Woodside has issued an update on the Minerva field decommissioning, with a focus on the removal of a pipeline from Commonwealth waters.
The company outlined anticipated timelines in a May 2026 Environmental Plan (EP) consultation sheet, with work on the horizon in the latter part of next year.
“Woodside Energy is planning to recommence subsea decommissioning activities for the Minerva field (previously operated by BHP Petroleum (Victoria) Pty Ltd),” the statement noted.
Work includes the removal of the Minerva pipeline bundle and stabilisation mattresses.
The field is located approximately 11 km south southwest of Port Campbell, Victoria, with infrastructure reaching across state and Commonwealth waters, in depths of approximately 15 – 60 metres.
“The proposed activity is planned to be undertaken, following acceptance of the EPs, between September 2027 and end of April 2028, outside the peak whale season,” the statement noted.
The duration of the proposed activity is expected to be 30–45 days in State and Commonwealth waters, respectively, for a total of 90 days subject to factors including regulatory approvals, vessel availability, weather, operational requirements and other circumstances.”
The works are planned to be completed no later than 30 April 2028, it added.
Woodside is the operator of Minerva field, and works alongside its joint venture partner, Amplitude Energy.
During 2025, wells were plugged and abandoned, and associated well infrastructure was removed in accordance with the accepted Minerva Plug and Abandonment (P&A) EP.
As well as timelines, the new EP consultation sheet also provides an overview of various activities, potential environmental impacts and risks, and the measures proposed to manage them ahead of the next phase of work.
The Minerva field ceased production in September 2019.Following cessation of production, the wells were suspended and the subsea system was preserved for decommissioning.
A vessel-based campaign was then conducted in 2021 to disconnect flowlines from wells and install barrier plugs.
To date, a total of around 1,671 tonnes of infrastructure have been removed from the Minerva Field, according to Woodside, with a recycling target of over 90% by weight.
The offshore energy sector faces a pivotal moment as ageing infrastructure and supply chain constraints collide with a massive backlog of projects.
At the Decommissioning and Abandonment Gulf of America (D&A GOA) 2026 conference held on 20 and 21 April, industry leaders addressed an urgent need to change the status quo through collaboration and conversation.
The scale of the challenge in the Gulf of America is staggering. Currently, more than 2,700 wells and 500 platforms are overdue for decommissioning. A primary concern is the rise of 'boomerang assets': infrastructure returned to predecessor operators in severely degraded conditions, often lacking reliable documentation or clear well status. One operator described receiving a platform nicknamed the 'widow maker', which featured spongy decks, missing handrails, and an inoperable crane and helideck. As decades' worth of deprioritised, underfunded infrastructure compounds, these dangerous boomerangs are becoming the rule rather than the exception.
Compounding the physical decay is a shrinking execution window caused by structural supply chain decline.
Industry experts argued that the sustainable path forward requires moving away from transactional contracting towards long-term operator-contractor partnerships. AI is no longer merely a talking point. Other innovations highlighted include:
Promethean, a co-chair of the event, emphasised that the quality of planning directly determines execution quality. Their model relies on lump sum commitments rather than time-and-materials arrangements to drive cost efficiency. A case study presented by SVP of Commercial, Steve Louis, detailed a high-risk project: an orphaned well on a platform listing at 12 degrees with a confirmed gas leak. Following five intensive days of engineering and risk assessment and seven days of offshore work, the asset was permanently abandoned under budget with zero significant downtime.
As D&A GOA 2026 concluded, the consensus was clear: the industry must embrace supermajor-level discipline and new technology to turn these liabilities into opportunities.
Downhole Tools International (DTI), a supplier of coil tubing, wireline, slickline and cable-deployed tools, has adopted the name Pragma as it redirects its strategic focus toward the development and commercialisation of advanced well barrier technologies
Backed by recent investment from FrontRow Energy Technology Group and BGF (Business Growth Fund), the company is reshaping its business around a three-tier well barrier portfolio. At the centre of this strategy is its flagship M-Bubble metal expandable barrier technology, while the company continues to provide customers with its broader range of downhole tools.
