Trendsetter Vulcan Offshore (TVO), a developer of innovative offshore industry solutions, has deployed its proprietary Hercules tethered blowout preventer (TBOP) system to support the restart of a shut-in well in the Gulf of America (GoA)
“Our TBOP technology is the foundation of innovative solutions installed globally, and we are continually refining functionality to meet the operator’s precise needs” said TVO President Jim Maher. “We work directly with energy companies to understand performance requirements so we can quickly tailor site-specific solutions.”
For a recent installation in the northwestern sector of the GoA, TVO partnered with an operator that had previously used the Hercules TBOP system successfully on another project. The advanced system was developed to enable a deepwater floater equipped with a dynamic positioning (DP) system to operate safely in shallow-water environments.
The operator engaged TVO during the well planning phase, outlining the conditions at the well location and its intention to deploy a DP rig that had been operating under a long-term deepwater contract to carry out the workover of a shallower-water well. This approach removed the requirement for a separate moored rig at the site, avoiding additional costs.
TVO’s technical team completed the necessary BOP modifications for the well location, rapidly designing and customising the system while conducting in situ load testing, marking the first time this validation process had been completed on site. The installation was successfully executed, allowing the deepwater DP rig to safely perform the workover operation.
For more than a decade, TVO’s solutions have supported offshore operations by enhancing safety and addressing complex technical and operational challenges in demanding environments. The company’s technologies have been deployed across the Gulf of America, North Sea, Australasia and South America.
Odfjell Technology (UK) Ltd has confirmed that a major North Sea operator has signed a Letter of Intent to exercise the remaining two-year option under its existing contract for comprehensive drilling services on a North Sea platform.
The operator has also extended the agreement by adding a further two-year option.
The contract covers a broad range of services, including the management of operations, maintenance and repairs for both the platform’s main rig drilling facility and an intervention completion unit.
Odfjell Technology has been supporting the asset through this contract since 2019, making it one of the company’s largest integrated operations. Following the exercised option, the firm contract period will now run until November 2028, with an additional two-year extension option available beyond that period.
Commenting on the contract extension, Kurt Meinert Fjell, EVP Operations at Odfjell Technology, said: “We are very pleased to continue this contract and build on the excellent work delivered over the past seven years. We look forward to continuing to deliver safe, efficient, and high-performing operations together with our client.”
McDermott has announced a highly coveted partnership: it has been hand-selected by Aramco as one of only eleven contractors to drive forward massive project management consultancy solutions across the Kingdom of Saudi Arabia.
Executing complex energy infrastructure is a strategic priority for Aramco, tied directly to the Kingdom’s long-term development goals. Securing robust project management provides a reliable, integrated framework for large-scale energy, downstream, petrochemical, and low-carbon programmes.
Through a newly established multi-year Project Management Consultancy (PMC) Long-Term Agreement (LTA), McDermott is officially positioned as a central engineering and project management service provider within Aramco's sprawling strategic investment portfolio. Operating as a fully integrated provider in over 30 countries with a workforce exceeding 30,000 personnel, McDermott continues to advance the next generation of global energy infrastructure.
The joint venture's integrated Out-of-Kingdom and In-Kingdom delivery model leverages McDermott's global experience alongside Solutions Leaders Fayez Engineering's (SLFE) local capabilities. SLFE operates as an Aramco-approved general engineering services plus (GES+) contractor, and this framework produces dynamic, efficient execution while adhering to Aramco's rigorous In-Kingdom Total Value Add (IKTVA) and localisation objectives.
As part of this strategic collaboration, McDermott will combine its overarching technical expertise and global delivery frameworks with SLFE's robust domestic presence to seamlessly transform project execution. McDermott will provide its technology leadership in overall execution planning, governance, and front-end development (pre-FEED and FEED), seamless integration through established engineering centres, and continuous oversight to develop a fit-for-purpose project management solution for Aramco processes. SLFE, meanwhile, will spearhead engineering and client support within the Kingdom.
