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.
Early design decisions and robust qualification of subsea connectors can fundamentally impact the long-term integrity of subsea pipelines, warns Lloyd’s Register (LR), in a new study for the Norwegian Ocean Industry Authority (Havtil).
The report “Integrity of Connectors in Pipelines and Subsea Systems” provides an updated basis of experience for assessing the integrity of welded and mechanical connectors in pipelines and subsea facilities, highlighting how the right choices early in the design phase are crucial for safe and responsible operations throughout the entire service life.
Pipelines and subsea facilities are critical components of offshore energy production, connecting fields to processing and export infrastructure while operating in some of the world's most demanding environments. Ensuring their structural integrity throughout decades of service remains a key challenge for operators and regulators alike. The integrity of connectors in pipelines and subsea systems is critical for the safe and continuous operation of offshore infrastructure. Common failure modes for subsea connectors include leakage, material failure, mechanical failure, and corrosion, with leakage identified as the most frequent failure mode.
Drawing on industry data, LR maps common fault mechanisms and performance trends, concluding that decisions taken at the design stage have a direct impact on failure risk throughout an asset’s life. Operators need to ensure that connector design and qualification processes are sufficiently robust for such critical components.
Comprehensive qualification provides confidence in the integrity of the connector throughout service life, while early involvement of the original equipment manufacturer can support life extension by validating key design assumptions and performance limits.
The report makes the following recommendations to enhance the integrity and reliability of subsea connectors:
• Collaboration with manufacturers: Engage with connector manufacturers to leverage their expertise in identifying potential failure modes and developing mitigation strategies. Manufacturers can provide valuable insights into the design, qualification, and maintenance of connectors.
• Regular inspections: Establish a robust inspection regime, in collaboration with manufacturers, that includes regular visual inspections, cathodic protection surveys, and postinstallation testing to detect and address potential issues early.
• Life extension assessments: Conduct life extension assessments for connectors approaching the end of their design life. This should include evaluating the condition of the connector, the loads it has been subjected to, and its compatibility with the transported fluids. Particular attention should be made towards components which are a single point of failure for the connector.
Sean Murray, Global Technical Authority – Pipelines and Subsea at Lloyd's Register, said, “Subsea systems are expected to perform safely and reliably for many years in challenging operating conditions. The choices made during design have a lasting impact on their integrity and long-term performance.
“This project consolidates industry experience, operational data, and failure insights to support improved risk-based decision-making across the lifecycle of subsea assets. It highlights that, while subsea connectors generally demonstrate high reliability, their performance is strongly dependent on robust design, manufacturing quality, installation control, and rigorous qualification.
“By better understanding how different connector solutions perform in service, operators can make more informed decisions that enhance safety, reduce risk and improve through-life reliability of these critical components.”
Steffen Andreasen, principal engineer at Havtil, added, “Sharing experience and knowledge across the industry is key to reducing risk and improving structural safety. This study highlights how the integrity of subsea connectors depends on robust design, qualification, and integrity management, which together are essential for maintaining safe and reliable operations throughout the lifetime of subsea infrastructure.”
Baker Hughes has won a significant award from bp to provide offshore stimulation services across the company’s UK North Sea operations.
Under the agreement, Baker Hughes will deploy a vessel-based stimulation solution, complete with its StimFORCE modular stimulation package to support well completions and production enhancement activities. The solution is designed to enhance operational reliability, minimise non-productive time and optimise recovery.
Executive Vice President of Oilfield Services & Equipment at Baker Hughes, Amerino Gatti, said, “By combining our vessel-based stimulation expertise, advanced intervention technologies and production optimisation capabilities, we are well positioned to help bp enhance reservoir performance, increase operational flexibility and unlock additional value from both new and mature fields across its North Sea portfolio.”
The dedicated vessel solution provides both schedule and operational flexibility, enabling stimulation activities to be executed efficiently.
Baker Hughes has a long-standing presence in the UK, helping operators optimise reservoir performance across the well lifecycle.
Aberdeen-headquartered well integrity and decommissioning specialist Unity has completed a technically challenging well intervention project in Central Italy for SMAPE, delivering a bespoke thru-tubing solution for a major international oil company.
