Perenco has announced the successful decommissioning of both the Leman South (53/02a-15Y) and the Durango (48/21a-4z) subsea assets in the Southern North Sea (SNS).
This was done within a single campaign framework that resulted in the plugging and abandonment of the wells, and the removal of the associated subsea infrastructure.
Specialist in integrated solutions for decommissioning and member of the Dixstone group, Petrodec, collaborated with Perenco to complete the work. The highly complex operations were conducted safely and on time using Petrodec’s HAEVA jack up vessel.
The campaign built on recent experience gained from the Gawain, Arthur and Davy subsea abandonment projects, which were also completed using the HAEVA.
Jo White, Perenco UK SNS Managing Director, said, “The Leman South and Durango campaigns were not routine P&A projects. They demonstrated Perenco’s ability to deliver repeatable, large-scale, technically complex subsea well abandonment and infrastructure recovery using an innovative single campaign approach centred on Petrodec’s HAEVA, rather than relying exclusively on high-cost drilling rigs and standalone offshore projects.
“I would like to thank our partners and the Perenco team who were involved in delivering some of the most technically demanding subsea well abandonment activities undertaken in the SNS.”
This industry case study from Expro highlights how its ReLine HYD expandable casing system helped Ithaca restore well integrity on the Captain platform offshore UK, enabling sidetrack drilling while reducing operational complexity and rig time.
Expro addresses casing integrity challenges on Ithaca’s Captain Platform
Expro has detailed a casing repair operation carried out for Ithaca on the Captain platform offshore UK, where corrosion in a 13⅜-inch casing section caused a leak and raised well integrity concerns.
The damage threatened the planned drilling programme. A conventional repair approach would have required cutting and retrieving the compromised casing, drilling a new 17½-inch hole section, and running and cementing replacement 13⅜-inch casing. This would have added operational complexity, rig time and cost.
According to Expro, the operator required a permanent repair solution capable of restoring casing integrity across an extended corroded interval while minimising operational risk and disruption.
ReLine HYD system used for expandable casing repair
Following an assessment of the available well data, Expro developed a tailored repair programme using its ReLine HYD expandable casing system. The solution involved installing a 500-foot expandable casing patch to clad the damaged section and provide a long-term integrity barrier.
The operation also included pressure testing the 13⅜-inch casing sections that would remain uncovered by the patch, following the cutting and retrieval of the 9⅝-inch casing. Expro used the AEON RTP and an abandonment valve as part of the integrity verification process.
The casing patch was deployed using Expro’s tubular running services (TRS), with the installation completed in a single run. Subsequent pressure testing confirmed that casing integrity had been restored.
Expro also highlighted collaboration across its product lines as a key factor in coordinating the operation and reducing execution risks.
Casing repair enables Ithaca to progress sidetrack operations
The repair eliminated the leak and restored wellbore integrity, allowing Ithaca to proceed with its planned activities. These included setting a cement plug below the repaired interval and advancing sidetrack drilling.
The intervention helped the operator avoid the extended delays and additional expenditure associated with a more extensive casing replacement programme. It also preserved the opportunity to develop the well further.
Without the repair, Ithaca could have faced prolonged operational disruption and the potential loss of the planned sidetrack opportunity.
Expandable casing technology supports offshore well integrity
The project illustrates the application of expandable casing technology to address corrosion-related well integrity challenges in an offshore environment.
As described in Expro’s case study, the intervention combined a targeted casing repair with integrated service delivery to restore well integrity and enable further drilling operations. The outcome highlights how specialist well intervention technologies can help operators manage casing damage, limit operational disruption and preserve future well value.
DOF Group ASA has announced the award of a Significant contract in the North Sea for a subsea decommissioning campaign.
The contract includes project management, engineering, offshore execution and disposal services for the removal of subsea infrastructure and seabed clearance across multiple offshore fields.
The offshore campaign is scheduled to go ahead during the first quarter of 2027.
Offshore operations will be performed by one of DOF’s Construction Support Vessels, utilising its integrated decommissioning capabilities, combining in-house engineering, project management, marine operations, ROV services, survey and offshore execution.
Mons S. Aase, CEO DOF Group, said, “We are pleased to secure this contract and look forward to delivering a safe and efficient decommissioning campaign.
“The award reflects the strength of DOF’s integrated service offering and our ability to execute complex offshore projects across the full project lifecycle.
With DOF defining a Significant contract as one with a value between USD 15 million and 20 million, this award further strengthens its position within the decommissioning market and highlights the continued demand for integrated end-of-life solutions for offshore infrastructure.
