Work to decommission the Northern Endeavour in the Timor Sea is moving to the next phase after the floating production storage and offtake (FPSO) vessel was disconnected from the Corallina and Laminaria oilfields recently.
Australia’s Department for Industry, Science and Resources reported that the decommissioning programme had accomplished what it called a “significant milestone” following the disconnection of risers and umbilical pipelines that had connected the vessel to the oilfields for 26 years, a step that “reduces risk to people and the environment.”
The process has not been without its challenges though after the FPSO reportedly lost power, resulting in the evacuation of crew as a safety precaution, according to a number of media outlets.
It is understood that power has now been restored to the ex-Woodside vessel, which is located some 550 km northwest of Darwin.
Phase 1 contractor Petrofac Facilities Management Limited and multi-purpose vessel, Skandi Hercules, cut eight risers and lowered them to the seabed.
“Removing the connection between the FPSO and the wells means there’s no risk of oil leaking from the FPSO,” the Department noted.
“The disconnection marks an important point in the FPSO’s history since its initial connection to the subsea wells in 1999.”
Nine mooring chains keep the FPSO connected to the seabed, holding it securely in place.
Cutting the chains will be one of the final milestones before removal of the FPSO from the field, an operation scheduled for later in 2025.
The COSCO semi-submersible heavy transport vessel, Hua Rui Long — the third largest of its kind in the world — will eventually tow the FPSO to a facility for decontamination, dismantling and recycling.
Dry towing is deemed the safest and most reliable method to transport a vessel of this size and condition, according to the Department.
The Northern Endeavour FPSO is 274m in length and weighs over 43,000t.
Officials are still going through tenders to find a supplier to ultimately recycle the FPSO.
Odfjell Drilling Ltd has announced the successful completion of the Special Periodic Survey (SPS) for the Deepsea Aberdeen, which has now resumed operations following three weeks of scheduled downtime.
The Deepsea Aberdeen is a sixth-generation, semi-submersible offshore drilling rig owned and operated by Odfjell, a Norwegian drilling contractor based in Bergen.
It is designed for harsh environment and ultra-deepwater operations, particularly in regions like the North Sea.
With the completion of the Deepsea AberdeenSPS, the company has completed SPS projects across its entire owned rig fleet: Deepsea Aberdeen, Deepsea Atlantic, Deepsea Stavanger, and Deepsea Nordkapp.
Odfjell said that these were all delivered on time and within budget. The average downtime across all four rigs was below initial estimates.
In addition to the core SPS work, Odfjell Drilling implemented significant upgrades.
A new blowout preventer (BOP) was installed on Deepsea Atlantic, and the variable deck-load capacity was increased on both Deepsea Atlantic and Deepsea Stavanger.
Several client-specific efficiency improvements and minor upgrade projects were also completed.
With the SPS programme now concluded, the company expects a reduction in capital expenditure.
Additionally, the completion eases distribution restrictions under the terms of its US$390mn senior secured first-lien bond.
The company’s next SPS is scheduled for the Deepsea Nordkapp in late 2028.
Kjetil Gjersdal, CEO of Odfjell Drilling AS, commented, “Since early 2022, we’ve been preparing for this critical SPS period. With all eight rigs scheduled between 2023 and 2025, careful planning and strong execution have been essential – and I would like to thank the project organisation and every one of our onshore and offshore personnel for their valuable contributions.
“Our rigs are now in prime condition and installed with the latest technologies providing solid foundations to deliver further value and excellent performance. With significantly reduced capex payments going forward and no debt maturities until 2028, we are well placed for further stakeholder returns.”
Recently, Odfjell’s rigs have been active in the North Sea. The Deepsea Aberdeen is drilling for Equinor at the Breidablikk field, with contracts extended to 2026 and potential options until 2029.
As oil and gas wells reach the end of their productive life, there is a risk of leaving shallow reservoirs untapped left behind casing. These shallow reservoirs, including gas caps and thin bed formations, may hold valuable resources that are uneconomical to produce using conventional rig based well recompletions.
In Indonesia's Belida field, operators tackled this challenge by implementing rigless up-hole recompletions and utilising 3M Ceramic Sand Screens for downhole sand control. By employing this, operator was able to achieve high production rates from short reservoir perforated zone, maximising hydrocarbons recovery and extending the productive life of the wells and asset.
What role did 3M Ceramic Sand Screens play in facilitating rigless up-hole recompletions for shallow reservoir extraction?
How 3M technology contributes the extension of asset life by accessing previously uneconomical reservoirs?
How does 3M's solution manage erosion and hotspotting risks contributing faster return on investment?
