The North Sea Transition Authority (NSTA) has highlighted the crucial nature of new technologies in improving and speeding up P&A operations in cementing the UK’s position as a world-leader in cost-effective decommissioning.
Over the last few years, smart technologies have been piloted in the UK Continental Shelf to help the sector build upon its reputation for innovation and cost-efficiency. Despite strong process, many more are still awaiting field trials.
Last month NSTA, along with the Net Zero Technology Centre, hosted a showcase event where more than 20 technology providers displayed their new technology to an audience of around 20 international operators. The event aimed to raise awareness of the technologies and encourage operators to facilitate more field trials every year.
Some of the showcased technologies included alternative materials with the potential to create barriers in the well, such as resigns, polymers and bismuth, and logging and perforating tools designed to make the P&A process more efficient.
In the UKCS, around 1,500 wells will be due for decommissioning between 2026 and 2030, presenting the industry a golden opportunity to test innovative P&A technologies to demonstrate how they can save operators time and money.
Not only do innovative technologies play an integral role in ensuring operators comply with their regulatory obligations in terms of decommissioning assets, but those technologies which prove successful will likely be in demand globally in areas such as Australia, Brazil and the Gulf of Mexico as the demand for decommissioning processes in those basins continues to rise.
Carlo Procaccini, Chief Technical Officer at the NSTA, said, “In the UK, we’re fortunate to have a supply chain which consistently produces ground-breaking technologies for offshore operations, including well decommissioning. However, the full potential of this innovation can only be unleashed if suppliers are given a chance to show what they can do in the field. With the current high volumes of well P&A activity, I encourage operators to offer field trials to progress innovation and make the most of the savings on offer.”
The decommissioning of offshore fields is no longer the final chapter in their lifecycle. Increasingly, these sites are being repurposed for carbon capture and storage (CCS), a key strategy in the global push to achieve net zero emissions by 2050.
By utilising depleted fields to store CO₂ beneath the seabed, operators can transform non-productive assets into environmental solutions, aligning with international climate commitments.
The International Energy Agency (IEA) highlights CCS as a crucial tool for reducing emissions from existing energy infrastructure, decarbonising hard-to-abate industries, and facilitating low-carbon hydrogen production. The technology has long been linked to enhanced oil recovery (EOR), with operators injecting CO₂ into reservoirs to boost extraction rates—a practice dating back to the 1970s.
Despite growing interest, the CCS sector faces economic and technical hurdles. The IEA reported a 35% increase in announced capture capacity and a 70% rise in storage capacity in 2023, bringing projected CO₂ capture to 435 million tonnes annually by 2030.
However, this remains well below the 1 gigatonne required to meet net zero targets. Analysts at Rystad Energy warn that many announced projects may not materialise due to economic feasibility concerns, a common critique of CCS. Additionally, the Center for International Environmental Law (CIEL) notes that many past projects have faced operational challenges or failures.
Nevertheless, government incentives are spurring investment. In the US, the Inflation Reduction Act of 2022 expanded the 45Q tax credit, offering US$85 per tonne of CO₂ permanently stored and US$60 per tonne for EOR, attracting new investors and developers to the sector.
“The sector is on the verge of a breakthrough,” said Benn Cannell, innovation director at Aquaterra Energy. “Trailblazing companies are now going through the steps needed to deliver CCS at scale.” As more projects move forward, the industry’s success will hinge on advancing technology, securing financial backing, and overcoming operational setbacks.
Paul Goodfellow has been appointed as the new President and Chief Executive Officer at Talos Energy where he will utilise his 30 years of experience to help the business define its next phase of growth and develop a new strategic plan.
He said, “I appreciate the confidence the Board of Directors has shown in selecting me to lead Talos with its strong asset base and solid balance sheet. I look forward to working with the Board, senior management, and its dedicated employees as we develop and execute a strategy to drive performance and maximise value for our shareholders.
