SLB has delivered the first reverse circulation cleanout using the powered downhole measurements system within its ACTive real-time downhole coiled tubing services, in an operation carried out on the Clair Ridge well in the UK North Sea.
The intervention was required by bp to support hydraulic fracturing operations at the field. The well presented a complex set of challenges, including pressure management, multiple zonal isolation requirements and internal diameter restrictions in the lower completion. Conventional reverse circulation cleanouts had offered limited real-time downhole visibility, raising the risk of pressure excursions, inefficient debris removal and nonproductive time.
To address this, SLB deployed a coiled tubing intervention incorporating the ACTive powered downhole measurements system, representing the first application of the technology during a reverse circulation cleanout. Continuous downhole pressure, temperature and casing collar locator measurements allowed for improved pressure management and earlier detection of screenout conditions.
Accurate casing collar correlation supported precise sleeve shifting and pressure testing, reducing the number of confirmation runs required and minimising time spent in the well. Controlled run-in-hole speeds and optimised operating procedures further reduced the risk of tool damage and debris accumulation.
As detailed in SLB’s case study, reverse circulation parameters were adjusted in real time based on downhole measurements, improving sand and proppant recovery while reducing total fluid volumes pumped. Enhanced debris removal at lower return rates supported efficient wellbore cleaning and subsequent post-fracture intervention activities.
Real-time collaboration was enabled through SLB’s InterACT secure wellsite data-delivery solution, improving alignment between offshore and onshore teams and supporting faster decision-making. The integrated approach established a repeatable workflow and benchmark for future offshore well interventions.
Angus Energy plc, a UK AIM-listed independent oil and gas company, has reported significant operational progress in its interim results for the six months ended 31 March 2026, with its well intervention programme at the Saltfleetby Gas Field delivering a substantial increase in production
During the period, the company successfully completed workovers on two producing wells at Saltfleetby, its flagship gas asset. The intervention programme was carried out safely and efficiently, resulting in production rates increasing by approximately 30% compared with pre-workover levels. The improved output has been maintained beyond the reporting period.
Angus Energy said the production uplift is expected to support stronger revenues and cash flow generation, while the company continues to evaluate further opportunities to optimise field performance and maximise the value of its reserves.
The company is also progressing reservoir modelling activities and assessing future development opportunities aimed at extending the operational life of the Saltfleetby field.
Alongside its gas operations, Angus Energy reported continued improvements at the Brockham Oil Field. Following a series of operational optimisation measures, average production rates have nearly doubled compared with levels recorded in early 2025. The company also highlighted improved operational efficiency and a continued reduction in water cut, which has supported enhanced field performance.
Preparations are also underway for the planned return of the BRX4z well at Brockham to production from the Portland reservoir, which Angus Energy believes could further improve production and cash flow from the field.
The company has continued efforts to strengthen its financial position through the restructuring of its financial obligations. Discussions with creditors and stakeholders have progressed, with Angus Energy expecting the process to provide a stronger balance sheet, improved liquidity and a simplified capital structure.
The company has also expanded its gas hedging arrangements through to June 2027. The combined hedge portfolio now covers approximately 12.3 million therms at an average weighted price of around 100 pence per therm, providing greater revenue visibility while maintaining exposure to potential future gas price increases.
For the six-month period, Angus Energy generated revenue of £9.5 million (approx. US$12.8 million), EBITDA of £5.3 million (approx. US$7.1 million) and operating profit of £1.5 million (approx. US$2 million). The company also generated £4.4 million (approximately US$5.9 million) in net cash from operating activities.
Despite continued volatility in commodity markets, Angus Energy remains positioned as a significant UK onshore gas producer. The company noted that approximately 56% of forecast production remains unhedged, allowing it to benefit from favourable gas market conditions.
The company maintained safe operations throughout the period, reporting no health, safety or environmental incidents.
Looking ahead, Angus Energy’s priorities include completing the restructuring process, restoring trading in the company’s shares and building on operational improvements across its portfolio. The company plans to explore further organic and inorganic growth opportunities, including potential mergers and acquisitions.
