often it is the operator’s desire to keep the compressor(s) running continuously, however if this requirement can be relaxed, it is possible to develop a highly robust compression system with intermittent power supply by adjusting compressor speed to make use of the power available. Taking the example of a subsea compression system powered by wind, there are several operating states that can be accommodated by the station: - In low/no wind periods, the compressor(s) can be powered-down and wellfluid may bypass the station; - In medium wind periods, compressor(s) can operate at lower speed, or in a multi-compressor system, some compressors could be operational whilst others are not; - In high wind periods, all compressors can operate with high power. During these periods, if the desired production rate is less than what can be produced, there are options to make use of the excess energy, e.g. by charging of batteries or gas line packing. The paper will discuss the design of such systems and compare with alternatives, thereby providing an additional path for decarbonizing the oil and gas industry."
Kjell Einar Ellingsen
EQUINOR
Lead Engineer
Equinor - "Subsea ShuttleTM"
"Equinor “Subsea ShuttleTM” UTC 2020 Abstract Key learning outcome: Subsea ShuttleTM is a large autonomous/remotely operated submarine for liquid transportation, running on renewable energy, at a constant depth. The Subsea ShuttleTM is an autonomous/remotely operated, underwater fluid tanker powered by renewable energy. It is essentially a supersized underwater cargo drone. Increased transport flexibility and zero carbon emissions in a subsea environment, are attractive aspects of this concept. The concept is intended to be an attractive alternative to pipelines and surface tanker concept for fluid transportation. This is why the Subsea ShuttleTM effort is directed towards CO2 transportation related to future Carbon Capture and Storage (CCS). It may transport liquid CO2, or other fluids, from a subsea docking station at loading point to a similar subsea dockings station at off-loading point. Scalable in size and number, safe and predictable since operating at constant depth deep and away from human interaction and weather impact, re-usable with minimum environmental impact The concept has 2 main technical aspects; the Subsea ShuttleTM as a vessel, and the Subsea ShuttleTM as a transportation system solution involving multiple vessels and on/off loading stations. This presentation will cover both aspects, with the focus on the overall transportation system solution. This is the first announcement of an innovative future offshore transportation concept, currently under development in Equinor`s Innovation KitchenTM. " Co-presenter: Ola Ravndal
Ina Ekeberg
ONESUBSEA
Technical Sales Manager
Can subsea technologies reduce CO2 emissions?
"Reducing CO2 emissions and environmental footprint are governing the road maps of oil and gas operators. The main drivers are the UN sustainable development goals. Taxes on CO2 emissions as well as funding for environmentally friendly oil and gas production are two effective means to reach the targets. The offshore oil and gas sector has been facing the green shift in several ways. The key strategy in NCS is supply of environmentally friendly energy to the production facilities, in form of offshore wind turbines or connecting the platform to the onshore power grid. Considerable investments in carbon capture and storage technology are also done. Another way of reducing the CO2 footprint, is by energy efficiency. Subsea boosting and compression can offer remarkable energy and CO2 savings per unit produced oil and gas, compared with conventional lifting methods. The associated benefit of improved production should be well known. This presentation will show that 75% of the energy consumed for lifting oil to the surface can be saved by applying subsea boosting pumps. Looking at gas production, subsea compressors enable even greater savings. In addition to the fact that compressing high-pressure subsea gas is much less energy demanding than compressing low-pressure topside gas, subsea compression also enables lower wellhead pressure and hence larger recovery than topside solutions. Energy savings are important also when energy is supplied from the onshore power grid. Subsea boosting can save energy equivalent to 20 000 households in one single application. "
Colin Russell
BAKER HUGHES
Flexible Pipe Product Line Manager
Flexible Pipe Technology Developments for HPHT and FLIP
"Offshore oil and gas fields increasingly require advances in technology to enable their development. Baker Hughes is continually advancing its flexible pipe technology to meet the demands of the market and this presentation will outline the status of two such developments: a new layer for preventing the conditions that lead to Flow Induced Pulsations (FLIP) in gas risers; and a new polymer material with an increased pressure and temperature capability. If FLIP occurs in gas risers it can lead to excessive vibration, and potentially failure, of small-bore topsides and subsea pipework. The phenomenon is caused by the interaction of the gas with the rough surface of a traditional flexible and the most effective way to deal with it is to remove it at the source. This is achieved by the use of a new layer, called Flex-Insert, which is inserted inside the carcass layer and changes the internal shape of the pipe. The use of Flex-Insert removes the issues associated with FLIP, which can include limitations on flow rate and/or costly modifications to existing subsea infrastructure, thereby offering significant value to the operator. There is an increased demand in the industry for flexible risers with higher design pressure and temperatures. Baker Hughes are developing a new pressure sheath material, called Flex130, to meet this demand, which will be suitable for design temperatures of 140ºC and pressures of 12,500 psi. The presentation will outline the status of both these programs."