Transocean Ltd. has secured a new drilling contract worth approximately US$62 million in firm backlog and received final approval for its previously announced Equinor agreement, bringing a further US$1 billion in contract value into its firm backlog.
The company’s Transocean Norge rig has been awarded a two-well programme by A/S Norske Shell in Norway. The work is expected to last around 120 days and begin immediately after the rig completes its existing contracted programmes in the country. The agreement also includes an option for one additional well. The estimated US$62 million backlog contribution excludes additional services.
Separately, Equinor granted final approval in late September for its previously announced agreement covering three harsh-environment semisubmersible rigs operating in Norway: Transocean Enabler, Transocean Encourage and Transocean Endurance. With approval confirmed, the agreement’s total value of approximately US$1 billion has now been formally added to Transocean’s backlog.
Norwegian energy group Equinor confirmed that it has discovered new gas reserves at the Gullfaks South field in the North Sea.
Rather than relying solely on frontier exploration in untested waters, energy operators in the North Sea have increasingly focused on maximising recovery near existing hubs. When new volumes are identified within the reach of active platforms, the pathway from discovery to extraction becomes substantially more straightforward. This latest announcement at Gullfaks South exemplifies how targeted exploration around long-standing assets can yield immediate operational value for the wider offshore sector.
In an official statement detailing the outcome of the evaluation, Equinor noted that the discovery holds between 0.5 million and 1.6 million standard cubic metres of recoverable oil equivalents.
Maintaining steady throughput at mature offshore installations is critical for extending the operational lifespan of the broader field. As reservoir pressures naturally shift over time, introducing fresh gas volumes helps keep topside facilities running efficiently and preserves employment and service activity across the regional supply chain. By confirming that these barrels are commercially sound, the operator underscores the strategic importance of continuous appraisal drilling within established production licences.
The stewardship of the Gullfaks asset reflects the collaborative joint-venture model that underpins offshore resource management in Norway. As the designated operator of the field, Equinor holds a 51% controlling stake, guiding the technical and operational strategy required to bring the newly discovered gas into the production stream.
The remaining equity is divided between two established partners in the region. Petoro withholds a substantial 30% stake in the licence, whilst OMV Norge holds the remaining 19% interest. Together, the three organisations share both the investment commitments and the commercial returns generated by extending the productive life of the Gullfaks South area. As work progresses to integrate these 3.3 million to 10.3 million barrels of oil equivalent into the field's output schedule, the discovery stands as clear evidence that the North Sea fifty-year-old hydrocarbon province still holds profitable surprises beneath the seabed.
Valaris Limited has announced it has been awarded new contracts and extensions, with an associated backlog sitting at approximately US$220mn.
The company has won a two-well exploration contract with Petronas Suriname Exploration & Production B.V for its drillship VALARIS DS-18. The contract is expected to commence in Q4 2026 with a duration of seven months.
VALARIS 107 will head over to Australia with a new contract expected to commence following its current commitments, with an expected duration of 300 days.
The company has also secured a new multi-well P&A contract in the Southern North Sea. The contract is a fleet award under which operations may be performed by any suitable rig within the North Sea fleet. The commencement window is up until December 2030, and has an estimated duration of 341 days.
A contract extension has been granted for VALARIS 122 with INEOS for a project in the Danish North Sea, which will commence in February 2027 for approximately 126 days.
Aker Solutions has been awarded a deal with BP for the provision of engineering and integrity services across the oil giant’s North Sea assets.
The new agreement, which includes engineering, integrity management, project support and operational services, expands Aker Solutions’ existing support for BP’s west of Shetland assets to also include central North Sea assets.
“We are proud to take on expanded responsibilities and look forward to continuing to support safe, reliable and efficient operations for BP” said Steinar Røgenes, acting Executive Vice President for Aker Solutions’ Life Cycle business.
The contract will be managed by Aker Solutions' Life Cycle segment from its facilities in Aberdeen, Scotland and is expected to support approximately 50 positions.
The agreement has an initial duration of three years, with two optional one-year extensions.
“This award strengthens our position in the UK market and supports our ambition to grow our Life Cycle business,” said Røgenes.
“Expanding our role across a broader asset portfolio demonstrates the value of combining technical expertise, commercial competitiveness and strong customer partnerships.”
The British Rig Owners Association (BROA) has announced the appointment of Phil Milton, Chief Executive Officer of Well-Safe Solutions, as its new Chair.
