Emerson, in collaboration with Interwell, a global leader in well intervention and integrity solutions, has announced the launch of the Adaptive Gas Lift System (AGLS), the world’s first retrievable electric gas lift system designed to comply with internationally recognised safety and performance standards
The AGLS enables continuous optimisation of oil production without requiring costly and intrusive well interventions. Its retrievable design reduces downtime while improving both safety and sustainability in gas lift operations.
Conventional gas lift systems are typically most effective in the early stages of a well’s life, when tubing pressure is high. As reservoir conditions change, drawdown efficiency drops and oil output declines, often resulting in over or under-injection of lift gas. Traditional injection pressure operated (IPO) valves must reduce casing pressure to close, which restricts injection depth and production capacity.
Controlling casing pressure and temperature-related uncertainties in valve behaviour can also cause multi-pointing, where gas is injected at unintended depths, creating inefficiencies and production losses. To address these challenges, operators often resort to costly interventions to alter valve port sizes or injection depths.
The Adaptive Gas Lift System revolutionises gas lift operations by offering real-time remote control of valve port sizes, gas injection rates, injection depths and drawdown, all without halting production. Since valve closure does not depend on reducing casing pressure, operators can achieve deeper injection, resulting in improved lifting efficiency throughout the well’s lifecycle.
With continuous data-based online adjustments, the AGLS removes the need for traditional intervention-based modifications, maximising uptime, production and safety while shortening project payback periods. Its unique retrievable design allows complete valve assembly replacements using standard wireline techniques, avoiding the need for costly workovers.
The system is powered and managed through Emerson’s Roxar Integrated Downhole Network, a permanent monitoring and control platform that delivers real-time data on pressure, temperature and flow for enhanced reservoir management. It also incorporates Interwell’s proven Side Pocket Mandrels and barrier-rated Gas Lift Valve.
AGLS has been designed and qualified to meet the American Petroleum Institute’s API 19G1 (V1), 19G2 (V0), and the Advanced Well Equipment Standards Group’s AWES 3362-36 standards.
By reducing the frequency of well interventions, which typically require heavy equipment mobilisation, energy use and associated emissions, the system lowers the carbon footprint of gas lift operations. Its enhanced production efficiency further decreases CO2 emissions per barrel of oil, supporting more sustainable energy production.
“We designed the AGLS to meet the most rigorous industry standards,” said Jan Inge Ellingsen, vice president and general manager for Roxar products at Emerson’s measurement solutions business. “This innovative technology will help unlock the full potential of assets in the field while eliminating the need for extensive interventions, improving safety, and supporting the transition toward net-zero energy production.”
“The oil and gas industry has long required a more dynamic and resilient approach to electric gas lift,” said Thormod Langballe, chief executive officer of Interwell. “Combining Emerson’s industry-leading digital automation expertise with Interwell’s specialised gas lift technology and know-how, we have developed a robust, real-time controllable gas lift solution that tackles these challenges head-on.”
Odfjell Technology (UK) Ltd has announced a two-year extension of its Master Service Agreement with Serica Energy (UK) Limited.
The renewed agreement underscores the companies’ strong partnership and Odfjell Technology’s ongoing commitment to delivering reliable, high-quality campaign support and maintenance services within the energy industry.
Originally awarded in November 2018, the Serica contract covers the provision of storage, preservation, maintenance, and drilling services. It has since been sustained through several rolling extensions. Under this agreement, Odfjell Technology supplies skilled personnel to support intervention and maintenance operations on the Bruce platform, along with engineering expertise through targeted surveys that contribute to Life of Field activities. The latest extension secures an additional two years of backlog for Odfjell Technology, reinforcing its continued support for Serica’s operational objectives.
John Moffat, Senior Vice President of Operations & P&A UK, commented, “This extension reflects the trust Serica places in Odfjell Technology and the value our teams deliver across intervention, maintenance, and drilling support. We are proud to continue this long-standing partnership and strengthen our position for future campaign readiness, reinforcing our commitment to reliable, flexible service delivery.”
