Expro, a leading energy services provider, has successfully completed the first full deployment of its Remote Clamp Installation System (RCIS), marking a major advancement in offshore safety and operational efficiency
Developed by Expro’s Frank’s Tubular Running Services (TRS), the RCIS provides a unique industry solution for smart well completions, enabling real-time monitoring and control of downhole tools from the surface via control lines. This technology allows operators to optimise production, manage downhole safety devices essential for well integrity, and extend well life, reducing the need for costly interventions. By fully automating clamp installation on tubing, the RCIS eliminates much of the manual work traditionally required, enhancing efficiency and reducing personnel exposure on the rig floor.
The RCIS was first deployed in the UK’s North Sea during Q4 2024 as part of a test trial, delivered in collaboration with BP, which partially sponsored the technology’s development.
Following this success, the RCIS was deployed again in Q2 2025 by another North Sea operator, where Expro ran a complete hands-free Upper Completion at up to 15 joints per hour with zero non-productive time or control line damage, increasing running efficiency by 25%. Control line clamps were installed remotely, cutting installation time by around two minutes, or 50% per clamp.
Jeremy Angelle, vice-president of Well Construction, said: “This is a breakthrough in clamp installation. By automating a previously manual and high-risk process, we’ve not only increased efficiency but also advanced safety in a meaningful way.”
“The RCIS is designed to offer a practical solution for reducing exposure in hazardous zones, improving crew safety, and streamlining completion activities. As the industry continues to seek ways to minimize manual intervention and improve efficiency, the RCIS represents a scalable, forward-looking solution for offshore operations worldwide.
Angelle added: “This is a new era of safer, smarter completions.”
Russian energy major Gazprom has confirmed a lengthy delay to its Sakhalin 3 offshore project, with first gas now unlikely before 2028, three years later than previously anticipated and one year after it is supposed to start supplying China through a new cross-border pipeline.
The revised schedule was disclosed by Sakhalin Governor Valery Limarenko during an industry gathering in Yuzhno-Sakhalinsk, where he noted that production at the complex would not begin until at least 2028.
Sakhalin 3 covers four separate deposits. The smallest, Kirinskoye, holds around 162bn cubic metres of reserves and began output in 2013 using subsea equipment supplied by FMC Technologies, now part of TechnipFMC.
Gazprom had initially intended to apply the same approach at South Kirinskoye, the largest field in the block with an estimated 815bn cubic metres of reserves.
That strategy collapsed in 2015 after the United States introduced sanctions following Russia’s annexation of Crimea. Since then, Gazprom has been forced to turn to domestic suppliers.
In 2019, it awarded a contract to defence manufacturer Almaz-Antey to design and build subsea production systems. While the company delivered two specialised subsea wellheads in 2023, progress on the remaining infrastructure has stalled, with no clear delivery schedule announced.
The continued delays underscore the difficulties Gazprom faces in developing technically complex offshore projects without Western technology, particularly as pressure mounts to secure new export flows to China.
Weatherford International plc has announced that it has been awarded an eight-year contract by SNGN Romgaz S.A., Romania’s largest natural gas producer and main supplier, and the third-largest gas producer in Europe.
The contract involves providing services for real-time monitoring and transmission of dynamic parameters from gas well wellheads, enhancing production optimization through digital and AI-enabled insights.
This represents Romgaz’s first engagement of such services, demonstrating the company’s commitment to digital transformation and production automation. Under the agreement, Weatherford will implement a wellsite monitoring campaign across thousands of existing wells. Using cloud infrastructure, Weatherford technology will gather critical field data, providing Romgaz with essential information for production decisions. This data will guide in-field automated infrastructure supplied by Weatherford to achieve Romgaz’s production optimisation goals.
Girish K Saligram, president and chief executive officer of Weatherford, commented, “We are proud to support Romgaz in their first deployment of real-time monitoring services. With our technology, expertise, and recent investments in Romania, Weatherford is well positioned to help Romgaz optimise production and build fields of the future with solutions that enable smarter and more reliable operations.”
