Ocean services provider DeepOcean has been selected to support the subsea decommissioning and disconnection of an FPSO in the UKCS.
The scope of work includes hydrocarbon and chemical injection flushing; isolation and disconnection of subsea trees, manifolds, and pipeline infrastructure; disconnection of risers and dynamic umbilicals; riser and mooring chain severance and recovery; and FPSO sail-away and tow to shore.
The project will be managed and executed by DeepOcean’s operations in Aberdeen.
Robin Mawhinney, Executive Vice President of DeepOcean’s EMEA region, said, “This is a significant project encompassing both subsea and topside scopes that strongly aligns with our extensive experience. Our innovative approach has been successfully demonstrated across many complex projects, and it’s our teamwork and proven capability that will drive a safe, efficient removal of subsea infrastructure, along with the safe towage of the FPSO.”
Gary Scott, Commercial Director of DeepOcean’s EMEA region, commented, “Execution will build on the methodologies and proprietary tooling that was pioneered at the disconnection of the Gryphon Alpha FPSO last year, enabling the full scope to be delivered entirely without the use of divers. This is a testimony to the team’s successful delivery of decommissioning scopes in the region.”
Following five years of abandonment, Perenco UK has managed to revive the Davy gas field in the Southern North Sea, which is now generating production.
This is no mean feat, given the field was shut in for so many years, and finally earmarked for decommissioning following several failed attempts to restart it.
Now the company has completed a comprehensive revival project with production from Davy wells A3 and A5 restarting in late April 2026. Both the platforms are now stably generating a combined yield of approximately 14 MMscf/d into Perenco’s Bacton terminal.
The primary consideration that drove the comprehensive work programme to prolong field life was safety. The company significantly simplified the original 1970s' design, and included material equipment upgrades, along with the installation of a wind turbine.
In addition, partial decommissioning of nonproductive wells has been achieved with the plugging and abandonment (P&A) of 2 platform wells and 2 subsea wells. The simplified Davy platform is now powered predominantly by wind energy rather than diesel generation, so the operation is now continuing with a lower carbon footprint.
Jo White, UK SNS General Manager said, “The restart of the Davy gas field after five years offline is an excellent result and showcases how assets consigned for decommissioning can be revived and continue to make a meaningful contribution to the UK’s energy mix. Davy is set to continue to produce for several years to come, and to operate reliably and with lower OPEX following the recent work programme. This is another successful collaboration between the highly-skilled Perenco and Petrodec operational and project teams, and I would like to congratulate all those involved in realising this important project.”
The ongoing US-Iran war and resulting disruptions in the Strait of Hormuz have triggered a pragmatic shift in European Union energy policy, forcing a temporary rethink of its green transition priorities in favour of immediate energy security.
Since the escalation of conflict in February 2026, which disrupted LNG flows from Qatar and pushed up global oil and gas prices, the EU has faced its second major energy crisis in four years.
According to some reports, additional costs for energy imports have already exceeded €24bn, prompting swift policy adjustments.
In April, the European Commission unveiled the AccelerateEU plan, proposing cuts to electricity taxes, coordinated summer gas storage refills, and incentives to accelerate clean energy deployment while shielding households and industry from price shocks.
The measures aim to make electricity cheaper than fossil fuels and support faster rollout of renewables and efficiency improvements.
More significantly, EU energy ministers are now openly discussing boosting domestic natural gas production.
At a meeting chaired by Cyprus (which holds substantial offshore reserves) officials are exploring greater use of indigenous resources to reduce reliance on volatile imports.
This marks a notable departure from previous reluctance to expand fossil fuel output within the bloc.
The Commission has also drafted guidance allowing member states to suspend penalties for oil and gas companies breaching the EU’s methane emissions regulation during supply crises.
The move follows intense industry and US pressure, aiming to prevent potential disruptions to imports as stricter rules approach in 2027.
These shifts highlight the tension between Europe’s long-term climate goals and short-term security needs.