“Just as the United States and the Kingdom share a commitment to long-term collaboration, we share a commitment with SLFE to localisation, knowledge transfer and sustainable capacity building within the Kingdom,” said Michael McKelvy, McDermott's chief executive officer and chair of the board.
“This long‑term agreement reflects Aramco's confidence in our proven execution capabilities and our track record of delivering complex, world‑class projects in the Kingdom,” added Rob Shaul, McDermott's senior vice president of low carbon solutions.
Ashraf Alkhaznadar, SLFE's president and CEO, noted the mutual benefits of the joint venture for the region's broader development. “We are proud to partner with McDermott on this strategic agreement with Aramco,” he said. “Together, we bring complementary strengths that support Aramco's long‑term vision while continuing to develop national engineering capability.”
This landmark agreement underscores McDermott’s deeply rooted relationship with Aramco and its established history of successfully executing intricate engineering and energy projects throughout the Middle East. By continuing to deliver fully integrated, technology-driven solutions from concept to commissioning, McDermott is not only cementing its critical role in advancing the Kingdom's long-term developmental and energy transition targets, but it is also actively shaping the next generation of global energy infrastructure to empower a more sustainable future for the wider industry.
Conrad Asia Energy has secured a rig in support of its work in the development of the Mako gas field, offshore Indonesia— a market it believes holds immense long-term growth potential.
This could translate into a wealth of opportunities for offshore service providers, well intervention companies and other specialists, as the market evolves.
The Asia-focused gas exploration and development company reported that its subsidiary, West Natuna Exploration Limited (WNEL), signed a binding contract with PT Pertamina Drilling Services Indonesia for the provision of the Admarine 502 jack-up rig.
WNEL is the operator of the Duyung PSC in the Natuna Sea, offshore Indonesia.
The scope of work includes the drilling of six development wells and the installation of the Conductor Support Frame (CSF) on the offshore site and is set to commence in Q2 2027.
Conrad Managing Director and CEO, Miltos Xynogalas, said it represents “a critical milestone” for the Duyung PSC joint venture team as the project advances toward Mako drilling.
The Mako project is structured as initially comprising six development wells tied back to a leased Mobile Offshore Production Unit (MOPU).Sales gas will be transported via a 59 km 18-inch pipeline to the KF platform in the adjoining Kakap PSC, then through the WNTS pipeline for delivery to the domestic market.
Details have also been released regarding the formal contract signing for a Subsea Umbilical, Flowline, and Riser EPCI contract with PT. Timas Suplindo.
Total capex to first gas is estimated at US$320mn (100%), according to Conrad Asia Energy, while future operating costs are targeted at US$70-80mn (100%) per annum, including pipeline transportation costs.
Xynogalas also said in a 16 June 2026 AGM update that Indonesia looks set to be a strong market for the energy industry for the foreseeable future.
The fourth most populous country on earth, forecasts suggest that Indonesia's gas demand will increase by more than 60% over the next decade — from approximately 1,600 to 2,600 million standard cubic feet per day.
“The country is diverting LNG exports back to the domestic market because it needs the gas at home,” he said.
“The government has placed domestic gas prioritisation at the centre of its energy policy. Conrad's gas is exactly what Indonesia needs for its energy security.”
Two companies offering well intervention and other specialist offshore services in the Gulf of America, Helix Energy and Hornbeck Offshore Services, are moving ahead with a major merger plan.
In a June presentation to investors — Creating a Premier Integrated Offshore Services Company — Helix Energy outlined the rationale behind the deal ,and status of the transaction, which is expected to close in the second half of 2026, subject to approvals.
Helix Energy is a well-known supplier of well intervention, subsea robotics and technical services in the Gulf of America and overseas, while Hornbeck Offshore is renowned for its high-spec fleet of specialty vessels.
After the merger, the presentation noted that more than half of total group revenues will come from the US market, with Brazil, North Sea and West Africa also significant.
