The global iell Intervention market is experiencing strong momentum as oil and gas companies continue to optimize production, extend the lifecycle of mature wells, and improve operational reliability.
According to Market Research Future (MRFR), rising energy security concerns, increasing exploration of unconventional resources, and the demand for cost-effective field development strategies are making well intervention technologies indispensable across both onshore and offshore assets. These interventions, ranging from wireline and coiled tubing operations to stimulation and remedial services, enable operators to maintain, enhance, and restore well productivity while reducing downtime and operational costs.
“As easily accessible reservoirs decline, global oilfield infrastructure is aging rapidly. Mature fields require continuous intervention activities, such as workovers, stimulation, and mechanical repairs, to maintain optimal production,” MRFR notes, highlighting that mature oilfields are a key driver for well intervention services. In addition, unconventional resources such as shale, tight reservoirs, and coal bed methane fields require frequent interventions due to complex geology and high decline rates. Growing investments in unconventional drilling, especially in North America and Asia-Pacific, are further boosting the adoption of advanced intervention tools and techniques.
Offshore production expansion is another key factor supporting the market. Deepwater and ultra-deepwater developments, coupled with harsh environmental conditions and complex operations, require periodic well interventions. Companies are increasingly focusing on production optimization and cost efficiency through digital optimization, predictive maintenance, and cost-effective well management strategies. Light Well Intervention (LWI) is gaining traction, particularly in offshore assets, as it significantly reduces operational costs compared to traditional rig-based methods. Government investments in energy security are also encouraging continuous well maintenance programs, especially among national oil companies in the Middle East and Asia.
Technological innovation is reshaping the Well Intervention Market. Digital monitoring, real-time analytics, robotics, autonomous systems, advanced coiled tubing, modern wireline and slickline solutions, subsea intervention systems, and improved well integrity technologies are enhancing efficiency, safety, and operational performance.
North America remains the largest market for well intervention services, driven by extensive shale production, high well counts, and continuous drilling and completion activities. The United States leads in coiled tubing and wireline services due to rapid development of unconventional assets such as the Permian Basin, Bakken, and Eagle Ford. Mature Gulf of Mexico fields also contribute significantly to offshore intervention demand.
The Well Intervention Market is projected to reach US$12.93 bn by 2035, growing at a CAGR of 5.32%, reinforcing its critical role in maintaining production, enhancing efficiency, and supporting cost-effective oil and gas operations worldwide.
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Kimberley Marine Support Base (KMSB), a new purpose-built floating wharf in Broome, is looking to aid Western Australia’s (WA) oil and gas decommissioning efforts.
The facility enables 24/7 operations independent of tides, a significant advantage in northern Australia, where tidal windows can create unpredictable delays and added costs.
KMSB marks another significant private investment in the state’s critical port infrastructure steered by Founder and Managing Director Andrew Natta — building on the successful model he established at the existing Onslow Marine Support Base (OMSB) in the Pilbara region of WA.
OMSB is an industry partner of the Centre of Decommissioning Australia (CODA), which highlighted the new project in its recent newsletter.
The new facility boasts a 300-metre berth and heavy-lift capability, and is designed to accommodate breakbulk and project cargo up to 600 tonnes, as well as roll-on roll-off (RoRo) equipment for the resource and defence sectors, and containerised freight, critical minerals, renewable energy infrastructure and decommissioning equipment.
The KMSB facility is designed to operate as a complementary terminal to the Port of Broome, which has served as the region’s main maritime logistics hub for more than 80 years.
Australia’s northwest has long grappled with infrastructure bottlenecks, such as vessels waiting on tides, delayed project cargo, and escalating costs from demurrage and congestion —operational constraints that all carry economic implications.
Broome, in particular, has been a critical hub supporting offshore oil and gas, community resupply, defence readiness and emerging renewable energy projects.
Yet, despite this strategic importance, limitations in port infrastructure have repeatedly challenged shipping schedules and project timelines.
“Our floating wharf at KMSB is designed for ‘non-tide dependant’ operations – removing the bottlenecks that have long-plagued supply chains within the region,” said Natta.
He said KMSB will boost productivity, safety and reduce costs for established Kimberley businesses in the agricultural and resources sectors, while also allowing cruise ships to come alongside for passengers to visit Broome without the need to wait for appropriate tides.
Crucially, the facility will also enable the growth of new sectors – such as proposed critical minerals and renewable energy developments – by providing the necessary infrastructure for handling specialised cargo like wind turbines, solar systems and commercial battery imports.