With more than 50 years of experience, Odfjell Technology is an integrated provider of offshore operations, well services technology, and engineering solutions. The company is dedicated to improving safety, efficiency, and sustainability across all operations while reducing time, cost, and emissions for clients. Operating in over 30 countries, Odfjell Technology employs more than 2,400 skilled professionals worldwide.
The Norwegian-based offshore and subsea services provider DOF Group ASA has announced contract extensions for three high-specification pipelay support vessels (PLSVs) owned via its joint venture with TechnipFMC (50:50).
The vessels are engaged by Petrobras in Brazil and are now set to bolster the company’s offshore presence well into the next decade.
The PLSVs Skandi Vitória and Skandi Niterói have had their existing contracts, originally due to end in Q4 2025, extended through to Q1 2027. Their subsequent three-year contracts, announced in June 2024, will commence once the extended period concludes. Meanwhile, Skandi Açu has seen its current charter, set to finish in Q3 2026, likewise extended to Q1 2027, ahead of a separate three-year deal announced in August 2024.
DOF says these amendments add approximately US$100mn to the company’s firm backlog, while all other terms of the previously disclosed three-year agreements remain unchanged. “We are happy to extend the firm backlog of these three high-end vessels into 2030,” said Mons Aase, CEO of DOF Group ASA. “Together with other contracts previously announced, DOF now has 17 vessels in Brazil with firm backlog extending towards and into the next decade.”
The announcement underscores the firm’s commitment to its offshore services footprint in Brazil, securing long-term engagements for its pipelay assets in a key global market.
Oceaneering International, Inc. has announced that its Offshore Projects Group (OPG) has received a contract from bp Exploration (Caspian Sea) Ltd. to provide riserless light well intervention (RLWI) services at the Azeri-Chirag-Deepwater Gunashli (ACG) oilfield in the Caspian Sea
As part of the agreement, Oceaneering will deliver RLWI services for a multi-well mechanical wireline intervention campaign using one of its deepwater systems, which will be integrated onto a subsea construction vessel provided by the client. The project scope also includes management, engineering, and systems integration services to be carried out by both local and international Oceaneering teams.
Engineering and pre-mobilisation activities are already underway, with field operations expected to begin in the fourth quarter of 2025.
Chris Dyer, Senior Vice President of OPG, said, “Oceaneering has successfully provided RLWI solutions to help restore and improve production from existing wells in other deepwater regions of the world. We appreciate bp’s continued trust in our ability to safely provide reliable and cost-effective deepwater intervention solutions, particularly in support of the critical production in the Deepwater Gunashli area of the ACG field.”
Aquaterra Energy, a leading provider of offshore engineering solutions, has announced the appointment of Matt Marcantonio as its new Head of Engineering, marking an important milestone in the company’s ongoing growth and dedication to advancing offshore technologies.
With more than 18 years of experience in the offshore energy sector, Marcantonio is a well-known figure in the industry. In his new role, he will oversee Aquaterra Energy’s global engineering function, driving innovation, enhancing product development, and strengthening the company’s technical leadership across Well Access and Offshore Developments, including well intervention, late-life abandonment operations, and carbon capture and storage (CCS).
Marcantonio joins Aquaterra Energy after nearly 17 years with Claxton Engineering and 18 years within the Acteon Group, bringing with him substantial expertise in riser systems, bespoke tooling, and complex well abandonment projects. He also brings experience in platform design gained during his time with UWG and 2H. With a strong history of leading multidisciplinary engineering teams to deliver innovative offshore solutions, Marcantonio’s appointment will help advance Aquaterra’s strategic focus on expanding its engineering capabilities and accelerating the development of proprietary technologies such as the Recoverable Abandonment Frame (RAF), the AQC systems suite, and the Sea Swift platform.
