DOF Group ASA has announced the award of a Significant contract in the North Sea for a subsea decommissioning campaign.
The contract includes project management, engineering, offshore execution and disposal services for the removal of subsea infrastructure and seabed clearance across multiple offshore fields.
The offshore campaign is scheduled to go ahead during the first quarter of 2027.
Offshore operations will be performed by one of DOF’s Construction Support Vessels, utilising its integrated decommissioning capabilities, combining in-house engineering, project management, marine operations, ROV services, survey and offshore execution.
Mons S. Aase, CEO DOF Group, said, “We are pleased to secure this contract and look forward to delivering a safe and efficient decommissioning campaign.
“The award reflects the strength of DOF’s integrated service offering and our ability to execute complex offshore projects across the full project lifecycle.
With DOF defining a Significant contract as one with a value between USD 15 million and 20 million, this award further strengthens its position within the decommissioning market and highlights the continued demand for integrated end-of-life solutions for offshore infrastructure.
As the upstream oil and gas industry evolves, managing end-of-life projects has become a defining challenge for operators and investors alike.
Across the Asia-Pacific, the complexities of transaction structuring, potential disputes, and the allocation of future liabilities are prompting critical discussions. The spotlight is now firmly on decommissioning risk, requiring careful navigation by companies dealing with mature upstream assets. Bringing significant expertise to this conversation, Valeura Energy will take a prominent role in an upcoming Asia-Pacific industry discussion focused entirely on these pressing issues.
Kelvin Tang, Valeura Energy's Executive Vice President, Corporate and General Counsel, is scheduled to speak at an Asia Chapter event in Singapore on 30 September 2026. The session aims to provide a comprehensive examination of how decommissioning obligations are treated across diverse Asia-Pacific markets. Furthermore, it will explore how those lingering obligations can affect mergers, acquisitions, and the broader landscape of future corporate liabilities.
For companies engaged in buying, selling, and operating mature upstream assets, the topic of decommissioning is of direct relevance. The reality of the oil and gas sector is that decommissioning costs and environmental responsibilities can remain securely tied to an asset long after production decisions have been made. Consequently, liability allocation has transformed into a fundamental component of strategic transaction planning.
When operators acquire or divest mature fields, failing to thoroughly account for end-of-life asset retirement can lead to profound operational and financial consequences. The upcoming event will systematically address these precise challenges, providing clarity on the legal frameworks governing the Asia-Pacific region.
Key themes defining the upcoming discussion include:
For Valeura Energy, participating in this discussion is closely aligned with Tang's extensive professional background. Boasting more than 18 years of experience within the international oil and gas sector, his career encompasses a broad spectrum of critical disciplines. Tang's expertise is not strictly limited to legal affairs; it actively covers daily operations, business development, and executive management.
Before joining Valeura Energy, Tang was Head of Business Development at Hibiscus Petroleum. Prior to that, his leadership credentials were fundamentally shaped at KrisEnergy, where he served as Chief Executive Officer. His ascent to the CEO role followed successful tenures as Chief Operating Officer and General Counsel. Notably, KrisEnergy was the direct predecessor to Valeura Energy's initial corporate interests in Thailand.
This rich career trajectory gives Tang direct exposure to the myriad of intricate issues covered by the Singapore event. His practical understanding of acquisition structures, operating responsibilities, and the specific legal treatment of long-term liabilities makes him a highly authoritative voice on decommissioning risk.
The emphasis on meticulous transaction planning and long-term asset stewardship perfectly mirrors the broader operational philosophy of Valeura Energy Inc (TSX:VLE). Operating strictly as an upstream oil and gas company, Valeura maintains a clear, forward-looking strategy designed to add consistent value for its shareholders over the coming years.
Central to the company’s current market position is its robust financial foundation. Valeura has a remarkably strong balance sheet, effectively positioning the organisation for potential inorganic growth opportunities in both the near and medium-term. Beyond its immediate merger and acquisition prospects, the business boasts substantial longer-term upside potential. This optimistic outlook is heavily driven by an operated deep, tight gas play that serves as a cornerstone of their portfolio. As the Asia-Pacific energy sector continues to grapple with the complex realities of mature fields and legacy infrastructure, Valeura's proactive approach to discussing decommissioning risk highlights its readiness to safely navigate the modern upstream landscape.
Woodside Energy is continuing the decommissioning of the Griffin oil and gas field offshore Western Australia, with a notified activity window running from 16 to 29 October 2026, according to the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA).