As Eni advances exploration activities in the Baleine field offshore Cote d'Ivoire, it onboarded Expro for its autonomous iTONG system to ensure operational safety, efficiency, and sustainability
The technologically advanced tong system has simplified the well construction process by eliminating considerable rig time and labour time, keeping personnel away from the hazardous Red Zone of the rig floor. Less rig time further brought down the net CO₂ emissions.
By automating the connection make-up and break-out of casing and tubing joints, iTONG provides precise torque control from the push of a single button - operated safely from the driller’s cabin - while enabling full connection make-up validation.
Expro secured the Tubular Running Services (TRS) contract aboard the Deep Value Driller (DVD) drillship, which arrived in Cote d'Ivoire in late 2023.
Jeremy Angelle, vice president of well construction, said, “Since its introduction to Norway four years ago, iTONG has been recognised by major operators as a top-tier solution for tubular connection make-up and validation.
“In this case, its performance has exceeded expectations, with a 50% reduction in make-up times. The vision and commitment demonstrated by both Eni and Expro in introducing this technology to Africa exemplify a shared dedication to safer, more efficient operations.”
Jeremy added, “iTONG continues to redefine industry standards, improving safety, efficiency, and cost-effectiveness for offshore operations worldwide. Thanks to cutting-edge systems like iTONG, our R&D teams are leading the TRS industry in enhancing safety, reducing emissions, and driving global cost savings.”
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Repsol Resources UK has selected Halliburton for a five-year contract to support the complete well lifecycle across its platform assets in the UK North Sea
Under the agreement, Halliburton will deliver subsurface technology, drilling and completion services, along with digital solutions to support major new developments. The contract also includes the implementation of a rigless intervention framework, designed to help Repsol Resources UK enhance well construction, production, and intervention efforts—particularly in support of plug and abandonment (P&A) operations.
“This collaboration between Halliburton and Repsol Resources UK marks a strategic milestone. The efforts to maximize the remaining potential of the UK North Sea align with our focus to provide safe and reliable P&A operations,” said Timothy Horsfall, vice president, Halliburton Europe.
The partnership is intended to set a new industry benchmark for innovation and economic progress. Halliburton’s integrated services will play a key role in advancing Repsol Resources UK’s decommissioning activities across the region.
The Intervention and Coiled Tubing Association (ICoTA) has re-established its China Chapter, a recognition of the country’s growing importance to global energy markets and in the evolution of advanced well technologies.
ICoTA called it a “significant milestone” in the association’s global expansion and a commitment to technological innovation in well intervention.
In a statement, it said the revitalised China Chapter would serve as a critical hub for networking, knowledge exchange and technological advancement in the well intervention and coiled tubing sector across the whole of the Asia-Pacific region.
“This strategic relaunch reflects ICoTA's dedication to supporting emerging markets and fostering global industry collaboration,” the association noted.
Steve Moir, Global Chair of ICoTA, called it a landmark moment with implications for the whole region.
“Re-establishing the China chapter of ICoTA marks a pivotal moment as we unite to harness the immense potential of well intervention services in one of the world’s largest markets,” he said.
“Together, we will drive innovation and collaboration, ensuring a prosperous future for coiled tubing technology in China and beyond."
Frank Kong, from CNPC USA, described the market for well intervention services in China alone as huge.
“In 2024, the number of coiled tubing operations is about 12,000 jobs,” he said.
“The CNPC Engineering Technology R&D Company and Jianghan Machinery Institute have taken the lead in establishing the Coiled Tubing Technical Committee of the China Petroleum Society, which plays a leading role in China. The combination of China and ICoTA will for sure greatly promote the development of the industry and expand ICoTA's influence.”
Key objectives of ICoTA’s renewed China Chapter include:
Providing a robust platform for Chinese and international professionals in well intervention technologies.
Facilitating knowledge sharing and technical expertise across regional and international boundaries.
Supporting local industry professionals through networking, training and professional development opportunities.
Promoting cutting-edge technological innovations in well intervention and coiled tubing operations.
Baker Hughes has been selected by Equinor to deliver plug and abandonment (P&A) services in the Oseberg East field, located on Norway’s continental shelf.
The project will be led by Baker Hughes’ Mature Assets Solutions team, which will oversee both the planning and execution of the integrated P&A campaign across multiple wells in the North Sea.
Known for its expertise in mature asset management, Baker Hughes brings a robust track record of enhancing efficiency, shortening project timelines, and lowering overall costs through its integrated P&A services.
Under this new programme, the company will handle well abandonment and project management duties on behalf of Equinor.
This latest assignment follows a multi-year framework agreement signed in March 2025 between Baker Hughes and Equinor for integrated P&A services.
As part of the engagement, Baker Hughes will set up a P&A Center of Excellence in Bergen and Stavanger.