Hany Elosta
TECHNIPFMC
Surf Lead / Senior Specialist
A State-Of-the-Art on Reliable and Cost-Effective Solution for Active Heating Flexible Pipe
"Integrated Production Bundle (ETH-IPB) and Heating Cables Replacing Armour Wires (ETH-HCRAW) have been developed to address the flow assurance challenges, these two technologies are using electrical cables with long industry track records, which provide heat to the fluid by the Joule effect. They are different in their design, efficiency and cost, and thus on their application domains. ETH-HCRAW is an attractive and cost effective active heating solution with a broad possible domain of application. This technology offers many advantages in terms of flexibility of operation, especially for hydrate and wax management. ETH-HCRAW facilitates the exploitation of deep water projects and long tie back by limiting the temperature losses along the lines. Such a solution, based on integrated electrical cables, has been demonstrated to be a safe and effective technology for active heating on flexible pipe through dedicated R&D development in the early 2000’s. The first flexible pipe with active heating technology ETH-HCRAW is fully developed, the design, qualification and the identified application envelope will be presented. The overall qualification of this technology is described considering two different levels. Firstly, the qualification of the components of the electrical system through extensive electrical and mechanical tests and then, the global mechanical behaviour and the reliability of the overall system are demonstrated by a phase of full scale tests. This work presents the latest developments that enable the ETH-HCRAW technology to be positioned as a leading solution for active heating with the advantages of flexible pipes. "
Helge Sverre Eide
BLUE LOGIC
Business Manager
Meeting challenges
"The last 12 months has seen rapid advances in underwater drone technology. Vehicles that were just concepts two or three years ago are due to enter commercial operation this year, paving the way for sustainable and intelligent fields for the future. The industry has come a long way. But, we’re only just at the start and there will still be hurdles. Blue Logic is playing a key role in supporting underwater drone technology development, providing the inductive technology that enables these vehicles to dock, charge and share data. We’ve designed and built the first open standard subsea docking stations with a design available to anyone and already proven with multiple vendor vehicles. We’re also driving work with the API, SWiG and DeepStar groups, to agree mechanical, electrical and communications standards, so these technologies can used across fields and operators. We will present the key achievements and innovations to date, as well as lessons learned. We’ll also outline the elements that still need to be put in place to truly enable the field for the future, including the architectures which will enable drones to dock into third party infrastructure and still connect seamlessly with their control rooms. We’ll also demonstrate how inductive technology can further enable these vehicles by providing hot-swappable tooling capability. We believe a mindset change is needed towards the design of subsea production systems and the business models that support them if subsea robotics’ full benefits are to be unlocked and their potential unleashed for other ocean industries."
Mike Avery
ONESUBSEA
Sales Engineer
Holistic Production Enhancement to Support Subsea Field Life Extension
"A holistic approach to production enhancement can help to sustain existing fields, allowing operators to cost-effectively unlock additional reserves. The implementation of such a philosophy is key to supporting optimization of a subsea well’s performance. An example from the UK North Sea shall be shared to demonstrate real world application. The operator utilized a patented choke access technology to install retrofit sensors upon a subsea production tree in order to prolong the operating life of a well by multiple years; this action alone unlocked significant hydrocarbon volumes. Following abandonment of the well, the retrofit package was recovered, refurbished, and installed upon another tree experiencing similar challenges. Without this innovative solution, the wells would have been shut-in. In parallel with this production well life extension, several water injector wells were stimulated using an innovative open-water hydraulic access technology. These treatments performed during 2018 provided injectivity improvements of over 300%. Due to the huge success rates, on-going stimulations are planned with a view to extend the efforts to production wells. To proactively support the field, an advanced retrofit module is currently undergoing detailed design. This package will deliver extended flexibility to the operator, permitting the cost-effective introduction of new technology, with an optimized hydraulic intervention point for on-going reservoir management. The combined impact of these discrete but interlinked activities has enabled significant additional production from the field. The ability to combine these unique elements together in a coordinated offering, enables truly holistic production enhancement over the life of field."