“Our 24/7 operational capability, combined with our flexible, client-focused approach, means businesses can now plan with confidence, operate cost effectively and significantly improve their supply chain efficiency.”
The offshore decommissioning market is entering a phase of significant change, particularly across the Asia–Pacific region, where ageing infrastructure, evolving regulations, and rising environmental expectations are reshaping industry priorities.
Governments throughout APAC are tightening their regulatory frameworks, introducing more comprehensive guidelines to ensure that the dismantling of offshore assets is carried out responsibly and with minimal environmental impact. These regulatory pressures are pushing operators to embrace innovative, sustainable technologies as they update their decommissioning strategies.
A major influence on this shift is the accelerating move towards renewable energy. As countries in the region prioritise cleaner energy sources, many oil and gas platforms are being retired to make room for offshore wind developments and other low-carbon alternatives. This transition is generating sustained demand for specialist decommissioning services, creating opportunities for companies able to support safe and efficient asset removal.
Collaboration is also becoming a defining feature of the offshore decommissioning market. Operators, contractors, and regulators are increasingly pooling expertise to streamline projects, share resources, and establish consistent industry standards. This cooperative approach supports smoother project delivery while encouraging the development of best-practice frameworks across the sector. Governments are also placing greater emphasis on local content, encouraging the involvement of domestic firms and promoting workforce development around decommissioning activities.
Several key drivers are shaping the market’s expansion. Ageing offshore infrastructure remains one of the most pressing, with more than 200 platforms in APAC expected to require full decommissioning by 2030. Analysts anticipate an annual market growth rate of around 10% as companies tackle end-of-life assets and associated safety and environmental risks.
At the same time, investment in renewable energy across APAC is forecast to exceed US$50bn by 2027, accelerating the removal of outdated platforms to support offshore wind and related developments. Evolving regulatory structures, particularly in markets such as Australia and Japan, are expected to increase compliance costs by as much as 15% over the next five years, compelling firms to enhance their decommissioning frameworks.
Technological advances especially in robotics, automated systems, and remotely operated vehicles—are helping to reduce project costs by as much as 20% while improving safety and precision. These innovations are strengthening the competitiveness of companies adopting them.
Market segmentation highlights several trends: Well Plugging and Abandonment remains the dominant service type due to strict environmental requirements, while Pipeline and Power Cable Decommissioning is emerging rapidly in response to renewable energy expansion. Shallow-water decommissioning still holds the largest market share, though deepwater activity is growing quickly as operators venture into more challenging environments. In terms of structure, Topside remains the largest segment, with Substructure decommissioning expanding at the fastest pace due to improved removal techniques.
The refurbished Salamanca floating production unit in the Gulf of America has been successfully generating around 66,000 barrels of oil equivalent per day under strong and rigorous regulatory and safety reviews by the Bureau of Safety and Environmental Enforcement.
In a first, the Salamanca hub in Keathley Canyon, operated by LLOG Exploration, was refurbished to reuse a decommissioned floating production unit in the Gulf. The transformation of a retired facility into a modern oil hub reflected an innovative push that ruled out time and cost constraints in building a platform from scratch. Besides, it also made a huge difference in reducing emissions, which is an otherwise unavoidable part of bringing a new facility online.
“These developments underscore the success of American Energy Dominance policies in not only expanding domestic energy supplies and creating jobs but also in boosting the economy and reducing reliance on foreign oil – all while maintaining the highest safety and environmental standards,” said Assistant Secretary for Land and Minerals Management, Leslie Beyer, while mentioning the Salamanca floating production unit innovation as part of “Unleashing American Energy” agenda.
While the Bureau recognised the novelty of the Salamanca hub, it made sure the project met all regulatory and safety standards in adding new barrels to US oil production.
“We're seeing the payoff of a bold offshore energy blueprint,” said Beyer. “From cutting-edge deepwater platforms to creative reuse of existing units, industry is answering the call to maximise domestic oil production. Under President Trump's leadership, the Gulf is again proving itself as a cornerstone of American energy security, ensuring a stable and reliable energy supply.”
The hull refurbishment for the Salamanca platform was completed at Seatrium in Brownsville, before the new topside equipment and deck was connected to the hull for the final outfitting of the FPU.
The Tiber project in the United States deepwaters will be supported by a subsea boosting system from SLB's OneSubsea in terms with a engineering, procurement and construction (EPC) contract from bp.