Approximately 80% of the 2025 combined revenues across both companies were derived from the oil and gas sector, with non-oil and gas accounting for just 20%.
While Hornbeck brings with it a larger fleet of offshore support and multipurpose vessels, Helix boasts a strong and established well intervention fleet.
In its Q1 2026 results, Helix Energy reported robust growth in its well intervention business, with results driven, in part, by strong Gulf of America activity.
Well Intervention revenues increased $28.4mn, or 16%, during the quarter compared to the prior quarter, primarily due to increases in the Gulf of America and Brazil, it noted.
The combined company will be renamed Hornbeck Offshore Services and trade on the New York Stock Exchange.
The post-merger team will be led by Todd M. Hornbeck, who will serve as the new combined entity’s President, CEO and Director.
Decommissioning will be in the spotlight at an inaugural well intervention forum hosted by the Australian chapter of the Intervention and Coiled Tubing Association (ICoTA).
The ICoTA Well Intervention Conference and Exhibition, to be held at the end of July in Perth, will include technical presentations and intervention insight from both Australian and regional operators.
It will look at production enhancement and well decommissioning case studies, among other technical issues.
As Australia’s offshore oil and gas sector matures, decommissioning has become an increasingly important focus for operators and regulators.
Industry stakeholders are seeking cost-effective and technically robust approaches to well plug and abandonment activities, while ensuring environmental and safety requirements are met.
The ICoTA event will also examine how well intervention technologies can support asset integrity, extend field life and improve operational efficiency across both producing and late-life assets.
In addition, the conference will profile intervention technology and innovation from ICoTA global prize winners, as well as include displays from service providers and offer networking opportunities with local and global industry peers.
The ICoTA event is planned for 29 July, 2026 at the Melbourne Hotel, Perth.
While much of the focus on Australia’s decommissioning efforts has been concentrated offshore, Esso Australia is quietly progressing work onshore at its Longford plant in southeastern Victoria.
The facility is a major natural gas and crude oil site that has long processed vital resources from the Bass Strait to supply the bulk of Victoria's domestic gas demand.
In a 9 June statement posted to the ExxonMobil Australia and New Zealand LinkedIn page, Longford Plant Manager Clinton Gentle highlighted how decommissioning work is taking place while his team continues to provide much-needed gas to the domestic market.
“For more than 50 years, the Bass Strait assets have played an important role in supplying energy to Australia,” he said.
“As some of these facilities reach the end of their working life, we’re now preparing for the next phase, including the removal of offshore platforms from 2027 as part of Australia’s largest decommissioning project.”
The focus throughout this process is on responsible decommissioning, he added.
Decommissioning work is already well advanced offshore.
The company and its partners have completed close to $3bn of early works, including the permanent plug and abandonment of over 200 wells.
This involved a range of specialised offshore vessels and rigs, drawing on expertise from similar projects in other parts of the world, like Canada, the USA and the North Sea.
At the same time, Esso Australia is also progressing decommissioning onshore at Longford.
“Longford has been at the centre of Gippsland Basin operations for decades, and as parts of the facility reach the end of their role, our teams have been carefully working through the decommissioning process,” said Gentle.
“This includes safely decontaminating equipment, dismantling infrastructure that was used to process crude oil and preparing areas for long-term retirement, all in line with our regulatory obligations.”
The scale of the task is “significant,” he added, demanding a strong focus on safety, precision and discipline.
“I’m proud of how our people have approached this work and the standard they’ve set.”
While some parts of its local operations are winding down, the company is also continuing to invest in the future of Gippsland Basin gas, he noted.
The Gippsland Basin Joint Venture has commenced drilling for the Turrum Phase 3 project, a $350mn investment that will support domestic gas supply.
This is expected to come online ahead of winter 2027 and will help meet ongoing demand across south east Australia.
Taken together, it reflects a balanced approach, according to Gentle.
