North America, Europe and Asia Pacific are shaping today's offshore decommissioning market as it is projected to grow at a compound annual growth rate (CAGR) of approximately 6-8% over the next six years.
According to an analysis by experts, growth of the global offshore decommissioning market is inevitable as the oil and gas industry is looking towards an ever-increasing numbers of retiring assets.
“With many offshore oil fields approaching the end of their productive life, companies are focusing on cost-effective and environmentally responsible methods for decommissioning platforms, subsea structures, and pipelines.
“The market’s trajectory underscores the importance of innovation, regulatory compliance, and environmental stewardship in shaping the future of offshore asset retirement,” reads an analysis by Market Research Future.
North America is looking at a chunk of mature offshore assets that are awaiting decommissioning, and the region is trying to keep up with the liabilities by leveraging advanced technologies such as artificial intelligence, Internet of Things and data analytics, among others. The region is spearheading the market, driven by its robust technological ecosystem, early adoption of advanced solutions, and sustained investments in innovation and automation.
While North America still enjoys comparatively stable demand patterns owing to established infrastructure and matured market conditions, its regulatory frameworks are going through a phase of steady evolution to accelerate turnarounds of its decommisssioning liabilities.
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.
Global technology company SLB has announced a three-year agreement with Azule Energy to extend and enhance the use of its enterprise digital platform across Azule’s operations in Angola
The platform aims to drive more consistent execution, speed up decision-making, and support reliable energy delivery throughout Azule’s portfolio.
Azule Energy, a joint venture between bp and Eni and the largest independent energy producer in Angola, manages some of the country’s most complex assets. This new agreement builds on two years of Delfi use within Azule’s reservoir organization, where the platform supports reservoir studies, modelling, simulation, and well planning workflows, while enabling enterprise-wide digital integration by connecting reservoir workflows with wider operational data environments over time.
“Azule operates large, complex energy assets where execution reliability and consistency matter,” said ND Maduemezia, president, Europe and Africa, SLB.
“This agreement expands the use of an enterprise digital platform that connects workflows and data, strengthening and accelerating decision-making and improving execution predictability in support of reliable energy delivery in Angola.”
The agreement highlights Azule’s shift toward enterprise-scale digital operations, leveraging SLB’s platform and cloud-based capabilities. Implementation is supported through the SLB Luanda Performance Center, which allows digital solutions to be deployed and maintained locally.
The platform supports critical workflows across Azule’s reservoir and planning functions, with gradual integration into broader operational data systems. It also positions Azule to quickly adopt emerging digital and AI-driven technologies, enabling continuous performance enhancements.
Early results demonstrate tangible benefits: integrated workflows, including DrillPlan coherent well planning and engineering solutions, have shortened planning cycles from days to hours while boosting automation and reducing manual coordination.
The enterprise platform strengthens execution consistency across Azule’s large, mature operations, where operational discipline is key to sustaining performance.
Key Points:
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.
With an aim to achieve a potential gross production uplift of around 9,000 barrels of oil per day, Afentra has secured contracts to advance its accelerated two-well drilling programme on Block 3/05 offshore Angola.
The primary objective will help define the material upside potential in the Pacassa SW area (up to 70 mmbo recoverable) and the Impala field (up to 50 mmbo recoverable).
The Block 3/05 Joint Venture partners have signed a commercial agreement with Sonangol to use the Borr Grid jackup rig for the well programme. It will begin with the drilling of Pacassa SW, which will determine the next well eligible for drilling, be it the Pacassa SW injection well or the Impala-2 development well.
The Pacassa field which is anticipated to hold up to 210 mmbbls of oil will be drilled from the Pacassa F4 platform. If the drilling is a success, the well will be put to completion before connecting it to the existing production infrastructure.
The Impala field, on the other hand, can potentially play a significant role in defining the upside potential of the field that can contain up to 200mmbo of oil in place. Impala-2 will be drilled from the Impala wellhead platform into the Impala field around 1000m from the existing Impala-1 production well. Upon completion the well will be connected to the existing production infrastructure. The outcome will also assist in defining the optimum Impala field development which has up to 50mmbo of incremental recoverable resources.