Located in production licence WA-10-L, approximately 65 km north-west of Onslow, the Griffin field lies in water depths of around 130 m. Its 12 former subsea oil production wells were permanently plugged in 2017, and associated subsea infrastructure was flushed of hydrocarbons.
Woodside’s accepted Griffin Decommissioning and Field Management Environment Plan covers the staged removal of subsea equipment, including wellheads, subsea trees, flexible production risers, flowlines, umbilicals and associated structures. The original plan identifies approximately 47 km of flexible production flowlines and 12 km of rigid production spools and flowlines within its scope.
The programme is being managed through separate environmental plans and regulatory approvals. The gas export pipeline and certain remaining field infrastructure are covered by separate approval arrangements.
Woodside reported significant progress during 2025, including completion of wellhead severance activities, following the recovery of the field’s riser turret mooring in 2024. The company also reported that more than 60 km of pipeline, flexible flowlines and umbilicals had been recovered and transported to an onshore facility near Onslow for cleaning and preparation for recycling, reuse or disposal.
NOPSEMA lists the October 2026 activity dates based on notifications submitted by Woodside. The dates relate to the notified activity and should not be taken as the start of the overall decommissioning programme.
For more information visit: https://info.nopsema.gov.au/activities/15/show_public
Transocean Ltd. has secured a new drilling contract worth approximately US$62 million in firm backlog and received final approval for its previously announced Equinor agreement, bringing a further US$1 billion in contract value into its firm backlog.
The company’s Transocean Norge rig has been awarded a two-well programme by A/S Norske Shell in Norway. The work is expected to last around 120 days and begin immediately after the rig completes its existing contracted programmes in the country. The agreement also includes an option for one additional well. The estimated US$62 million backlog contribution excludes additional services.
Separately, Equinor granted final approval in late September for its previously announced agreement covering three harsh-environment semisubmersible rigs operating in Norway: Transocean Enabler, Transocean Encourage and Transocean Endurance. With approval confirmed, the agreement’s total value of approximately US$1 billion has now been formally added to Transocean’s backlog.
EnerMech has secured a five-year extension to its non-destructive testing (NDT) contract with Chevron Australia, continuing an agreement that will now run to the end of 2031.
Having first secured the work in 2017, the renewed contract will see EnerMech continue to deliver inspection and asset integrity services across Chevron Australia's operations, building on a partnership that has supported some of Western Australia's most significant energy developments.
“Strong customer relationships are earned through consistent performance, technical expertise and an uncompromising commitment to safety,” said Charles 'Chuck' Davison, Jr., EnerMech’s CEO.
“Our Australian team has built a reputation for delivering high-quality solutions in some of the industry's most demanding operating environments.”
Backed by a broad integrity management offering, EnerMech provides advanced NDT, condition monitoring, corrosion and inspection services, statutory inspections, engineering support, and specialist asset integrity solutions across its Australian operations.
In Australia, it delivers multi-disciplined services across integrity management, process, pipeline and subsea, cranes and lifting, hydraulics, valves, and electrical and instrumentation, providing customers with support throughout the asset lifecycle.
“As asset owners continue to focus on reliability, efficiency and long-term performance, EnerMech remains committed to helping our customers maximise value from their operations through specialist capability and integrated service delivery,” said Davison, Jr.
The company has supported Chevron regionally on major assets, including two major LNG developments, Gorgon and Wheatstone, delivering services spanning commissioning, maintenance, shutdowns and ongoing operational support.
“Our focus is on giving our customers confidence that their assets are being supported safely, efficiently and with the right technical expertise,” said Heath Ward, Regional Vice President - Australia at EnerMech.
“The continuity we bring through our local workforce, established systems and deep understanding of Chevron Australia’s operating environment allows us to respond quickly and deliver with discipline.
“We are pleased to continue this important relationship and remain focused on delivering the reliability and service quality our customers expect.”
Baker Hughes has announced two strategic agreements to accelerate the revitalisation of Venezuela’s energy infrastructure.
The US services group signed a strategic alliance agreement with PDVSA, Lindsayca and Fulcrum LNG, Inc. to update and expand the country’s natural gas infrastructure.
It also recently signed a separate Memorandum of Understanding (MOU) with New Stratus Energy Inc. to support the development of future oil and gas prospects.
