As offshore operators are increasingly looking for standardised technology that can enhance performance through project predictability and schedule certainties, big energy services providers like TechnipFMC have them covered.
Adding to its growing subsea momentum, TechnipFMC has signed a memorandum of understanding (MoU) with bp subsidiary to supply 20,000 psi (20K) subsea tree systems for bp’s Paleogene projects in the Gulf of Mexico.
This comes as part of collaboration initiatives to identify areas of cooperation and exploring opportunities for future technology development, which will secure smoother turnaround times.
Doug Pferdehirt, chair and CEO at TechnipFMC, said, “The MoU reflects our commitment to advancing the deployment of standardised 20K solutions. By combining proven technologies with repeatable and systematic project delivery, TechnipFMC can help improve predictability and performance across future developments.”
Earlier, the energy services provider was appointed offshore Angola by another bp venture called Azule Energy to supply flexible flowlines and risers for the Greater PAJ development.
The flowline and risers network will be manufactured and designed to connect wells in water depths approaching 2,000 meters to a new floating production unit.
Jonathan Landes, President, Subsea at TechnipFMC, said, “This award builds on expertise we have developed on large, deepwater projects in the region, including our proven flexible pipe technology. We are proud to be chosen to deliver a technically robust solution on an accelerated timeframe that creates value for our client.”
Perenco has announced the successful decommissioning of both the Leman South (53/02a-15Y) and the Durango (48/21a-4z) subsea assets in the Southern North Sea (SNS).
This was done within a single campaign framework that resulted in the plugging and abandonment of the wells, and the removal of the associated subsea infrastructure.
Specialist in integrated solutions for decommissioning and member of the Dixstone group, Petrodec, collaborated with Perenco to complete the work. The highly complex operations were conducted safely and on time using Petrodec’s HAEVA jack up vessel.
The campaign built on recent experience gained from the Gawain, Arthur and Davy subsea abandonment projects, which were also completed using the HAEVA.
Jo White, Perenco UK SNS Managing Director, said, “The Leman South and Durango campaigns were not routine P&A projects. They demonstrated Perenco’s ability to deliver repeatable, large-scale, technically complex subsea well abandonment and infrastructure recovery using an innovative single campaign approach centred on Petrodec’s HAEVA, rather than relying exclusively on high-cost drilling rigs and standalone offshore projects.
“I would like to thank our partners and the Perenco team who were involved in delivering some of the most technically demanding subsea well abandonment activities undertaken in the SNS.”
Australia’s Department of Industry, Science and Resources has launched a competitive procurement process to find an Australian lead contractor to manage waste materials as part of Phase 3b of the Northern Endeavour decommissioning programme.
The Northern Endeavour was a 274 m long floating production, storage and offloading (FPSO) facility which has now been disconnected and removed. It was permanently moored between the Laminaria and Corallina oil fields, around 550 km northwest of Darwin in the Timor Sea. Originally developed and operated by a joint venture compromising Woodside, BHP and Shell, it was acquired and operated by Northern Oil & Gas Australia in 2016, which went into liquidation in 2019.
The Australia Federal Government was then forced to step in and take ownership of the FPSO, announcing plans for its decommissioning, disconnection and disposal and the remediation of the Laminaria-Corallina oilfields.
The decommissioning of the 43,000 tonne FPSO is being managed by the Australian government and carried out in three phases. Phase 1 of the program is operationally complete and recycling of the FPSO is now underway following its safe delivery to the recycling facility in Denmark.
Phase 2 of the programme is in progress. This phase focuses on design and planning to permanently plug and abandon the nine wells in the Laminaria and Corallina oil fields. DISR engaged Zenith Energy Australia Pty as the lead contractor and is now working with them, to plan and design the work to plug and abandon the nine wells.
The third and final phase will focus on removing the remaining subsea infrastructure, recycling and waste management, including over 12,000 tonnes of steel, managing the subsea infrastructure after removal, including decontamination, recycling and disposal, and restoring the marine environment.