Razvan Popescu, chief executive officer of Romgaz, added, “Partnering with Weatherford marks a significant step forward in Romgaz’s digital transformation journey. For the first time, we are implementing real-time wellsite monitoring technologies that will provide actionable insights and enhance the efficiency of our operations. This initiative aligns with our strategic objectives of innovation and operational excellence. We are confident that this collaboration with Weatherford represents a strategic first step in integrating AI-driven technologies into our operations and laying the foundation for a new era of intelligent transformation.”
Weatherford’s well monitoring solutions deliver continuous, high-fidelity well data, enabling smarter decision-making and proactive intervention strategies. Implementing these systems will allow Romgaz to gain enhanced visibility of well conditions and optimise production throughout the duration of the contract.
Petrofac has secured an extension to its contract with ONEgas West, reinforcing its presence in the Southern North Sea market.
The deal, issued on 15 September 2025, continues Petrofac’s long-running service role across ONEgas West’s portfolio, including support for the Clipper South complex, Leman Alpha assets, Bacton Terminal, and OneGas barge operations.
John Pearson, chief operating officer of Petrofac’s Asset Solutions and Energy Transition Projects, noted that the company has supported these assets since 2020, positioning it as an embedded member of the delivery team with the ability to assist in production enhancement and field life extension.
This extension builds on a similar EPC contract awarded in March 2024, when Petrofac won a two-year brownfield EPC extension with ONEgas West, which is operated by NAM and owned by Shell UK. The renewed scope underscores ONEgas West’s confidence in Petrofac’s teams in Great Yarmouth and Aberdeen, valued for their operational knowledge and delivery.
As the industry faces pressures including energy transition goals and tighter regulation, contracts like this become strategic. Supporting key infrastructure such as terminals, complex offshore installations, and barge operations helps ensure continuity of supply and contributes to operational resilience.
For Petrofac, this deal strengthens its standing in one of its primary markets and demonstrates its capability to deliver both maintenance and enhancement in challenging offshore settings.
“Having supported these assets since 2020, Petrofac is embedded within the delivery team and is uniquely placed to support production enhancement and field life extension,” said Pearson.
“The North Sea remains one of Asset Solutions’ core markets and this award demonstrates confidence held in our team and the value they drive. We look forward to continuing this relationship, delivering safe and reliable operations.”
UK's Serica Energy has revised its 2025 production guidance following maintenance challenges and scheduled subsea work on fields tied to the Triton FPSO.
The Triton Floating Production Storage and Offloading (FPSO) vessel is operated by South Korea's Dana Petroleum.
Serica Energy said production guidance has been reduced to between 29,000 and 32,000 barrels of oil equivalent per day (boepd), down from a previous range of 33,000–35,000 boepd.
Operator Dana Petroleum notified Serica of a temporary reduction in output from the Triton FPSO due to a vibration issue within the compression trains.
Production is currently running at a significantly reduced rate but is expected to return to normal levels by the end of September once repairs are completed.
Production net to Serica from the Triton FPSO exceeded 25,000 boepd in August. Once both compressors are operational, output will be boosted further, supported by additional production from the EV02 well on the Evelyn field.
Dana has also scheduled subsea intervention work on the Bittern field for November 2025 to address an emerging infrastructure vulnerability.
Originally expected in 2026, the three-week scope will now halt production not only from Bittern but also from the Evelyn and Gannet fields, temporarily reducing Serica’s output by more than 20,000 boepd.
Despite the setbacks, Serica highlighted that production ramp-ups earlier this year had lifted wider portfolio output to more than 55,000 boepd in mid-August, before the maintenance-related constraints began.
HELLENiQ Energy has confirmed its participation, in partnership with Chevron, in the Call for Tenders issued by the Ministry of Environment & Energy (FEK 2104/30.04.2025) for hydrocarbon exploration and production rights in four offshore blocks located south of the Peloponnese and south of Crete.
The joint offer was formally submitted on 10 September, in line with tender regulations.