Together, these agreements establish a framework to connect upstream resource development, midstream infrastructure, gas monetisation and LNG commercialisation on a pathway to unlock the nation’s natural gas potential, according to Lorenzo Simonelli, Chairman and CEO of Baker Hughes.
“A central objective of these partnerships is the development of an integrated gas value chain capable of transforming Venezuela's substantial natural gas resources into reliable domestic supply and future export opportunities — including the potential to export the first LNG molecules produced in Venezuela,” said Simonelli.
“Venezuela holds tremendous potential to become a significant contributor to the evolving global energy landscape, and these agreements are designed to bring world-class resource opportunities, project development, energy infrastructure and technologies and financing expertise together to realise this.”
Baker Hughes has been engaged in Venezuela’s energy sector for more than 60 years.
Its work includes more than 1,200 oil production systems, the largest artificial lift footprint, significant flexible pipe infrastructure, and approximately 240 turbomachinery units across 23 sites.
Under the alliance with PDVSA, Lindsayca and Fulcrum, the group will combine Baker Hughes' broad portfolio of energy solutions, Lindsayca's engineering, procurement, construction and operational capabilities, and Fulcrum's midstream and LNG project development, financing and market access.
This collaboration will focus on developing project specific agreements and advance critical infrastructure required to process, transport, commercialise and export gas, for the first time in the history of Venezuela.
“This strategic alliance with PDVSA is a historic opportunity to maximise the use and value of Venezuela's natural gas resources,” said Jesus Bronchalo, CEO of Fulcrum LNG, Inc.
"In the near term, we will work closely with PDVSA to identify and execute the infrastructure developments and upgrades needed to meet its internal gas requirements, while pursuing opportunities to supply natural gas to the domestic market to support reliable power generation for Venezuela and its people,” Bronchalo added.
“Over the medium and long term, we will evaluate the development and financing of new open-access midstream and LNG infrastructure that gives PDVSA and other upstream operators solutions to monetise their gas, positioning Venezuela to become a key player in the global gas and LNG industry and helping meet growing world energy demand.”
Through the MOU with New Stratus Energy, Baker Hughes will also support the development of future oil and gas prospects.
Officials and operators in the US Gulf of America (GoA) are assessing any damage to offshore infrastructure following Hurricane Isaias.
The Marine Minerals Administration (MMA) is monitoring offshore oil and gas platforms and other facilities after the evacuation of platforms and rigs in response to the storm.
The MMA reported on 11 October that its teams will work with offshore operators and other state and federal agencies until operations return to normal, and the storm is no longer a threat to GoA oil and gas activities.
Onshore, a number of individuals died, in Florida and Alabama, including people who were killed when trees fell on their houses, while hundreds of thousands were left without power after the hurricane battered parts of the southern US with powerful winds and heavy rain.
According to the MMA, oil personnel were evacuated from a total of 32 production platforms, representing around 8.7% of the 371 manned platforms in the US GoA.
It added that none of the 17 dynamically positioned rigs in the region moved off location out of the storm’s path as a precaution.
Dynamically positioned rigs maintain their location while conducting well operations by using thrusters and propellers; these rigs are not moored to the seafloor, so they can move out of harm’s way in a relatively short time frame.
The Administration said that personnel remained on board to return to the original location after the storm had passed.
From operator reports, the MMA estimates that approximately 57.5% of current daily oil production and 49.1% of current daily natural gas production in the GoA was shut in as a result of the storm.
“After the storm has passed, facilities will be inspected,” it added.
“Once all standard checks have been completed, production from undamaged facilities will be brought back online immediately. Facilities sustaining damage may take longer to bring back online.”
With around 700 facilities estimated to be approaching the end of life in the Middle East, decommissioning activity is set to accelerate.
An indication of the activity to come was the award of a decommissioning engineering contract earlier this year to McDermott by QatarEnergy, in the first project of its kind in the country. McDermott will develop a comprehensive technical and commercial framework and conduct detailed techno-economic studies to ensure the safe and systematic retirement and removal of 27 ageing offshore platforms and associated subsea infrastructure. Leveraging its deep knowledge of these assets, most of which it installed, and global expertise in strategic offshore decommissioning, McDermott says will deliver a solution that prioritises safety, efficiency and environmental responsibility, ensuring seamless transition from decommissioning definition engineering to execution.
The company is “uniquely positioned to deliver a landmark framework that will set new industry benchmarks and establish best-in-class standards for future decommissioning efforts in the region and beyond," according to managing director Mike Sutherland, McDermott Senior Vice President, Offshore Middle East.
