The annual Offshore Well Intervention Awards Global 2026 will return to Aberdeen this November, ready to once again shine the spotlight on the greatest minds within the industry.
This year, the judges will review each entry across six different criteria, including originality and creativity; functionality and technical qualities; ease of use; impact on the industry; performance and track record; and sustainability and growth.
The awards up for grabs this year include:
Guests will be treated to an evening of networking, entertainment, a three course meal, and the chance to raise a glass with the best in the industry and celebrate the success with their peers.
The ceremony will take place at the Union Kirk, Aberdeen on 19 November, 2026. Tickets are available on the website.
The Federal Government has stepped in to ensure the abandoned Cliff Head platform off the West Australia coast remains in a safe condition, following the entry of its owners into administration in July.
Federal Resources Minister Madeleine King authorised taxpayer funding to maintain the rig, with her office giving assurances that all costs to government would be recovered from the industry.
Triangle Energy entered administration faced with estimated decommissioning liabilities for the Cliff Head oilfield and associated infrastructure of $200mn after its partner, Pilot Energy entered administration having failed to secure funding to buy out Triangle’s stake in the joint venture.
The case has echoes of the Northern Endeavour scenario, when in 2020 the government took over responsibility for decommissioning and remediating the Northern Endeavour FPSO and its associated infrastructure, after its owner went into liquidation. Six years later, the work is still ongoing. Since then, various reforms have been implemented to ensure operators carry out their decommissioning obligations and prevent a similar event occurring again. The Federal Government also imposed a levy on the Australian petroleum industry to cover the Northern Endeavour decommissioning costs.
Conservation Council of WA (CCWA) Executive Director Matt Roberts said taxpayer funded maintenance of the Cliff Head Oil platform would have been avoided by stronger oil and gas decommissioning laws.
“The Federal Government should not be using Australian taxpayer money to maintain the fossil fuel industry’s abandoned infrastructure.
“What we need now is a clear plan and timeline to recover these funds from industry and meaningful, legislated changes to avoid this happening again in the future.”
Noting that the Federal Government is planning reforms to decommissioning legislation he added, “With $60 billion in decommissioning liabilities sitting offshore across Australia to be worked through in the decades ahead, we must get these reforms right.”
Law firm Clyde & Co, in an article on its website comments, “It appears that Triangle's collapse, and the current uncertainty surrounding responsibility for the Cliff Head decommissioning, is a consequence of matters which occurred under the pre-reform regulatory regime rather than a failure of the current regulatory regime.
“Triangle and Pilot’s acquisition of the Cliff Head oil field and its associated infrastructure occurred before the Walker Review reforms and in circumstances where the pre-reform regulatory regime did not provide for adequate regulatory oversight. It remains to be seen whether any other late-life offshore assets acquired by smaller operators under the pre-reform regime will emerge with solvency concerns as production ceases and decommissioning liabilities crystallise.
“It may be that the original developers of Cliff Head avoid decommissioning liability in this instance due to limitations on the retrospective effect of the trailing liability reforms.”
Clyde & Co added that the expanded trailing liability regime means that the regulator may also look to related persons where appropriate with respect to decommissioning, as well as the two companies concerned.
“Triangle and Pilot’s collapse may cause regulators, financiers and project proponents to scrutinise more closely whether adequate security or funding arrangements are in place to meet both operational and eventual decommissioning liabilities for late-life offshore assets,” Clyde & Co concluded.
Advanced oceanographic technology is driving the rapid expansion of South America’s offshore energy sector, particularly in Brazil’s deepwater pre-salt fields and Guyana’s Stabroek Block.
Effective operations across harsh marine environments require real-time ocean data for supporting subsea construction, drilling and vessel safety. Operators are increasingly relying on wave monitoring and oil spill detection systems to manage operational risks and ensure environmental protection across the region.
Accelerating commercial momentum in South America, the Norwegian ocean technology company Miros has reported for the year several wins in double-digits across the region.
These contracts were secured during the end of 2025, and continue to generate value for the company. The first three quarters of 2026 have set a positive tone for the company's future, with most activities concentrated in Brazil alongside deployments linked to offshore operations in Guyana.
The deployments span real-time wave and ocean monitoring and oil spill detection, supporting operations including subsea construction, offshore vessel operations, drilling-related activities and environmental response.