This step marks a significant milestone for HELLENiQ Energy as it builds on its existing exploration and production portfolio in Greece, reinforcing the company’s commitment to supporting the country’s energy ambitions and strengthening its upstream activities.
For Chevron, the participation represents a strategic new entry into the Greek energy market, underscoring the international appeal of Greece’s offshore potential.
The partnership between HELLENiQ Energy and Chevron combines deep technical expertise, operational experience, and financial strength, positioning the consortium as a competitive player in unlocking the hydrocarbon resources of the region.
If awarded, the project is expected to contribute to enhancing domestic energy security, diversifying supply sources, and supporting the wider energy transition goals of Greece and the European Union.
Stavros Papastavrou , Greek Minister of Environment and Energy, said on Wednesday, "Today, the Chevron and HELLENiQ Energy consortium announced its participation in the international competition for the 4 offshore blocks south of Crete and the Peloponnese. Thus, a new chapter opens for the exploitation of the underwater energy wealth of our homeland."
"This is a development of Hope and Perspective for our country. Greece, with national self-confidence, is laying solid foundations for its energy self-sufficiency and capitalising on its geopolitical position in the Eastern Mediterranean. The Government of Kyriakos Mitsotakis is fulfilling its duty to our children and future generations, implementing its commitments for a Greece that is energy secure, investment attractive and geopolitically strong. Starting tomorrow, we are moving forward even more decisively, faster, unlocking our country's potential for progress and prosperity for all Greek women and men."
Europe’s offshore oil and gas sector is witnessing a wave of technological advancements in subsea production and well intervention. From all-electric subsea systems to automated clamp installations, operators and technology firms are driving efficiency, safety, and energy resilience across the continent’s offshore fields.
Subsea7 Sakarya Phase 3 Contract
Subsea7 has secured a major contract with Turkish Petroleum Offshore Technology Centre (TP-OTC) for Phase 3 of the Sakarya field in the Black Sea. The EPCI scope covers subsea umbilicals, risers, and flowlines, with execution managed from Subsea7’s Istanbul office. David Bertin, Senior Vice President, highlighted the award as strengthening Subsea7’s track record in Türkiye while reinforcing its role in supporting the country’s strategic energy goals. Türkiye Business Unit Director, Hulya Ozgur, further emphasized the project’s contribution to energy independence and local content development.
SLB OneSubsea All-Electric Breakthrough
SLB’s OneSubsea joint venture with Equinor has been awarded an EPC contract for a 12-well, all-electric subsea production system at the Fram Sør field offshore Norway. The development, executed as a tieback to the Troll C platform, will minimize topside modifications while significantly lowering emissions. SLB OneSubsea CEO, Mads Hjelmeland, described it as “the first large-scale all-electric subsea production system,” unlocking future tieback opportunities and enabling more marginal resource development on the Norwegian Continental Shelf.
Ace Well Technology’s Automated Clamp Success
Ace Well Technology, with partners Expro and Archer, has completed the first offshore deployment of its Ace Control Line Clamp (ACLC) using Expro’s Remote Clamp Installation System (RCIS) on the Norwegian Continental Shelf. Built on Ace’s proven ratchet technology, the system achieved installation speeds of 15–16 joints per hour with consistent precision. Technology manager Anbjørn Kaurstad highlighted its ability to reduce red zone exposure, while Archer’s Bjørn Christensen praised its contribution to safety and operational consistency.
Ace Well Technology, in collaboration with Expro and Archer, has successfully completed the first well deployment of the Ace Control Line Clamp (ACLC) using Expro’s Remote Clamp Installation System (RCIS) on the Norwegian Continental Shelf (NCS). This marks a significant milestone in advancing well completion operations through automation, combining precision engineering and operational efficiency.
“The ACLC was engineered with the objective of maintaining mechanical robustness while enabling remote installation under dynamic rig conditions. By leveraging our proven ratcheting mechanism, we’ve developed a clamp that delivers consistent holding force, precise alignment, and rapid installation - whilst significantly reducing red zone exposure. This first deployment confirms the system’s performance in real-world conditions and validates the design choices that underpin its functionality,” said Anbjørn Kaurstad, technology manager at Ace Well Technology.