Aker BP and DeepOcean have carried out an advanced subsea operation without sending key personnel offshore
A task that previously required up to two weeks of offshore activity was completed in around 12 hours, with operations controlled from a Remote Operations Center in Haugesund.
The milestone was achieved at the Idun Nord field in the Skarv area of the Norwegian Sea, where a subsea well was stabilised hundreds of metres below the surface without engineers travelling offshore.
Remote technology transforms subsea intervention
Together with strategic partner DeepOcean, Aker BP completed the well intervention operation using remote technology. The work involved stabilising the well by filling the borehole with gravel, an activity carried out as part of inspection, maintenance and repair (IMR) operations.
The vessel Dina Star was initially mobilised to map the seabed around the Skarv area and was not originally planned for intervention work. To enable the operation, Aker BP transferred the complete operational management process to shore.
From the Remote Operations Center in Haugesund, the team coordinated activities onboard Dina Star in real time. The subsea work was performed by a remotely operated vehicle (ROV), which was also controlled from shore.
Advanced technology and stable communication solutions enabled the onshore team to work closely with offshore personnel throughout the operation.
Improving efficiency through remote operations
The remote subsea intervention highlights how digital technologies can improve offshore efficiency while maintaining safety and operational control.
“We greatly value our collaboration with DeepOcean in developing remote operations. This is a strong example of our ambition to increase efficiency by optimizing the use of vessels and personnel, while maintaining a strong focus on safety and operational control,” commented Jarle Marius Solland, Operations Manager Subsea Execution & Survey at Aker BP.
Solland highlighted several benefits of the approach, including fewer personnel being sent offshore, improved access to specialised expertise across multiple projects, more flexible planning and reduced time and costs.
Although this is the first operation of its kind, Aker BP expects remote working methods to become increasingly important in future offshore activities. Greater control from shore could enable more specialists to contribute to advanced operations without travelling offshore.
A step towards the future of offshore operations
For Aker BP, the remote subsea operation supports its strategy of integrating drones, robotics and remote technologies into offshore activities.
“Aker BP’s operating strategy involves drones and robots on platforms and subsea (ROVs) being an integrated part of observation, inspection, and task execution offshore. These technologies will operate autonomously or via remote control, either locally or from shore,” says Thomas Øvretveit, SVP Operations at Aker BP.
“The successful advanced remote ROV operation in the Skarv area in the Norwegian Sea confirms that we are well on our way to delivering on our strategy as the oil and gas company of the future,” Øvretveit adds.
Odfjell Technology (UK) Ltd has confirmed that a major North Sea operator has signed a Letter of Intent to exercise the remaining two-year option under its existing contract for comprehensive drilling services on a North Sea platform.
The operator has also extended the agreement by adding a further two-year option.
The contract covers a broad range of services, including the management of operations, maintenance and repairs for both the platform’s main rig drilling facility and an intervention completion unit.
Odfjell Technology has been supporting the asset through this contract since 2019, making it one of the company’s largest integrated operations. Following the exercised option, the firm contract period will now run until November 2028, with an additional two-year extension option available beyond that period.
Commenting on the contract extension, Kurt Meinert Fjell, EVP Operations at Odfjell Technology, said: “We are very pleased to continue this contract and build on the excellent work delivered over the past seven years. We look forward to continuing to deliver safe, efficient, and high-performing operations together with our client.”
As offshore energy infrastructure expands into increasingly demanding environments, safeguarding the integrity of underwater assets has become a priority for the energy sector.
Rising to this challenge, the underwater technology specialist Sonardyne has formally signed a Memorandum of Understanding (MoU) with AMOG, an international advanced engineering company. Together, they are set to provide a complete subsea asset monitoring service tailored directly to the needs of offshore energy infrastructure operators.
This strategic alliance integrates Sonardyne’s trusted underwater positioning, communication, and monitoring technologies with the industry-leading engineering assessment expertise of AMOG. By harnessing their combined capabilities, the partnership aims to unlock vital insights into asset health, substantially reduce costly operational downtime, and enable the safe life extension of critical underwater architecture. It will support a wide spectrum of subsea installations, encompassing floating offshore wind platforms and traditional oil and gas moorings, alongside essential pipelines and risers.