His appointment comes at a pivotal time for offshore operators as the industry is navigating the challenges of maintaining energy security while accelerating the transition to a low-carbon future.
As a highly-respected industry leader, boasting more than 30 years’ experience, Milton brings extensive expertise in well lifecycle services, including decommissioning, project delivery, and energy transition activity. As CEO, he has overseen Well-Safe Solutions’ growth into a leading specialist contractor and has become a prominent voice in the industry.
Milton said, “It is an honour to be appointed Chair of the British Rig Owners Association. I have spent my entire career working on and with rigs, from starting as a machine shop apprentice in the early nineties to building Well-Safe Solutions over the last decade, with our own three rigs now in operation. This is a proud moment for me, and I look forward to supporting our membership through the current challenging climate.
“Our industry has always been subject to high-impact changes and pressures. However, British rigs have now reached a critical point: skills, supply chain and investment are all under severe strain. We need to act decisively to ensure that we continue to have a market here in the UK. Along with the BROA team and the wider UK Chamber of Shipping leadership, I hope to help navigate us towards calmer seas.”
This appointment follows approvals by the UK Chamber of Shipping Supervisory Board, where the BROA Chair holds and official seat, strengthening the representation of offshore rig sector.
Unity, a global specialist in well integrity and decommissioning, has introduced Unity Qb, an ultra-compact blowout preventer (BOP) valve designed to provide pressure control in offshore environments where conventional BOP systems cannot be accommodated.
The new valve is approximately one-third the width of conventional BOP equipment, allowing operators to carry out well intervention activities in areas where space limitations have previously prevented the use of standard systems. Its potential applications include wireline, slickline, coiled tubing and future drilling operations.
Unity has invested around £500,000 in research and development to bring the technology to market. Known as Unity Qb, or 'cube', the valve has been developed specifically for confined spaces on offshore platforms, where the size and configuration of conventional pressure-control equipment can restrict deployment options.
Traditional BOPs are high-pressure safety devices positioned at the top of a well to prevent the uncontrolled release of hydrocarbons. Their large, cross-shaped configuration can determine where they can be installed on an offshore platform. Conventional systems use rams that move linearly from opposite sides of the well bore to seal or shear in response to a hydrocarbon release.
Unity Qb uses a different mechanism. Its rams rotate around a central cartridge inside the valve housing, creating a proprietary design that combines characteristics of a conventional BOP and a ball valve. The arrangement allows the valve to perform conventional BOP functions while occupying substantially less space.
This compact configuration could allow BOP equipment to be installed in locations where a conventional system would not fit and where historically only a Shear-Seal Ball Valve could be accommodated.
The patented valve has a pressure rating of 10,000 psi, which is twice the rating of Unity's existing CSS Valve and other traditional systems referenced by the company. It maintains the same weight while providing the higher pressure rating, allowing Unity Qb to be considered for higher-pressure wells that cannot be serviced by lower-rated equipment.
The system can also be configured in single, dual or triple stacks. Together, these capabilities allow Unity to target applications beyond coiled tubing, an area where the company's CSS technology currently has most of its work worldwide.
Gary Smart, CEO at Unity said: “The future of well intervention will be defined by technologies that deliver more capability from a smaller footprint - Unity Qb represents exactly that step-change. We recognised that the** **size and complexity of conventional BOP systems were increasingly constraining operations in space-limited environments. Rather than accepting those limitations, our engineering team reimagined the design from the ground up. The result is an ultra-compact BOP valve that delivers the performance operators expect while dramatically reducing the space required to deploy it.
“By unlocking access to constrained work environments and creating greater flexibility in system design, Unity Qb has the potential to reshape how intervention operations are executed offshore. This innovation challenges established conventions and expands what's possible for our industry.
“Our CSS valve will remain part of our offering, ensuring our existing fleet continues to support clients who need it. The new Unity Qb is intended to extend the range of interventions we can support, in addition to what we have already been delivering successfully for the last three decades.”
Unity, headquartered in Aberdeen, is part of the FrontRow Energy Technology Group. The company has a 30-year track record in supporting energy operations worldwide, with a focus on helping operators reduce risk, address operational constraints and extend asset life.
The annual Offshore Well Intervention Awards Global 2026 will return to Aberdeen this November, ready to once again shine the spotlight on the greatest minds within the industry.
This year, the judges will review each entry across six different criteria, including originality and creativity; functionality and technical qualities; ease of use; impact on the industry; performance and track record; and sustainability and growth.