“During my first 100 days at Talos, I plan to gain a deeper understanding of our business and identify the key drivers of Talos's success. Additionally, I will collaborate with the leadership team to define the next phase of our growth and develop a strategic plan. Once this process is complete, we plan to announce our new strategic plan."
Goodfellow, who will also join the Board of Directors for the company, is bringing more than three decades’ worth of domestic and international experience in the oil and gas industry to Talos. During his career, Goodfellow has held various senior executive roles at Shell, including leading the operator’s global deepwater business across the Gulf of Mexico, Brazil, West Africa, Malaysia and the North Sea. He also held positions overseeing Shell’s well intervention organisation and served as a key member of the Projects & Technology and Upstream leadership teams.
Currently, Goodfellow is Executive Vice President and Group Chief Internal Auditor for Shell. He has also served as Executive Vice President, Deep Water for Shell’s global deepwater business, as well as Executive Vice President, Wells, Vice President and Managing Director, UK and Ireland and Vice President, Unconventionals US and Canada.
Neal Goldman, Chairman of Talos’ Board of Directors, commented, “I am very pleased to welcome Paul to Talos. The Board of Directors is confident that his extensive oil and natural gas experience, particularly in deepwater operations, along with his strategic judgement, performance track record and seasoned perspective, will be key in continuing to drive Talos’ strategy.
“Under Paul’s leadership, we expect to remain focused on leveraging our strengths in deepwater exploration and development to create compelling value for all our shareholders.”
Offshore Network’s premier well intervention event is returning to Kuala Lumpur this May where attendees will gain exclusive insights into decisive strategies, cutting-edge technologies and regulatory updates set to shape the region’s oil and gas future.
Back for its ninth edition, this year’s installation of the OWI APAC 2025 conference will take place in the JW Marriott Hotel Kuala Lumpur on 20-21 May, where 30 expert speakers will take centre stage to discuss new innovations changing the oil and gas landscape; the impact the energy transition has on intervention best practices; and the importance of cross-industry collaboration to drive production gains and asset integrity.
Featuring 10 technology demos , the conference promises to be an insightful and lucrative experience for all. More than 200 decision makers are expected to descend into the showcase halls, partaking in nine devoted networking events and engaging with a series of key sessions discussing topics such as strategic pathways and partnerships for integrated intervention, the impact of the energy transition, advanced innovations, and structured collaboration policies.
Not only will attendees have ample time to engage with other delegates in an informal manner over drinks, but Premium Pass holders will also experience an elevated offering in the form of an exclusive VIP Dinner and Drinks. Delegates will have the unique opportunity to connect in an intimate over high-end cuisine and cocktails.
For more information regarding OWI APAC 2025, the full brochure can be found here.
The Asia Pacific Offshore Decommissioning Services Market shows significant growth potential, driven by technological advancements, increased consumer demand, and evolving regulatory frameworks.
The APAC market is projected to reach US$3bn by 2030, growing at a CAGR of 9.5% from 2024 to 2030. As the market matures, innovation in product offerings and digital transformation is expected to shape its expansion. Rising interest in sustainable and eco-friendly solutions, especially in sectors like manufacturing and healthcare, is likely to drive demand. Additionally, France’s aging population and shrinking workforce may push for automation and AI-driven technologies across industries.
Sales ratios are projected to shift toward higher-value, premium products, fueled by increasing disposable incomes and consumer preferences for quality over quantity. Government initiatives promoting industry modernisation and international trade partnerships will further enhance growth opportunities. However, competitive pressures and stringent regulations may influence market dynamics.
The Offshore Decommissioning Services Market in North America showcases significant regional diversity, driven by varying consumer preferences, technological advancements, and regulatory landscapes across the US, Canada, and Mexico. The US remains the dominant player, offering a robust infrastructure and high demand across sectors such as healthcare, technology, and consumer goods. Canada complements with a focus on innovation and sustainability, while Mexico's manufacturing base plays a crucial role in cost-efficient production.