Anja Bilsbak
CLAMPON
Marketing Coordinator
Sand monitoring in the cloud – how digitalization can be a game changer for sand detection systems
"21 years ago when the first ClampOn subsea sand detectors were supplied, the acoustic sand detector basically provided a stand-alone sand alarm. Since then many improvements have been made on the instrument’s technology, mainly on improving its performance and reliability. With the current focus on digitalization, it is time to look at how subsea sand detection data in the cloud may improve monitoring and well productivity. Digitalization enables new possibilities – and acoustic sand detection systems can be smarter and more accurate through machine learning. And besides measuring sand, the measurement of both of sound and movement by the ASD (Acoustic Sand Detector) can be used for other purposes, for example in a condition monitoring system. Combining different readings in a cloud based configuration is a potential game change, opening up for more computerized intelligence, providing a smarter system with more information than “just sand”."
Ketil Firing Hanssen
DNV GL
Principal Engineer
Quality Assurance of Digital Twins
"Building robust digital twins that can be used for operational decisions, is a key industrial challenge. As a response to this challenge DNV GL is currently developing a recommended practice for development and assurance of digital twins together with TechnipFMC. Digital twins mirroring physical assets are increasingly being applied in the oil and gas industry. Providing a digital twin as part of a field delivery is more and more often being required by the operators. Whereas digital twins will impact decisions from early design to decommissioning, the full value of the digital twin will only be capitalized if there is evidence that the digital twin will function as specified. Lack of trust will limit the value gained from the digital twin. There is currently no common agreed standard that a digital twin can be developed and delivered according to. DNV GL has responded to this challenge by establishing a recommended practice for quality assurance of digital twins, where the criticality of the twin in terms of input to decision support will govern the amount and level of activities to assure the quality of the twin. To be able to take full advantage of the twin during the operational phase, it must be confirmed that data and algorithm quality remains within required limits, and that changes to the physical asset are reflected in the digital twin. An important feature of the recommended practice is therefore an in-operation quality index, showing the actual confidence level of the output from the digital twin."
Neil Brown
SUBSEA 7
Innovation & Technology Manager
Innovation in the new contracting landscape
"There has been a rapid increase in early-phase engagement activities between operators, their partners and Tier 1 contractors. This is intended to deliver cost reductions through reducing interface costs, as well as schedule acceleration through improved planning and execution. We are now seeing additional benefits through the ability of Tier 1 contractors to rapidly identify optimal field architectures through linking reservoir drainage strategies to optimal field layouts and new technologies. With this capability established within the Tier 1 contractor organisations, we are positioned well for a new phase in the evolution of the procurement of infrastructure. The increase in the volume of contracts that enable contractor led solutions has provided the climate for Contractors to align market strategy to an associated set of product strategies and then a re-configured supply chain. This paper presents a set of opportunities tied to the closer integration of market, product and supply chain strategies, and the ability to establish approaches to modularity and interface standardisation. The opportunities include more rapid adoption of new technologies, as well as capturing value through innovations in the supply chain eco-system. The outcomes are likely to be reduced schedules and an enhanced balance of functionality and risk within a generation of modular subsea products integrated with standardised interfaces. The paper will highlight the potential emergence of alternative business models (e.g. leasing) as well as data driven strategies for operational management that enable re-use, an alternative view on the field of the future. "
Mark Ausborn
EXXONMOBIL UPSTREAM RESEARCH COMPANY
Marine Technical Team Lead
Building Blocks to the Subsea Field of the Future
"Sensing, automation, communication, and robotic system capabilities have advanced significantly in the recent past, yet these new capabilities have not been fully utilized in the oil and gas industry. The new capabilities with technology advancement have great potential to perform new tasks or optimize the design of subsea equipment. ExxonMobil is looking to define the subsea field of the future by examining how technology advances can be fully leveraged to drive future subsea field designs. This study examines relevant current and future technologies such as resident ROV/AUVs, subsea inspection and sensors, “through water” communication, navigation technologies, etc. It is then determined how these technologies can be leveraged to best meet the functional requirements of the subsea system. The study goal is to reduce the constraint of fitting new technology into existing subsea field designs, and open the possibility of re-designing subsea equipment to take full advantage of these technologies. A range of applications will be examined, from implementation of existing technology into a brownfield application, up to implementation of future, “blue sky” technologies to redefine how a subsea field may be designed and operated. The value proposition and risk profile of the potential applications will be also assessed to identify those technologies with the highest impact. Co-authors: Dmitri Matskevitch and Tao Cheng "
