Equinor has awarded DeepOcean a four-year frame agreement for marine services that includes subsea intervention and repair contingency for subsea pipelines, structures and high voltage cables for not only oil and gas fields but also offshore renewables.
The agreement comes with a scope for extension up to another four years.
Geographically the agreement is valid for work on the Norwegian continental shelf and internationally for planned Equinor work and for contingency work for the PRSI pool members, which comprises 23 energy companies that cover their offshore pipeline and power cable repair contingency via the pool.
The contract delivery will be managed by DeepOcean from its Haugesund-based office in Norway.
“Such a long-term agreement allows us to constantly evolve working methods, collaboration models and technologies, with the objective of making offshore operations and subsea cable repair work as cost-effective as possible. We look forward to supporting Equinor and the PRSI Pool members over the coming years,” said Olaf A Hansen, Managing Director of DeepOcean’s European operation.
For work in the offshore oil and gas industry, the frame agreement covers planned or unplanned marine services using remote operated intervention methods with or without the use of PRS equipment.
Under the agreement, DeepOcean is also expected to be equipped to produce multiple engineering or preparedness studies as requested by Equinor or PRSI pool members.
“DeepOcean has a 400 people-strong engineering team that are specialists on solving subsea challenges across industries. We are industry agnostic and share learnings and experiences from subsea operations across different types of operations and industries in order to develop the best possible solutions for our clients. Our experience from oil and gas is highly valuable for offshore renewables – and vice versa," said Normann Vikse, Offshore Renewables Director at DeepOcean.
DeepOcean has already received the first call-offs for work under the new frame agreement.
On behalf of Gassco and Equinor, DeepOcean will perform seabed preparations and complex remote hot tap tie-in operations at three different locations on the Norwegian continental shelf. Hot tapping is a method of connecting to a pressurised system, such as a pipeline, without removing the pipe from service.
On behalf of Gassco with Equinor acting as technical service provider, DeepOcean has already performed marine services to support baseline inline inspection of a large sized pipeline.
An integrated service provider from Aberdeenshire, AquaTerra Group has announced four decommissioning contract wins that add up to a seven-figure sum.
The last year has marked several firsts for the Group, including the first time that the company was subcontracted by Dutch offshore contractor, Allseas. Under the contract, AquaTerra supported an EPRD project on Enquest’s Heather Alpha platform. It provided engineering, fabrication, access, and construction teams to complete underdeck preparation scopes for topside removal.
Also for Allseas, AquaTerra removed underdeck obstructions in preparation for the topside removal of TAQA’s Cormorant Alpha platform. This was followed by a subcontract from Wood, which involved further work on the same platform.
By utilising its lifting and rigging equipment and services, including its modular suspended access platform QuikDeck, AquaTerra also won its first decommissioning contract with another operator to support conductor decommissioning.
Stephen Taylor, Managing Director of AquaTerra Group, said, “The team and I are delighted that we were selected by Allseas through what was a competitive tendering process for the Enquest and TAQA projects. This is also the first time that we have worked with Wood in several years, so it is great to be supporting them again.
“We’re tendering for more big projects than we’ve ever tendered for before in decommissioning, and this is already paving the way for us achieving our target of £14 million turnover in 2024.”
The Net Zero Technology Centre (NZTC) has called for innovations in rigless plug and abandonment.
This has been made in partnership with the 'Go Radical P&A' project, a venture by Energy Transition Norway, Danish Offshore Technology Centre, Centre of Decommissioning Australia and the Petroleum Technology Alliance Canada.
A cost-efficient and environmentally sensitive option for well decommissioning, new innovations in rigless plug and abandonment is considered one of the best way to meet regulatory requirements. They will also help address technical challenges such as accessing the wellbore without a drilling rig.
This comes as part of NZTC’s Well Decommissioning Collaboration initiative, which is actively supported by the Technology Leadership Board, North Sea Transition Authority, and Offshore Energies UK. The initiative aims to trial and test new technologies in multi-operator collaboration field trials, enabling faster, lower-cost trials and wider industry adoption in the UK and beyond, aligning with UKCS cost and emission reduction targets.
Selected participants will get to interact with a consortium that includes Harbour Energy, ConocoPhillips, Respol, TotalEnergies and Petrobras, with potential for support in developing, trialling and testing technologies. They will get exposure at similar operator consortiums in Norway, Denmark, Australia and Canada as well.