This specialised hub will centralise operations and bring together project managers and technical experts to ensure safe, cost-effective, and efficient well decommissioning.
The company will deploy advanced technologies from its P&A portfolio, including PRIME Powered Mechanical Applications, CICM (Casing Integrity & Cement Mapping), the MASTODON casing retrieval system, and the Xtreme SJI mechanical slotting tool.
Planning is already underway, with field execution expected to start in 2026.
“Our Mature Assets Solutions experts are well equipped to manage every phase of P&A and optimise operations to meet Equinor’s well abandonment goals,” said Amerino Gatti, executive vice president of Oilfield Services & Equipment at Baker Hughes. “As this project unfolds, we will collectively unlock new efficiencies that set new standards for well abandonment solutions, providing cost-effective solutions to Equinor through collaboration, technology, optimisation and integration.”
The Asia Pacific region is set to continue to provide a steady stream of work for the interventions market for some years to come, as high levels of upstream activity drive demand for drilling contractors and specialist expertise across a broad range of areas.
The well interventions segment is likely to prosper injecting new life into some of the region’s ageing oil and gas fields, all set against a backdrop of a general rise in energy demand globally.
This is likewise driving current upstream activity in the area.
According to industry consultancy, Westwood Energy, there are more than a dozen high-impact wells expected across the Asia Pacific region during the course of this year.
This includes the Hai Su Vang-1X well, which was completed as a discovery in early 2025.
As the region’s oil and gas sector expands and matures, the demand for well intervention services from local and international contractors is expected to follow suit.
Energy services provider, Expro Group, for example, reported significant contracts from the Asia-Pacific region in its Q1 results, including work to provide combined e-line cased hole and slickline services across 315 wells.
UK-listed EnQuest is among the upstream operators with an eye on the region’s hydrocarbon potential, with operations now spread across Malaysia, Vietnam and Indonesia.
Organic and transactional growth in the region already provides a pathway for the company to grow its South East Asian production to more than 35,000 Boepd by the end of the decade, EnQuest Chief Executive, Amjad Bseisu, said at the end of May.
He also noted that the group is in “advanced discussions” around a further new country entry in the region, highlighting keen investor appetite.
It underscores the potential for contracting teams, including across the well services and internentions market, to secure more business as the industry flourishes.
Westwood Energy identified various other key frontier wells for 2025 across the region, offshore South Korea at Daewanggorae, as well as at Mailu offshore Papua New Guinea.
Drilling will also continue in the Kutei Basin, offshore Indonesia, it noted, whilst a 2025 exploration programme offshore Malaysia is still to be firmed up, with only the Megah high-impact well currently drilling confirmed.
In addition, India should see at least five or six high impact wells from Oil India and ONGC across the east coast and Andaman Islands basins, the consultancy group noted earlier this year.
Integrated decommissioning solutions, late-life asset management, and engineering services tailored for deepwater wells are among the key investment opportunities in the Gulf of America decommissioning market.
That’s according to a new report from Verified Market Research, which highlights that joint ventures and strategic partnerships are on the increase, in response to high CapEx requirements given the average cost per well decommissioning of around US$1-5mn. The rise in offshore renewable energy projects also presents opportunities to repurpose infrastructure or convert platforms to artificial reefs.
However, risks include fluctuating oil prices affecting operator cash flows, particularly now with the Iran/Israel conflict sending oil prices spiralling, and an ever-changing US tariff regime impacting the oil market. Complex regulatory requirements and regulatory uncertainty, with the rolling back of some Biden-era legislation, can also pose a challenge, along with environmental liabilities. Legal challenges from improper decommissioning and long project timelines (often 12-36 months) pose further capital exposure. Due diligence on operator history, liability transfers, and local regulatory adherence is critical for financial stability and ROI predictability, the report advises.
Key trends include a shift toward sustainable decommissioning, cost optimisation strategies, and integration of robotics and ROVs (remotely operated vehicles) to enhance efficiency and safety. There is a growing focus on sustainability, spurred by both consumer pressure and regulatory requirements, with increased use of eco-friendly materials, implementation of energy-efficient processes, and introduction of waste reduction initiatives. Reflecting developments in the industry generally, the decommissioning market is embracing digital transformation, incorporating cutting-edge technologies such as AI, IoT, and blockchain, which is significantly enhancing operational efficiency and boosting innovation.
Stringent U.S. federal mandates on well abandonment and subsea asset removal are pushing operators to adopt ESG-aligned practices, the report finds. ESG frameworks now play a decisive role in decommissioning project bids and funding eligibility, with green decommissioning, carbon footprint reporting, and stakeholder transparency becoming market entry norms. Companies integrating ESG metrics into decommissioning lifecycle planning are positioned to attract sustainable capital flows and maintain a competitive edge in this evolving offshore energy transition market, the report suggests.