“We’re safely retiring infrastructure that has reached the end of its life, while continuing to invest in projects that support reliable energy supply and local jobs.”
Vaalco Energy has brought back online the Baobab field on CI-40 block offshore Ivory Coast following the refurbishment of Baobab Ivoirien Floating Production Storage and Offloading vessel.
This comes following a nine-month refurbishment in Dubai, as the FPSO returned to Côte d’Ivoire in early Q2 2026, was moored into position and re-connected to the field infrastructure.
Production has resumed from four producing wells with the remaining three producers expected to come online shortly; the field is performing in line with Vaalco’s expectations.
FPSO refurbishment was undertaken to extend the life of the vessel and to ensure its long-term operational capacity as a significant development drilling program at Baobab is planned to begin in the second half of 2026; and Phase 5 drilling programme is expected to include four producers, two to three injectors and two workovers providing potential meaningful additions to production from the main Baobab field.
George Maxwell, Vaalco’s Chief Executive Officer, commented, “We are excited that the Baobab field on the CI-40 block offshore Côte d’Ivoire has restarted production in line with our projected timeline. We have the CI-40 block license extended through 2038 and believe that there is significant development drilling upside at Baobab. In early 2024, we had no assets in Côte d’Ivoire and now we have developed a strong position with development and exploration potential. We are at a critical junction, with successes in the Gabon drilling campaign and the Baobab field returning to production, and we believe that the remainder of 2026 will be very impactful. We remain focused on execution and driving meaningful growth through our organic capital programs that we believe will translate into value for our shareholders in 2026 and beyond.”
Global energy services leader Expro has secured a contract extension with a major operator, bringing cutting-edge subsea safety technology to the Gulf of America (GOA)
On 4 June 2026, the firm confirmed a comprehensive contract extension that will see it continue to deliver essential subsea completion and intervention services within the challenging waters of the GOA. This new agreement, set to span up to five years, serves as a testament to a collaborative partnership that has successfully endured for over twenty years.
Capitalising on the momentum of recent fruitful projects, this renewed arrangement notably features the deployment of one of the company's most recent innovations. For the first time within this partnership, Expro will deploy its proprietary Solus technology, a highly specialised shear-and-seal valve. This sophisticated piece of equipment is meticulously designed to provide a critical, additional layer of safety and reliability throughout complex subsea operations. By supporting robust well integrity in some of the most unforgiving and challenging offshore environments, the deployment of this valve illustrates Expro's ongoing commitment to bringing pioneering 'new technology' to the global market.
Under the terms of the extended contract, Expro will be tasked with supplying comprehensive subsea landing string services. The firm will draw on the extensive subsea well access expertise cultivated within its North and Latin America (NLA) regional operations to accomplish this. The tailored system is engineered to enable highly safe and efficient well intervention and completion activities. Crucially, it offers the necessary adaptability and operational flexibility required to meet the client's constantly evolving project demands.
Speaking on the significance of the agreement, Daniel More, Vice President, Subsea Well Access of Expro, said, “This contract represents the continued strength of our long-term relationship with the global operator and underlines their confidence in Expro’s subsea capabilities. We’re extremely proud of the success we’ve achieved together and look forward to supporting their ongoing projects in the Gulf of America with safe, reliable, and efficient subsea services.”
This prolonged partnership reinforces Expro’s position as a comprehensive 'well lifecycle partner'. From carbon storage well testing to complex subsea plug and abandonment campaigns, the company's diverse portfolio continues to evolve in step with its clientele's needs.
The PetroJarl Rosebank FPSO vessel has arrived on site to the west of Shetland, marking a major milestone in production generation goals from one of the largest undeveloped oil and gas field in the United Kingdom.
Once regulatory processes are cleared and formal government approval are in place, the field is considered significant to North Sea jobs, the UK economy and energy security.
