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.
Under a new framework with Equinor, Reach Subsea has been awarded two new call-offs covering both gas reservoir monitoring and IMR services on the Norwegian Continental Shelf.
The first call-off supports gas reservoir monitoring at the Troll field and includes options for additional survey scopes. Reach’s proprietary gWatch technology will be deployed, which has proven to be a strong operational match for Reach Remote through successful delivery of similar projects for both Norwegian and international clients.
The second IMR call-off contract will cover detailed inspection of a large number of subsea assets across multiple locations. The scope will be executed using Reach’s ROV deployed from Reach Remote 1, combined with the company’s purpose-built tooling designed specifically for remote and unscrewed operations.
Jostein Alendal, CEO of Reach Subsea, said, “These awards further strengthen our collaboration with Equinor and confirm Reach Remote as a robust and flexible platform for both reservoir monitoring and IMR operations. The integration of Reach Remote with our proprietary gWatch technology, as well as ROV-based inspection and tooling, demonstrates how unscrewed solutions can deliver high-quality data and services while reducing operational complexity and emissions.”
Planning and preparation for both campaigns will commence immediately, with the majority of offshore operations scheduled for execution in Q2 and Q3 2026.
A major milestone in offshore energy has been reached by Aker BP, as it successfully deploys a new well stimulation method for the first time at the Valhall field.
The approach, known as “Single-Trip Multi-Frac”, marks a shift in how reservoirs can be treated more efficiently beneath the seabed.
Traditionally, stimulating a reservoir zone has been a slow and demanding process, often taking two to three days for just one section. Now, with this new technique, multiple zones can be fractured in a single trip down the well. This is made possible through a sleeve mechanism installed in the well completion, allowing operators to open and close sections without pulling equipment out each time.
“The traditional method takes two-three days to fracture a single zone of the reservoir. With ‘Single-Trip Multi-Frac’, we can now do two zones in a day. We also see a potential for doing this more efficiently,” says Stian Ø. Jørgensen, head of the the Well Intervention and Stimulation Alliance in Aker BP.
The benefits are clear. Reduced time spent on operations means lower reliance on vessels and equipment, cutting costs significantly. It also allows wells to come into production sooner.
“The new method will make implementation of several projects possible,” says Tommy Sigmundstad, SVP Drilling and Well in Aker BP. “It provides more flexibility; we spend less time per well, and it decreases the unit cost of the operations. In turn, this results in a reduced price for the stimulation and we can bring the well on stream earlier compared with the conventional stimulation method that has been used. Therefore, we see a substantial upside through use of this stimulation method,” he added.
At Valhall, where chalk formations limit natural flow, stimulation has always been essential. The new method simplifies the process by allowing continuous operation, eliminating the need to repeatedly remove coiled tubing.
Despite being common onshore, adapting this technique offshore at depths of 3,500 metres required years of effort. Collaboration with Schlumberger, Stimwell Services, and NCS Multistage played a key role in overcoming technical challenges.
Valhall has already produced one billion barrels since 1982, and with innovations like this, the ambition to double that output looks increasingly achievable.
Expro has introduced Solus, a new solution 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.
Traditionally, this dual-valve approach increases operational time and introduces additional complexity, along with higher risk due to the use of multiple tools. As operators continue to prioritise streamlined processes and safer well intervention campaigns, the demand for more integrated technologies has grown. Solus responds to this need by combining shearing and sealing into a single ball-valve system capable of performing both functions in one operation.
Enhanced well control capabilities
Solus has been tested and validated to API Std 17G and is fully compliant with NACE MR0175 standards. It is designed as a fail-close, bi-directional sealing system with high debris tolerance, capable of shearing and sealing braided wireline, slickline and coiled tubing. The system can be integrated into a subsea test tree assembly or deployed in open water applications, providing a primary and independent barrier for well isolation during testing or intervention activities while also helping to mitigate emissions risks.
The system has been qualified using a 15% sand slurry, demonstrating its ability to operate effectively in environments with high levels of debris, aggressive media and entrained solids. This makes it particularly suitable for wells where reservoir fracturing has taken place or where challenging fluid conditions are present.