Kenneth Olsvik
XSENS
VP Business Development
How Equinor aims to improve quality and save cost for qualification of a new subsea compressor for Åsgard by introducing and qualifying a new clampon gas flow meter
"During the project planning of retrofitting the Åsgard field with an upgraded subsea compressor, the Åsgard Subsea Compression Phase II, an early challenge was revealed in how to measure the flow rates in the cooling gas system without introducing an extra pressure loss and additional flanges. Equinor needed a Flow Meter that would measure gas with high accuracy on several of the cooling gas pipelines. If this could be a clamped-on type, the cost would be reduced and quality improved (no new pressure loss introduced). Xsens AS had already developed a new clamp-on ultrasonic flow Meter that could measure the full velocity profile similar to an inline ultrasonic Meter for liquid and was asked if this could be utilized for gas with small amounts of liquid present. This ended up in a project where the Meter was tested at Equinor`s test site named K-lab (located at Kårstø Gas Processing Plant) and qualified through a blind test. The tests confirmed that the accuracy was well within Equinor`s requirements. The paper will describe Equinor`s challenge to measure the correct gas flow rates in the subsea compressor cooling gas system, the technology behind the Xsens clampon Flow Meter, results from the testing of a such a meter and how these Subsea Meters are now being built and used in the upcoming qualification of a new subsea compressor. "
Anna Arteeva
EQUINOR
Project Manager
Concept development for small subsea tie-backs at Equinor. Halten Øst project experience
"Small tie-back projects are growing in number at Equinor and on NCS in general. Making small discoveries profitable is a challenge though, and developing marginal tie-in fields requires significant cost reduction. Maximising total recovery of oil and gas is also an important factor. All of this calls for new technical solutions and new ways of working. Halten Øst (HØ) is one of many small tie-back projects in Equinor's early phase portfolio. HØ business case comprises a development of several small discoveries and prospects around the Midgard and Mikkel area with tie-back to Åsgard Subsea Compressor infrastructure. The main challenge for HØ is to ensure an economically robust development. After several iterations, HØ has already managed to lower its break-even by 30%. The presentation will address the measures that have made this possible, and how this strengthens the business cases for similar small tie-back projects."
Christophe Vielliard
ONESUBSEA
Production Assurance Manager
Taking Hydrates Management to the Digital Age
"The Zohr subsea production system, around 180 km off the coast of Egypt in 1,500-m water depth, was configured with a novel metering system providing the necessary functionalities for optimized hydrate inhibition, as a conventional approach would have had a significant impact on the technical and financial viability of the development. A data interpretation model was developed for the subsea water analysis sensor based on flow loop testing and analytical methods, allowing for real-time measurement of the MEG dosage for each well. Flow assurance modeling was performed to validate subsea measurements, and to explore model limitations and enhancements. Field data comparisons provided unprecedented insight into unexpected reservoir behavior several weeks faster than measuring fluids arriving onshore, considering the 220-km tieback distance. Indeed, the produced fluids at startup contained water at an order of magnitude more than initially expected, which would normally have resulted in underinhibition and a possible hydrate blockage risk. The subsea measurement system allows for MEG dosage to be monitored and injection flow rates to be adjusted in real time, from the first day of production, to respond to the fluids produced subsea. Data analytics were applied to validate the measurements obtained, identify trends, and anticipate onshore fluid arrival conditions weeks in advance. This is the first time in the industry that direct hydrate inhibitor concentration monitoring and control, aimed at real-time hydrate management, has been achieved subsea. This pioneering application of subsea technology is a game changer that will enable unlocking additional long-distance deepwater gas reserves."
Alexander Fuglesang
FASTSUBSEA
Founder & CEO
FASTsubsea - Topside-less "All Electric" Boosting System - Simple and Reliable