George Morrison, CEO at Aquaterra Energy, commented, “Hiring a talent like Matt underscores our ambition to remain at the forefront of offshore energy innovation while addressing our clients’ offshore challenges. His combination of deep technical knowledge, product development experience and leadership capability will be instrumental as we expand globally and continue developing technologies that support the energy transition and deliver value across the full well lifecycle.”
Alongside enhancing Aquaterra’s intellectual property portfolio and promoting operational excellence across global projects, Marcantonio will also focus on mentoring the company’s emerging engineering talent, helping to strengthen skills within Aquaterra and the wider offshore industry.
Matt Marcantonio, Head of Engineering, added, “I’ve always admired Aquaterra Energy’s reputation for innovation and engineering excellence, so I’m delighted to be joining such a talented and ambitious team. This is a company that delivers practical, field-ready solutions to solve some of the offshore industry’s biggest challenges – from cost-effective abandonment to enabling the future of CCS. What excites me most is the chance to support the next generation of engineers, sharing experience and building confidence in a sector that urgently needs new talent. Together, we have the chance to strengthen Aquaterra’s position as a leader in offshore innovation and make a lasting impact across the energy industry.”
The United Kingdom has witnessed the successful drilling of the country's first carbon storage appraisal well as part of its ambitious carbon capture and storage objectives.
According to Offshore Energies UK, this new well in the decommissioned Hewett gas field off Bacton on the coast of North Norfolk, will play a significant role in accelerating the path to net zero greenhouse gas emissions as it serves as a major carbon store in the region. The project reflects the UK industry's sustainable approach as it repurposes existing oil and gas infrastructure, delivering carbon capture and storage with the help of efficient supply chains and skilled workforce.
The site operated by the global energy company Eni, is part of the North Sea Transition Authority’s first carbon storage licencing round.
Powering the UK with gas for decades, the Hewett field will now boast a storage capacity of up to 10 million tonnes of CO2 annually as a large-scale carbon storage facility. This equals the yearly greenhouse gas emissions of around a fifth of all UK industry.
The location of Hewett is particularly well placed to support the decarbonisation of industry in Southern England and also industrial greenhouse gas producers in continental Europe.
With an aim to accelerate this process, Offshore Energies UK has initiated a round table with the European Commission, looking to navigate regulatory barriers that currently prevent cross border transport of carbon emissions.
The North Sea Transition Authority which oversees Britain’s carbon capture plans, has already awarded permits for the UK’s first two carbon storage projects. These are the Northern Endurance Partnership off Teesside in December 2024, and Liverpool Bay carbon capture and storage project in April 2025, which is also operated by Eni.
These two projects together could store more than 200 million tonnes of CO2, equivalent to taking 110 million cars off the road for a year. The permits have also unlocked £6bn worth of supply chain contracts and 4,000 construction jobs.
Enrique Cornejo, OEUK Head of Energy Policy, said, “This Hewett appraisal well is a powerful signal of industry’s commitment to invest in the UK’s net zero future. It shows how our existing energy infrastructure and expertise are being repurposed to deliver climate solutions. But for commercial carbon capture and storage to succeed at scale, government must accelerate a clear route to market for projects like Bacton CCS which are outside the government’s planned cluster sequencing process. The Hewett appraisal well is a tangible example of industry stepping up, and now it’s time for policy to keep pace.”
Adverse weather conditions have disrupted TotalEnergies EP Danmark’s operations, delaying production from the remaining fields at its natural gas redevelopment project in the Danish sector of the North Sea.
As a result, the company has updated its timeline for achieving full production capacity at the Tyra gas field, Denmark’s largest natural gas field.
The Tyra redevelopment project has been underway since March 2024, with the first gas export from Tyra II marking the successful initial production following a major revamp. However, challenges have emerged in the process of reactivating and optimising offshore wells, particularly in relation to the reactivation of the Tyra satellite wells. These wells are critical to achieving the anticipated production plateau, and the necessary well interventions have been delayed by adverse offshore weather.