The operation was carried out with Archer as the drilling contractor, who welcomed the new system for its operational consistency and technical advantages. “We’re excited to join this breakthrough – hands-free completion enhances safety and efficiency by reducing manual risks and delivering more consistent results. Upholding strong QHSE standards is vital to every project, and this innovation helps us protect our team while improving the quality of our deliveries,” said Bjørn Christensen, One Archer Manager FLX.
Built on Ace’s proven Ace Ratchet Collar (ARC) technology, the ACLC automates control line clamp installation while maintaining reliability under rigorous well conditions. The combined ACLC and RCIS system performed seamlessly during the first deployment, achieving a peak running speed of 15–16 joints per hour. All clamps functioned as designed, with control lines securely fastened throughout the operation and an average installation time of around 50 seconds per joint.
The ACLC concept was initiated in 2020 at the request of Equinor to improve completion operations by integrating automation. Ace Well Technology partnered with Expro to develop the system, combining Ace’s expertise in mechanical downhole solutions with Expro’s remote handling technology. The collaboration culminated in this successful deployment, demonstrating both the technical capabilities and operational efficiency of the system.
The achievement represents a significant step in the evolution of well completion processes, showcasing how automation can streamline installation tasks while maintaining reliability and precision. Interested readers can watch a video demonstration of the RCIS system on YouTube to see the operation in action.
This first deployment of the ACLC with RCIS underlines the growing role of technology-driven solutions in the oil and gas sector, illustrating how engineering innovation can enhance performance, consistency, and operational excellence on the Norwegian Continental Shelf.
Global energy technology company SLB has announced that its OneSubsea joint venture has secured an engineering, procurement, and construction (EPC) contract from Equinor for a 12-well, all-electric Subsea Production System (SPS) in the Fram Sør field, located offshore Norway.
The contract follows a year-long collaborative Front-End Engineering Design phase during which Equinor and SLB OneSubsea jointly advanced the project. This collaboration resulted in the finalized development plan and final investment decision (FID). Under the EPC scope, SLB OneSubsea will provide four subsea templates and 12 all-electric subsea trees. This eliminates the need for hydraulic fluid supplied from the host platform and minimizes topside modifications, offering a cost-efficient solution while preserving topside capacity for potential future developments in the area.
"Fram Sør is a breakthrough project for our industry, marking the first large-scale all-electric subsea production system," said Mads Hjelmeland, chief executive officer of SLB OneSubsea. "Not only do all-electric subsea solutions significantly reduce topside needs to make large-scale tiebacks such as the Fram Sør development possible, but they also hold the key to unlock more marginal resources through their reduced footprint and simplified operations."
The development will be executed as a subsea tieback to the Troll C host platform in the North Sea, enhancing energy supply security from the Norwegian continental shelf (NCS) to Europe. Since the host platform is powered from the Norwegian mainland, production from Fram Sør will have very low emissions.
The contract remains subject to regulatory approval of the plan for development and operations (PDO).
Subsea7 has secured a major contract with Turkish Petroleum Offshore Technology Centre (TP-OTC) for the development of Phase 3 of the Sakarya field development in the Black Sea.
Subsea7’s scope includes engineering, procurement, construction and installation (EPCI) of the subsea umbilicals, risers and flowlines. Progress will begin immediately and will be managed by the Subsea7 office in Istanbul.
David Bertin, Senior Vice President for Subsea7 Global Projects Centre East, said, “This awards builds on our track record in Türkiye and further reinforces our relationship with TP-OTC, demonstrating Subsea7’s expertise in delivering complex, integrated offshore projects safely and reliably. It underlines our commitment to supporting Türkiye’s strategic energy goals and advancing our strong regional presence.”
Hulya Ozgur, Subsea7’s Türkiye Business Unit Director, commented, “We are proud to continue our journey with TP-OTC on the Sakarya Gas Field Development Project, supporting Türkiye’s vision for energy independence. This new award reflects the dedication and capability of our Türkiye team, our commitment to local content development, and our focus on delivering safe and efficient offshore solutions.”