The fact that the Middle East is at an early stage in the decommissioning journey means that a structured and integrated approach to decommissioning can be introduced at the outset.
Lee Vettese, regional manager – Middle East at leading logistics, materials and operational management specialist ASCO argues that getting the decommissioning model right now will reduce risk, protect schedules and build the local skills, infrastructure and supply chains needed for future projects.
It is about building the physical capacity, regulatory frameworks, specialist skills and operating models needed to manage decommissioning safely and efficiently, he says, highlighting that the Middle East can learn from the experience of more mature decommissioning markets such as the North Sea, combining international delivery experience with local content and knowledge.
Asco has recently opened an office in Qatar, its first in the Middle East, to serve the growing GCC and wider Middle East market, seeing increasing demand in a number of areas including environmental handling and decommissioning services.
Also having the Middle East in its sights as a critical market, is a new decommissioning partnership between Aquaterra Energy, a leading provider of engineered products and services for well access and offshore developments, and James Fisher, a global provider of specialist marine and energy solutions. The two organisations aim to streamline offshore decommissioning delivery by providing energy operators with a single, integrated route to plan and execute well abandonment and infrastructure removal programmes, in contrast with fragmented traditional decommissioning models, connecting early-stage planning, detailed engineering, and well access with final offshore execution. For operators, this means fewer handovers between disparate contractors, substantially stronger accountability throughout the project lifecycle, and greater certainty from initial scope development through to final execution.
Also targeting the Middle East as a priority region is Blue Ocean Decom, a new company set up to provide engineered, specialist subsea removal solutions for the offshore energy sector as global decommissioning activity accelerates. With a focus on execution discipline and environmental responsibility, the firm provides specialised equipment packages to support complex platform and well cutting operations, as well as services for the safe subsea asset removal of pipelines and risers, seabed preparation and clearance, and subsea asset recovery.
“Decommissioning no longer represents a simple back-end obligation. The industry now treats it as a top strategic priority. Operators face immense pressure to execute these complex projects with absolute precision,” the company comments, viewing subsea removal as deserving the same level of specialist attention as any other critical path discipline.
Over the next two decades, thousands of subsea structures, pipelines, and platforms are scheduled to cease operations.
As these massive industrial installations reach the end of their productive lives, regulators, operators, and environmental scientists are confronted with a colossal task: determining the safest, most sustainable methods for managing redundant offshore infrastructure. The financial and environmental stakes are remarkably high, demanding a careful balance between economic feasibility and ecological preservation.
By 2040, more than 2,500 offshore oil and gas structures will be retired worldwide. Managing this transition requires an extraordinary financial investment, with decommissioning costs projected to reach up to US$13 billion per year. Australia, for example, faces a monumental task in addressing its legacy infrastructure.
This includes:
Under standard regulatory frameworks, the default requirement for operators is the complete removal of all property from the ocean. However, lifting thousands of tonnes of steel and concrete from the seabed is not always the most environmentally sound option. Alternative strategies, such as in-situ decommissioning, are increasingly being evaluated by industry and governments alike. This approach involves leaving some or all of the infrastructure in the marine environment, potentially repurposing defunct platforms into artificial reefs. Such alternatives may be permitted provided they comply with strict domestic regulations and international treaty obligations.
The primary objective of any decommissioning strategy is to minimise environmental impacts and reduce risks to a level that is as low as reasonably practicable. In-situ decommissioning can deliver substantial ecological benefits. Over decades of operation, many underwater structures have been colonised by marine life, transforming into thriving artificial reefs that support diverse marine ecosystems. Conversely, leaving industrial materials in the ocean introduces the risk of pollution, such as the potential release of heavy metals or naturally occurring contaminants, which could pose unacceptable risks.
To navigate this complex dilemma, regulators and industry leaders require robust, independent scientific data. Organisations such as the Australian Institute of Marine Science (AIMS) play a pivotal role in delivering this vital intelligence. AIMS conducts comprehensive research to understand how marine life interacts with offshore structures at both local and regional scales. Their studies provide the essential evidence needed to assess pollution risks and evaluate how different decommissioning scenarios might influence crucial ecosystem processes, such as population connectivity. Because every marine environment is unique, scientists must determine the most appropriate strategy on a rigorous, case-by-case basis.
