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.
The products and services provider for offshore developments has secured a multi-year contract worth seven figures with a global offshore services company to support intervention and abandonment activities offshore Spain.
Under the agreement Aquaterra will deliver a subsea well access solution across 11 wells. The campaign will be executed from a semi-submersible vessel, where Aquaterra will supply a 7-3/8” ID, 5,000 psi rated intervention riser system. The complete riser-based solution will integrate with the customer’s subsea pressure control system to enable efficient intervention and abandonment activities.
Aquaterra Energy CEO, George Morrison, said, “Securing this multi-year contract is a significant milestone for Aquaterra Energy. Well intervention and abandonment is increasingly the defining challenge for many mature offshore basins and we have invested in building the team, capability and technology required to make these campaigns a success as our customers navigate complex late-life field operations.”
Ben Cannell, Innovation Director at Aquaterra, commented, “Well access to support intervention and abandonment remains a key focus for us as we continue to expand our capability and presence in this market. This project is a strong example of collaboration in action, bringing together our riser-based well access solution and OEM AQC-CW connector technology to deliver a practical, integrated system that supports safe, efficient and reliable offshore operations throughout complex abandonment campaigns.”
According to Westwood, plug and abandonment is expected to account for almost half of total decommissioning expenditure in the UK North Sea, with similar pressures of ageing assets moving into the abandonment phase being witnessed in Spain.
The integrated subsurface, wells and facilities specialist has acquired Applied Petroleum Technology AS (APT), a geoscience company in a move which strengthens Elemental’s existing subsurface capabilities.
APT provides basin modelling and subsurface analysis to support well exploration, production and plug and abandonment decisions. The acquisition helps Elemental create an integrated team spanning geoscience, reservoir engineering, geochemistry and petroleum engineering.
The acquisition meets rising demand for deeper subsurface insights, with APT’s laboratory-based geochemical analysis adding a critical layer of subsurface insight to Elemental’s offering alongside traditional geoscience and reservoir engineering workflows.
APT will also bring established digital tools to Elemental’s portfolio, including Girasol which is used for wellsite gas interpretation and P&A decision-making.
Mike Adams, CEO of Elemental Energies, said, “As subsurface decisions become more complex across mature assets, decommissioning and CCS, we are continuing to invest in specialist capabilities that help our clients make more informed decisions. Bringing APT into Elemental Energies expands out subsurface and geochemistry expertise, creates new opportunities for our teams and strengthens our ability to support clients at every stage of the asset life cycle.”
Helge Nyrønning, CEO of APT, commented, “APT has always focused on delivering high-quality geochemical insight to support critical subsurface decisions. Becoming part of Elemental Energies is an exciting next step for our business and our people. It gives us the scale, reach and multidisciplinary environment to grow our capabilities, work more closely with clients we already know well, and apply our geochemistry expertise within fully integrated subsurface and wells team, particularly form our strong base in Norway.”
AF Offshore Decom has signed a contract with Ithaca Energy for decommissioning work in the UK sector of the North Sea
The contract scope includes the engineering receipt, cleaning, dismantling and recycling of a FSU weighing approximately 24,000 metric tons.
Lars Myhre Hjelmeset, EVP Offshore at AF Gruppen, said, “We are very pleased to have been awarded a second major contract by Ithaca Energy following the award of the FPF-1 asset in December 2025. As a result of the awards, AF Environmental Base Vats will receive close to 50,000 tons of floating production and storage facilities from Ithaca energy in 2026.
“The two units will, after initial preparations, be loaded onto our yard in a combined gloat over and load in operation, consistent with earlier similar projects at AFEBV. The units will be cleaned, dismantled and thereafter the steel will be repurposed, upcycled and recycled creating several circular material solutions for the agriculture, construction and civil industries in the Nordic region.”
The contract has been valued in the range of NOK350-400mn (approximately US$36-41mn).
Aker Solutions has secured a five-year framework agreement to provide maintenance, modification, and operations (MMO) services in the Yggdrasil area, with options to extend for up to two additional four-year periods from 1 March 2026. The work will form part of the next-generation MMO alliance covering Valhall, Fenris, Ula, EIGA (Edvard Grieg and Ivar Aasen), Skarv, Alvheim, and Yggdrasil.
The alliance aims to set new benchmarks in project execution and delivery, embracing advanced technology and AI-driven methods to boost productivity, reduce costs, and shorten project lead times. Greater organisational integration and a performance-focused commercial model are central to the approach.
Kjetel Digre, Chief Executive Officer at Aker Solutions, said: “This contract marks a new chapter for Aker Solutions. We are proud to serve as the MMO provider for the Yggdrasil Area, including three topsides, Hugin A, Hugin B, and Munin. It is an area that will set a new benchmark for remote operations and low-manned and unmanned production platforms.”