Welcoming the arrival, Russell Borthwick, Chief Executive of Aberdeen & Grampian Chamber of Commerce, said, “Despite a protracted regulatory process which remains ongoing, it’s great to see work continuing to bring Rosebank closer to the point of production with the FPSO arriving at the field in recent days.
“Rosebank represents the very best in North Sea engineering capability, a multibillion-pound investment by the developer, major contracts for the UK supply chain and thousands of energy jobs supported throughout the lifetime of the project.
“New North Sea oil and gas development is vital for delivering energy security and economic growth for the UK.
“Rosebank is exactly the sort of at-scale oil and gas project will help tackle the chronic short supply of essential fuels in the UK and across Europe right now and bring more gas into homes from as early as next year. The reality is that Britain still relies on oil and gas for over 70% of our energy needs. While we still need it, we should produce as much of our it as possible from our own waters.
“There’s still a bright future for the North Sea, provided we see the regulatory process moving, the tax regime reformed and a pragmatic approach on how we secure the supply of domestic oil and gas that Britain needs in the years to come.”
As offshore energy infrastructure expands into increasingly demanding environments, safeguarding the integrity of underwater assets has become a priority for the energy sector.
Rising to this challenge, the underwater technology specialist Sonardyne has formally signed a Memorandum of Understanding (MoU) with AMOG, an international advanced engineering company. Together, they are set to provide a complete subsea asset monitoring service tailored directly to the needs of offshore energy infrastructure operators.
This strategic alliance integrates Sonardyne’s trusted underwater positioning, communication, and monitoring technologies with the industry-leading engineering assessment expertise of AMOG. By harnessing their combined capabilities, the partnership aims to unlock vital insights into asset health, substantially reduce costly operational downtime, and enable the safe life extension of critical underwater architecture. It will support a wide spectrum of subsea installations, encompassing floating offshore wind platforms and traditional oil and gas moorings, alongside essential pipelines and risers.
Dr Hayden Marcollo, director at AMOG said, “Combining high quality subsea data, processed at source on Observer, with advanced engineering assessments, will provide asset owners with more actionable, near-real-time insight into the condition and behaviour of critical subsea infrastructure.
“For operators, this could support earlier detection of anomalies, improved understanding of loads and motions, and more informed decisions around inspection, maintenance and integrity management, as well as asset longevity, in one end-to-end solution.”
Frank Rose, business development manager at Sonardyne, added, “By integrating on-demand and long term monitoring data from subsea environments with engineering models and analytics, there’s an opportunity to provide a more complete picture of asset performance—whether supporting day to day operations, integrity assurance or life extension strategies.”
“By working alongside AMOG, we’re exploring how data and engineering assessments can come together to give operators greater confidence in the way their subsea assets are performing, today and over the long term.”
Led by North America the global decommissioning industry is seeing a shift from a regulatory obligation approach to embracing sustainability practices that involve cost optimisation strategies and meeting environmental goals.
Decommissioning is not being seen as a liability anymore but a multi-billion-dollar opportunity in the form of new industries and multiple means of employment generation. This outlook sits perfectly with the requirements of the global energy transition landscape.
This is also the ideal way to tackle the burgeoning decommissioning liabilities as thousands of offshore platforms approach end-of-life across mature basins. The market is projected to witness strong compound annual growth rate through 2030, fueled by aging infrastructure across the Gulf of Mexico, among other regions. Well plugging & abandonment (P&A) activities has seen a boost alongside strict environmental compliance regulations and rising investments in subsea cutting, heavy-lift removal, and digital planning technologies.
These scenarios have pushed decommissioning to the forefront, with asset retirement and lifecycle management determining operators' annual budgets. They are working to stay up to date with regulatory risk exposures, forecasting capital expenditure cycles and tender pipelines, and aligning with ESG-driven investment strategies.
The significance of decommissioning in the offshore industry has led to a structured market growth, whereby players are prioritising regional entry strategies, building partnerships with EPC and subsea service providers, optimising cost modeling and bid strategies, and improving long-term investment planning.