While these agreements comprise several exisiting customers, deals were secured with new clients as well. Miros got several bookings for services extensions in additional vessels and assets, including offshore support vessels, marine response vessels and drilling-related assets.
Marius Five Aarset, CEO of Miros, said, “What is particularly encouraging is not simply the number of wins, but the pattern behind them. We are seeing new customers adopting Miros’ technology, existing customers expanding to additional vessels, and growing activity in Brazil.”
“Across subsea operations, drilling, vessel operations and oil spill response, the common requirement is reliable real-time information that supports safer and better-informed decisions offshore.”
Andrew Wallace, Regional Commercial Manager at Miros, said, “At Miros we have a long-term commitment to Brazil and the wider South American market. We continue investment in the region through our technology, engineering expertise, commercial resources and direct customer engagement, supported by our trusted local partners who strengthen our regional reach and delivery capabilities.
"The continued activity strengthens Miros’ presence in South America, with Brazil at the center of its regional growth and further opportunities across offshore energy, vessel operations and environmental monitoring.”
While carrying a history of severe geopolitical instability, Libya's resilience in still being able to attract global investment interests speaks volumes about the richness of its reserves
Known to hold Africa's largest proven oil resources, Libya moves North African supply dynamics. International oil companies are increasingly returning to reactivate dormant fields and tap into high-potential basins. Central to this resurgence is the Sirte Basin, a historically prolific region offering significant infrastructure proximity.
Recently, the country has reported several successful appraisals, marking a critical turning point for international investment, signaling restored commercial confidence and renewed momentum in Libya’s long-term energy output goals.
OMV has classified the Essar well in Libya’s Sirte Basin as commercially viable following technical and economic evaluations. Previously, the Libya NOC too approved the discovery's commercial viability.
The well lies in the concession area C 103, where OMV holds 12% interest.
With an indication of total recoverable resources reaching up to 45 million barrels of oil, the reservoir is being prepared for development by Zueitina Oil Company. It will be easier to hit production timelines from thew concession sooner as it lies adjacent to existing production and processing facilities, ensuring cost-efficiency as well. The discovery highlights Libya’s potential as one of Africa’s most important energy regions and marks another milestone in the long-standing partnership between OMV and the NOC.
“The Essar discovery is a major milestone for OMV and our partners at the NOC. It confirms not only Libya’s considerable potential, but also the value of long-term partnerships, technical excellence, and our unwavering commitment on the ground. Strategic collaborations such as this are essential to providing the energy the world needs. I am proud of what we have achieved together and look forward to the next chapter in Libya”, said Berislav Gaso, OMV executive vice president for energy.
OMV holds Libya strategically important as part of its upstream growth interests in North Africa. The company has been an active player in Libya for around 50 years and is among the country’s long-standing international energy partners. It resumed operations in the country in 2024, after a hiatus of more than ten years.
OMV has extensive experience in the exploration and production of oil and gas in North Africa and relies on close cooperation with local partners as well as the continuous optimization of existing assets. Libya holds Africa’s largest proven oil reserves and ranks among the world’s most significant oil-producing countries.
Australia’s Department of Industry, Science and Resources has reported back on common issues and concerns regarding the decommissioning process, following an industry and stakeholder consultation process as part of its reforms overhaul.
It comes as Australia seeks to tighten financial and regulatory safeguards around offshore oil and gas decommissioning, amid concerns that companies could leave taxpayers exposed to costly clean-up liabilities.
The Department said it was running its targeted consultation on the practical workings of proposed regulatory design amid updates to offshore decommissioning and financial assurance reforms.
Common themes to emerge from stakeholders included the need for:
• Earlier and regularly updated decommissioning planning
• Robust and credible decommissioning cost estimates
• Greater public transparency of decommissioning information
• Stronger financial assurance requirements
• Clear and effective enforcement options capable of intervening where required
• Clear regulatory triggers and expectations
The consultation process focused on a range of issues including decommissioning planning; financial planning and assurance; decommissioning and financial capacity risk assessments;
compliance and enforcement tools; and title surrender.
The Department said that it received 38 submissions and published 30 responses, while issues identified have “directly shaped” the proposed model, including its emphasis on:
• Staged planning
• Greater transparency
• Effective compliance and enforcement tools
• A proportionate, risk-based regulatory approach
“We are now conducting roundtables and meetings with stakeholders to test the regulatory design for the reforms,” the Department noted.