While accelerating homegrown clean energy remains a priority, the crisis has underscored vulnerabilities in global LNG markets and reinforced the role of reliable regional suppliers like Norway, which is expanding its offshore output.
Analysts warn that prolonged reliance on emergency measures could delay the energy transition, yet most agree the current geopolitical reality demands a balanced approach.
EU leaders continue to stress that domestic production increases should not lock the bloc into long-term carbon dependence.
Norway is intensifying its offshore petroleum activities to strengthen European energy security amid ongoing global supply uncertainties.
Energy Minister Terje Aasland has underscored the importance of expanding, rather than reducing, operations on the Norwegian continental shelf.
On 5 May 2026, the Norwegian authorities announced the APA 2026 licensing round, offering up to 70 new exploration blocks: 38 in the Barents Sea, 22 in the North Sea, and 10 in the Norwegian Sea.
Applications are invited until 1 September 2026, with awards scheduled for early 2027.
This move continues Norway’s strategy of sustaining long-term production and attracting investment from international oil companies.In a separate development, plans were confirmed to reopen three historic North Sea gas fields like Albuskjell, Vest Ekofisk, and Tommeliten Gamma, which have been closed since 1998.
Operator ConocoPhillips, together with partners, is set to invest approximately €1.8bn, with production potentially resuming by 2028.
The fields could deliver significant gas volumes to markets in Germany and the United Kingdom through to 2048.
Additionally, Equinor has recently started production from the Eirin field via a subsea tie-back to the Gina Krog and Sleipner installations, adding further gas supply to Europe.
These initiatives reflect Norway’s response to tightening global energy markets.
By maximising output from mature and frontier areas, the country aims to provide reliable supplies while balancing its energy transition commitments.
Industry observers note that heightened geopolitical tensions have reinforced the role of Norwegian gas in stabilising European energy prices.
The developments are expected to generate substantial economic activity and support thousands of jobs across the Norwegian supply chain.
Equinor ASA has extended a series of major supplier agreements for drilling and well services, with a combined value of about NOK 17 billion.
The extensions are aimed at sustaining production on the Norwegian continental shelf, maintaining operational activity and supporting consistent energy supply to Europe.
The company has activated one-year extension options for three integrated drilling and well service contracts, alongside two-year extensions for 18 corporate framework agreements covering specialised services associated with these operations.
The integrated drilling and well services contracts are valued at NOK 8.3 billion, while the framework agreements for specialist services are expected to generate around NOK 4.3 billion annually over a two-year period.
Contracts for integrated drilling and well services have been awarded to Baker Hughes Norge AS, Halliburton AS and SLB Norge AS. These companies, along with an additional 15 suppliers, have also secured framework agreements for specialised services. The agreements are designed to ensure access to the expertise and advanced technologies required to improve efficiency in well operations and adapt to evolving operational demands.
“These agreements are among the largest we have, and they are crucial for activity on the Norwegian continental shelf. New wells enable us to maintain high production and deliver stable energy to Europe. This is particularly important at a time of turbulence in the energy markets,” says Jannicke Nilsson, chief procurement officer.
The contracts are expected to support around 2,500 jobs and will cover operations across both fixed installations and mobile drilling rigs on the Norwegian continental shelf.
As the region matures, drilling and well activities are becoming increasingly vital to sustaining output levels. Equinor aims to maintain production at approximately 1.2 million barrels of oil equivalent per day through to 2035.
“New wells are expected to account for around 70 percent of Equinor’s production in 2035. This involves both more wells and more well interventions, which must be delivered faster and significantly more cost-efficiently than today. That requires closer collaboration with the supplier industry and increased use of technology and standardisation,” says Rune Nedregaard, senior vice president for Wells.
“We are now moving to a greater extent towards industry standards. Together with our suppliers, we will use this to simplify work processes, reduce costs and increase pace, while maintaining safety,” Nedregaard continues.
Equinor ASA has awarded Archer a three-year contract extension for wireline and intervention services on the Norwegian Continental Shelf.