Driving operational efficiency
Solus is engineered for both in-riser and open water operations, offering faster performance compared to conventional manual systems. Its modular design enables operators to isolate and disconnect from the well in a manner similar to traditional subsea test tree systems. In addition, its compact and lightweight configuration supports the industry’s transition towards smaller, next-generation blowout preventer stacks.
The solution is applicable across the full well lifecycle, from exploration and appraisal through to completion, intervention and eventual decommissioning. It supports a wide range of activities including subsea engineering, offshore drilling, well control and supply chain operations, helping operators enhance overall efficiency.
Proven field deployment
Solus has already demonstrated its capabilities in real-world applications. It has been successfully deployed in an in-riser completions development project in the Gulf of Mexico and has also been commissioned for an open water plug and abandonment campaign in the North Sea. These deployments highlight its adaptability across different offshore environments and operational requirements.
Read the complete story here: www.expro.com/media-hub/blog
IMI has secured a contract to deliver specialist control valves for an offshore development in the North Sea, supporting ultra-high-pressure injection systems.
The valves will operate in demanding environments where pressures exceed 600 bar (8,700 psi), enabling chemical injection processes that help maintain flow and optimise production from deepwater wells.
As part of the scope, IMI will supply its EroSolve Metamorphic Trim valve range, designed for precise pressure regulation under severe service conditions. The technology is capable of handling full pressure drops from more than 620 bar to near vacuum levels while maintaining stable low-flow control, a requirement for safe offshore operations.
The valves feature a multi-stage pressure reduction system, allowing energy to be dissipated in a controlled manner across the trim. This design helps to minimise wear on internal components and extend operational life in high-stress environments.
The award follows the successful completion of an extensive endurance testing programme, during which both balanced and unbalanced valve configurations were tested under conditions replicating long-term field operations.
Roby Buyung, President for Process Automation at IMI, said offshore developments are increasingly moving into deeper and higher-pressure fields, placing greater demands on equipment performance. He noted that the project required highly specialised valve technology capable of delivering consistent and accurate pressure control in challenging conditions.
Buyung added that IMI’s valve solutions are engineered specifically for critical applications, where reliability and repeatable performance are essential to maintaining safety and operational efficiency.
The contract forms part of a broader offshore development programme, with delivery progressing in line with the project schedule.
Halliburton has successfully completed a series of offshore wireline operations for Croatia’s INA Group in the Adriatic Sea, demonstrating both technical strength and operational efficiency.
The project involved logging activities across four wells, where the Wireline team carried out 17 combined runs without any health, safety, or environmental incidents, while also maintaining zero non productive time.
Over the course of more than 272 hours of continuous operations, the team ensured that all personnel and equipment were securely managed on site. By keeping closely aligned with INA’s project schedule, Halliburton delivered the work within the agreed timeline, allowing the client to assess well performance and make informed operational decisions in real time.
A key element of the project was the development of an integrated workflow that combined measurement and analysis. This approach played an important role in identifying promising production opportunities as well as uncovering new hydrocarbon zones offshore Croatia. The team worked closely with INA’s subsurface specialists, offering real time support through formation testing and detailed petrophysical interpretation.
To better understand thin geological layers, Halliburton deployed its Xtended range water based mud imager. This technology enabled accurate identification of sandstone intervals and helped determine net pay zones. In addition, enhanced vertical resolution techniques were used to capture density and neutron porosity data, improving the analysis of shaly sand formations and refining estimates of porosity and gas saturation.
Further insights were gained through the use of the Reservoir Description Tool, which measured fluid density, capacitance, and resistivity during pump out operations. These measurements confirmed the presence of productive gas zones. The team also applied magnetic resonance technology to distinguish between moveable and bound hydrocarbons, providing a clearer picture of reservoir potential.
Through a combination of innovation, precision, and collaboration, Halliburton delivered a seamless operation that supported INA in unlocking valuable subsurface insights.
Equinor has completed its investigation into a well control incident on the Deepsea Bollsta drilling rig that resulted in a gas release during operations in September 2025.