“The focus of this consultation is on technical and implementation issues. This includes how the model would operate in practice across different project types and life cycle stages.”
It said this targeted feedback would help reduce the risks of “unintended consequences” and ensure a robust, proportionate and balanced regulatory regime.
“Our reforms seek to ensure industry decommissions offshore infrastructure in a timely, safe and environmentally responsible way. This includes remaining responsible for the risks and liabilities of offshore activities,” the Department said in a statement.
There is expected to be a further consultation on the legislative changes in 2027.
Tackling millions of acres of ocean waters that make up the Outer Continental Shelf (OCS) is no mean feat and will only turn more challenging if not addressed in an optimised manner.
The United States Department of the Interior (DoI) is hence proactively initiating structural realignments so that resource leasing is done in an environmentally responsible manner. A clear administrative structure in place will eliminate regulatory friction while upholding safety standards.
In a significant consolidation move of its offshore regulatory agencies for enhanced oversight across the OCS, the DoI has announced the unification of the Bureau of Ocean Energy Management (BOEM) and the Bureau of Safety and Environmental Enforcement (BSEE) into a single Bureau -- the Marine Minerals Administration (MMA).
This move will simplify supervision of activities in the OCS due to effective administration from streamlined governance as MMA begins to operate as part of the DoI.
MMA was formerly known as Minerals Management Service (MMS), whose operations were split across the Bureau of Ocean Energy Management (BOEM) and the Bureau of Safety and Environmental Enforcement (BSEE). While at BOEM MMS administered offshore energy and minerals leasing, resource evaluation and environmental review, at BSEE it was responsible for overseeing operational safety, environmental enforcement, resource conservation and regulatory compliance.
When independently operating, a lot of complications hampered the operations of both Bureau. There were unnecessary bureaucracy and administrative systems that were only obstructing the DoI's capacity for strategic deployment, and could simply be done without. Reunification of BOEM and BSEE into a single Bureau will reduce overhead, enhance the deployment of subject matter expertise across the entire mission area and deliver stronger safety outcomes for the workers and communities who depend on safe and responsible OCS operations. It will allow DoI a holistic approach in addressing safety and environmental concerns throughout the OCS for all leasing, exploration, development, production and decommissioning processes, which will improve leadership decision-making.
The MMA will cover all aspects of DoI's offshore energy and mineral resource management and conservation, safety oversight, environmental enforcement and related activities on the OCS. The position will be spearheaded by a Director under the supervision of the Assistant Secretary – Land and Minerals Management (AS-LMM).
A North Sea operator improved the reliability of its offshore production operations after deploying a new electric submersible pump (ESP) system supported by Halliburton’s Summit ESP service and digital monitoring technologies
The deployment addressed challenges with the operator’s previous ESP supplier, including missed delivery timelines, limited equipment availability, mechanical failures and high intervention costs. The operator also required a reliable solution that could be installed on an active production platform using hydraulic workover (HWO) unit operations.
According to a Halliburton case study, the operator needed an ESP system that could be delivered quickly, installed without disruption and supported through continuous monitoring and optimisation.
Addressing offshore ESP reliability challenges
The operator’s previous ESP systems had experienced limited stock availability and extended delivery times, while mechanical failures had contributed to operational challenges.
Installation also presented specific risks. Capillary chemical injection lines had been damaged during previous installation activities, creating concerns about the long-term performance of the ESP system.
In addition, offshore cybersecurity requirements added complexity to the deployment of digital monitoring and remote optimisation capabilities.
To address these challenges, Summit ESP, a Halliburton service, worked with the customer to conduct a detailed factory assessment of each ESP component.
The team designed a custom protector flange to safeguard the capillary line. The component was manufactured locally in Emmen, the Netherlands.
ESP system delivered ahead of schedule
Early delivery of the ESP system enabled comprehensive fit-up testing with HWO tools before offshore installation. This helped verify compatibility and prepare the equipment for deployment on the production platform.
Halliburton’s global field service team subsequently installed the system, removed the failed equipment and commissioned the replacement ESP system.
The installation achieved 100% KPI compliance, while the Intelevate® platform, powered by the Summit Knowledge® digital ecosystem, provided real-time data, health checks and optimisation recommendations from the start of operations.
The system was delivered one month ahead of schedule, while the deployment recorded zero non-productive time (NPT).
The Intelevate platform also provided 24 hours of daily real-time monitoring and optimisation.