A key operational challenge arose from issues related to two transformers supplying power to essential gas compressors, which have impeded the full commissioning of the project. Despite these setbacks, TotalEnergies has made significant progress in repairing and commissioning equipment, although the anticipated timeline for full technical capacity was initially set for mid-November 2024. Uncertainties about remaining operational conditions have led to delays.
The ramp-up phase, which is closely tied to well intervention activities, has allowed for gas production to be restored from three of the six fields. However, due to weather conditions and other operational issues, the reactivation of the Tyra satellite wells has faced further delays. Offshore weather constraints, including limited weather windows, have hindered the progress of well interventions and postponed the critical reactivation of these satellite wells.
Given the current weather forecasts, the timeline for reactivating all satellite wells to achieve plateau production has been extended by approximately three weeks. The revised timeline now places the expected achievement of plateau production in the second half of January 2025.
The Tyra field is part of the Danish Underground Consortium, with TotalEnergies EP Danmark (43.2%), BlueNord (36.8%), and Nordsøfonden (20%) as the key stakeholders.
Euan Shirlaw, CEO of BlueNord, commented, “Although it is disappointing that plateau production is now expected in the new year, we are confident that the recent above-ground challenges are well understood. Once the remaining satellite wells have been reactivated, the performance of the field will no longer be constrained by weather, as has been the case during the startup phase. We look forward to reaching plateau production in January 2025 and sharing the promising results of our HEMJ program.”
TotalEnergies points out that oil and gas supply nearly 50% of Denmark’s energy needs, and once the Tyra field reaches plateau production, it is expected to contribute around 6% of the European Union's natural gas output, marking Denmark’s return as a net gas exporter.
Additionally, in June 2024, drilling operations in the Harald East area, conducted with the Shelf Drilling Winner jack-up rig, led to the discovery of additional gas condensate resources in the Harald field, which is located in shallow waters 250 km off Denmark's west coast. These new reserves could further boost production from the region, with ongoing well intervention efforts to optimise the production from the field.
In its latest operations update, British independent upstream oil and gas company, Serica Energy, announced that its investment plans for the Bruce and Keith Light Well Intervention Vessel (LWIV) campaign is on track to take place between March and May 2024.
This follows previous campaigns in 2022 and 2023, which have delivered low-cost incremental production. The intervention is expected to restart production from the Keith field this year following successful preparation work on the Keith subsea facilities carried out in 2023. Additional well interventions from the Bruce platform are scheduled for the second half of 2024.
Besides well work on the Bruce and Keith fields, investments in 2024 include four wells in the Triton area (Bittern B1z sidetrack, Gannet E GE-05, Guillemot North West EC1 and Evelyn EV-02). The start date of the B1z sidetrack is set in March 2024. This well and the subsequent three wells are scheduled to take about three months each, meaning that drilling will continue into 2025. Serica has also exercised an option to keep the rig for a further well following completion of the fourth well in the programme (EV-02).
Serica is maturing plans for two infill wells on the Bruce field too with the aim of drilling in 2026.
Abandonment costs in 2024 are forecast to be about £14 million (pre-tax) net to Serica. These will be incurred mainly on the final decommissioning of the Arthur field, situated in the UK Southern North Sea, which was held by Tailwind Energy.
Reflecting on Serica's investment focus on enabling maximum production like from the Bruce and Triton assets, Mitch Flegg, Chief Executive of the company, said, "Production in 2024 is expected to be higher than in 2023 with guidance between 41,000 boe/d and 48,000 boe/d for the year. This reflects a range of outcomes in a year of significant activity including the speed with which the scheduled drilling and well work deliver incremental production.