The company confirmed that the incident, which occurred on 23 September while plugging a well at the Troll Field, has been classified in its most serious internal category of severity.
According to the investigation report, the event happened while crews were cutting a 13-3/8-inch casing at a depth of around 510 metres. During the operation, gas and fluid escaped from the well and spread across the drill floor and into the shaker room, an area where rock fragments and drill cuttings are separated from drilling fluids before the fluid is circulated back into the well.
One worker experienced difficulty leaving the room because of pressure differences caused by the release. The individual managed to exit using force but suffered minor injuries and received first aid on board the rig. The escaping gas and fluid also caused damage to the ventilation system in the room’s ceiling.
Despite the seriousness of the event, company officials said multiple safety barriers operated as intended. Automatic gas detection systems activated emergency protocols, which included shutting down potential ignition sources across the rig.
Crew members then activated the rig’s blowout preventer and diverter system in line with emergency procedures. The diverter redirected gas, fluids and pressure away from the installation before the blowout preventer fully closed.
The system sealed the well after approximately 71 seconds, stopping the flow of gas. Operators reported that the situation was brought under control within about half an hour.
Calculations carried out during the investigation estimate that roughly 930 kilograms of gas were released over a short period. The volume triggered a “Red 1” classification within the company’s internal risk management framework, indicating the highest level of severity.
The investigation found that the blowout preventer remained open at the moment the casing was cut, while gas had accumulated behind the casing in a confined space. Equipment used to log the annulus area behind the casing had not been correctly calibrated, meaning the trapped gas was not detected before the operation began.
Officials stressed that the gas was contained in a limited volume behind the casing and was not connected to the reservoir, meaning the incident did not present a risk of an uncontrolled blowout.
Following the event, the company introduced new procedures requiring the blowout preventer to be closed when cutting shallow casings or pulling casing strings, regardless of activation timing.
Rune Nedregaard, senior vice president for drilling and well operations, said the findings would be shared with industry partners and suppliers, while the investigation by the Norwegian Ocean Industry Authority would also inform further safety improvements.
Chevron and HELLENiQ ENERGY have signed a landmark agreement with the Hellenic Republic granting exploration rights to four major offshore blocks, opening one of the largest unexplored maritime areas in the European Union to potential natural gas development.
Under the agreement, Chevron will hold a 70% stake and act as operator, while HELLENiQ ENERGY will retain the remaining 30%. The blocks are located south of Crete and the Peloponnese and cover a combined area of approximately 47,000 sq km.
The move is seen as a significant step in Europe’s ongoing efforts to diversify energy supplies and reduce reliance on Russian gas, which still accounts for roughly one-fifth of the EU’s imports. By unlocking new exploration acreage in the Eastern Mediterranean, Greece is positioning itself as a potential contributor to future regional gas supply.
The joint venture partners confirmed that the exploration programme will proceed in phases, beginning with seismic surveys scheduled to commence later this year. The initial data acquisition will help assess the hydrocarbon potential of the largely untapped offshore area before any drilling decisions are made.
Speaking at the signing ceremony in Athens, Prime Minister Kyriakos Mitsotakis described the agreement as a strategic development for both Greece and the wider European energy market. He noted that the European Union’s decision to curb dependence on Russian gas had created new opportunities for member states to strengthen domestic and regional energy production.
Mitsotakis highlighted Greece’s ambition to enhance its role as a regional energy hub, citing existing and planned infrastructure projects that connect South-Eastern Europe with broader European gas networks. He emphasised that, despite the EU’s long-term climate goals and transition towards renewable energy, natural gas would remain an essential component of Europe’s energy mix for years to come.
Industry observers view the agreement as a potential catalyst for further exploration activity in Greek waters, which have historically been underexplored compared with other parts of the Mediterranean. The size of the concession area makes it one of the most significant offshore licensing arrangements within the EU in recent years.
For Chevron, the deal strengthens its presence in the Eastern Mediterranean, while HELLENiQ ENERGY consolidates its role in domestic upstream development. The success of the initial seismic phase will be critical in determining whether the region can deliver commercially viable gas resources capable of contributing to Europe’s long-term energy security.
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