The project required an alternative approach after conventional cement squeeze operations failed to achieve the necessary well isolation. Cement was being absorbed by a thief zone located behind a slotted liner, preventing the operation from delivering the required result.
The well’s geometry presented a further challenge. Standard mechanical isolation equipment could not be used because the retainer needed to pass through a tight 2.188-inch nipple restriction before expanding and setting securely within a 3.958-inch ID above the thief zone.
Planning also had to account for the well’s low fluid level. This was necessary to prevent premature disconnection during the cementing operation and ensure the treatment packer was not pressurised beyond its operating limitations.
Unity responded by engineering an inflatable cement retainer capable of passing through the restricted nipple profile. The solution was developed after attempts to achieve isolation using cement alone had proved unsuccessful.
Rather than relying on an off-the-shelf product, Unity selected components from across the OEM market and engineered them to suit the specific requirements of the well. This OEM-agnostic approach allows its thru-tubing team to develop tailored solutions for complex intervention challenges.
For the project, Unity’s specialist thru-tubing team developed a custom 2.125-inch inflatable cement retainer. The Bottom-Hole Assembly was modified with a dual check valve system and shear disconnect, while a cement plug was incorporated into the solution.
This configuration enabled the rig team to release from the cement retainer immediately after the squeeze operation without dropping additional balls or facing complications after the packer had been inflated.
Unity Thru-Tubing Operations Manager Chris Myles said: “This is the first time we have used this configuration, which draws on established principles. This is really the heart of how we work at Unity thru-tubing. We're not tied to one OEM's solution, so we can pull in whatever's most appropriate, adapt it, and build something that fits the exact problem in front of us. That's what sets Unity apart, and it's what clients get in return - a solution built around their well requirements, not the other way round.
“This project marks our second collaboration with SMAPE, and it’s fantastic that the team see the value we bring to complex well integrity challenges. These are often the kinds of jobs where a standard approach isn’t enough, so being able to work closely with the client and develop a solution around the specific requirements of the well is where our expertise really makes a difference.”
The project forms part of Unity’s wider investment in well intervention capabilities. Since the beginning of 2025, the company has expanded its intervention tooling portfolio, strengthening its ability to deliver integrated well integrity and intervention services through a single supplier relationship.
By combining engineering expertise, OEM-agnostic tool selection and operational experience, Unity provides operators and service providers with customised solutions for complex well integrity requirements. The approach is also designed to streamline operations by reducing the cost and complexity associated with managing multiple suppliers.
Unity is part of the FrontRow Energy Technology Group and has a 30-year track record of supporting operators worldwide in reducing risk, overcoming operational constraints and extending asset life across energy operations.
SMAPE is an independent engineering company specialising in coiled tubing and well services.
Expro keeps building its stronghold in the UK North Sea plug and abandonment (P&A) market with its latest contract from a major UK operator, amounting multi-million-pounds.
The agreement secures Expro's delivery of safe subsea services, including 7-3/8” large bore Subsea Test Tree Assembly (SSTTA) safety system that will advance an extensive P&A campaign across a portfolio of mature subsea wells. Expro will be working on six firm wells, with a further six optional wells.
Expro’s subsea well access systems are designed to be robust and reliable, providing dual barrier protection and disconnect capability. This simplifies P&A operations while also minimising operational risk and downtime. These systems are critical to maintaining well integrity throughout abandonment activities, particularly in complex offshore environments. Solus is one of the latest launches by Expro, designed to simplify subsea well control operations while improving efficiency and reducing operational risk. The system addresses longstanding challenges in in-riser subsea well intervention, where conventional methods typically rely on two separate valves, one for shearing and another for sealing coiled tubing.
Carole Paley, Expro’s UK Managing Director said, “Expro has in depth knowledge of North Sea wells and has performed numerous operations on many of these wells over their lifecycle. This deep-rooted expertise supported by local resources enables the delivery of meaningful cost efficiencies. We look forward to working closely with our client on this project as they progress this important campaign over the coming year.”
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