"The ability to accelerate our drilling programme is a pivotal moment for Afentra, marking a clear transition to the execution phase of our organic growth strategy. This opportunity is a direct result of the strong, collaborative partnership we have with Sonangol and the Joint Venture. The funding structure agreed with Sonangol allows us to fast-track the unlocking of significant potential value from both the Pacassa SW area and the Impala field without impacting our 2026 cash capex. This programme is designed to efficiently convert resources into production, growing volumes through our existing infrastructure and delivering tangible value for our shareholders. Crucially, it will also provide invaluable data to de-risk and define future prospectivity across the wider Block 3/05 area, optimising our long-term development plan," said Paul McDade, Chief Executive Officer of Afentra.
Operators are likely looking at cost-effective decommissioning in future with the 'rollback' of supplemental financial assurance rule that has recently been announced by the United States Interior Department.
This, the department officials believe, can be achieved from the ultimate cost optimisation approach that drives the new proposal, which will potentially bring a shift in the Bureau of Ocean Energy Management's evaluation of financial risks.
It will allow BOEM to approve new projects of significant capital investments for companies while securing taxpayers' contribution by leveraging updated risk metrics and data from the Bureau of Safety and Environmental Enforcement.
This development will replace the 2024 rule that mandated companies to set aside as much as US$6.9bn in supplemental financial assurance. About US$6bn of that burden were likely shouldered by small businesses that make up most of the operators on the Outer Continental Shelf.
According to DOI, the proposal will help maintain strong accountability for lessees and grant holders under the Outer Continental Shelf Lands Act but reduces “excessive financial barriers” that can hinder progress.
Saving about US$484mn annually in compliance costs, the move can potentially unlock billions of dollars for investment, exploration, production and employment generation.
“For too long, Washington red tape has strangled American energy producers and held back small businesses,” said Interior Secretary Doug Burgum. “President Trump is delivering on his promise to put American workers first, cut burdensome regulations and unleash our vast energy potential. These updates will free up billions of dollars for exploration and development, create good-paying jobs and unlock domestic energy production so we are never forced to rely on foreign adversaries for the resources that power our economy.”
The DOI said that the Bureau of Ocean Energy Management (BOEM) is acting in response to President Trump’s Executive Order 14154, “Unleashing American Energy.”
The proposed changes will be published in the Federal Register with a 60-day public comment period.
Welcoming the change, the Independent Petroleum Association of America's Executive Vice President and Chief Policy Officer, Dan Naatz, said, “We applaud the Trump Administration for taking steps to roll back the flawed financial assurance rule promulgated during the Biden Administration. Had it been fully implemented, the Biden rule would have disproportionately affected independent offshore oil and gas producers and had them bear most of the associated costs."
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.
bp and Eni venture, Azule Energy, has announced start-up of gas production from the Quiluma field, part of the New Gas Consortium (NGC) in Angola, which is initially expected to reach 150 mn standard cu/ft per day and ramp up to 330 mn standard cu/ft per day by the year end.
A first for Angola's non-associated gas development, the NGC project is driven by gas produced from the shallow water offshore Quiluma field. This gas is directed for export from the Angola LNG plant following treatment at an onshore processing facility.
Azule Energy is operator of the NGC, with a 37.4% participation, in partnership with Cabinda Gulf Oil Company (CABGOC) with 31%, Sonangol E&P with 19.8% and TotalEnergies with 11.8% and ANPG as the National Concessionaire.
Gordon Birrell, bp’s executive vice president for production and operations, and Azule board member, said, "The safe delivery of the NGC project is another example of bp’s strategic progress and demonstrates what strong partnerships and collaboration can deliver. This project marks an important step for Angola’s energy system and strengthens the country’s energy mix as it looks to enhance its position as a global player in the natural gas market.”
This development comes following the inauguration the project’s gas treatment plant in November 2025. The NGC start-up is the latest in a series of upstream advancements such as the Agogo field at the Agogo Integrated West Hub (Agogo IWH) project, in block 15/06, offshore Angola, and the Ndungu start-up in February 2026.
Energy technology company, SLB's joint venture, OneSubsea, has signed an agreement to initiate the acquisition of Norway-based Envirex Group AS' subsea business.
The transaction makes Envirex's subsea segment part of SLB OneSubsea, with the former's specialised technologies and research and development expertise adding to the latter's global technology portfolio. This timely launch in a ever-dynamic subsea market will advance the deployment of new technology solutions, providing global clients with a diverse range of innovative services to choose from.