This market's economic significance lies in its contribution to GDP growth, job creation, and international trade, making it a key driver in both domestic and global economies. Regional strengths combined with market size position North America as a critical hub for the expansion and investment opportunities in the Offshore Decommissioning Services industry.
The key factors driving the growth of the offshore decommissioning services market include an increasing number of aging offshore oil and gas platforms, stringent regulations regarding decommissioning activities, and advancements in decommissioning technologies. The key players in the offshore decommissioning services market include Schlumberger, Baker Hughes, Halliburton, Weatherford International, and Tetra Technologies.
Technological advancements such as robotics, drones, and advanced sensing technologies are enabling more efficient and cost-effective decommissioning activities in the offshore sector. Market trends in the offshore decommissioning services industry, such as regulatory changes, technological advancements, and industry consolidation, can impact business investment decisions by influencing the demand for decommissioning services, the competitive landscape, and the potential for growth and profitability.
The offshore decommissioning services market aligns with environmental and sustainability goals by addressing the safe and efficient retirement of offshore infrastructure, minimising environmental impacts, and promoting the responsible management of decommissioning waste and materials.
Moreover, stakeholders' engagement plays a major role in the offshore decommissioning services market. Stakeholder engagement is essential in the offshore decommissioning services market to address the concerns and interests of various stakeholders, including regulatory bodies, industry players, environmental groups, local communities, and investors, throughout the decommissioning process.
The Woodside-operated Shenzi field has undergone planned shutdown to approach integrity and reliability scopes
An unplanned outage also had to be addressed, after which a key well was brought to production in November 2024.
The Shenzi North project has been in production in the US Gulf of Mexico since September 2023. For optimised production, this two-well subsea tieback operates as an extension of the existing Shenzi infrastructure.
Situated approximately 195 km off the coast of Louisiana in the Green Canyon protraction area, the Shenzi assets comprise of the Caesar oil pipeline and the Cleopatra natural gas pipeline that form the main source of the several connecting pipelines that help the product reach onshore from the Green Canyon region. While the crude oil produced is consumed in Gulf Coast, the natural gas generated from the field is directed to the Cleopatra via a lateral pipeline that connects onshore to the Neptune processing plant in St Mary’s Parish, Louisiana.
Commenting on the project's notably short turnaround, Woodside CEO Meg O’Neill had said, "First production from Shenzi North shows how we are leveraging existing infrastructure to increase production and provide attractive returns from our Gulf of Mexico business.
"Taking the project from FID to first oil in 26 months is a great achievement. I commend the project team on safely bringing this resource into production well ahead of schedule.”
Enjoying a 72% interest, Woodside had discovered the Shenzi field in 2002, with first hydrocarbons production following in 2009. Besides Woodside, Repsol is a partner in the field with a 28% interest.
Gulf Coast customers benefit from more than 100,000 barrels of oil per day and 50 million standard cubic feet of gas per day that comes from the Shenzi field.
A well from the Mad Dog Argos that is part of the Mad Dog conventional oil and gas field situated 200km off the coast of Louisiana in the south-eastern Green Canyon protraction area, US Gulf of Mexico, has maintained production at the peak rate of ~130 kbbl/d, and is undergoing an infill injector well.
Argos is considered the driving force of the second phase of the Mad Dog project as it helped the brownfield site to reach a gross production capacity of up to 140,000 boepd. This semi-submersible platform has helped bp to boost production by atleast 20%. "Argos is key to our strategy of increasing our Gulf of Mexico production to around 400,000 barrels of oil equivalent per day by the middle of this decade,” said Ewan Drummond, Senior Vice President, Projects, Production and Operations.
An infill development well work has also began at Mad Dog A-Spar, besides a planned offshore facility shutdown.