An oil producer from the United States employed Emerson and the company's local partner, Puffer-Sweiven, to replace existing traditional actuator systems on shutdown valves at production wellheads with two Bettis RTS electric valve actuators
Successfully pilot-tested, the solutions reduced power consumption and surge events, improved time to market (TTM) with quick implementation, and ensured data-based maintenance decisions. The FQ Series fail-safe quarter-turn actuator mounted on a ball valve, and the FL Series fail-safe linear actuator mounted on a reverse-acting gate valve. As electric actuators, these did not require air compressors, filtration and tubing.
The existing model cost the producer high maintenance charges and operational disruptions as it required addressing failures in cases of power outages or air leaks. Diaphragm wear and corrosion in the air lines raised safety issues as they needed manual intervention. Emerson's systems eliminated this step with its onboard diagnostic features to enable remote monitoring and troubleshooting, including partial valve stroke test (PVST). Equipped to achieve Safety Integrity Level 3 (SIL3), they are mechanical fail-safe to support emergency shutdown applications with the necessary response time. To deal with outage issues, the systems come with a fail-safe 24 V DC circuit, independent of the main power grid.
Capable of operating within a temperature range from -40 °F to +140 °F (-40 °C to +60 °C), it solved the problem of frozen instrument air supply lines of the traditional actuators during colder seasons.
The new systems eliminated methane emissions which were common with each stroke from the tradional actuators.
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China’s DS Global Offshore has reported that its Huan Qiu 1200 vessel has now completed decommissioning contract work in Thailand, on behalf of operator, Chevron.
The vessel has now returned to Chinese waters for domestic-based work.
“From early spring 2024 to late spring 2025, after more than a year of hard work, the Thailand Chevron oil and gas field subsea pipeline recovery project led by the ship, Huan Qiu 1200, of DS Global Offshore Engineering (Tianjin) Co.,Ltd. has successfully concluded,” it noted in a statement.
“After more than 400 days, with the excellent performance of the DP2 power positioning system, the team successfully recovered more than 60 21-inch cement-coated sea pipes in the deep sea, breaking the industry record and setting a new benchmark for global deep-sea energy development.”
It described the submarine pipeline labyrinth as an “underwater steel forest” spanning multiple kilometres in length.
DS Global Offshore said in its statement that precision technology and solutions had won praise from Chevron for overcoming challenges such as the increased weight of cement coatings and disturbance from underwater currents in the deep-sea environment.
It said the project team adopted the “segmented disassembly and precise lifting scheme, optimising the cutting path through dynamic simulation and using high-precision sensors to adjust the lifting angle in real time, successfully avoiding the risk of pipeline entanglement.”
At the core of the project, it noted, was the vessel’s DP2 power positioning system.
“The system analyses wind speed, ocean currents and ship displacement data in real-time through onboard computers, automatically adjusts the propulsion power, and controls the positioning error of the engineering ship within three metres, even in deep sea and level four sea conditions,” the DS Global Offshore statement noted.
The company added: “The Chevron owner stated: This cooperation fully demonstrates the excellent technical strength and professional competence of the engineering ship team, setting a benchmark for future offshore energy projects.”
Chevron is looking to decommission dozens of offshore platforms and subsea pipelines in Thailand over the coming years.
A recent report by Allied Market Research titled “Well Intervention Market by Service, Intervention Type, Well Type and Application: Global Opportunity Analysis and Industry Forecast, 2021–2030” forecasts strong growth in the global well intervention market.
Valued at US$8.7bn in 2020, the market is expected to reach US$15.3bn by 2030, growing at a CAGR of 5.8%
Well intervention involves various operations designed to increase the productivity of oil and gas wells. These services include slickline and wireline interventions, subsea intervention, coiled tubing, hydraulic workover, remedial services, stimulation, and others.
Globally, mature oilfields contribute up to 75% of total oil production, which significantly drives the demand for well intervention services. This demand is expected to rise as operators seek to enhance well productivity and efficiency.
In Europe, countries such as Germany, France, Spain, and Italy have been impacted by the COVID-19 pandemic, which introduced challenges to well intervention activities. Strict safety measures like social distancing and movement restrictions reduced manpower availability and disrupted supply chains, leading to slower operational activity.
Despite these challenges, Europe continues to be an important market due to its mature oilfields and ongoing need for well maintenance and production enhancement.
Key drivers influencing the growth of the well intervention market include:
The report highlights several market segments:
Regionally, North America remains the dominant market due to extensive shale oil developments and the presence of key players. However, Europe’s mature fields and regulatory environment make it a critical region for well intervention services.
For a comprehensive insight into the global well intervention market, you can access the full report by Allied Market Research here.
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