"This agreement represents a natural next step in a collaboration that has developed over more than a decade,” said Mads Hjelmeland, chief executive officer of SLB OneSubsea. “Once completed, the transaction would strengthen our technology portfolio and enhance the value we deliver to our customers."
The transaction is expected to close in the first half of 2026, subject to regulatory approvals and other customary closing conditions.
Based in Oslo and Houston, SLB OneSubsea is a joint venture by SLB, Aker Solutions and Subsea7. The joint venture is working to define a new era of subsea services by leveraging technology and innovation for a sustainable offshore industry.
Equinor has commenced drilling operations for one of Brazil’s most significant natural gas projects
The Raia project in the pre salt of the Campos Basin, Brazil, which represents Equinor’s largest international investment to date, has recoverable reserves exceeding one billion barrels of oil equivalent, and is due to start up in 2028.Once completed, the project, operated by Equinor (35%), in partnership with Repsol Sinopec Brasil (35%) and Petrobras (30%) will have the capacity to export up to 16 million cubic metres of natural gas per day, potentially representing 15% of Brazil’s natural gas demand.
The drilling campaign, which is being carried out by the Valaris DS-17 drillingship, includes six wells in the Raia area, located around 200 kilometres offshore Brazil in water depths of around 2,900 metres. Wells will be connected to an FPSO, which will treat produced oil/condensate and gas, with natural gas being transported via pipeline to Cabiúnas, in the city of Macaé, Rio de Janeiro state.
Drilling activities build on the companies’ combined competence in deepwater operations, including previous experience on the Bacalhau field, where the DS 17 also took part in the drilling campaign.
“Raia is Equinor’s largest project under execution and marks the deepest water depth operation in our portfolio. Together with our partners and suppliers, we are applying world-class technology and decades of offshore expertise. While drilling takes place, integration and commissioning activities on the FPSO are progressing well putting us on track towards a safe start of operations in 2028,” said Geir Tungesvik, executive vice president, Projects, Drilling and Procurement at Equinor.
Brazil represents a key growth area for Equinor, which has a diversified oil and gas portfolio in the country as well as expanding activities in renewable energy, with US$25bn set to be invested in the market by 2030.
Australian marine services provider Bhagwan Marine Limited has secured a contract from a major oil and gas operator to remove oil tanker moorings and navigation buoys at Barrow Island, marking a strategic step into a wider offshore decommissioning programme.
The award is seen as an entry point into a broader pipeline of asset retirement projects linked to ageing infrastructure in the region. The scope of work will allow the company to demonstrate its technical capabilities in nearshore and shallow-water environments, where demand for efficient removal solutions is expected to grow.
Bhagwan Marine said it is developing a removal methodology that could be replicated across similar projects, positioning the firm to capitalise on a rising number of decommissioning campaigns. Many offshore operators face comparable challenges as legacy infrastructure reaches the end of its operational life, particularly in mature basins.
The company has been steadily building its credentials in this segment. In 2024, it completed the Thevenard Island project, one of Australia’s largest offshore decommissioning undertakings. The campaign involved the removal of nine platforms and required approximately 180 offshore personnel, with more than 850,000 hours worked. The project underscored Bhagwan Marine’s ability to manage complex operations while maintaining safety and efficiency standards.
Since then, the company has expanded its portfolio through additional assignments, including work on Northern Endeavour operations in the Timor Sea, as well as projects involving the Harriet Alpha and Angel platforms offshore Western Australia. These engagements have strengthened its presence in the evolving decommissioning market.
Industry projections indicate that Australia is entering a prolonged phase of offshore asset retirement, driven by ageing oil and gas infrastructure. Estimates suggest total decommissioning liabilities could reach US$60bn, with the bulk of activity concentrated in Western Australia and the Gippsland Basin. Assets slated for removal include platforms, pipelines, wells and subsea installations, creating sustained demand for specialised marine contractors.
Bhagwan Marine’s leadership believes the latest contract reinforces its long-term strategy to expand in this space. Managing director Loui Kannikoski said the company has been positioning itself to capture emerging opportunities across Australia’s offshore basins.
He added that the development of scalable and cost-effective removal techniques will be critical as decommissioning activity accelerates over the coming decade. With its fleet, engineering expertise and operational experience, Bhagwan Marine aims to secure a larger share of what is expected to be a multi-billion-dollar market.
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
Page 1 of 121