A Spar is a subsea truss spar which processed Phase 1 of the Mad Dog project, with over 100,000 boepd transported to Ship Shoal 332B through the Caesar pipeline, followed by the Cameron Highway Oil Pipeline System, which further provides gateway to the US interior. More than 60 mn st cu/ft of gas, on the other hand, goes through the Cleopatra pipeline to finally reach the Nautilus Gas Transportation System into Louisiana.
While bp operates the Mad Dog field, Woodside holds a 23.9% interest in the project.
To know more about the global well intervention scene, click here.
Well services and engineering solutions provider Odfjell Technology has entered into a cooperation agreement with Australian-based R&D Solutions to expand its presence in the Asia Pacific region.
The agreement allows Odfjell Technology to utilise its well intervention services, wellbore clean up and whipstock tools to service the Australian well services and deepwater markets. The company also has future plans for growth in the regional plug and abandonment (P&A) sector.
Paul Toner, Vice President – Middle East & Asia Pacific at Odfjell Technology, said, “Expanding our reputation and relationships into Australia is a critical part of our global growth strategy. With strong localised operations already in place across Southeast Asia, we are confident our new cooperation agreement with R&D Solutions will enable the same excellent level of customer service and delivery for the Australian energy market.”
Doug Gillespie, Director and Managing Partner at R&D Solutions, commented, “R&D Solutions prides itself on the technology and service capabilities it has delivered to market over the years […] we feel Odfjell Technology compliments the spirit of our motto ‘Tomorrow’s Technology Today’, bringing the next level of excellence in quality service and technology to Australia.”
It was a widely successful 2024 for Petrobras as the Brazilian operator has reported it has achieved all of its production targets that were established in the 2024-2028+ Strategic Plan.
In total, oil and natural gas production reached 2.7 million barrels of oil equivalent (boed). Commercial oil and natural gas production reached 2.4 million boed and oil production was reported at 2.2 million barrels per day.
The operator set a new annual record for total own and operated production in the pre-salt, with 2.2 million boed and 3.2 million boed respectively, equating to 81% of the company’s total production.
Petrobras made significant headway in 2024, with one note-worthy project including the start-up of two new platforms: the FPSO Maria Quitéria, located in the Jubarte field in the Campos Basin; and the FPSO Marechal Duque de Caxias in the Mero field located in the Santos Basin pre-salt layer.
During the year, the FPSO Sepetiba platform, in the Mero field, reached its maximum oil production capacity after eight months of operation. The ramp-up of FPSO platforms partially offset the losses resulting from maintenance shutdowns and the decline in mature fields in addition to the impact on production due to unscheduled shutdowns determined by the ANP and the effects of the Ibama strike.
Another significant milestone of the year was the start of commercial operations of the Natural Gas Processing Unit (UPGN), located in the Boaventura Energy Complex, in November which has the capacity to process 10.5 million m3/day of gas through its first module.
The Australian government is seeking expert guidance to dismantle over 200 aging oil and gas structures set for decommissioning this year. The Department of Industry, Science, and Resources (DISR) has issued a call for technical specialists to oversee the process, ensuring compliance with environmental and regulatory standards.
With a wave of decommissioning ahead, Australia is preparing for large-scale offshore infrastructure removal. The Centre of Decommissioning Australia (CODA) projects significant activity between February and July 2025. The scope includes 41 platform wells, 34 subsea wells, 15 exploration wells, multiple production units, pipelines, and various subsea structures.
Strengthening regulations and industry oversight
The growing number of obsolete offshore installations has prompted a tightening of Australia’s regulatory framework. Amendments to the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGGS Act) have introduced stricter financial requirements, increased oversight on asset transfers, and implemented trailing liability measures—holding companies accountable long after operations cease.
CODA estimates decommissioning liabilities at approximately USD $40.5 billion, with well plug and abandonment (P&A) and pipeline removals making up the bulk of costs. In response, DISR has created a dedicated Decommissioning Branch, recruiting specialists to refine policies, assess risks, and align strategies with international best practices.
