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13:30 - 17:00
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13:30 - 13:35
Track 1
Plenary - Welcome
13:30 - 13:35
13:35 - 13:55
13:55 - 14:15
14:15 - 14:35
Track 1
Break
14:15 - 14:35
Track 1
PARALLEL SESSION #1
14:35 - 14:55
Track 1
Subsea Boosting - 6 years of successful operating experience at Åsgard and Gullfaks fields
14:35 - 14:55
Caroline Roxane B. Harvengt, EQUINORPart 1, Boosting
Track 2
A Winning Solution: Electrical BOP Technology
John Dale, ELECTRICAL SUBSEA & DRILLINGPart 2, All-Electric
Track 3
New Technology – A DNV Type Approved solution of permanently repairing CRA Clad or Lined pipe with a mechanical connector
Chris Matthews, CONNECTOR SUBSEA SOLUTIONSPart 3, SURF / Operation
14:55 - 15:15
Track 1
Can subsea technologies reduce CO2 emissions?
14:55 - 15:15
Ina Ekeberg, ONESUBSEACecilie Steine Lillevik, ONESUBSEAPart 1, Boosting
Track 3
Flexible Pipe Technology Developments for HPHT and FLIP
Colin Russell, BAKER HUGHESPart 3, SURF / Operation
15:15 - 15:35
Track 1
Topside-less "All Electric" Boosting System - Simple and Reliable
15:15 - 15:35
Alexander Fuglesang, FASTSUBSEAPart 1, Boosting
Track 2
PACT – Digital, fail-safe, wellhead and production tree actuator system
Dag Almar Hansen, TECHNIPart 2, All-Electric
15:35 - 15:55
Track 1
Break
15:35 - 15:55
Track 1
PARALLEL SESSION #2
15:55 - 16:15
Track 1
New Building Blocks for Subsea Plant Solutions
15:55 - 16:15
Sigbjørn Daasvatn, SUBSEA 7Part 4, Field of the future
Track 2
Development of an equipment centric subsea condition monitoring application - an operator's experience
15:55 - 16:15
Andy Gower, Total E&PPart 5, Digitalisation
Track 3
Technology Transfer Across Industries - a Case Study
Neil Douglas, VIPER INNOVATIONSPart 6, Low carbon / Tech. Transfer
16:15 - 16:35
Track 1
Subsea Compression Powered by Renewables
16:15 - 16:35
Andrew Grant, AKER SOLUTIONSPart 4, Field of the future
Track 3
Troll phase 3: A genuine Kinder Surprise
Rune Mode Ramberg, EQUINORPart 6, Low carbon / Tech. Transfer
16:35 - 16:55
Track 1
The Cold Flow Enabler - Rethinking Flow Assurance
16:35 - 16:55
Fredrik Lund, EmpigPart 4, Field of the future
Track 2
Wireless Sea Trial for Production Systems – A Seamless Integration with the AUV technology
Juliano Pimentel, AKER SOLUTIONSPart 5, Digitalisation
Track 3
Transforming underwater inspection through Fast Digital Imaging, Unmanned Surface Vessels and Integrated Underwater Vehicles. The BP 2025 vision.
Eric Primeau, BPPart 6, Low carbon / Tech. Transfer
16:55 - 17:00
Track 1
Plenary - Closing remarks & announcement of UTC2021
16:55 - 17:00
Jon Oddvar Hellevang & Marie Bueie Holstad
Sverre Alvik
DNV GL
Fredrik Lund
Empig
CTO and Founder
Cecilie Steine Lillevik
ONESUBSEA
Early Engagement Engineer, Sales
Alexander Fuglesang
FASTSUBSEA
Founder & CEO
Camilla Leon
AKER BP
VP Projects - Subsea Alliance
Marie Bueie Holstad
NORCE Norwegian Research Centre AS
Chief Scientist
Jon Oddvar Hellevang
GCE Ocean Technology
Senior Ocean Technology Innovator
Dag Almar Hansen
TECHNI
CEO
Glenn-Roar Halvorsen
EQUINOR
Andy Gower
Total E&P
Neil Douglas
VIPER INNOVATIONS
Director
Eric Primeau
BP
Senior Technical Specialist
Andrew Grant
AKER SOLUTIONS
Senior Process Engineer
Ina Ekeberg
ONESUBSEA
Technical Sales Manager
Colin Russell
BAKER HUGHES
Flexible Pipe Product Line Manager
Ketil Firing Hanssen
DNV GL
Principal Engineer
Grethe Malene Sagerup
EQUINOR
Project Manager
Sigbjørn Daasvatn
SUBSEA 7
Strategic Technology Development Manager
Chris Matthews
CONNECTOR SUBSEA SOLUTIONS
Senior Design Engineer
John Dale
ELECTRICAL SUBSEA & DRILLING
CEO
Caroline Roxane B. Harvengt
EQUINOR
Leading Advisor Subsea Processing
Rune Mode Ramberg
EQUINOR
Project Manager
Juliano Pimentel
AKER SOLUTIONS
First Chief Engineer
Sverre Alvik
DNV GL
Energy Transition Outlook 2020 - DNV GL's Energy Transition Outlook is an independent, model-based forecast of the world's most likely energy future through to 2050
Fredrik Lund
Empig
CTO and Founder
Cecilie Steine Lillevik
ONESUBSEA
Early Engagement Engineer, Sales
Cecilie Steine Lillevik Joined OneSubsea Processing in 2013 and started as a Mechanical engineer, specializing in subsea operations and installation. She currently works as an Early Engagement Engineer in the Front End Engineering Sales team. She holds a Bachelor degree in Underwater Technolgy - Operations and Maintenance from Bergen University College
Alexander Fuglesang
FASTSUBSEA
Founder & CEO
Camilla Leon
AKER BP
VP Projects - Subsea Alliance
Technology as an enabler for value creation
Marie Bueie Holstad
NORCE Norwegian Research Centre AS
Chief Scientist
Jon Oddvar Hellevang
GCE Ocean Technology
Senior Ocean Technology Innovator
Dag Almar Hansen
TECHNI
CEO
PACT – Digital, fail-safe, wellhead and production tree actuator system
Glenn-Roar Halvorsen
EQUINOR
Andy Gower
Total E&P
Development of an equipment centric subsea condition monitoring application - an operator's experience
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. "
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."
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."
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."
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. "
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. "
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. "
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. "
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. "