"FASTsubsea, a Joint Venture between FSubsea and Aker Solutions, is marrying the best technology from each company to make the simplest, most cost effective, autonomous and sustainable subsea multiphase pumping (MPP) system available. The ""topside-less"" and ""VSD-less"" MPP system will be targeted mainly at brownfields, tie-backs and marginal or distributed new fields, where traditional systems are often costly to install. As the FASTsubsea booster eliminates the need for the majority of topside support equipment and does not require any hydraulic umbilical or fragilebarrier-fluid system, it will have 50-70% lower capex cost than conventional systems. Furthermore it will have an improved environmental profile, as there in some cases will be no need for platform (topside) and no risk of any hydraulic spillage to sea (hermetically sealed unit). Other benefits include being able to serve several pumps from one common power cable, as opposed to the current method of having dedicated power & fluid umbilicals from each topside power and control module to each pump. Aker Solutions contributes with its qualified (TRL-5) MultiBooster pump hydraulics and FSubsea contributes with the innovative Hydromag drive system. Much of the testing of these technologies is already completed (fresh data can be shared at UTC 2020). The Pump Module will be freely available in the market to operators and all subsea EPC contractors by mid 2022. Three major operators have provided LOIs to joint the pilot testing and 11 MNOK has been granted from the Demo2000 program in December 2019. "
Grethe Malene Sagerup
EQUINOR
Project Manager
Bacalhau – SURF in Deepwater Brazil
"Bacalhau is a new deep water field development project in Brazil located in Santos basin 220km from shore, in pre-salt Carbonate reservoir area (high pressure). The concept consist of a spread-moored FPSO, steel-lazy wave risers and flowlines for production, water injection and gas injection. The field is planned with 19 single wells tied-in to the flowlines via inline manifolds (11 Producers, 4 Water- and 4 Gas-injectors). The presentation will cover the characteristics of the field, the field development process to accommodate the field requirements and the main characteristics of the solutions. Equinor has built on its extensive experience from field development in Norway and production experience from Peregrino in Brazil. In addition to partner experience and utilizing contractors with local presence and knowledge. The selected concept and development strategy has been done in tight dialogue with authorities. Final investment decision is planned December 2020. "
Lars Standal Strømmegjerde
EMPIG
CEO
Empig AS - The Cold Flow Enabler - Rethinking Flow Assurance
"Empig AS develops flow assurance technology for the future. The core technology is a subsea system for cooling and stabilization of hydrocarbon flow from a reservoir (HP/HT), enabling long distance transport, with no potential for wax and hydrate formation in tieback flowlines. Empig enables Cold Flow. In the heart of the system is an Always Clean Cooler System (ACS), a compact cooler unit, where warm hydrocarbons flowing from the reservoir are cooled below WAT/HAT. All potential for wax and hydrate formation is localized, and solidified, in the cooler unit. The fluids leaving the cooler has no potential for further precipitation downstream. A key feature of the technology is seeding of solid wax and hydrate particles, serving as catalysts for crystallization of wax and hydrate particles in the bulk flow. Empig has adopted the seeding technology from SINTEF, our R&D-partner with 30+ years of experience on the topic. At certain conditions part of the precipitates will deposit at the inner surface of the cooling pipes. Any deposit is removed in a solid state, using inductive heating. The inductive heater moves along the pipes using an autonomous subsea robotic system. The solid-state particles are carried by the stabilized flow to receiving facilities. In 2019 Empig ended a JIP (PETROMAKS2) where Proof of Concept, and TRL4 (0-7), was achieved for the core technology. The company was recently awarded DEMO2000 funding in a new JIP, where the scope is to reach TRL4 for the full system, as part of preparing for a field trial. "
Victor Fonseca
PETROBRAS
Subsea Engineer
Improving Performance of Subsea Tie-in Operations by Means of Suitable Equipment Design Requirements
The objective of this paper is to show how operations with improved performance and efficiency can be achieved by a process of searching for suitable design requirements for the involved equipment. A case study related to the specification of Vertical Connection Modules (VCMs) is shown which presents the process of looking for design requirements that can improve subsea operations performance and safety. Basically, typical tie-in operation with VCMs is detailed and broken down into steps with known timespans. Each step is assessed in terms of how it can be shorten. The performance of different designs is compared, per steps, which allows the identification of the most efficient options in order to improve the design. Reports of operational incidents and lessons learned are recollected and evaluated to identify design changes that would avoid them from repeating. All observations are then translated into design requirements that are later included in Technical Specifications. Best results are reached when the whole operation is well known, because the uncertainties are reduced and a reference of performance gain for each design requirement can be compared with the cost of its implementation. This paper presents practical measures that may be taken when specifying subsea equipment that can lead to improved efficiency and performance of subsea operations. Also, it shows the subjects that should bear in mind during specification of equipment when efficiency is sought.