"Serica's strategy of investing in its assets continues to be central to our record of consistently achieving high levels of reserves replacement, combined with increased levels of production. We are looking forward, therefore, to the start of the four well Triton area drilling programme in March, with the benefits of added production expected to start coming through in the second half of the year. During 2024 there is also an extensive programme of interventions in both platform and subsea wells on the Bruce and Keith fields. The objectives include re-establishing consistent production from the Keith field.
"In addition, Serica has a healthy portfolio of potential new projects. This includes the possible developments of the Buchan and Belinda fields, which offer the prospect of further replacement of produced reserves and incremental production from 2026 onwards. Our plans for drilling two Bruce infill wells, the first new wells on the field since 2012, are progressing and, during the next eighteen months, we will be participating in the Parkmead operated Skerryvore exploration well situated in the UK Central North Sea. As a UK taxpayer, Serica will benefit from tax relief for its share of the associated development and exploration costs.
"Serica is extremely well placed, therefore, to continue its track record of replacing reserves and increasing production. This platform has been achieved while maintaining a very strong balance sheet, which is both the result and enabler of our strategy to invest and grow organically and through disciplined M&A."
Norwegian energy producer Equinor will deploy Emerson's suite of Roxar downhole monitoring tools to achieve optimal results from the Rosebank oil and gas field offshore the United Kingdom.
With an estimated capacity of more than 300 million barrels of recoverable oil resources, the Rosebank field is considered a significant asset in meeting the UK’s energy security requirements. The first phase of the Rosebank field development will involve a refurbished, electrification-ready floating production storage and offloading vessel connected to a subsea production system. Startup of the Rosebank field’s first phase is planned for 2026-2027.
Emerson's advanced well completion monitoring systems enable advanced oil recovery techniques, optimise reservoir performance and verify well integrity in real time. A challenging task amid harsh environment conditions, the Roxar integrated downhole network technology provides an uninterrupted coverage of pressure and temperature data from active wells, which leads to safe operation, production optimisation and well integrity maintenance.
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.
Energy services provider Expro has announced it has entered into a definitive agreement to acquire Coretrax, a technology leader in well integrity and production optimisation solutions, from an investment group led by Buckthorn Partners.
The acquisition of Coretrax will enable Expro to expand its portfolio of cost-effective, technology-enabled well construction and well integrity solutions, particularly across the North and Latin American, Europe and sub-Saharan Africa, and the Middle East and North Africa. Building on Coretrax’s successful 15-year history, the acquisition will accelerate the availability of the company’s innovative tools by leveraging Expro’s global operating footprint.
Michael Jordan, Chief Executive Officer, said, “We are thrilled to announce our proposed acquisition of Coretrax and look forward to welcoming John Fraser and his teammates to the Expro family.
“Coretrax has a complementary offering to Expro with little overlap and will bolster the portfolio of technology-enabled services and solutions offered through our Well Construction and Well Intervention & Integrity product lines, adding significant value to our clients from innovative technologies that reduce risk and cost, optimise drilling efficiency, extend the life of existing well stock, and optimise production.”
John Fraser, CEO at Coretrax, commented, “The synergies between our respective technology portfolios will enable us to grow our market share while significantly increasing our capabilities to tackle the most complex well challenges. We are proud of the innovation-led approach, strong customer base and performance history that we developed over the last 15 years, and we look forward to joining forces with Expro to create greater value for our customers globally.”
Siem Offshore has secured long-term contracts with Helix Energy Solutions for two of its Siem Helix well intervention vessels.
The two contracts for Siem Helix 1 and Siem Helix 2, valued at US$682mn, will come into effect from 1 January, 2025, and 1 January, 2026, respectively and will replace existing agreements to ensure firm utilisation for these vessels until at least 2030.
Each vessel will have a duration period of six years, with an optional extension period of up to five years, the contracts provide a solid foundation for future endeavors and growth for Siem Offshore. Siem Helix vessels have played a crucial role in the well intervention segment, and the longstanding partnership between Siem and Helix is a testament to the success both companies have endured.
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