Lewis Harper, Project Manager for NZTC’s Well Decommissioning Collaboration, “Our Wells Decommissioning Collaboration initiative highlights how joint innovation is crucial for advancing technologies needed for affordable and sustainable well decommissioning, supporting the industry in reaching its net zero targets. It’s an exciting chance for emerging developers to join in, gain exposure, and potentially receive support to propel their technology development.”
UK Government Minister for Scotland Donald Cameron said, “This is a fantastic initiative that aims to deliver innovative and affordable solutions through information sharing and trials to help secure the future prosperity of the energy sector while helping to achieve our net zero goals. I encourage those working with this technology to find out more.
“The UK Government is investing £90 million in the Net Zero Technology Centre and more than £3 billion to level up right across Scotland.”
The deadline for applications is 23:59 on 31 May.
Expro has officially completed its acquisition of Coretrax, marking a significant milestone in the growth of both businesses.
The acquisition will allow Expro to expand its portfolio of cost-effective, technology-enable well construction, well intervention and integrity solutions, while Coretrax will be able to accelerate its technology application globally.
John Fraser, CEO of Coretrax, highlighted how this acquisition marks the start of a “brand-new chapter” for the company by uniting with Expro to expand its capabilities: “Completing this agreement means both organisations working in sync to take on the most complex well challenges. We are proud of our innovation-led approach, strong customer base and performance history as we join forces with Expro to create greater value for customers around the globe.”
Michael Jardon, Chief Executive Officer at Expro, added, “We expect the acquisition to accelerate the growth of Coretrax’s innovative, high value-adding drilling optimisation, well integrity and production enhancing technology solutions by leveraging Expro’s global operating footprint.”
Sea1 Offshore is the new name of the international offshore and subsea shipping company following a general meeting held earlier in May.
The formal decision was made in the wake of Kristian Siem’s withdrawal and will be accompanied by a new company logo. The company stated that crew and expertise will be transferred to the new company, even if nine of the company's vessels are taken over by Kristian Siem as part of the transaction.
Apart from this, the company has assured, it will be business as usual, although Bernt Omdal, CEO of Sea1 Offshore, has his eyes set on further growth.
“A more unified ownership structure will help to set a clearer course for the company,” Omdal explained. “We continue to operate all the vessels in our fleet, including the nine that are now owned by Siem. But we have changed the name and are replacing the logos at our offices in Brazil, Australia and Canada, and at the head office in Kristiansand.
“We are witnessing the start of a new upswing,” he continued. “We consider strengthening our fleet with several new construction vessels in order to take a larger part of the market in the offshore energy sector.”
James Fisher Decommissioning, part of James Fisher and Sons plc, has completed a significant decommissioning project in the Gulf of Thailand.
After extending the contract with a major offshore engineering, preparations, removal and disposal (EPRD) operator, the project became the largest to date for James Fisher, involving the removal of 25 offshore jackets in support of the client’s wider asset end-of-life campaign.
James Fisher was able to support the client through the expertise of its in-house decommissioning team and equipment, including abrasive waterjet cutting, hydraulic demolition shears and diamond wire saws.
To complete the multi-million-pound project, the decommissioning specialist utilised abrasive cut verification technology which ensured operations are completed successfully on the first attempt and without the need to re-evaluate the initial cut. It is estimated that, by improving efficiency of the operations in this way, cutting time was reduced by 50%.
“We pride ourselves on providing bespoke, environmentally focused solutions to overcome some of the most complex decommissioning structures faced by our customers,” Mark Stephen, Decommissioning Director for James Fisher, remarked. “This type of operation was a first for James Fisher Decommissioning in terms of jacket removal volume and duration, and we are extremely proud to have been part of the project. Utilising our strong in-house decommissioning capabilities and real-time monitoring technology, we saved valuable project time during the cutting process while ensuring the project was completed to the highest standards for our client.”
This represents the latest success for the company since the launch of the decommissioning business line.
Designed particularly for geothermal energy applications, Halliburton Company's latest product range includes the GeoESP lifting pumps, distinguished with features such as advanced submersible borehole and surface pump technology.
Developed by an in-house service called Summit ESP, these pumps cater to fluids transportation challenges. They are characterised by a unique high-flow inlet design that protects it against solids, minimises power consumption, and effectively tackles scale formation.
Keeping harsh environment in mind, these pumps have been designed with the durability to withstand temperatures up to 220°C (428°F). It is capable of resisting any range of scale, corrosion, and abrasion. With standardised pump dimensions, it is suitable for various geothermal well conditions.