Digital monitoring supports offshore operations
The deployment marked the first use of Halliburton’s Intelevate digital platform in the North Sea, according to the Halliburton case study.
The platform provided continuous visibility into the ESP system and supported 24/7 optimisation from day one.
The early arrival of the ESP system also allowed additional pre-checks and in-country fit-up testing before offshore installation. This confirmed compatibility with the HWO equipment and helped eliminate risks associated with non-productive time and minimise deferred production.
Restoring ESP performance offshore
The replacement ESP system met production targets and restored reliability to the operator’s offshore operations.
Continuous support through the Intelevate platform helped maintain operational efficiency through real-time monitoring and optimisation.
The customer acknowledged the service quality, with the deployment representing a milestone in the operator’s offshore ESP operations.
Engineers Australia, the country’s national body for engineering, is organising a site visit to an Oceaneering subsea engineering facility that will explore asset integrity management and other key industry issues.
Operating from its Jandakot facility in Western Australia, Oceaneering develops and delivers innovative technologies that support the inspection, maintenance, repair and integrity management of critical subsea infrastructure for the offshore energy industry.
“Explore the future of subsea engineering and offshore technology with Oceaneering,” an Engineers Australia statement noted.
The visit is scheduled to take place on 23 September 2026.
The statement highlighted the “exclusive industrial visit” to Oceaneering Australia, “a global leader in subsea engineering, remotely operated vehicle (ROV) technology, asset integrity management and offshore engineering solutions.”
Hosted by the Engineers Australia Mechanical College, the visit will offer a glimpse into the engineering challenges associated with operating and maintaining subsea assets in some of the world's most demanding environments.
The statement added that participants will develop an understanding of the complexity of subsea pipeline inspection and repair activities, including the influence of deepwater conditions, corrosion, accessibility, operational risks and stringent safety requirements.
“The visit will also provide valuable exposure to the role of remotely operated vehicles (ROVs) and other advanced submersible technologies used for subsea inspection, intervention, and repair, highlighting how these systems enable engineers to safely perform complex offshore operations that would otherwise be impossible for human divers.”
Sarawak-based oil and gas services firm United Asiapac Energy Bhd is looking to further expand its well intervention services business in East Malaysia following its debut on the ACE Market of Bursa Malaysia, reported Bernama.
The company’s shares opened flat at 35 sen, with 2.78 million shares changing hands during the early trading session. By 5pm, the stock had closed 11.4% lower at 31 sen, with 40.8 million shares traded.
Speaking after the company’s listing ceremony, executive director and chief corporate officer Ng Her Yinn said the initial public offering (IPO) would provide an opportunity to broaden United Asiapac Energy’s reach beyond its existing markets and strengthen its presence across Malaysia.
“Our plan is to continue growing our presence in Sabah and Sarawak. At the same time, our presence and the work that we deliver are not limited there.
“We already have a presence across Malaysia and this (IPO) will allow us to further expand our business, while also contributing to the development of Sabah and Sarawak,” she said.
The listing ceremony was attended by United Asiapac Energy managing director Ahmad Fadzuli Ali, Deputy Economy Minister Datuk Mohd Shahar Abdullah and TERAJU chief executive officer Junady Nawawi.
Ng said the company has a competitive advantage in providing its services despite the prevailing geopolitical situation.
The company specialises in well intervention services and has an established presence across Malaysia. Its IPO is expected to support further business expansion as it seeks to strengthen its operations and contribute to the development of Sabah and Sarawak, according to Bernama.
Baker Hughes has been chosen to provide gas compression systems for the Cloud Connector Pipeline project in Louisiana, as well as a modular liquefaction solution including cold boxes to support the expansion of the Plaquemines LNG facility.
Together, the pipeline and liquefaction awards demonstrate the critical role of integrated natural gas infrastructure in expanding LNG supply and enhancing energy security for global markets, the company said in a statement.
The pipeline award, which includes 13 gas compression systems driven by Frame 5/2E gas turbines, represents one of the largest deployments for LNG feed gas transportation in the US.
It will enable reliable transportation of feed gas through the Cloud Connector Pipeline to Venture Global LNG’s Plaquemines facility.
Baker Hughes will also provide four liquefaction blocks, comprising a total of eight modules, to support additional production capacity at the Plaquemines LNG facility.