Sigbjørn Daasvatn
SUBSEA 7
Strategic Technology Development Manager
New Building Blocks for Subsea Plant Solutions
"Subsea pre-conditioning of well streams bring new ways of developing fields more economically, safer and more environmentally friendly. A major effect of moving topside processing to seabed is the reduction of complexity of systems required to operate a subsea platform. This makes the systems more reliable and reduces the overall cost significantly. The power consumption is typically halved and thus, the environmental impact is dramatically reduced for subsea plants compared to topside plants. The lack of qualified subsea building blocks often becomes a bottleneck in the early stages of field developments. Subsea 7 has developed a new, cost-effective, versatile and open technology platform where suppliers can integrate their equipment. Subsea 7 and equipment suppliers are together developing modularized building blocks for future subsea solutions, often based on the suppliers already well working topside equipment. In such standardized development processes, Subsea 7 brings the subsea experience and know-how, while the supplier brings the functional know-how and experience. These new function modules can take part in specific solutions designed for the corresponding specific subsea field developments. In this way, the subsea market is opened for more suppliers of equipment. The newly developed Submerged Production Unit has resulted in a cost-effective technology platform for the integration of a suite of new building blocks providing functions for field specific subsea production and processing systems. Larger subsea plants are ideal for towed installation and reduces our dependency on expensive heavy lift vessels. The presentation will outline a series of examples of new building blocks. "
Chris Matthews
CONNECTOR SUBSEA SOLUTIONS
Senior Design Engineer
New Technology – A DNV Type Approved solution of permanently repairing CRA Clad or Lined pipe with a mechanical connector
"As part of a new technology development program in line with DNVGL-RP-A203, Connector Subsea Solutions in partnership with Chevron and Woodside through a joint industry project (JIP), have developed a new patented method of sealing on the inside of a CRA clad or lined pipe, thus enabling a permanent repair solution. The seal takes advantage of the corrosion resistant and ductile properties of Alloy 625 (UNS N06625) and experience gained through extensive testing of graphite in order to create a seal that conforms to NACE MR0175 / ISO15156-3. The seal forms around all pipeline manufacturing tolerances and even localised irregularities such as internal weld seams. The seal can be easily integrated into existing mechanical connector configurations and is able to be adapted for both diver installed and remote repairs. The technology qualification was completed through a combination of analysis (including development of a parametric FEA model to cover all future design scenarios), 3rd party material testing, component testing in specialised test rigs; all culminating in full scale testing within a mechanical connector. The presentation will focus on the analysis and testing completed during the technology qualification process and highlight any key failure modes that had to be addressed, as well as any findings that were made during the qualification. DNVGL type approval was awarded to the CRA clad and lined pipe end seal in December 2019. "
He Zhao
AKER SOLUTIONS
Senior Specialist Engineer
Ready for Subsea Produced Water Treatment using Compact Flotation Technology
"Produced water is the largest volume waste stream in oil and gas production and averagely 3-5 barrels of water are produced with one barrel of oil. Handling such a huge volume of water is particularly difficult offshore, and it involves substantial CAPEX and OPEX. Treating produced water subsea instead of topside can bring several unbeatable advantages. These include enabling marginal fields, increased oil recovery, system simplification and reduced economical and environmental impact. However, there has been a lack of robust and qualified technology for subsea produced water treatment. Compact flotation unit (CFU) with no moving parts and simple internals has topside proven track record for water cleaning, while never been operated at subsea relevant pressures. Aker Solutions and partners Aker BP, Equinor and Total with additional support from the Research Counsil of Norway have successfully completed a joint industry project in 2019 to qualify the CFU technology for subsea use at higher pressure. Tests of a pilot subsea CFU with pressure up to 90 bara was carried out in Equinor’s large-scale test facilities in Porsgrunn with crude oil, natural gas and synthetic produced water. The CFU demonstrated good performance, comparable or better than that at topside operational conditions. The technology also showed robust performance with a large turndown ratio, proving it a viable and flexible solution for subsea use."
Mostafa Valavi
EDRMEDESO
Senior Technical Consultant
Toward Electrification in Oil & Gas Industry – The Role and Power of Engineering Simulation
"Electrification has been an interesting and increasingly important topic in the oil and gas sector. There is now a strong global trend of electrification in various industries (particularly in transportation sector), due to both environmental and technical consideration. Also, in oil and gas sector, going electric (or even more electric) can offer distinct advantages in different applications. Electrification of oil and gas platforms and installations effectively contributes to reduce the emissions. In addition, more electric components and systems can potentially improve the reliability, flexibility, and efficiency of oil and gas systems. Interesting examples are electric actuator systems and more integrated subsea pumps. Moving toward electrification and development of more electric products require strong R&D focus and this is where engineering simulation can have a significant role to accelerate the product development. In this presentation, we will discuss how simulation can be effectively used in different applications related to electrification in oil & gas industry. We will specifically cover power systems and electromagnetic simulations and their coupling to structural and thermal simulations, enabling multiphysics simulation-based design and optimization. Another interesting topic to be addressed is system-level simulation, as this allows the analysis of system-level interactions and paves the way for development of digital twins. "