The awards up for grabs this year include:
Guests will be treated to an evening of networking, entertainment, a three course meal, and the chance to raise a glass with the best in the industry and celebrate the success with their peers.
The ceremony will take place at the Union Kirk, Aberdeen on 19 November, 2026. Tickets are available on the website.
A North Sea operator improved the reliability of its offshore production operations after deploying a new electric submersible pump (ESP) system supported by Halliburton’s Summit ESP service and digital monitoring technologies
The deployment addressed challenges with the operator’s previous ESP supplier, including missed delivery timelines, limited equipment availability, mechanical failures and high intervention costs. The operator also required a reliable solution that could be installed on an active production platform using hydraulic workover (HWO) unit operations.
According to a Halliburton case study, the operator needed an ESP system that could be delivered quickly, installed without disruption and supported through continuous monitoring and optimisation.
Addressing offshore ESP reliability challenges
The operator’s previous ESP systems had experienced limited stock availability and extended delivery times, while mechanical failures had contributed to operational challenges.
Installation also presented specific risks. Capillary chemical injection lines had been damaged during previous installation activities, creating concerns about the long-term performance of the ESP system.
In addition, offshore cybersecurity requirements added complexity to the deployment of digital monitoring and remote optimisation capabilities.
To address these challenges, Summit ESP, a Halliburton service, worked with the customer to conduct a detailed factory assessment of each ESP component.
The team designed a custom protector flange to safeguard the capillary line. The component was manufactured locally in Emmen, the Netherlands.
ESP system delivered ahead of schedule
Early delivery of the ESP system enabled comprehensive fit-up testing with HWO tools before offshore installation. This helped verify compatibility and prepare the equipment for deployment on the production platform.
Halliburton’s global field service team subsequently installed the system, removed the failed equipment and commissioned the replacement ESP system.
The installation achieved 100% KPI compliance, while the Intelevate® platform, powered by the Summit Knowledge® digital ecosystem, provided real-time data, health checks and optimisation recommendations from the start of operations.
The system was delivered one month ahead of schedule, while the deployment recorded zero non-productive time (NPT).
The Intelevate platform also provided 24 hours of daily real-time monitoring and optimisation.
Digital monitoring supports offshore operations
The deployment marked the first use of Halliburton’s Intelevate digital platform in the North Sea, according to the Halliburton case study.
The platform provided continuous visibility into the ESP system and supported 24/7 optimisation from day one.
The early arrival of the ESP system also allowed additional pre-checks and in-country fit-up testing before offshore installation. This confirmed compatibility with the HWO equipment and helped eliminate risks associated with non-productive time and minimise deferred production.
Restoring ESP performance offshore
The replacement ESP system met production targets and restored reliability to the operator’s offshore operations.
Continuous support through the Intelevate platform helped maintain operational efficiency through real-time monitoring and optimisation.
The customer acknowledged the service quality, with the deployment representing a milestone in the operator’s offshore ESP operations.
Halliburton has secured a bundled well construction and completions contract from Eni for the Cronos ultra-deepwater development in Block 6 of the Cyprus Exclusive Economic Zone
The award strengthens Halliburton’s offshore portfolio in the Eastern Mediterranean and expands its role in the region’s strategic natural gas development.
Under the contract, Halliburton will provide integrated drilling, well construction, automation and completions services for exploration and development wells. The bundled scope is designed to reduce operational interfaces, improve execution certainty and support efficient delivery across the multi-year ultra-deepwater development.
The Cronos award builds on Halliburton’s longstanding relationship with Eni and reflects the company’s ability to deliver integrated offshore solutions for complex deepwater developments. It also strengthens Halliburton’s position in the Eastern Mediterranean, an emerging offshore gas region. The company expects its integrated delivery model to support future development as operators prioritise efficiency, performance and long-term value.
Jean-Marc Lopez, senior vice president, Europe, Eurasia, and Sub-Saharan Africa, Halliburton
The scope includes drilling fluids, directional drilling, LOGIX automation and remote operations, cementing, surface well testing and coiled tubing. Halliburton will support the campaign through its established infrastructure and regional capabilities in Cyprus, providing logistical advantages and supporting reliable execution throughout the programme.
The Cronos project provides a platform for future deepwater development in the Eastern Mediterranean. Halliburton expects to apply its integrated delivery model to additional offshore campaigns as operators seek greater efficiency, reliable performance and long-term value in increasingly complex offshore environments.
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