The rebranding represents a return to the company’s original name and reflects a renewed commitment to its innovation-driven heritage. Pragma will continue developing technologies designed to address complex well integrity, water management, and plug and abandonment challenges across the global energy industry.
To support this direction, the company has made significant investments in its workforce, technology development pipeline and international presence, strengthening its position for sustained future growth.
The appointment of David Stephenson as CEO in late 2025 was followed by the establishment of an enhanced management and international business development team. The team brings extensive experience in global well intervention and well barrier development, covering design, operations and commercialisation.
Alongside the redesign and relaunch of its PKB and IX plug technologies under the Pragma brand, the company will maintain M-Bubble as a key component of its growth plans. Efforts will continue to focus on commercial deployment and wider international adoption, particularly in the Middle East and Asia Pacific markets.
David Stephenson comments: “Rebranding as Pragma is about more than a change of name - it’s about reaffirming our focus on well barrier technology and the innovative approach upon which the business was founded.
“With the support of FrontRow and BGF, we’re in a strong position to grow M-Bubble whilst developing well technologies from concept through to commercial deployment, as we help operators tackle increasingly complex well integrity and water management issues.”
The deep waters off the coast of Egypt are witnessing a quiet revolution in subsea engineering, as heavy, corrosive steel makes way for lighter, more sustainable composite technologies.
For the first time in the region, advanced thermoplastic composite pipe (TCP) technology is being deployed to modernise offshore infrastructure. Leading TCP manufacturer Strohm has secured a landmark contract to supply a 2,000-meter flowline for one of the West Delta Deep Marine (WDDM) projects. Operated by the Burullus Gas Company, a joint venture uniting EGAS, Shell, and Petronas— this project signals a significant shift in deep-sea energy logistics.
The new flowline, engineered with carbon fibre and PA12 polymer, is designed to withstand extreme subsea conditions with a pressure rating of 5,000psi and is qualified to the DNV-ST-F119 standard. Resting at depths of nearly 600 meters, this state-of-the-art system is actively replacing an existing steel flowline. The TCP technology offers a striking environmental and logistical edge over its predecessor: it is inherently strong, non-corrosive, spoolable, and lightweight. Crucially, the material is 100% recyclable and drastically reduces the carbon footprint of subsea operations by allowing installation from small vessels or subsea pallets rather than energy-intensive specialised installation ships.
The installation itself, managed by Oceaneering International, will employ a cost-effective 'horizontal lay' method utilising a multi-purpose vessel to maximise efficiency. Norman Lentsch, Strohm's Business Development Manager for Africa, recognises the strategic importance of this regional debut. “This contract marks an important milestone for us as we enter the Egyptian market for the first time. We are proud to work with Oceaneering International and Burullus Gas Company as we support the region's growing energy infrastructure needs with our high-quality flowline solutions,” he said.
He further emphasised the industry's growing trust in this innovative material, saying, “Our entry into the local market underscores the confidence operators have in our TCP products, our extensive track record and our ability to deliver consistent quality and performance. We look forward to demonstrating Strohm's commitment to safety and excellence.”
The partnership with Oceaneering brings critical installation expertise to the table, further optimising the project's bottom line. Chris Dyer, Senior Vice President at Oceaneering's Offshore Project Group, detailed how their existing capabilities create seamless project execution. Dyer said, “At Oceaneering, we have extensive experience installing flexible products, including TCP. By leveraging our umbilical product installation capabilities to support TCP installations, we can maximise our assets globally and streamline project execution, providing tangible benefits to the end user in overall project cost and schedule."
By moving away from traditional steel toward next-generation composite pipes, this Egyptian deployment acts as a blueprint for the future of offshore energy, where flexibility, carbon reduction, and cost efficiency guide deep-water development.
Leading international jackup drilling contractor Borr Drilling remains upbeat on more Middle East work despite current issues facing the region.
In the company’s Q1 2026 results, Bruno Morand, CEO, painted a positive picture overall with revenues reaching US$247mn and strong operational performance with technical utilisation of 99.4%.
As well as updates from other regions, such as the USA and Mexico, Morand outlined his thoughts on the state of play in the Middle East and its potential impact for work around the world.
“While the Middle East conflict has created near-term uncertainty, key tenders in the region continue to progress, with some modest delays,” he noted.