John Dale
ELECTRICAL SUBSEA & DRILLING
CEO
A Winning Solution: Electrical BOP Technology
"Subsea BOP control systems are up against a wall with legacy technology that is increasingly unable to meet operational, economic, and regulatory demands. These critical challenges point to the need for a pivotal change in BOP technology. Such a change speaks not only to current constraints, but will be important for tomorrow’s vessel solutions, with digitalization and new MPD technology. Based on 90-year-old hydraulics technology, the BOP technology struggles to meet current subsea demands. The industry’s response is not encouraging as component size, weight and complexities steadily increase, with reduced reliability and increased wellhead loading as a result. All-electric BOP controls resolve many of the constraints of hydraulic systems, including complexity and multiple fault sources, as well as the elimination of large accumulator systems. Electric motors driving rams, annular and connectors enhance BOP control and facilitate real-time monitoring and condition-based maintenance. Shedding of hydraulic components reduces BOP size and weight and provides cost reduction of the control system. A smaller, lighter BOP reduces bending and fatigue on the wellhead. It also improves handling and storage on the rig and reduces topside capital investment. The inherent reliability and functionality of “all electric” controls with Condition Based Monitoring will provide large savings in maintenance and operational expenditure through reduced time between wells. As an industry, we are on the verge of taking another significant step away from technology that has served us well, but limits progress. All-electric BOP controls will create a new wave of opportunities with significant and far-reaching ramifications. "
Espen Sten Johansen
TECHNI
CCO
Worlds' Fastest Fail-Safe Wellhead Actuator
"Hydraulic actuators for wellhead control have inherent limitations including slow opening and closing time, in particular for long subsea transmission lines that can result in delayed handling of emergency situations. Long high-pressure hydraulic lines also pose a significant environmental risk. Furthermore, hydraulic actuator systems rely on costly umbilicals, hydraulic power units and control systems. PACT (Pressure Control Actuator) is a new and innovative wellhead actuator technology. The all-electric actuator displaces current hydraulic systems, with improved reliability, faster and more precise actuation and reduced risk of spills. Primary application is for wellheads, but the modular technology is designed for a range topside and subsea mission critical pressure control applications. PACT is a joint development program supported by Equinor, Baker Hughes and Techni. PACT is designed to be an integral part of automated and remote-controlled digital systems. The actuator has a patent pending fail safe mechanism with worlds’ fastest closing time to ensure containment during critical situations and ESD. It employs a compact embedded permanent magnet motor that ensures max torque from start and an innovative transmission system that offers ultra-low torque transfer loss. Opening time of 32 to 60 seconds (depending on valve size) and adjustable closing time of 4 to 8 seconds (valve closing in less than 1 second has been demonstrated). Stepping features with high resolution encoders enable fast and precise operation with position feedback. PACT is designed with small physical footprint (drop in replacement for hydraulic actuators) and low power consumption, key factors for subsea applications. "
Caroline Roxane B. Harvengt
EQUINOR
Leading Advisor Subsea Processing
Subsea Boosting - 6 years of successful operating experience at Åsgard and Gullfaks fields
"After significant track record subsea boosting is now considered proven technology based on Equinor’s governance and experience from Åsgard and Gullfaks, two fields operated on the Norwegian continental shelf. In total more than 6 years of successful operating experience, increasing recovery from two very different fields. Control over the pressure balance, high flexibility, operability and robustness of the system have been the key to success. All four installed compressors have an impressive technical availability of close to 100%. The compressor trains at Åsgard are producing at full power and the production has been better than anticipated. After 67.000 running hours, comprehensive operational experience has been gathered. Whereas the actual compressors have been working flawless, trips and upsets caused by other parts of the system have been seen. As the reservoirs pressure continue to decrease, compressors with higher pressure ratio are been developed to mitigate the effect of the minimum flow rate in the production flowlines and to extend the life time of the Åsgard Field further. The wet gas compressors at Gullfaks have been used to maximize value creation, adjusting oil/gas mix according to demand/price and processing capacity at the host. The compressors have been producing in different modes since start-up, at first in single mode, then in parallel mode, comprising of over 32.000 running hours. Work has been initiated to allow for higher capacity. Projects and operators are taking onboard the technology. The industry is ready for multi-use implementation. Compressors adjustments for unmanned topside application are also being assessed. "
Arill S. Hagland
ONESUBSEA
Technical Sales Manager
Ormen Lange Phase 3 – Implementing Subsea Multiphase Compression