Dr Hayden Marcollo, director at AMOG said, “Combining high quality subsea data, processed at source on Observer, with advanced engineering assessments, will provide asset owners with more actionable, near-real-time insight into the condition and behaviour of critical subsea infrastructure.
“For operators, this could support earlier detection of anomalies, improved understanding of loads and motions, and more informed decisions around inspection, maintenance and integrity management, as well as asset longevity, in one end-to-end solution.”
Frank Rose, business development manager at Sonardyne, added, “By integrating on-demand and long term monitoring data from subsea environments with engineering models and analytics, there’s an opportunity to provide a more complete picture of asset performance—whether supporting day to day operations, integrity assurance or life extension strategies.”
“By working alongside AMOG, we’re exploring how data and engineering assessments can come together to give operators greater confidence in the way their subsea assets are performing, today and over the long term.”
Last week, Geoactive announced the launch of DecomX, a new P&A decision support system designed to reduce time and overhead around well decommissioning.
The technology addresses the increasing effort required when selecting the de-risked option, in the shape of validating compliance, drafting submissions, planning campaigns and keeping designs aligned as conditions change.
DecomX supports well abandonment designs across environmental, risk, cost, compliance, and execution. The P&A design has been built directly into the platform, with the system generating feasible alternative options for ALARP comparison. Compliance checks run independently on every design change, checking regulatory standards and internal company rules.
Submissions export a single PDF that includes schematics, barrier definitions, demonstrable evidence, compliance findings, and cost risk justification.
DecomX also allows for wells to be grouped into campaigns, allowing for planning, offshore unit scheduling and equipment allocation to be supported within the same environment.
Gary McWilliam, DecomX Product Champion, said, “P&A engineering itself is demanding, but most teams are spending more time proving and demonstrating decisions than doing the engineering. DecomX was built to deal with that overhead; not by replacing engineers, but by supporting their decisions with consistent, traceable evidence.”
Downhole Tools International (DTI), a supplier of coil tubing, wireline, slickline and cable-deployed tools, has adopted the name Pragma as it redirects its strategic focus toward the development and commercialisation of advanced well barrier technologies
Backed by recent investment from FrontRow Energy Technology Group and BGF (Business Growth Fund), the company is reshaping its business around a three-tier well barrier portfolio. At the centre of this strategy is its flagship M-Bubble metal expandable barrier technology, while the company continues to provide customers with its broader range of downhole tools.
The rebranding represents a return to the company’s original name and reflects a renewed commitment to its innovation-driven heritage. Pragma will continue developing technologies designed to address complex well integrity, water management, and plug and abandonment challenges across the global energy industry.
To support this direction, the company has made significant investments in its workforce, technology development pipeline and international presence, strengthening its position for sustained future growth.
The appointment of David Stephenson as CEO in late 2025 was followed by the establishment of an enhanced management and international business development team. The team brings extensive experience in global well intervention and well barrier development, covering design, operations and commercialisation.
Alongside the redesign and relaunch of its PKB and IX plug technologies under the Pragma brand, the company will maintain M-Bubble as a key component of its growth plans. Efforts will continue to focus on commercial deployment and wider international adoption, particularly in the Middle East and Asia Pacific markets.
David Stephenson comments: “Rebranding as Pragma is about more than a change of name - it’s about reaffirming our focus on well barrier technology and the innovative approach upon which the business was founded.
“With the support of FrontRow and BGF, we’re in a strong position to grow M-Bubble whilst developing well technologies from concept through to commercial deployment, as we help operators tackle increasingly complex well integrity and water management issues.”
Baker Hughes has announced two major contract extensions with Equinor to deliver integrated drilling and well services solutions, along with wireline intervention services.
The multi-year agreements will support Equinor’s offshore hydrocarbon production activities in the North Sea.