“More broadly, in our view, recent events have strengthened the longer-term outlook for the sector providing for a higher oil price and a renewed focus on energy security.”
He added that shallow-water basins “continue to represent an attractive resource, offering low-cost, short-cycle barrels that enable our customers to respond rapidly to the market backdrop.”
Due to the planning and budgeting processes of its customers, the company expects that improved activity and day rates will lag the oil price development by 6 to 12 months, as evidenced after the military invasion of Ukraine, when day rates strongly increased.
As such, Morand said the company is “increasingly confident” about its prospects for 2027 and 2028, adding that he expects the disruptions from the conflict in the Middle East to be both substantial and long lasting.
Reflecting this confidence, Borr Drilling completed the acquisition of five jack-up rigs from Noble Corporation in January 2026 for US$360mn and entered into agreements to acquire five further jack-up rigs via a new joint venture for a further US$287mn.
“With this backdrop, Borr Drilling's expanded fleet is well placed to support our customers’ demand and deliver long-term shareholder value as the cycle develops.”
Baker Hughes has announced two major contract extensions with Equinor to deliver integrated drilling and well services solutions, along with wireline intervention services.
The multi-year agreements will support Equinor’s offshore hydrocarbon production activities in the North Sea.
As part of the integrated drilling and well services contract, Baker Hughes will provide a comprehensive range of solutions for both mature assets and new developments. The company will draw on expertise from its Well Construction and Completions, Intervention and Measurement portfolios to support projects across the Norwegian continental shelf. Technologies including the Kantori autonomous well construction solution and TRU-ARMS advanced reservoir mapping services will be utilised to help develop offshore resources more efficiently.
Under the intervention services agreement, Baker Hughes will supply fully integrated well intervention solutions, combining its surface and downhole technologies with complementary systems provided by service partners. The objective is to enhance the lifespan and performance of offshore wells operating in the North Sea. The extended contract also broadens the deployment of Baker Hughes’ technology portfolio built around the PRIME Technology Platform, supporting both production optimisation and emissions reduction initiatives across the Norwegian Continental Shelf.
“Baker Hughes’ ability to provide holistic solutions that unlock incremental value for our customers has been proven through decades of operation in the North Sea,” said Baker Hughes Executive Vice President of Oilfield Services & Equipment Amerino Gatti. “From greenfield well construction operations to interventions that extend the life of mature fields, our innovative technologies and ability to integrate our services can help create a more secure energy future for Norway and all of Europe. We look forward to being part of this new chapter of collaboration with Equinor.”
Baker Hughes has maintained a longstanding presence in Norway’s energy industry, employing thousands of people and operating multiple facilities across the country. Earlier this year, the company inaugurated its new Subsea Services Center of Excellence and manufacturing facility in Dusavik. It also operates a dedicated Center of Excellence for Plug & Abandonment in Stavanger.
Energy and marine consultancy ABL has been commissioned by Esso Australia Resources Pty Ltd (Esso) to provide marine warranty survey (MWS) services to support the safe and efficient delivery of the first phase of the Gippsland Decommissioning Campaign, Australia’s largest offshore decommissioning project.
Esso is the operator of the assets in the Bass Strait that are part of the Gippsland Basin Joint Venture. These comprise around 400 wells, six subsea facilities and more than 800 kilometres of subsea pipelines, and 19 platforms.
Esso is now undertaking the first Bass Strait decommissioning campaign, which is set to play a big role in Australia’s decommissioning and circular economy ambitions, given it involves the removal of around 60,000 tonnes of offshore structures and a target to recycle over 95% of materials.
Preparations for the campaign are well advanced, with the offshore lifting campaign to remove up to 12 platforms scheduled to commence in 2027 using Allseas’ Pioneering Spirit. In preparation, ABL is conducting suitability surveys to validate the proposed marine spread, and technical review and approval of decommissioning documentation. Its scope of work will include on-site attendance at all warranted offshore operations to ensure activities are executed safely and in line with approved procedures.