Positioning Australia as a decommissioning leader
Beyond environmental and financial safeguards, Australia sees an opportunity to build a competitive decommissioning industry. With an estimated $60 billion in offshore retirement costs over the next 30–50 years, the government is laying the groundwork for a domestic sector that could drive job creation, innovation, and expertise.
The National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) is leading efforts to uphold safety and environmental protocols throughout the process. By establishing best-in-class decommissioning capabilities, Australia aims to not only manage its offshore legacy but also export its expertise to global markets, transforming a costly challenge into an economic opportunity.
A recent report on Offshore Oil and Gas Decommissioning by the Australian Academy of Technology Sciences and Engineering highlights the surge in the development and deployment of advanced technologies tailored to the decommissioning process.
The oil and gas industry has embraced a sector-wide digital transformation, with the benefits of enhancing worker safety, reducing environmental impacts, driving efficiencies and cutting costs. This transformation has enabled a reduction in the number of workers on offshore facilities, for example, thanks to increasing remote operations and increased automation. There is likewise scope for the decommissioning sector to undergo a similar transformation.
However the report notes that, while digital technologies are a key enabler for more efficient decommissioning practices, they need to be accompanied by the further development of physical technologies to advance decommissioning processes.
One key area of technological advancement highlighted is the use of robotics and autonomous systems for subsea infrastructure removal and dismantling. These technologies enable precise and controlled operations in challenging offshore environments, such as the Gulf of Mexico, reducing the need for human intervention and minimising safety risks. Automated cutting systems use robotics and advanced machinery to perform precise cutting tasks during the removal phase of decommissioning, for example ROVs equipped with cutting devices can be used to cut pipes into sections, facilitating pipeline removal, and swarm robotics for collaborative subsea monitoring, involving the use of multiple small, autonomous robots for collaborative monitoring tasks, can enhance efficiency and coverage in subsea environments. The integration of AI and ML algorithms is enhancing the predictive maintenance of decommissioning equipment, facilitating process optimisation, and improving cost-effectiveness.
Rigless P&A processes are being explored globally due to potential cost efficiency gains, improved environmental compliance and enhanced safety outcomes, the report notes. This approach enables safe pressure testing, providing a comprehensive understanding of individual well conditions, leading to safer and more cost-effective P&A interventions. In addition, alternative barrier technologies such as thermite plug technology, resin plugs and bismuth alloy play an important role in ensuring the integrity of decommissioned wells as attentions shifts towards more cost-effective, efficient and environmentally compliant decommissioning solutions.
Another technological development highlighted is the application of advanced sensing and monitoring systems, which can assess environmental impacts and support risk assessment during decommissioning activities. This includes autonomous and remote systems equipped with state-of-the-art sensors, as well as satellite imagery. These technologies are also being used to provide real-time data on areas such as water quality, marine life and ecosystem health, helping operators to make informed decisions about decommissioning strategies and mitigating potential environmental risks.
Circular economy principles are increasingly driving innovation, the report notes, particularly in recycling and reusing decommissioned materials. Advanced material separation technologies and processing methods can be used to recover valuable resources from decommissioned equipment and structures, contributing to resource conservation, and reducing waste.
As part of its promise to boost the competitiveness of its upstream sector while pursuing a sustainable future, PETRONAS will continue to prioritise its decommissioning responsibilities, directing its focus to accessing unused assets for potential repurposing.
The Malaysia-based operator has released its 2025-2027 Activity Outlook report, where it highlights the call to decommission the Sabah-Sarawak Gas Pipeline alongside 37 offshore facilities. PETRONAS’ three-year plan also includes the plugging and abandonment of 153 wells within the region.
The report states, “PETRONAS continues to explore innovative decommissioning solutions focusing on technologies, reuse/repurpose options, integrated multi-year execution approach for economies of scale, as well as identifying potential alternatives that can introduce cost compression. Thus, participation and collaboration are encouraging from all parties.”
PETRONAS’ report noted the importance of decommissioning matured assets in Malaysia’s upstream oil and gas industry as it is “essential to restore the area to a safe and environmentally stable condition.”