The extension builds on the integrated wireline contract originally awarded to Archer in 2021, under which the company, along with partners, delivered services across key Equinor assets. While extension options were available in the original contract, the current award represents a firm three-year extension, providing continued operational continuity and visibility.
The contract represents a total contract value of approximately NOK3bn (around US$322,117), with around half attributed to Archer and the remainder allocated to alliance partners.
Dag Skindlo, Chief Executive Officer at Archer, said, “This contract extension reflects the strong and long-standing relationship we have built with Equinor. We are pleased to continue supporting Equinor’s operations and consider this agreement strategically important for Archer. It provides long-term visibility to our business, reinforces the strength of our alliance model, and demonstrates the trust placed in our people, technology and service quality.”
The agreement reinforces Archer’s position as a trusted provider of advanced well services, supporting Equinor’s operations through the continued delivery of wireline and intervention solutions.
Well-Safe Solutions, a tier-one specialist in well decommissioning, has secured a multi-year agreement with Apache North Sea Limited to decommission platform and subsea wells in the Forties Field.
The programme is scheduled to commence in 2026, with Well-Safe Solutions taking responsibility for all well-related project management, well and subsurface engineering, and offshore execution for both platform and subsea wells.
The contract is expected to sustain hundreds of jobs in Aberdeen while providing a welcome economic uplift to northeast Scotland during a period of ongoing pressure on the sector and concerns around long-term workforce retention.
Phil Milton, Chief Executive Officer at Well-Safe Solutions, said:
“This award is a defining moment for Well-Safe Solutions and a testament to the confidence Apache has in our team to deliver safe, efficient and technically robust decommissioning solutions at scale.
“This contract award is exciting news for our business and for the wider economy, sending a powerful signal to the supply chain and helping to secure critical talent and resources. Today’s announcement is undoubtably a huge moment for our business and our industry, however, it comes at a particularly difficult time for our sector when we are hopeful of retaining the talent and capability that we have in the North Sea”
Industry capacity for mobile offshore drilling units able to carry out both drilling and decommissioning work on platform and subsea wells has fallen steadily in recent years. Only five semi-submersible rigs now remain in the UK Continental Shelf. This continued decline in available assets could hinder the UK’s ability to satisfy future energy requirements and fulfil decommissioning commitments, with thousands of wells expected to require decommissioning before the decade ends.
Donald Martin, Vice President, Decommissioning, Apache, commented:
“We are pleased to partner with Well-Safe Solutions on this large-scale decommissioning programme across the Forties Field. This contract reflects our commitment to delivering safe, predictable and cost-effective decommissioning through disciplined execution and with a high-performing, integrated team.
“Building on decades of successful production from one of the North Sea’s cornerstone assets, Apache is focused on maximising late-life asset value, reducing risk, and delivering a safe, efficient and disciplined transition into decommissioning.”
The latest award further strengthens Well-Safe Solutions’ standing as a strategic leader in the UK decommissioning market. It follows successful recent campaigns involving the Well-Safe Defender and Well-Safe Protector, as well as two other significant North Sea contract wins announced earlier this summer.
Odfjell Technology has announced the signing of a five-and-a-half-year contract with ConocoPhillips Skandinavia AS for integrated services in the North Sea.
The contract period has been agreed until 31 December 2031, and covers the provision of platform drilling operations and maintenance services, tubular running services, well engineering, and well planning in Norway.
The contract also covers options for the provision of downhole equipment and permanent plug and abandonment execution. The agreement forms a strong foundation for the company’s growth in the market.
Kurt Meinert Fjell, EVP Operations at Odfjell Technology, said, “We are pleased to further strengthen our partnership through this contract. The agreement underlines the strong relationship between our teams and provides a strong foundation for continued innovation and value creation.”
SLB has completed its acquisition of HydraWell Intervention AS, a Norway based company known for its advanced solutions in well abandonment and integrity management
This move strengthens SLB’s position in the growing field of well intervention and supports its focus on delivering practical and efficient solutions for the energy sector.