“This is a landmark project for Australia’s offshore industry, involving highly complex marine operations, including offshore lifting, transportation and discharge of substantial tonnage of assets that are up to half a century old,” said Adam Solomons, East Coast manager at ABL Australia. “Our extensive track record and multi-disciplined expertise that we offer in decommissioning, alongside our deep experience in offshore Australia – makes ABL well positioned to support Esso in reducing risk and optimizing their operations.”
ABL, which is part of the Oslo-listed ABL Group and whose Australian operation is headquartered in Perth, will draw on more than four decades of decommissioning experience, offering services from feasibility and owner’s engineering through to marine consultancy and MWS.
Petralon Energy is an African exploration and production company with proven capacity to acquire, develop, finance, and operate oil and gas assets.
Operating through its subsidiary Petralon 54, the company holds a 100% working interest in the Dawes Island Field in the Eastern Niger Delta.
In just under six months, Petralon 54 has revamped its production capacity significantly through its recently established DI-3 well. Operations began on 14 March 2026 and has since delivered average additional daily production of approximately 2,800 barrels of oil per day (bopd), bringing the field's combined production capacity to approximately 4,800 bopd.
DI-2 has been onstream since October 2025 and DI-3 builds directly on the performance of its predecessor. Together, the two wells have sustained back-to-back drilling programme on a field that was non-producing at the time of Petralon's acquisition in 2021. Till date, the company has exported over 350,000 barrels of oil from the field via the Bonny Oil and Gas Terminal, which is located around 30km from the field. The DI-3 well became operational with zero lost-time incidents and it reflects the company's commitment to world-class health, safety, and environmental standards across its operations.
Dawes Island is located approximately 15km from Port Harcourt in the Eastern Niger Delta. The island covers roughly 46 sq km and holds an estimated 17.6 mn barrels of recoverable oil. “Our success at Dawes Island was built on the conviction that Nigerians could acquire, develop, and operate world-class energy assets. That conviction once required courage, today, it stands on proof. The easy thing after DI-2 would have been to pause, but the determination and resilience of every single member of the Petralon team drove us forward, and DI-3 is the result of that effort. Progress like this is only possible through the strong collaboration we have built with our host communities, our regulator, and our partners. This is only the beginning of what Dawes Island can deliver," said Ahonsi Unuigbe, founder and chief executive officer of Petralon Energy.
Through the commencement of DI-3 production, Petralon Energy validates another major step in the phased development of Dawes Island. The company stays focused on growing production, strengthening its position as a leading indigenous operator in Nigeria's upstream sector, and advancing its longer-term ambition for the field.
Well-Safe Solutions has been awarded a new contract to provide full Well Operatorship and asset execution for an unnamed client in the North Sea.
The contract scope will see the company undertake operations management of the well decommissioning, including initial subsurface analysis and well design engineering, followed by rig, service, and support vessel provision.
This marks the first Well Operatorship awarded to the company, providing a pivotal step for Well-Safe Solutions’ expanding service offerings across the well lifecycle.
The logical step forward enables more efficient well management through fully integrated package offerings – with owned assets, engineering and services under a single contract.
Phil Milton, CEO of West-Safe Solutions, said, “It has always been our plan to position the business to be able to fulfil the role of Well Operator for our customers and we are grateful for the opportunity to do so under this new contract. This contract, and the Well Operator appointment, recognises our credentials as a cost and schedule3 efficient partners with an outstanding safety record. With our market-leading assets, technical expertise and project management capabilities, we are ideally positioned to provide full Well Operatorship responsibility in the North Sea.”
This contract award represents the fourth major contract win for Well-Safe Solutions this year, following three previous North Sea decommissioning projects.
Archer has agreed to acquire well technology specialist isol8 through a share purchase agreement, strengthening its capabilities in plugging and abandonment (P&A) and expanding its portfolio of well barrier technologies.
The acquisition will add isol8’s expertise in alloy-based barrier systems and advanced materials to Archer’s existing offering. The technologies are designed for application across well completions, intervention activities and P&A operations, supporting the company's ambition to further develop its plug business and enhance its position in the global well abandonment market.
By incorporating isol8’s products and technical expertise, Archer aims to broaden the range of solutions available to customers undertaking well lifecycle management projects, particularly in subsea and rigless abandonment operations.