With that initiative at the forefront, in December 2024 the operator collaborated with the Department of Fisheries to launch the 10-year Malaysia Master Reefing Plan which outlines the potential for reefing in the region by spotlighting suitable candidates and locations to undergo the ‘rigs-to-reef’ operation: an initiative which stands as a popular decommissioning alternative in the Gulf of Mexico.
Alongside decommissioning, PETRONAS shares its outlook regarding upstream operations. In the short-term, the operator will focus on intensifying exploration activities and expediting appraisal programmes to sustain production and contribute towards Malaysia’s energy security. In the medium- to long-term, PETRONAS will continue to meet production targets and maximise shareholder value while decarbonising the value chain through innovation, technical deployment, and close collaboration with industry partners.
To read the full 2025-2027 Activity Outlook, click here.
Woodside Energy has released an update of the company's decommissioning activities for the fourth quarter of 2024.
The removal of the Griffin Riser Turret Mooring (RTM) has been a highlight for the company as it marked the removal of nearly 25000 tonnes of infrastructure that included over 200 kms of pipe and 100 subsea structures that covered the Enfield, Echo Yodel, Stybarrow and Griffin fields. RTM removal besides, 20 wells have also been permanently plugged.
The RTM was recovered without significant obstacles to be transported to the Australian Marine Complex at Henderson, Western Australia, where its components will be cleaned and disassembled for recycling or reuse.
The Griffin field that is situated off 65 km north west of Onslow and 94 km north east of Exmouth had served in its lifetime Western Australia’s power needs with not only 62 billion cubic feet of gas, but also 167 million barrels of oil.
Above: Australia is preparing for a wave of decommissioning activity this year. (Image source: Adobe Stock)
Woodside's decommissioning campaigns at Stybarrow included the plugging and abandoning of three wells, removal of several moorings, structures, and wellheads that covered multiple fields offshore Western Australia. Last year, the company plugged and abandoned seven of 10 Stybarrow wells, recovered more than 90 subsea structures including wellheads, Xmas trees
and manifolds, and recovered 149 km of pipe.
Woodside's decommissioning work in Stybarrow was supported by McDermott under an engineering, procurement and removal contract.
“This award not only demonstrates McDermott’s proven track record in undertaking deepwater projects of diverse scopes, but it also highlights the critical importance of decommissioning in the offshore industry.
“With our seamless integration of engineering, fabrication, and offshore mobilisation expertise, we believe we are well-equipped to execute this project efficiently and responsibly, ensuring the safe recovery and removal of the Stybarrow DTM buoy,” said Mahesh Swaminathan, Senior Vice President, Subsea and Floating Facilities, McDermott.
The contract enables McDermott to fully remove the Stybarrow disconnectable turret mooring (DTM) buoy, and provide project management and engineering services for the recovery, transportation and offloading of the DTM buoy to an onshore yard for dismantling and disposal.
The Bass Strait decommissioning work continues as well, with plug and abandonment completed on the Perch and Dolphin facilities. Steel gravity based monotowers, the Perch and Dolphin facilities saw the deployment of DOF multi-purpose support vessel (MPSV) Skandi Darwin.
The MPSV's floating support asset can accomodate the whole workforce, eliminating crew transportaion costs. It also allows to complete abandonment operations on non-producing facilities which do not have accommodation based on them.
Speaking of the MSVP, Marine Field Superintendent, Matt Barney said, “We’re excited to start utilising the MPSV to expand our capabilities and adopt new technology to identify efficiencies, while ensuring the work can be completed safely.”
Allseas is also part of the Bass Strait decommissioning campaign, whereby the company will be dismantling up to 12 retired platforms from the region. “This landmark decommissioning project represents a significant milestone for Allseas in Australia,” said Evert van Herel, General Manager of Allseas Australia.
To know more about Australia's decommissioning scene, click here.
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