"The Ormen Lange has been one of the most challenging field developments on the Norwegian continental shelf with many industries firsts since the discovery was made in 1997. This journey is now set to continue with the adoption of subsea multiphase compression. The subsea to shore philosophy will persist as the 32MW compression system will be powered from shore through a record breaking 120 km step-out distance. The development strategy has always been to utilize compression on Ormen Lange in order to fully explore the potential of the giant gas discovery. A significant effort has been made by Shell and the license partners to develop subsea compression technology as this is far more effective and represents a significant lower CO2 footprint than topside compression. However, the cost and maturity of the technology has delayed the decision to apply this until now. Norske Shell has recently signed a frame agreement with OneSubsea covering the provision of a FEED study and technology qualification program, and following a later final investment decision the contract will cover the engineering, procurement, construction and installation (EPCI) of a subsea multiphase compression system. Through the contract, OneSubsea and its Subsea Integration Alliance partner Subsea 7 will supply and install a complete subsea multiphase compression system on Ormen Lange. This presentation will describe the concept selection process including pre-FEED engineering and testing activities, the ongoing technology qualification program and the EPCI scope of the contract. In addition, a high level description of the compression system will be provided. "
Rune Mode Ramberg
EQUINOR
Project Manager
Troll phase 3: A genuine Kinder Surprise
"Troll Phase 3 is a genuine Kinder Suprise: 1. The project will supply more energy to the society than phase 1 of the Johan Sverdrup. 2. The CO2 foot print in the production phase is very low. Only 0.1 kg/barrel. 3. The business case is very good. Break even is less than 10$/bbl. The project will generate a lot of cash that can be used to invest in even greener projects. The project is a huge subsea tie-back to Troll A with a big bore subsea production system to minimize the energy loss form reservoir to production platform. The presentation will give an overview of the experiences gathered during design and execution of the SURF project: Big bore production wells, x-trees, and manifolds, 36 inch infield production lines, full size tie-in to large bore PLEMS and Troll A trough seal tubes, 303m below sea-level on Troll A. The Troll phase 3 project is an example on how our industry is a part of a sustainable future. "
Juliano Pimentel
AKER SOLUTIONS
First Chief Engineer
Wireless Sea Trial for Production Systems – A Seamless Integration with the AUV technology
"A new era for subsea production systems has started with autonomous underwater vehicles been qualified to provide long-term services subsea. A new range of enabling technologies have been matured to meet stringent requirements of subsea operations. Reliable communication, data transfer, recharging and edge computing are technologies that have been developed in the recent years to make it feasible. Aker Solutions has integrated and tested, at a representative environment, a set of different technologies in partnership with their suppliers. A wireless sea trial was performed in Trieste Italy, at Saipem’s playground test facility, to test and prove the feasibility of acoustics, free space optics, inductive communication and power and high-definition real time video streaming for subsea production system’s monitoring and communication. A full system has been put together to allow communication, data acquisition, edge computation and cloud based visualization. The wireless modems and sensors were strategically mounted at interest areas of the playground underwater test area, where equipment mockups were installed to represent a subsea field. The acoustic modems were mounted on top of pipelines, the underwater camera installed to survey a specific valve position indicator and the inductive coupler provided access for a high-definition video streaming. These remote modems are battery powered, communication is purely wireless to the hub. A comprehensive set of tests were performed to characterize communication channels, different technologies interoperability and limitations for subsea production system's application. The main findings and conclusions are presented in this work and recommended way forward on further integration of the technology. "
Torunn Myhre
TECHNIPFMC
Engineering Manager
Reactive Flex Joint enabling cost effective satellite structures
Late December 2019 TechnipFMC’s newest generation Reactiv Flex Joint (RFJ) was put in operation during well completion operation in the Barents sea. By reducing mechanical fatigue on the wellhead the RFJ removes the need for costly Well Load Relieve systems and saves valuable rig time. The RFJ also impact the design of Integrated Template Structures and allows for lightweight and cost effective design of satellite well structures in particular. Summer 2020 TechnipFMC will install the first satellite well structures optimized for use of RFJ. The presentation will focus on new cost effective satellite structures to fit different soil condition and give an introduction to the Reactiv Flex Joint and the latest operational experience. Co-presenter: Knut Olav Sønåsen, TechnipFMC
Ståle Størkersen
EQUINOR
Advisor
Large Connections for Norwegian gas Troll's
"Norway is a main gas supplier to Europe through large diameter pipeline export system. Big bore pipeline is a very cost-effective transportation but give also challenges to technology and methods for installation. Since the 1970’s, pipeline technology, competence and associated know-how have developed solutions for utilizing gas natural resources and bringing gas to market. During the last years, pipeline technology has been essential for exploiting deep waters, keeping pressure drop low as well as tie-backs of new infrastructure to existing facilities. Troll Field will use technology and solutions similar to Polarled installed in 1300m water depth. Integral solution for mechanical connection technology, valve stations and subsea structures is being developed and presented in this presentation. Highlights are subsea–to–shore and subsea tie-back for Polarled/Troll A/EP2 in 36’’ size. The new and unique 36’’ tie-in system is including clamp, tooling and pigtrap operations. The solution has now operated for 1 year and intentionally will serve as new ‘’standard’’. Presentation included full system description such as foundations, valve stations, pipelay, RFO, tie-in, spool tie-ins assisted by handling frames as well as future subsea expansion to Troll A. Technology is owned by and shared between many license owners and maintenance/operation of tooling and technology is under control of Equinor as operator. This arrangement gives overall goal of cost sharing, availability, keep competence and make technology equally available to competitive engineering partners and marine contractors. "