"US natural gas is helping to deliver the energy continuity required for industries, communities and economies to thrive, grow and innovate,” said Lorenzo Simonelli, chairman and CEO of Baker Hughes.
“Baker Hughes is proud to work alongside our partners at Venture Global as they expand Plaquemines LNG, providing the critical energy infrastructure needed to meet growing global long-term global energy demand.”
The liquefaction solution provided by Baker Hughes for the Plaquemines expansion follows a similar scope recently awarded for the CP2 project.
Each liquefaction block is based on two electric-motor driven, single mixed-refrigerant (SMR) liquefaction modules and associated compression trains featuring Baker Hughes' advanced centrifugal compressor technology, as well as cold boxes, air coolers and integrated control systems.
The Cloud Connector award is the second order of Frame 5/2E gas turbine-driven centrifugal compressor packages for Venture Global’s feed gas pipeline, expanding the fleet to 23 Frame 5/2E-driven gas compression systems for the Plaquemines LNG facility.
The award further strengthens Baker Hughes’ strategic relationship with Venture Global, supporting more than 100 MTPA of existing and planned LNG production capacity, and reinforces Baker Hughes’ role as a leading industrialised energy provider across the natural gas value chain.
“Baker Hughes has been a trusted partner across our LNG developments, both at our LNG facilities and across our pipeline infrastructure,” said Mike Sabel, CEO of Venture Global.
“As we advance the expansion of Plaquemines LNG, this collaboration not only supports our expansion plans, but also helps ensure we deliver the reliable feed gas transportation necessary to realise our mission of supplying secure LNG to global markets.”
Halliburton has secured a bundled well construction and completions contract from Eni for the Cronos ultra-deepwater development in Block 6 of the Cyprus Exclusive Economic Zone
The award strengthens Halliburton’s offshore portfolio in the Eastern Mediterranean and expands its role in the region’s strategic natural gas development.
Under the contract, Halliburton will provide integrated drilling, well construction, automation and completions services for exploration and development wells. The bundled scope is designed to reduce operational interfaces, improve execution certainty and support efficient delivery across the multi-year ultra-deepwater development.
The Cronos award builds on Halliburton’s longstanding relationship with Eni and reflects the company’s ability to deliver integrated offshore solutions for complex deepwater developments. It also strengthens Halliburton’s position in the Eastern Mediterranean, an emerging offshore gas region. The company expects its integrated delivery model to support future development as operators prioritise efficiency, performance and long-term value.
Jean-Marc Lopez, senior vice president, Europe, Eurasia, and Sub-Saharan Africa, Halliburton
The scope includes drilling fluids, directional drilling, LOGIX automation and remote operations, cementing, surface well testing and coiled tubing. Halliburton will support the campaign through its established infrastructure and regional capabilities in Cyprus, providing logistical advantages and supporting reliable execution throughout the programme.
The Cronos project provides a platform for future deepwater development in the Eastern Mediterranean. Halliburton expects to apply its integrated delivery model to additional offshore campaigns as operators seek greater efficiency, reliable performance and long-term value in increasingly complex offshore environments.
Software company Aize has acquired Samp, a French industrial AI company, in a move to unite their respective technologies, teams and visions to create a comprehensive approach to industrial asset information.
The combination will address industrial assets across their full lifecycle, from greenfield facilities to decades-old brownfield assets.
Samp has developed Shared Reality, an AI-powered platform that transforms reality-capture data, such as laser scans, into structured asset information and connects the physical identity of the field with engineering information such as tags, drawings and P&IDs.
Samp’s technology is already being used across more than 500 industrial facilities, with a strong focus on energy and water. Aize is used by leading companies across the energy sector, including bp, ExxonMobil, SBM Offshore, Aker BP, and Aker Solutions, to bring engineering, operational and asset information together in one digital environment.
Jarle Skrebergene, CEO of Aize, said, “What convinced us about Samp was not only the technology, but the team, their commercial momentum and how closely their vision aligns with ours. Together, we can connect engineering intent, operational information and what actually exists in the field, creating a uniquely powerful foundation for industrial companies to understand and work their assets throughout their lifecycle.”
CEO and Co-Founder of Samp, Laurent Bourgouin, commented, “Samp was founded around a simple conviction: for existing industrial facilities, the field is the ultimate source of truth. Shared Reality bridges the gap between physical reality and the technical information companies rely on every day. Together with Aize, we can connect engineering, operations and field reality across the entire asset lifecycle.”