Archer CEO Dag Skindlo commented: “This acquisition brings valuable technologies and talent into Archer. Isol8’s solutions will strengthen and expand our leading plug portfolio and advance our subsea and rigless P&A offering. The acquisition reinforces our ability to deliver safe, efficient, and scalable well abandonment solutions to our global customers.”
Founded by Andrew Louden, isol8 has developed a range of proprietary barrier technologies designed to improve well integrity and support safe, long-term isolation throughout the well lifecycle. The company’s solutions are used in applications ranging from completions and interventions to final abandonment.
Andrew Louden, Founder and CEO of isol8, commented: “Archer’s global reach and established customer base create a strong platform to scale deployment of isol8’s technologies across the entire well lifecycle. Together, we have the opportunity to expand adoption of our existing alloy barrier products and accelerate the commercialisation of our emerging metal element technology.”
Weatherford International has received a deepwater integrated completions contract by ExxonMobil affiliate Esso Exploration & Production Nigeria Ltd offshore Nigeria.
Selected for its well construction and completions portfolio, the contract secures Weatherford's integrated upper and lower completions services for deepwater wells. It also comes with a scope for supporting safety, reliability, well integrity, and operational efficiency over the lifecycle of the well.
The integrated completions equipment will be configured and prepared through Weatherford’s global supply chain and supported locally in Nigeria, in line with contract terms, to enable in-country execution and service delivery.
Girish Saligram, Weatherford’s president and chief executive officer, said, "This contract reflects our ability to deliver integrated completions solutions for deepwater operations. We will provide technologies designed to support well integrity, reliability, and efficient execution in complex offshore environments.”
Nigerian deepwater development sees consistent advancement, with Eni being one of the several oil majors investing in the region. The company's chief executive officer, Claudio Descalzi, recently met Nigeria's President, Bola Ahmed Tinubu, to discuss Eni’s significant investment portfolio — including the Abo and Bonga fields and Nigeria LNG — as well as on potential new developments designed to expand the country’s offshore production capacity. Within this framework, and in line with its long-term strategy in the country, Eni has recently expanded its interests in deep-water developments, with the acquisition of an additional stake in OML 118, now holding 15%.
Saipem and Petrobras have signed an agreement to initiate a technical dialogue aimed at assessing and potentially developing integrated solutions for decommissioning activities in Brazil, relating to oil and gas fields, subsea systems and associated infrastructure.
The one-year agreement focuses on plug and abandonment activities as well as subsea decommissioning, and defines a framework for technical and operational collaboration between the two companies, with the aim of improving the efficiency, sustainability and level of innovation of end of life infrastructure activities.
Under the agreement, Saipem and Petrobras will collaborate in the assessment of potential partnerships with specialised companies and institutions for decommissioning activities, as well as in the development and implementation of new technologies, methodologies and integrated solutions for this specific type of activity.
The cooperation will also include the evaluation of logistical and operational alternatives, such as the use of drilling units and vessels, as well as the enhancement of existing practices to address the main technical and operational challenges related to decommissioning activities.
Brazil is one of the world’s largest decommissioning markets. Since 2013, Petrobras has decommissioned the fixed Cação platforms (PCA-1, PCA-2 and PCA-3), in the Espírito Santo Basin, its own floating platforms P-7, P-12, P-15, P-27, P-34, in the Campos Basin, in addition to the chartered floating platforms FPSO Piranema Spirit, in the Sergipe Alagoas Basin, FPSO Brasil, FPSO Marlim Sul, FPSO Rio de Janeiro, FPSO Rio das Ostras, in the Campos Basin and FPSO Cidade de São Vicente, in the Santos Basin. 23 platforms and 2,000km flexible lines are set to be decommissioned by 2028, with a further 40 platforms after 2028.
Petrobras stresses the opportunities arising from decommissioning, and the potential to develop a new production chain, generating employment, income and value for society. It also emphasises the sustainable decommissioning model, with a circular economy approach and respect for the environment and local populations, as well as its focus on R&D into new decommissioning technologies and approaches.
Saipem meanwhkle has completed over 30 major decommissioning projects in various countries in the world since 1995. Its integrated engineering capabilities, logistics expertise and strong partnerships have enabled the company to successfully complete projects of any size in a wide variety of contexts.