The Tiber project is a greenfield development by bp, which is being advanced alsongside bp's Kaskida initiative. Both projects — which target prolific Paleogene reserves — leverage the same supplier-led, standardised high-pressure subsea pump system solution.
“We look forward to helping bp realise even more value from their Paleogene developments,” said Mads Hjelmeland, CEO at SLB OneSubsea. “We are seeing more and more operators adopt subsea boosting strategies that free up topside space and reduce power requirements.”
bp has also booked Seatrium for the development of the Tiber FPU with engineering, procurement, construction and onshore commissioning services. With a capacity of 80000 bopd, the Tiber FPU will produce from the Tiber and Guadalupe fields in the Gulf of America.
Frequent delays across offshore energy and infrastructure projects are putting the UK’s underwater supply chain at risk, according to new findings from Global Underwater Hub (GUH), the national trade and industry development body for the sector.
In its Business Survey 2025, almost all respondents (96%) reported that activity in oil and gas, offshore wind and defence is progressing too slowly, while 81% believe developments are failing to move at the pace the country requires.
The report, titled ‘Minding the Gap’, warns that continued slow project delivery may push companies to relocate overseas, with 82% of the sector saying current UK supply-chain capacity does not match demand. Alongside capturing industry sentiment, the annual survey provides insight into market size, growth opportunities and business confidence.
Neil Gordon, GUH CEO, said, “For much of the last year I have warned of the risk of ‘minding the gap’, where oil and gas projects slow and renewables projects are delayed, creating a vacuum of inactivity that threatens the UK’s world-leading underwater supply chain. Our latest business survey shows this is already playing out and, increasingly, there is a real possibility this gap will be filled by fast-moving international projects, drawing away our assets, facilities and skilled personnel. If this is to happen, then a return to the UK will be incredibly unlikely, even when our own projects eventually begin.”
Despite these concerns, the study highlights a modest increase in the size of the UK underwater market, rising from approximately US$11.5bn in 2024 to US$11.75bn in 2025. This growth is driven largely by new project construction across various global markets, reflected in rising export activity. Exports now account for 43% of all revenue generated by UK underwater supply-chain companies, underscoring the sector’s strong international reputation while also presenting a risk of long-term talent and investment drift.
Gordon noted, “Our research shows that companies increasingly view greater prospects internationally than domestically, with shorter timelines, supportive government policy and greater volume. A sea-based supply chain is, by nature, highly mobile and, unless things improve in the UK, then it seems inevitable that companies will consider not just exporting to other regions but relocating there.”
Ahead of the Autumn Budget, the report urges swift action to safeguard the UK’s underwater supply chain and identifies four priorities: accelerating domestic project delivery, improving policy certainty and support, strengthening the skills pipeline and promoting strategic diversification. Together, these recommendations aim to close the energy transition gap, improve supply-chain utilisation and build long-term resilience.
Gordon added, “The UK has a supply chain with the capability and capacity to lead, but confidence in project timelines and policy support is eroding. Major industrial projects take years to mobilise, and we risk repeating past declines that cannot be reversed overnight. This is a pivotal moment. We need a coordinated industrial strategy, targeted investment and a sustainable skills pipeline to keep the UK at the forefront of underwater innovation. Stakeholders must act now to align policy, project flow and investment with the supply chain’s readiness and ambition. The opportunity is clear, but so is the risk.”
QatarEnergy has signed a production sharing agreement (PSA) for shallow-water Block S4 offshore Guyana, formalising its participation in the block awarded during the country’s 2022 licensing round.
Saad Sherida Al-Kaabi, Qatar’s Minister of State for Energy Affairs and President and CEO of QatarEnergy, said the agreement aligns with the company’s strategy to expand its international upstream footprint.
“We are pleased to secure this exploration block in Guyana, further building on the strategy to expand our global upstream exploration activities,” he said.
“I would like to thank the government of the Cooperative Republic of Guyana and our partners in the block for their valued support and cooperation. We look forward to working together to deliver on our exploration objectives.”
Under the PSA, TotalEnergies will operate the block with a 40% stake. QatarEnergy will hold 35%, while Petronas will take the remaining 25%.
Block S4 spans 1,788 sq km and lies around 50–100 km offshore Guyana, in shallow waters ranging from 30–100 metres. The agreement further strengthens QatarEnergy’s growing presence in the Americas’ exploration landscape.