In another digital innovation to geothermal well management, the Intelevate data science-driven platform generates real-time diagnostics and rich visualisations of 'smart' field data. This system improves well operations, extends system run life, minimises shutdowns, reduces energy consumption, and increases production.
"With increased global focus on low carbon energy sources, we are using our many decades of geothermal production expertise to help our customers maximise safety and improve efficiency. Our GeoESP lifting pumps build upon our current system to minimise power usage and help push the boundaries of what is possible with more complex well designs," said Greg Schneider, Vice President - Artificial Lift, Halliburton.
Working for a prominent energy company, offshore lifting solutions provider Thunder Cranes offered mobilising its small-footprint, portable modular crane on a small supply vessel to the work site.
After reaching the site, it can be rigged up, load tested, and prepared for lifting operations, all in a day, rather than going with the costly option of a barge or vessel crane, which can also render ineffectual.
While the project involved challenges from limited deck space to heavy lifting requirements, Thunder Cranes was well-equipped to tackle them with its compact, hydraulic powerpack/prime mover, TC20 stiff leg crane with a 60-ft boom length, and a 'self-lifting' package of TC's proprietary.
The choices of equipment and services by Thunder Cranes were reached post a thorough assessment of the client's lifting requirements, platform drawings, general specifications, and project timelines. This was followed by a site visit for verification, which became the basis for practical solutions.
The energy company required solutions with their offshore coiled tubing operations that involved the lifting of their CTU equipment onto their offshore platform which only had a small jib crane of 1.8-ton capacity, while the coiled tubing reel itself weighed 16 tons. Thunder Crane's modern approach with its portable-modular crane technology instead of the traditional large vessel or barge crane helped its client to optimise their logistics and enhance project uptime, while maintaining a high level of safety and cost-effectiveness.
The European Investment Bank (EIB) has provided a loan to Eavor Technologies to support the commercial-scale geothermal heating project in the German state of Bavaria.
Eavor will implement its closed-loop technology, Eavor-Loop, for the first time at commercial scale in the Bavarian town of Geretsried with the help of EIB’s loan of close to €45mn. The loan comes with a guarantee by the European InvestEU programme.
The project is co-financed by Japan Bank for International Cooperation, ING Bank N.V., and Mizuho Bank Ltd, and is insured by Japan’s Export Credit Agency, Nippon Export and Investment Insurance. It qualifies as a green loan in accordance with the Loan Market Association’s Green Loan principals. The combined support amounts to €130mn. The project is also being developed with the additional support of a €91.6mn grant from the EU Innovation Fund.
The Eavor-Loop will provide heating to households and businesses in Geretsried. In addition, an on-site power station will convert the geothermal heat into electricity. Eavor intends to start heat delivery by 2026, and the Eavor-Loop has started developing a second project in Germany to supply 15-20% of the demand of district heating in Hanover.
Nicola Beer, EIB Vice President, said, “The Eavor-Loop supports the transition to a carbon-neutral energy system in Germany and helps the country to get independent form fossil fuels, while adding to energy security for the people and businesses.”
Commissioner for Climate Action, Wopke Hoekstra, commented, “Once again, we see how valuable the work of the Innovation Fund is through the funding it provides for cutting edge projects that lower emissions. Today, thanks to €45mn investment by the European Investment Bank and €91.6mn from the Innovation Fund, we are supporting the innovative geothermal technology Eavor-Loop in Bavaria, Germany.”
Daniel Molk, Executive Vice President Europe Operations, concluded, “We are impressed and honoured that, after the EU Innovation Fund, the European Investment Bank is now also co-financing our project in Geretsried. Europe has recognised that the Eavor Loop is a scalable key technology for achieving climate neutrality and significantly more energy security on this continent."
Woodside Energy has prepared and submitted an experts-consulted, final environment plan (EP) to the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), in accordance with the requirements of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 and Environment Regulations.
In the capacity of a titleholder under the Offshore Petroleum and Greenhouse Gas Storage (Environment) Regulations 2023 (Commonwealth), Woodside has proposed to undertake decommissioning activities within offshore petroleum production licence VIC/L22 and pipeline licence VIC/PL33.
It will include the removal of approximately 5 km of pipeline bundle and associated equipment, well tie-in infrastructure, and Minerva-2A wellhead and guide base that make up the Minerva subsea infrastructure.
As planning activities are well in progress, a rig has been secured for plug and abandonment in the Minerva field through a rig consortium with other titleholders in the region.
