Norway is intensifying its offshore petroleum activities to strengthen European energy security amid ongoing global supply uncertainties.
Energy Minister Terje Aasland has underscored the importance of expanding, rather than reducing, operations on the Norwegian continental shelf.
On 5 May 2026, the Norwegian authorities announced the APA 2026 licensing round, offering up to 70 new exploration blocks: 38 in the Barents Sea, 22 in the North Sea, and 10 in the Norwegian Sea.
Applications are invited until 1 September 2026, with awards scheduled for early 2027.
This move continues Norway’s strategy of sustaining long-term production and attracting investment from international oil companies.In a separate development, plans were confirmed to reopen three historic North Sea gas fields like Albuskjell, Vest Ekofisk, and Tommeliten Gamma, which have been closed since 1998.
Operator ConocoPhillips, together with partners, is set to invest approximately €1.8bn, with production potentially resuming by 2028.
The fields could deliver significant gas volumes to markets in Germany and the United Kingdom through to 2048.
Additionally, Equinor has recently started production from the Eirin field via a subsea tie-back to the Gina Krog and Sleipner installations, adding further gas supply to Europe.
These initiatives reflect Norway’s response to tightening global energy markets.
By maximising output from mature and frontier areas, the country aims to provide reliable supplies while balancing its energy transition commitments.
Industry observers note that heightened geopolitical tensions have reinforced the role of Norwegian gas in stabilising European energy prices.
The developments are expected to generate substantial economic activity and support thousands of jobs across the Norwegian supply chain.
Equinor ASA has extended a series of major supplier agreements for drilling and well services, with a combined value of about NOK 17 billion.
The extensions are aimed at sustaining production on the Norwegian continental shelf, maintaining operational activity and supporting consistent energy supply to Europe.
The company has activated one-year extension options for three integrated drilling and well service contracts, alongside two-year extensions for 18 corporate framework agreements covering specialised services associated with these operations.
The integrated drilling and well services contracts are valued at NOK 8.3 billion, while the framework agreements for specialist services are expected to generate around NOK 4.3 billion annually over a two-year period.
Contracts for integrated drilling and well services have been awarded to Baker Hughes Norge AS, Halliburton AS and SLB Norge AS. These companies, along with an additional 15 suppliers, have also secured framework agreements for specialised services. The agreements are designed to ensure access to the expertise and advanced technologies required to improve efficiency in well operations and adapt to evolving operational demands.
“These agreements are among the largest we have, and they are crucial for activity on the Norwegian continental shelf. New wells enable us to maintain high production and deliver stable energy to Europe. This is particularly important at a time of turbulence in the energy markets,” says Jannicke Nilsson, chief procurement officer.
The contracts are expected to support around 2,500 jobs and will cover operations across both fixed installations and mobile drilling rigs on the Norwegian continental shelf.
As the region matures, drilling and well activities are becoming increasingly vital to sustaining output levels. Equinor aims to maintain production at approximately 1.2 million barrels of oil equivalent per day through to 2035.
“New wells are expected to account for around 70 percent of Equinor’s production in 2035. This involves both more wells and more well interventions, which must be delivered faster and significantly more cost-efficiently than today. That requires closer collaboration with the supplier industry and increased use of technology and standardisation,” says Rune Nedregaard, senior vice president for Wells.
“We are now moving to a greater extent towards industry standards. Together with our suppliers, we will use this to simplify work processes, reduce costs and increase pace, while maintaining safety,” Nedregaard continues.
Equinor ASA has awarded Archer a three-year contract extension for wireline and intervention services on the Norwegian Continental Shelf.
The extension builds on the integrated wireline contract originally awarded to Archer in 2021, under which the company, along with partners, delivered services across key Equinor assets. While extension options were available in the original contract, the current award represents a firm three-year extension, providing continued operational continuity and visibility.
The contract represents a total contract value of approximately NOK3bn (around US$322,117), with around half attributed to Archer and the remainder allocated to alliance partners.
Dag Skindlo, Chief Executive Officer at Archer, said, “This contract extension reflects the strong and long-standing relationship we have built with Equinor. We are pleased to continue supporting Equinor’s operations and consider this agreement strategically important for Archer. It provides long-term visibility to our business, reinforces the strength of our alliance model, and demonstrates the trust placed in our people, technology and service quality.”
The agreement reinforces Archer’s position as a trusted provider of advanced well services, supporting Equinor’s operations through the continued delivery of wireline and intervention solutions.
Well-Safe Solutions, a tier-one specialist in well decommissioning, has secured a multi-year agreement with Apache North Sea Limited to decommission platform and subsea wells in the Forties Field.
The programme is scheduled to commence in 2026, with Well-Safe Solutions taking responsibility for all well-related project management, well and subsurface engineering, and offshore execution for both platform and subsea wells.
The contract is expected to sustain hundreds of jobs in Aberdeen while providing a welcome economic uplift to northeast Scotland during a period of ongoing pressure on the sector and concerns around long-term workforce retention.
Phil Milton, Chief Executive Officer at Well-Safe Solutions, said:
“This award is a defining moment for Well-Safe Solutions and a testament to the confidence Apache has in our team to deliver safe, efficient and technically robust decommissioning solutions at scale.
“This contract award is exciting news for our business and for the wider economy, sending a powerful signal to the supply chain and helping to secure critical talent and resources. Today’s announcement is undoubtably a huge moment for our business and our industry, however, it comes at a particularly difficult time for our sector when we are hopeful of retaining the talent and capability that we have in the North Sea”
Industry capacity for mobile offshore drilling units able to carry out both drilling and decommissioning work on platform and subsea wells has fallen steadily in recent years. Only five semi-submersible rigs now remain in the UK Continental Shelf. This continued decline in available assets could hinder the UK’s ability to satisfy future energy requirements and fulfil decommissioning commitments, with thousands of wells expected to require decommissioning before the decade ends.
Donald Martin, Vice President, Decommissioning, Apache, commented:
“We are pleased to partner with Well-Safe Solutions on this large-scale decommissioning programme across the Forties Field. This contract reflects our commitment to delivering safe, predictable and cost-effective decommissioning through disciplined execution and with a high-performing, integrated team.
“Building on decades of successful production from one of the North Sea’s cornerstone assets, Apache is focused on maximising late-life asset value, reducing risk, and delivering a safe, efficient and disciplined transition into decommissioning.”
The latest award further strengthens Well-Safe Solutions’ standing as a strategic leader in the UK decommissioning market. It follows successful recent campaigns involving the Well-Safe Defender and Well-Safe Protector, as well as two other significant North Sea contract wins announced earlier this summer.
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
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