HydraWell brings with it a specialised approach to plug and abandonment, often referred to as P and A. Its core technology, known as perforate, wash and cement, offers a different way of sealing wells. Instead of relying on traditional methods that often involve heavy mechanical work, this process creates strong barriers within the well structure in a more direct and controlled manner. The result is a simpler operation that reduces both time and cost.
“This acquisition represents an important step in SLB’s strategy to deliver transformative solutions for our customers,” said Frederik Majkut, president, Reservoir Performance, SLB. “By integrating HydraWell’s groundbreaking technology with the global expertise and intervention capabilities of SLB, we are uniquely positioned to redefine operational efficiency and cost-effectiveness in well decommissioning and other well integrity remediation challenges.”
The technology developed by HydraWell has already been tested in real field conditions and supported by detailed modelling. It allows for effective cleaning of the well and careful placement of barriers, ensuring long term safety and performance. By removing the need for complex steps such as casing removal, it offers a more straightforward solution for operators managing ageing wells.
This acquisition also gives SLB the ability to offer flexible services across different types of well work. While it is designed for permanent closure, the same approach can also support other tasks such as zonal plugging and general well repair. This makes it useful for companies aiming to maintain efficiency while meeting strict environmental and regulatory standards.
As the demand for responsible well closure continues to rise, SLB is positioning itself to meet these needs with modern and reliable solutions. The addition of HydraWell strengthens its ability to support customers through every stage of a well’s life cycle.
Vaisala has introduced its Maritime Automatic Weather Station AWS830, a next-generation solution designed to strengthen safety and operational reliability in offshore and marine environments.
The system provides continuous, real-time data on key parameters such as wind speed, atmospheric pressure, visibility, temperature, humidity and wave conditions. This level of monitoring is critical for offshore operations, where changing weather can directly impact navigation, lifting activities and helideck operations.
Engineered for harsh marine conditions, the AWS830 is built to withstand corrosion, vibration, extreme temperatures and high humidity. Its rugged design ensures dependable performance in exposed offshore settings, supporting safer decision-making across vessels and platforms.
Security and data integrity are also central to the system. The AWS830 incorporates advanced cybersecurity features to ensure that weather data remains accurate, authenticated and protected. This is particularly important in offshore environments, where reliable information is essential for both safety and operational continuity.
Panu Partanen, vice president of sales and marketing for Weather, Energy and Environment at Vaisala, said the launch represents a significant technological step forward. “AWS830 represents a fundamental next-generation advancement in maritime weather monitoring of which we have decades of experience. This launch reinforces our commitment to supporting maritime operations through reliable, cybersecure weather intelligence,” he noted.
The system’s modular design allows integration with vessel navigation and automation systems, while also supporting a wide range of sensors. It is compatible with Vaisala Elements Helideck Monitoring Software, enhancing safety for offshore helicopter operations.
Mikko Nikkanen, head of maritime at Vaisala, emphasised the importance of reliability in critical environments. “Maritime operations demand weather monitoring systems that perform flawlessly while meeting stringent safety and environmental standards. Our customers need systems they can depend on and trust for critical operational decisions,” he said.
Deliveries of the AWS830 are expected to begin in June 2026, as demand grows for advanced monitoring solutions in offshore energy and maritime sectors.
A case study on Dynamic Gyro Compass (DGC) technology highlights how survey time in North Sea sections was reduced by 76%, as SLB and bp advanced gyro-while-drilling (GWD) capabilities at the Clair Ridge development
The solution enabled accurate, real-time survey measurements under all heave conditions, independent of the BHA provider, ensuring consistent performance in offshore environments.
The application of DGC technology has significantly improved operational efficiency. By removing the need for wireline scoping runs, the solution reduced survey time by 76%, while also lowering personnel exposure in high-risk red zones. This has contributed to stronger health and safety outcomes and streamlined offshore operations.