Talos Energy Inc reported strong operational and financial results for Q3 2025, reflecting disciplined capital management, production growth, and shareholder returns.
The company produced 95.2 thousand barrels of oil equivalent per day, with 70% from oil and 76% liquids, generating US$103.4 million in adjusted free cash flow.
Talos returned over US$100 million to shareholders in 2025 through share repurchases and continued progress on its Optimal Performance Plan, exceeding the year-end target of US$25 million by realising over US$40 million in cash flow enhancements.
Full-year guidance was improved due to higher production, lower operating expenses, and reduced capital expenditures, while the balance sheet remains strong with US$332.7 million in cash and low net debt.
Operationally, Talos continues to expand its deepwater portfolio in North America. Notably, the Daenerys exploration prospect on Walker Ridge blocks 106, 107, 150, and 151 delivered a successful discovery in sub-salt Miocene sands, with an appraisal well planned for Q2 2026.
The Monument discovery in Walker Ridge blocks 271, 272, 315, and 316 is set for development as a subsea tie-back to the Shenandoah facility, with the first well expected to spud in early 2026 and production targeted later in the year. Talos’s disciplined drilling and exploration strategy in North America, combined with operational efficiency and capital discipline, positions the company to enhance production, advance resource delineation, and sustain long-term growth.
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Another significant deepwater project following the Kaskida floating production unit for bp, Seatrium Limited has now landed a contract from the major for the engineering, procurement, construction and onshore commissioning of the Tiber FPU as well in the Gulf of America.
William Gu, Executive Vice President of Seatrium Energy (International), said, “The Tiber FPU award marks a significant milestone in our relationship with bp and underscores the strength of our series-build approach for the Gulf of America production units. It also highlights Seatrium’s expanding foothold in the FPU segment, delivering exceptional quality and efficiency with uncompromising safety through maximum on-ground completion and single-lift capability. Drawing on lessons learned from our growing portfolio of FPU projects, we will continue to translate experience into execution excellence. Our commitment remains steadfast in supporting bp’s offshore developments.”
The Tiber FPU will have a production capacity of 80,000 barrels of crude oil per day and incorporate advanced technologies to enhance operational efficiency and safety. It will produce from the Tiber and Guadalupe fields in the Keathley Canyon area of the Gulf of America, about 300 miles southwest of New Orleans, in water depths of around 4,100 ft.
The design of the Tiber FPU will largely follow that of Kaskida FPU, backed by Seatrium's well-established expertise in designing from the last project. The company has chosen this strategy to leverage key engineering and commissioning support partners, as well as trusted equipment suppliers, ensuring consistent and streamlined execution to get the ball rolling for the large-scale offshore project.
The topside for the Tiber FPU will be installed onto the hull using Seatrium’s single-lift integration methodology, enabled by its Goliath twin cranes with a combined lifting capacity of 30,000 tonnes. This approach allows the topside to be fully completed and tested at ground level, maximising readiness, safety and efficiency.
With an aim to expand its engineering and procurement services to support operations and decommissioning in the North East, Tattva Group has announced a UK£2mn investment in Project Development International (PDi).
This will support not only the advancement of PDi’s offerings in subsea engineering and decommissioning but also enhance its wider engineering services in topsides. This allows the company to serve the nation at an apt time, as it navigates policy uncertainty and supply chain volatilities.
Welcoming the move as 'a vote of confidence' for PDi, the company's new CEO, Girish Kabra, said, “Tattva Group’s commitment to PDi — especially amid current policy uncertainty from the UK Government and pressures facing the supply chain – is welcomed, to boost workforce confidence and support the collective regional effort to retain skills in the North Sea.”
“This strategic capital injection of UK£2mn empowers us to expand and elevate our engineering and procurement services, with a sharpened focus on supporting late-life asset management and decommissioning activities. We’re committed to delivering even more flexible and value-added solutions, addressing the evolving needs of the UK energy sector and solidifying PDi’s position as a key partner in the North Sea’s future. This investment means greater capacity, deeper expertise, and a more robust offering to help all our clients and customers navigate their operational and decommissioning challenges efficiently and effectively.”
Explaining the copmpany's strategy behind the move, TR Narayanaswamy, Group Chairman of Tattva, said, “We see a gap in the market where operators are seeking more flexibility and value-added service offerings...With its refreshed management team and focus, PDi is uniquely positioned to meet that need and deliver long term value to clients.”