In June 2025, Equinor and Shell announced the creation of Adura, a joint venture poised to become the UK North Sea’s largest independent oil and gas producer.
First revealed in December 2024, Adura merges the offshore oil and gas assets and expertise of two energy giants to sustain domestic production and enhance UK energy security.
Headquartered at the Silver Fin building in Aberdeen, Adura is deeply rooted in the city’s legacy as the UK’s energy capital.
The name Adura, combining the “A” of Aberdeen with the “dura” of durability, reflects the venture’s foundation in the granite-strong energy community and its commitment to the North Sea’s long-term future.
The company will manage key assets, including Equinor’s stakes in Mariner and Buzzard and Shell’s interests in Shearwater, Penguins, Gannet, Nelson, Pierce, Victory, Clair, and Schiehallion, alongside various exploration licenses.
Adura is projected to produce over 140,000 barrels of oil equivalent per day in 2025, with ambitions to reach 200,000–220,000 boed within five years as new projects come online.
Since its naming, Adura has progressed toward its planned launch by the end of 2025, pending regulatory approvals.
Approximately 1,300 employees from Equinor and Shell are transitioning to the venture, with Shell staff already based at Silver Fin and Equinor’s workforce relocating from Kingswells in phases through 2026.
This move reinforces Aberdeen’s role as a global hub for energy expertise. Equinor’s £6bn in deferred tax losses will bolster Adura’s financial flexibility, while Shell’s robust production capacity enhances cash flow, positioning the venture for cost-competitive operations in a maturing basin.
Camilla Salthe, senior vice president Equinor UK Upstream, said, “We are so pleased to have reached this major milestone in the creation of the new company with Shell. For us, the name Adura represents the very heart of this company and speaks to its people and place within the energy community anchored in Aberdeen, alongside its longevity and commitment to the North Sea.”
Simon Roddy, senior vice president Shell UK Upstream, said, “Adura takes an exciting step forward today as we unveil its new name – rooted in a proud history in the North Sea and looking forward with confidence to delivering secure energy for the UK for many years to come.When Adura launches later this year it will become the UK’s largest independent producer. Through combining assets and expertise, we will create a robust portfolio, with a shared purpose, to unlock long term value.”
Norway is moving ahead with new oil and gas exploration in an effort to sustain long-term production on the Norwegian continental shelf.
The Ministry of Energy has officially initiated the process for the 26th licensing round, opening the door for companies to nominate acreage for potential development.
“Norway will remain a long-term supplier of oil and gas to Europe, while the Norwegian continental shelf will continue to create values and jobs for our country. To deliver on this commitment, we must make more discoveries — and to make more discoveries, we must explore. That is why today we are launching the process for the 26th licensing round for awarding new production licenses,” said Minister of Energy Terje Aasland.
The announcement coincides with Aasland’s inauguration of the Johan Castberg field in the Barents Sea, one of the largest new projects on the shelf in recent years.
Much of Norway’s remaining oil and gas resources have yet to be proven, making new exploration critical. Without fresh discoveries, production is expected to gradually decline from the early 2030s. Alongside exploration, improved recovery techniques and the development of profitable finds are seen as essential to slowing that trend.
The government has pledged to keep annual licensing rounds at the centre of its strategy. The Awards in Predefined Areas (APA) rounds, which cover most opened and available acreage, remain the backbone of policy. Numbered rounds, such as the 26th, apply to areas outside the APA zone.
“The Labour Party Government has a long-term perspective on the further development of our continental shelf. Europe will need oil and gas for a long time to come. Our goal is to ensure that we can supply oil and gas produced with low emissions for as long as there is a demand. Annual licensing rounds going forward are important to achieve this,” Aasland added.
As part of the 26th round, the Norwegian Offshore Directorate has been tasked with managing the nomination process, allowing licensees to propose areas for inclusion. Their input, combined with the Directorate’s own subsurface assessments, will guide recommendations to the Ministry on which acreage should ultimately be made available.
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