During tophole drilling at Clair Ridge, bp encountered difficult conditions that disrupted conventional gyro tools. The high levels of environmental noise made traditional methods unreliable, forcing reliance on wireline scoping gyro surveys. These operations were not only time-intensive but also required repeated red-zone access and additional personnel, increasing both safety risks and operational costs.
To overcome these issues, bp aimed to minimise time spent drilling and sitting on bottom, reduce red-zone entries, and lower the total number of personnel on board.
SLB addressed these challenges by integrating its DGC technology with the Quest GWD solid-state gyro while drilling system. The solution effectively filtered out environmental noise, enabling accurate survey readings in complex tophole conditions and eliminating the need for wireline runs.
Across two drilling sections, the average survey time dropped to 13 minutes, compared to 66 minutes per wireline run, saving approximately 53 minutes per survey. With around 21 surveys typically required per section, this translated into a time saving of nearly 18 hours per section. Notably, the sections drilled using DGC technology were completed faster than any previously recorded in the field.
“The use of DGC technology with the Quest GWD solid-state gyro while drilling tool allowed us to eliminate multiple wireline surveying runs typically required during tophole operations. This significantly enhanced operational efficiency and safety by improving red-zone management and reducing the risk of dropped objects.”
Jim O'Leary, vice-president Wells North Sea, Mauritania, Senegal & Brazil, bp.
Read the complete story here: www.slb.com
DroneQ Robotics has partnered with Mark Offshore to deploy the research and survey vessel R/V Mintis as a multi-functional offshore platform, integrating remotely operated vehicle (ROV) systems, drone technologies and specialised marine services.
The move marks a strategic expansion of DroneQ’s advanced unmanned robotics services offering, positioning the vessel as a combined solution for subsea inspection, survey and maintenance operations across offshore energy and maritime sectors.
Mark Offshore, which recently assumed operational management of the vessel on behalf of Klaipėda University, said the initiative builds on a long-standing collaboration between the two companies. The partnership aims to enhance service delivery by combining vessel operations with cutting-edge robotics and inspection capabilities.
R/V Mintis, a DP1-class vessel, has been upgraded with a suite of advanced ROV systems designed to operate in both shallow and deep-water environments. These include a newly deployed Class I system capable of operating at depths of up to 350 metres, equipped with high-resolution cameras, sonar technologies and obstacle detection systems to support detailed subsea inspections.
A second, more advanced Class II ROV system extends operational capability to depths of 1,000 m, incorporating precision navigation tools, 3D imaging technology and non-destructive testing equipment. The system is supported by dedicated offshore control and workshop units, enabling efficient deployment and real-time data analysis.
In addition to subsea robotics, the vessel will also utilise industrial-grade maritime drones designed for offshore conditions. These systems enable aerial inspections of assets such as wind turbines and oil and gas installations, providing an additional layer of operational flexibility and safety.
John Troch, co-founder of DroneQ Robotics, said, “The partnership with Mark Offshore and this vessel is a big leap forward in the growth of DroneQ Robotics in general, and our Advanced Unmanned Robotics Services, AURS, proposition for the offshore market in particular! The market is beginning to realize that Big, Bigger, Biggest is not always the best solution.”
The vessel is expected to support a wide range of activities, including subsea construction support, environmental surveys, pipeline and cable inspections, and salvage operations. Its capabilities also extend to bathymetric mapping and unexploded ordnance detection campaigns.
Mark Offshore highlighted that the collaboration has already delivered early commercial success. Managing director Mark van der Star said, “Due to our long-standing relationship with John, and our shared drive to deliver results, our cooperation already translated into a concrete project in the very first week of our commercial management of R/V Mintis.”
He added that the company’s approach focuses on maximising asset value from the outset, transforming vessels into revenue-generating platforms through integrated service offerings.
The deployment of R/V Mintis reflects growing demand for efficient, technology-driven offshore solutions, as operators seek to improve safety, reduce costs and enhance inspection accuracy across complex marine environments.
Copyright © 2026 Offshore Network