The agreement includes a significant share of local deliveries, supporting Norwegian industry through engineering and project management in Stavanger, Sandnessjøen, and Mumbai, and fabrication at Aker Solutions’ yards in Egersund and Sandnessjøen. Offshore employees will also benefit from the programme.
The award will be recorded as order intake in the Life Cycle segment in the first quarter of 2026, reflecting expected work during the five-year fixed period.
Energy services provider Expro has unveiled a new high-debris single shear and seal ball valve system, designed to provide enhanced flexibility, functionality, and safety for subsea well access in the global oil and gas sector
By replacing the traditional requirement for two valves with just one, the system transforms subsea well access operations, reducing risk and complexity while supporting more cost-effective subsea intervention technologies.
Tested and validated according to API Std 17G, the system is the first fully NACE MR0175-compliant fail-close, bi-directional high-debris ball valve capable of shearing and sealing on wire and coiled tubing.
Expro’s new equipment can be applied in both riser and open water environments across the full well lifecycle – from exploration and appraisal to completion intervention, plug and abandonment, and decommissioning.
The system has already been deployed for a new in-riser completions project in the Gulf of America and installed in an open water system for a North Sea plug and abandonment campaign. It provides shear and post-shear sealing for gas and liquids on slickline, braided electrical cable, and coiled tubing, delivering bi-directional sealing even after pump-through operations.
It is also integrated into Expro’s lightweight open water intervention riser system. By achieving shear and seal in a single valve, the system allows more efficient operations in open water applications.
The modular design enables isolation and disconnection from the well, while its compact size and flexibility align with the industry’s move toward smaller blowout preventer stacks and streamlined supply chain management. The fail-close configuration reduces emissions risk and provides an additional well safety barrier. Expro’s integrated approach gives users confidence and simplifies operations by replacing a two-valve system with just one.
The system offers superior high-debris flexibility, handling solids up to 15% ingress qualification size, making it suitable for a wide range of subsea well lifecycle challenges.
Daniel More, Vice President Subsea Well Access at Expro, said:
“In introducing this system, Expro now offers the subsea engineering market a distinctive new solution that provides the ultimate integrated shear and seal on coiled tubing and wire using just a single valve. It cuts through operational complexity. Simple to use, flexible, with a compact design for smaller BOP stack sizes, this is the latest in fail-safe technology developed by the experts of valve technology and systems integration.
“When there’s no room for error, the system is designed to provide the assurance of an independent well safety barrier, combined with the surety and confidence that comes from Expro’s integration experience and expertise at the ‘whole system’ level. It’s the latest example of Expro’s engineering excellence and deep understanding of customer needs to move our industry forward.”
The system is available in Expro’s landing string assembly equipment offering, and can be deployed in-riser as a single valve, a single valve with a latch mechanism, within a subsea test tree, or within an open water intervention riser system.
OKEA, alongside its partners, has announced a petroleum discovery at the 'Knockando Fensfjord' prospect in the North Sea.
The well was drilled from the Brage installation as part of a development well for oil (31/4-A-15 D) within production licence 055, according to the Norwegian Offshore Directorate.
Preliminary estimates suggest that, if the discovery contains oil, it could add between 0.5 and 1.5 million standard cubic metres (Sm³) of recoverable oil equivalent (o.e.) to Brage’s resources. If the find is gas, estimated volumes range from 0.4 to 0.9 million Sm³ o.e.
Well 31/4-A-15 D recently began production from the 31/4-A-1 B 'Talisker' discovery on 11 January 2026. The licence holders are now evaluating potential development options for the Knockando Fensfjord discovery.
Production licence 055 was awarded in Norway’s fourth licensing round on the Norwegian continental shelf (NCS) in 1978. The Brage field was proven in 1980, with the plan for development and operation (PDO) approved by the Storting in 1990. Several new discoveries have been made in the Brage area in recent years, including “Talisker Cook/Statfjord” (31/4-A-15 B) and “Prince” (31/4-A-23 G), both confirmed in 2025.
The current licensees in production licence 055 include OKEA (operator), Lime Petroleum, DNO, Petrolia NOCO, and M Vest Energy.
The development well 31/4-A-15 D targeted the lower Fensfjord Formation of Late Jurassic age en route to the “Talisker” production target in the Middle Jurassic Brent Group. The well confirmed a 38.5-metre hydrocarbon column across multiple sandstone layers with moderate to good reservoir quality. The petroleum-water contact was not encountered.
The well reached measured and vertical depths of 10,009 metres and 2,309 metres below sea level, respectively, before being terminated in the Oseberg Formation of the Middle Jurassic. Geological and reservoir data were collected throughout the discovery interval.
This latest find adds to OKEA and its partners’ ongoing efforts to optimise resource recovery in the Brage area, further strengthening the field’s contribution to Norway’s oil production.