In August, DISR released a request for tender for a lead contractor to deliver Phase 3a of the programme, which involves recovery, transport and offloading of subsea infrastructure from the Laminaria and Corallina oil fields to a nominated Australian port. Submissions close 23 October 2026.
Phase 3b of the Northern Endeavour decommissioning program involves managing, recycling and disposing of materials from the Laminaria and Corallina oil fields.
DISR has used the Defence Scrapping and Disposal of Defence Material Panel to request quotes from potential lead contractors to deliver this work. The panel includes pre-qualified Australian companies who joined through an open tender process and have expertise in scrapping and disposing of government assets.
DISR claims that using the panel for this procurement will support the domestic decommissioning industry and jobs by:
It will also help ensure an efficient process and value for money.
The decommissioning of the Northern Endeavour is funded by The Offshore Petroleum Laminaria and Corallina Decommissioning Cost Recovery Levy (OP Levy), which is being charged from June 2021 to June 2029 on oil and gas producers. Decommissioning activity in Australia is being spurred by increasingly stringent regulatory pressures and requirements in a bid to avoid any repetition of the Northern Endeavour debacle.
Australia’s offshore regulator, the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), has released a fact sheet outlining the roles and responsibilities of the country’s various regulatory agencies and clarifying the distinctions between their functions.
The document — entitled ‘Safety on offshore vessels and structures: Who is the regulator?’ — also references offshore decommissioning activities.
In Commonwealth waters – generally beyond the three nautical mile coastal waters boundary – safety requirements for offshore vessels and structures are usually overseen by either NOPSEMA or the Australian Maritime Safety Authority (AMSA).
State and territory regulators are generally responsible for activities in coastal waters.
NOPSEMA regulates health and safety, well integrity, and environmental management, for petroleum and greenhouse gas storage activities in Commonwealth waters.
It also regulates these things in coastal waters where a state or territory has conferred regulatory powers— this currently includes Victoria’s coastal waters.
Crucially, NOPSEMA’s regulation of safety focuses on ‘facilities’.
It defines a facility as “any vessel or structure whether floating or fixed, and regardless of its ability to navigate independently – that is being used, or is being prepared for use, for the recovery, processing, storage or offloading of petroleum.”
This includes vessels engaged in drilling, well servicing, pipeline construction, erection, dismantling or decommissioning, or other petroleum-related activities in regulated waters, as well as accommodation for people working on another facility.
AMSA broadly regulates vessel and seafarer safety, and protection of the environment from vessel-sourced pollution.In the document, a number of case studies are presented to help workers identify the appropriate safety regulator.
In one example, a supply vessel leaves Dampier Port, on the northwest coast of Western Australia in the Pilbara Region, to bring divers and equipment to support decommissioning work on a fixed platform in Commonwealth waters.
The vessel is regulated by AMSA while it is enroute to the title area.
However, NOPSEMA becomes the regulator for the vessel when it arrives at the title area and starts preparations for diving work associated with the facility.
“Supply vessels performing other work, and tugs and anchor handlers, are generally not facilities, unless they are being used, or being prepared for use, for the recovery, processing, storage or offloading of petroleum,” the document notes.
NOPSEMA says the document, including the fact sheet and case studies, is for illustrative and general guidance only to help workers understand typical regulatory boundaries.
This industry case study from Expro highlights how its ReLine HYD expandable casing system helped Ithaca restore well integrity on the Captain platform offshore UK, enabling sidetrack drilling while reducing operational complexity and rig time.
Expro addresses casing integrity challenges on Ithaca’s Captain Platform
Expro has detailed a casing repair operation carried out for Ithaca on the Captain platform offshore UK, where corrosion in a 13⅜-inch casing section caused a leak and raised well integrity concerns.