Improved efficiencies and experience may help to ease the cost of decommissioning Australia’s ageing offshore oil and gas infrastructure, a new report suggests.
The Department of Industry, Science, and Resources recently commissioned consultancy, Xodus Group, to explore the nation's overall decommissioning liabilities.
The report — Australian Offshore Oil & Gas Decommissioning Liability Estimate 2025 — estimates the industry will spend A$43.6bn through to 2070, rising to A$66.8bn when factoring in inflation.
This includes all fixed and floating facilities, rigid and flexible lines, subsea infrastructure and wells.
It added that around 55% of the decommissioning spend will occur before 2040, with 61% of the liability focused on Western Australia, 23% in Victoria and 16% off the Northern Territory.
The decommissioning of wells represents the single largest portion of the decommissioning liability, with an estimated cost of A$17.9bn, the report added, followed closely by pipeline decommissioning, with an estimated liability of A$17.85bn.
The report noted that decommissioning practice and technology have already improved since 2020, a trend that could continue, yielding benefits along the way.
There is an opportunity for further improvements in efficiency, it added, through operator cooperation when decommissioning, in addition to further technological advances and industry investment in onshore disposal and recycling.
“Possible cost reductions primarily relate to the opportunity for efficiencies, technological development and future infrastructure investments,” it stated.
These include:
Single and multiple operator campaigns to distribute the costs of equipment and vessels across multiple assets.
A dedicated disposal yard for deconstruction and cleaning.
Domestic steel recycling to reduce the amount of steel which is exported for recycling.
Aligning decommissioning campaigns with offshore wind construction to reduce vessel mobilisation rates.
Implementing new technologies and/or engineering practices to ensure that the most appropriate and efficient methodology, vessels, and equipment are used to perform decommissioning activities. Here, it cites the example of changes in the commonly accepted removal methodologies for certain infrastructure types.For example, reverse s-lay was previously considered the only methodology for recovery of pipelines — however, cut and lift now remains the most accepted method for pipeline removal.
Other findings in the report highlight the sheer magnitude of the task now facing contractors and operators across the board, with at least 2.7 million tonnes of infrastructure set to be removed, including a large portion of steel, with huge potential for local recycling.
Saudi Aramco has deepened its long-standing relationship with the United States by signing 17 new memoranda of understanding and agreements worth more than US$30bn, marking another significant step in its strategy to broaden global partnerships and support long-term growth.
These latest commitments span a wide range of sectors, from liquefied natural gas (LNG) and advanced materials to financial services and industrial supply chains, reinforcing Aramco’s position at the centre of global energy and technology collaboration.
The new deals build on the company’s earlier announcement in May 2025, when Aramco unveiled 34 MoUs and agreements with a combined potential value of around US$90bn. Together, the partnerships announced this year now approach an impressive US$120bn, reflecting a sharp expansion of its collaborative pipeline with American companies.
A major emphasis of the new agreements lies in LNG development. Aramco signed an MoU with MidOcean Energy linked to potential investment in the Lake Charles LNG project on the US Gulf Coast. The company is also assessing opportunities for cooperation with Commonwealth LNG on its liquefaction project in Louisiana, including discussions involving potential LNG and gas purchases through Aramco Trading. These moves highlight the Saudi energy giant’s increasing interest in global LNG markets as demand continues to evolve.
Aramco also strengthened ties with leading US suppliers such as SLB, Baker Hughes, McDermott, Halliburton, NESR, KBR, Flowserve, NOV, Worley and Fluor. These agreements reflect ongoing requirements across the company’s upstream and downstream operations, ensuring continued access to essential materials, engineering services and procurement support.
In the field of advanced materials, Aramco extended its existing MoU with Syensqo to examine opportunities for localising the production of carbon fibre and composite materials, a sector seen as increasingly important for industrial innovation and lightweight manufacturing.
Financial services were another key focus. Wisayah, Aramco’s investment arm, entered into asset management and investment agreements with Loomis Sayles, Blackstone and PGIM, while Aramco reached a strategic partnership with J.P. Morgan centred on cash account management.
Amin H. Nasser, Aramco President and CEO, said,“Since the 1930s, US firms have played a major role in supporting the company’s success… We expect the multi-billion dollar MoUs and agreements announced today to act as a springboard for further progress, strengthening Aramco’s longstanding legacy of collaboration with American counterparties and unlocking new value creation opportunities that promote innovation and growth."
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