Seadrill Limited has provided an update on its contracting activities in Europe and beyond, highlighting a new agreement for its West Elara rig on the Norwegian Continental Shelf.
In Norway, the West Elara has secured an accommodation contract with Equinor AS, expected to commence in the third quarter of 2026 and continue into the fourth quarter of 2027. The firm contract value is US$78mn, with three priced options of three months each. Prior to this fixture, Seadrill reached a mutual agreement with the current contract holder to make the West Elara available. “This update to the rig’s schedule results in a net increase in total contract value of US$23mn,” the company noted.
Seadrill’s president and chief executive officer, Simon Johnson, said, “We are excited to confirm these important contracts with several of our long-standing customers. … In Norway, the West Elara’s contract with Equinor represents a harmonious solution to a potential gap in the rig’s operations, reaffirming that Seadrill’s collaborative approach with customers continues to create value for all stakeholders.”
Outside Europe, the ultra-deepwater drillship West Capella in Malaysia has secured a contract with an undisclosed operator. The well-based programme is expected to start in the second quarter of 2026, with an estimated duration of 440 days, plus priced options for three additional wells. The total firm-term contract value is approximately US$157mn, including a US$5mn mobilisation fee and excluding additional services.
Meanwhile, the West Carina in Brazil has had its current contract extended through April 2026.
Johnson added, “The reactivation of the West Capella materially enhances Seadrill’s earnings potential in a region with reinvigorated demand for offshore drilling.”
Seadrill’s latest contracts underscore its focus on strengthening European operations while maintaining a global presence across key offshore markets. In Norway, the West Elara deal highlights the company’s ability to optimise rig utilisation in collaboration with major operators, ensuring minimal downtime and maximising the value of its fleet.
The accommodation contract comes amid growing offshore activity in the Norwegian Continental Shelf, where operators are seeking flexible solutions to support extended field development and maintenance projects. Seadrill’s approach reflects a broader trend in the offshore drilling sector, combining operational adaptability with long-term strategic partnerships.
Technology solutions company, Rosenxt Group, has acquired K.U.M Umwelt- und Meerestechnik Kiel GmbH (K.U.M), strengthening its position in the growing subsea technology market and expands its portfolio with specialised solutions for deep-sea monitoring and data acquisition.
K.U.M boasts a vast portfolio of customised subsea monitoring systems, ocean-bottom seismometers, seabed instrument carriers, and other advanced deep-sea solutions. The company has more than 400 offshore expeditions and a broad customer base across 40 countries. Now, as part of Rosenxt Group, K.U.M will gain access to a broader international market and be able to scale its subsea solutions more rapidly.
Through the acquisition, Rosenxt will significantly expand its presence in the specialised subsea domain: K.U.M brings more than 20 years of experience in developing complete subsea systems. The acquisition supports Rosenxt’s strategy on integrating sensing, robotics, digitalisation, materials technology and deep environmental expertise to develop robust solutions that create value across subsea, offshore and upstream applications.
Hermann Rosen, Chairman of the Board at Rosenxt, said, “The integration of K.U.M is a consistent contribution to our responsibility to shape the future of critical infrastructure in a resilient and technologically excellent way. K.U.M brings decades of subsea engineering expertise and precise data acquisition to the table – a strong addition to our group. We think in the long term – beyond market cycles – and are laying the foundations today for the solutions of tomorrow. Rosenxt is staying true to its course and sending a clear signal about its ambitious development in the subsea market.”
CEO of K.U.M, Onno Bliss, commented, “Joining the Rosenxt Group enables K.U.M to further scale our subsea data acquisition and instrumentation solutions and benefit from the group’s broader technology ecosystem. Our shared values – innovation, precision, integrity – make this partnership an excellent fit.”
Equinor has been granted approval by the Norwegian Offshore Directorate to drill a new exploration well in the Norwegian part of the North Sea, strengthening ongoing activity in one of the country’s mature offshore areas.
The permit relates to the 34/8-A-37 H wildcat well within production licence 120, a licence originally awarded on 23 August 1985 and currently valid through to 2034. Equinor operates the licence with a 53.2% interest. The remaining stakes are held by Petoro, which owns 30%, ConocoPhillips Skandinavia with 9.1%, and Repsol Norge with 7.7%.
Drilling of the well is planned to take place from the Visund field, with operations expected to commence in January 2026. The Visund field is situated in the northern North Sea, northeast of the Gullfaks field, in waters measuring around 335 m in depth.
Discovered in 1986, Visund moved into the development phase following approval of its plan for development and operation in 1996. First oil was achieved three years later, in 1999, and the field has remained an active production hub since then.
The development comprises the Visund A platform, a semi-submersible installation that combines accommodation, drilling and processing functions. This surface infrastructure is supported by a subsea production facility located in the northern part of the field, enabling continued operations in the area.
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