The damage threatened the planned drilling programme. A conventional repair approach would have required cutting and retrieving the compromised casing, drilling a new 17½-inch hole section, and running and cementing replacement 13⅜-inch casing. This would have added operational complexity, rig time and cost.
According to Expro, the operator required a permanent repair solution capable of restoring casing integrity across an extended corroded interval while minimising operational risk and disruption.
ReLine HYD system used for expandable casing repair
Following an assessment of the available well data, Expro developed a tailored repair programme using its ReLine HYD expandable casing system. The solution involved installing a 500-foot expandable casing patch to clad the damaged section and provide a long-term integrity barrier.
The operation also included pressure testing the 13⅜-inch casing sections that would remain uncovered by the patch, following the cutting and retrieval of the 9⅝-inch casing. Expro used the AEON RTP and an abandonment valve as part of the integrity verification process.
The casing patch was deployed using Expro’s tubular running services (TRS), with the installation completed in a single run. Subsequent pressure testing confirmed that casing integrity had been restored.
Expro also highlighted collaboration across its product lines as a key factor in coordinating the operation and reducing execution risks.
Casing repair enables Ithaca to progress sidetrack operations
The repair eliminated the leak and restored wellbore integrity, allowing Ithaca to proceed with its planned activities. These included setting a cement plug below the repaired interval and advancing sidetrack drilling.
The intervention helped the operator avoid the extended delays and additional expenditure associated with a more extensive casing replacement programme. It also preserved the opportunity to develop the well further.
Without the repair, Ithaca could have faced prolonged operational disruption and the potential loss of the planned sidetrack opportunity.
Expandable casing technology supports offshore well integrity
The project illustrates the application of expandable casing technology to address corrosion-related well integrity challenges in an offshore environment.
As described in Expro’s case study, the intervention combined a targeted casing repair with integrated service delivery to restore well integrity and enable further drilling operations. The outcome highlights how specialist well intervention technologies can help operators manage casing damage, limit operational disruption and preserve future well value.
VAALCO Energy has completed its Phase 3 offshore drilling programme in Gabon, bringing the ETSEM-3H development well into production and demobilising the Borr Norve drilling rig from the SE Etame platform.
The company has also commenced drilling activities under the Baobab Phase 5 campaign offshore Côte d’Ivoire
At the SE Etame field in Gabon, the ETSEM-3H well was drilled and completed in an attic location, targeting 300 metres of net pay in high-quality Gamba reservoir sands along its lateral wellbore. The well achieved a stabilised initial production rate of approximately 2,000 gross barrels of oil per day (BOPD), equivalent to 1,140 BOPD net to VAALCO.
With ETSEM-3H completed, the Phase 3 drilling programme has concluded, and the Borr Norve rig has been removed from the field.
Offshore Côte d’Ivoire, work has begun on the Baobab Phase 5 drilling programme, with the operator batch-setting the top-hole sections of the planned wells. Once the top-hole sections have been drilled across the programme, the wells will be completed and brought into production sequentially.
The campaign comprises four production wells, three water-injection wells and two workovers. VAALCO expects the first new producer to come online towards the end of 2026, with the programme anticipated to support significant production growth in 2027.
George Maxwell, VAALCO’s Chief Executive Officer, commented, “We are pleased with the results of the ETSEM-3H development well, which was landed in an attic location within the SE Etame field, and is now on production at about 2,000 gross BOPD (1,140 BOPD net to Vaalco). This represents the final well in our successful Phase 3 drilling campaign, and the drilling rig has now been demobilized from the field. In Côte d’Ivoire, following the successful re-start of the Baobab field during the second quarter, we have now commenced the Phase 5 drilling campaign with batch-setting the top-hole sections of the new wells. The current plan for the Phase 5 drilling campaign consists of four producers, three water injectors and two workovers. We expect to have the first new producer online near the end of the year, with meaningful production increases expected in 2027. Our continued success and organic project pipeline support Vaalco’s strategic focus on growing production, reserves and value for our shareholders.”
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.
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