As part of the integrated drilling and well services contract, Baker Hughes will provide a comprehensive range of solutions for both mature assets and new developments. The company will draw on expertise from its Well Construction and Completions, Intervention and Measurement portfolios to support projects across the Norwegian continental shelf. Technologies including the Kantori autonomous well construction solution and TRU-ARMS advanced reservoir mapping services will be utilised to help develop offshore resources more efficiently.
Under the intervention services agreement, Baker Hughes will supply fully integrated well intervention solutions, combining its surface and downhole technologies with complementary systems provided by service partners. The objective is to enhance the lifespan and performance of offshore wells operating in the North Sea. The extended contract also broadens the deployment of Baker Hughes’ technology portfolio built around the PRIME Technology Platform, supporting both production optimisation and emissions reduction initiatives across the Norwegian Continental Shelf.
“Baker Hughes’ ability to provide holistic solutions that unlock incremental value for our customers has been proven through decades of operation in the North Sea,” said Baker Hughes Executive Vice President of Oilfield Services & Equipment Amerino Gatti. “From greenfield well construction operations to interventions that extend the life of mature fields, our innovative technologies and ability to integrate our services can help create a more secure energy future for Norway and all of Europe. We look forward to being part of this new chapter of collaboration with Equinor.”
Baker Hughes has maintained a longstanding presence in Norway’s energy industry, employing thousands of people and operating multiple facilities across the country. Earlier this year, the company inaugurated its new Subsea Services Center of Excellence and manufacturing facility in Dusavik. It also operates a dedicated Center of Excellence for Plug & Abandonment in Stavanger.
Well-Safe Solutions has been awarded a new contract to provide full Well Operatorship and asset execution for an unnamed client in the North Sea.
The contract scope will see the company undertake operations management of the well decommissioning, including initial subsurface analysis and well design engineering, followed by rig, service, and support vessel provision.
This marks the first Well Operatorship awarded to the company, providing a pivotal step for Well-Safe Solutions’ expanding service offerings across the well lifecycle.
The logical step forward enables more efficient well management through fully integrated package offerings – with owned assets, engineering and services under a single contract.
Phil Milton, CEO of West-Safe Solutions, said, “It has always been our plan to position the business to be able to fulfil the role of Well Operator for our customers and we are grateful for the opportunity to do so under this new contract. This contract, and the Well Operator appointment, recognises our credentials as a cost and schedule3 efficient partners with an outstanding safety record. With our market-leading assets, technical expertise and project management capabilities, we are ideally positioned to provide full Well Operatorship responsibility in the North Sea.”
This contract award represents the fourth major contract win for Well-Safe Solutions this year, following three previous North Sea decommissioning projects.
Archer has agreed to acquire well technology specialist isol8 through a share purchase agreement, strengthening its capabilities in plugging and abandonment (P&A) and expanding its portfolio of well barrier technologies.
The acquisition will add isol8’s expertise in alloy-based barrier systems and advanced materials to Archer’s existing offering. The technologies are designed for application across well completions, intervention activities and P&A operations, supporting the company's ambition to further develop its plug business and enhance its position in the global well abandonment market.
By incorporating isol8’s products and technical expertise, Archer aims to broaden the range of solutions available to customers undertaking well lifecycle management projects, particularly in subsea and rigless abandonment operations.
Archer CEO Dag Skindlo commented: “This acquisition brings valuable technologies and talent into Archer. Isol8’s solutions will strengthen and expand our leading plug portfolio and advance our subsea and rigless P&A offering. The acquisition reinforces our ability to deliver safe, efficient, and scalable well abandonment solutions to our global customers.”
Founded by Andrew Louden, isol8 has developed a range of proprietary barrier technologies designed to improve well integrity and support safe, long-term isolation throughout the well lifecycle. The company’s solutions are used in applications ranging from completions and interventions to final abandonment.
Andrew Louden, Founder and CEO of isol8, commented: “Archer’s global reach and established customer base create a strong platform to scale deployment of isol8’s technologies across the entire well lifecycle. Together, we have the opportunity to expand adoption of our existing alloy barrier products and accelerate the commercialisation of our emerging metal element technology.”
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.”
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