Keeping with the Environment Regulations, Woodside's EP has attempted to identify and describe the probable environmental impacts and risks that may arise during the end-of-life operations. It has worked out a process of appropriate management controls to reduce impacts and risks to a level that is ‘as low as reasonably practicable’ and acceptable. It defines Environmental Performance Outcomes (EPOs), Performance Standards (PSs) and Measurement Criteria (MCs) to ensure minimum adverse impact.
Woodside is planning the plug and abandonment of the Minerva-1, Minerva-2A, Minerva-3 and Minerva-4 wells (in accordance with a separate Minerva Plug and Abandonment EP), and removal of property in VIC/L22 and VIC/PL33 (under this EP).
Woodside's scope of decommissioning activity as mentioned in the EP is focussed in Commonwealth waters in the Otway Basin approximately 7 km south-southwest of Port Campbell, Victoria, where the Minerva subsea infrastructure is in approximately 55–59 m water depth at lowest astronomical tide (LAT). The operational area is thus defined as a 1,000 m radius around the subsea infrastructure, wellheads, and the gas production pipeline (the pipeline) within Commonwealth waters.
Spread over 24-hours per day, and seven days per week, Woodside believes the decommissioning activities might take up to 90-120 days, and completion is not anticipated before 30 June 2025.
Export credit agency UK Export Finance (UKEF) will be supporting Brazilian contractor Ocyan's decommissioning drive with a US$7.5mn guarantee.
After initial discussions with UKEF, Ocyan onboarded Scottish business Maritime Developments Ltd in 2022 who would take care of the equipment needs for the decommissioning project in Brazil. This was made possible using the UKEF grant which helped Ocyan procure financing from ABC International Bank to successfully set off the MDL deal. The grant will be applicable on a reimbursement basis, boosting its access to working capital.
Charlotte Wiltshire, European Head of Wholesale Banking, ABC International Bank plc said, "We are delighted to continue our support of UK businesses in conjunction with UKEF, leveraging off Bank ABC Group’s MENA and international footprint. This is an important milestone transaction, promoting the UK’s expertise in the oil and gas decommissioning and renewable energy arena. Bank ABC is looking forward to enabling similar energy transition projects in future."
A subsea pipelaying specialist from Aberdeen, MDL's wheeled horizontal lay system technology will be deployed by Ocyan to remove hundreds of kilometres of subsea cables and pipes from defunct FPSO oil and gas rigs in Brazilian waters.
Andrew Blaquiere, MDL Managing Director, said, "MDL is known worldwide for our forward-thinking technology that enables challenging scopes to progress on time and on budget, and this delivery to a Brazilian indigenous company is proof of that. Our engineering studies identified limitations with existing technology on the market when it came to recovery capability from deep waters like those in Brazil. The alternative for these operations would be to use a specialist construction vessel, resulting in high cost and scheduling challenges.
"In a true MDL ‘We Build Innovation’ style, we put our heads together, brainstormed alternative approaches – and delivered the Wheeled HLS. As a result, the client – and the Brazilian market – gained a cost-effective way to kit-out a vessel of opportunity to handle high loads and tackle recovery projects – this way enabling more sustainable end-of-life operations."
The first-ever overseas grant from UKEF also stands to benefit more than 70 Scottish businesses which are responsible for the entirely local MDL model.
AGR has been awarded a contract by geothermal energy supplier Innargi for the provision of technical consultancy for three appraisal wells being drilled in Aarhus, Denmark.
Through the contract, AGR will provide wellsite geology and drilling supervision over the Aarhus wells as the company boasts extensive experience in well and reservoir engineering for geothermal wells. AGR has previously supplied software solutions for managing geothermal drilling time and costs for projects throughout Germany and Austria.
Lene Thorstensen, Manager Operations and Wellsire Geology at AGR, said, “Our team has a track record of managing drilling of more than 200 wells in the North Sea. The Aarhus project is a great example of valuable competence transfer from the oil and gas industry to renewable energy sources.”
Innargi aims to bring clean and reliable district heating to Europe through geothermal energy, and the Aarhus plant project provides a stepping-stone to achieving that goal. The geothermal plant, if everything goes accordingly, will become the EU’s largest geothermal district heating system. A 6,000 horsepower drilling rig has been set to drill 2.5 km into the ground to extract the heated water, with heat delivery set to begin in 2025. The system is projected to provide 20% of Aarhus’ district heating upon completion.
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