Research institutions collaborate closely with global partners, including the National Decommissioning Research Initiative, to bridge critical knowledge gaps. To study these deep-sea habitats without impeding commercial offshore operations, researchers employ a wide range of innovative methodologies.
Key technologies and methods include:
Ultimately, the transition away from active oil and gas extraction presents a unique opportunity to rethink marine conservation and industrial responsibility. By fostering strong partnerships between scientific institutions and the offshore industry, it is possible to gather rigorous ecological data swiftly and safely. As the world grapples with the immense logistical and financial hurdles of decommissioning, science-led approaches will be absolutely crucial. Whether an offshore platform is completely removed or thoughtfully preserved as a novel habitat, ensuring the long-term health and resilience of our oceans remains the ultimate priority.
Norwegian energy group Equinor confirmed that it has discovered new gas reserves at the Gullfaks South field in the North Sea.
Rather than relying solely on frontier exploration in untested waters, energy operators in the North Sea have increasingly focused on maximising recovery near existing hubs. When new volumes are identified within the reach of active platforms, the pathway from discovery to extraction becomes substantially more straightforward. This latest announcement at Gullfaks South exemplifies how targeted exploration around long-standing assets can yield immediate operational value for the wider offshore sector.
In an official statement detailing the outcome of the evaluation, Equinor noted that the discovery holds between 0.5 million and 1.6 million standard cubic metres of recoverable oil equivalents.
Maintaining steady throughput at mature offshore installations is critical for extending the operational lifespan of the broader field. As reservoir pressures naturally shift over time, introducing fresh gas volumes helps keep topside facilities running efficiently and preserves employment and service activity across the regional supply chain. By confirming that these barrels are commercially sound, the operator underscores the strategic importance of continuous appraisal drilling within established production licences.
The stewardship of the Gullfaks asset reflects the collaborative joint-venture model that underpins offshore resource management in Norway. As the designated operator of the field, Equinor holds a 51% controlling stake, guiding the technical and operational strategy required to bring the newly discovered gas into the production stream.
The remaining equity is divided between two established partners in the region. Petoro withholds a substantial 30% stake in the licence, whilst OMV Norge holds the remaining 19% interest. Together, the three organisations share both the investment commitments and the commercial returns generated by extending the productive life of the Gullfaks South area. As work progresses to integrate these 3.3 million to 10.3 million barrels of oil equivalent into the field's output schedule, the discovery stands as clear evidence that the North Sea fifty-year-old hydrocarbon province still holds profitable surprises beneath the seabed.
Valaris Limited has announced it has been awarded new contracts and extensions, with an associated backlog sitting at approximately US$220mn.
The company has won a two-well exploration contract with Petronas Suriname Exploration & Production B.V for its drillship VALARIS DS-18. The contract is expected to commence in Q4 2026 with a duration of seven months.
VALARIS 107 will head over to Australia with a new contract expected to commence following its current commitments, with an expected duration of 300 days.
The company has also secured a new multi-well P&A contract in the Southern North Sea. The contract is a fleet award under which operations may be performed by any suitable rig within the North Sea fleet. The commencement window is up until December 2030, and has an estimated duration of 341 days.
A contract extension has been granted for VALARIS 122 with INEOS for a project in the Danish North Sea, which will commence in February 2027 for approximately 126 days.
Guardian Decommissioning and Wild Well Control have announced a strategic agreement for the decommissioning of the Bullwinkle platform in the Green Canyon Block 65 in the Gulf of America.
The agreement further strengthens the long-standing relationship between the two companies, building on the successful collaborations in decommissioning, well abandonment, and specialist well control operations.
Guardian will assume operatorship as agent of the wells, the pipelines and platform. The company will also work closely with current platform operator, Talos Energy, and Wild Well Control to execute simultaneous well abandonment activities alongside ongoing production operations.
The wells phase of the project will be first, followed by the pipelines and platform scopes. From Q4 2026, Guardian will execute well abandonment activities, platform removal, jacket reefing, and site clearance through to project completion.
Iain Murray, President of Guardian Decommissioning, said, “This agreement reflects the complementary strengths of our organisations. Guardian is built to manage complex offshore decommissioning projects, including multi-well campaigns and large-asset topside removals and jacket reefing. We look forward to delivering a safe and efficient retirement of the Bullwinkle assets while allowing Wild Well Control to continue focusing on its core intervention business.”
The agreement allows Guardian to apply its extensive decommissioning expertise while enabling Wild Well Control to focus on its growing well intervention and well control businesses.
