Eni, in partnership with the Libyan National Oil Corporation (NOC) through the Mellitah Oil & Gas joint venture, has start-up hydrocarbon production from the Sabratha Compression Project.
This is a strategic offshore development for Eni to leverage the Bahr Essalam offshore field for boosted and sustained gas generation.
The Sabratha Compression Project comprises an installation of a new 1,600-ton compression module on the Sabratha platform, equipped with new compression trains, providing an overall compression capacity of about 440 MMscfd.
The new module can produce under low-pressure conditions, enhancing gas recovery from the gradually declining Bahr Essalam field. This process secures the generation of boosted gas volumes at about 800 million cu/m per year and associated condensate. This additional production will play a critical role in sustaining national power generation, reinforcing Libya’s energy security, and supporting export to Italy via the Greenstream pipeline.
With a smoothy delivery of the challenging and complex Sabratha Compression Project, Eni and NOC is able to secure a resilient gas infrastructure for Libya, adding to the stability and growth of the country’s energy sector.
Two additional strategic projects are presently in execution in the country: Bouri Gas Utilization Project, whose tie-in and commissioning activities are currently underway after the recent installation of the Bouri Gas Recovery Module, and Structures A&E, whose execution is underway to develop two offshore gas fields.
Eni has been present in Libya since 1959 and is the country’s leading international operator, with an equity production of approximately 162,000 barrels of oil equivalent per day in 2025 and three development projects currently in execution for a total investment of about 10 billion dollars.
A new collaboration between FutureOn and SteelTrace is set to help operators make faster maintenance and integrity decisions while maintaining a complete audit trail.
FutureOn, a leading provider of digital twin technology for the energy industry and SteelTrace, a cloud-based Smart Manufacturing Record (SMR) platform have agreed to integrate SteelTrace’s Smart Manufacturing Records into FieldTwin, FutureOn’s digital twin platform for offshore energy projects. This will reduce the time spent locating essential documentation, a common challenge across offshore projects.
Material Test Records (MTRs), weld records, coating documentation, Non-Destructive Examination (NDE) results and fabrication sign-offs are created throughout the manufacturing and construction process but are often stored separately from the engineering models and operational systems used to manage offshore assets. Once assets enter operations, engineers can spend valuable time searching disconnected systems and archived documentation to locate the information they need.
The integration will enable operators and EPCIs to access material test records, weld records and inspection data within FieldTwin, providing trusted information for asset integrity, maintenance planning and decommissioning within a single geospatial workspace.
SteelTrace’s blockchain-backed Smart Manufacturing Records (SMRs) replace static PDF certificates with structured, trusted digital compliance records that provide a verified audit trail from raw material through fabrication and installation. By capturing and validating manufacturing and inspection data against project specifications in real time, SteelTrace creates a single, auditable source of truth across the entire asset lifecycle. The integration will bring these records directly into FieldTwin, improving traceability without changing existing engineering workflows.
Tom Meulendijks, CEO and Founder of SteelTrace, said, "Every offshore asset has a history. From the steel mill through fabrication and installation, thousands of records are created to demonstrate quality and compliance. The challenge isn't creating that information, it's making sure engineers can easily access it years later when they need it most.
“By connecting SteelTrace with FieldTwin, we're making verified material records available alongside the asset itself.”
Filip Valica, VP Corporate Development at FutureOn, said, "A digital twin only delivers real value when it gives engineers immediate access to the information behind the asset. As offshore infrastructure matures, operators need trusted material information to extend asset life, support maintenance and plan for decommissioning.
“Bringing SteelTrace's verified material records directly into FieldTwin enables operations teams to quickly access the documentation they need to support maintenance, in-field repairs and decommissioning without searching across multiple systems."
Energy data and AI specialist Enverus has expanded its subsurface data offering with the acquisition of the A2D well log library from TGS, bringing what it says is the world's largest commercial well log database onto its energy intelligence platform.
Announced on 8 July, the deal adds more than eight million depth-calibrated raster logs, 1.9 million digital LAS files and over five million proprietary well logs covering every major US producing basin.
Financial terms of the transaction were not disclosed.
Enverus said integrating A2D's well logs, formation tops and petrophysical data with its existing production, completions, land, ownership, cost and economics datasets will give customers a more connected view of the subsurface, helping them move from geological interpretation to commercial decision-making more quickly.
"We have always believed energy data becomes more valuable when it is connected," said Manuj Nikhanj, CEO of Enverus.
"A2D brings subsurface depth and quality that customers have trusted for decades. When logs, tops and petrophysics can be connected with production, completions, ownership, costs and economics, teams can move from understanding the rock to understanding the return."
The acquisition also brings more than two million interpreted formation tops, basin temperature models and analytics-ready log attributes into the Enverus platform, allowing users to carry out basin-scale reservoir analysis without moving between multiple systems. Existing A2D licensing and subscription agreements will remain in place.
For TGS, the transaction marks the next chapter for a well log library that has been built up over more than three decades.
"We built the A2D library into something the industry depends on, and this transaction ensures it keeps getting better," said Kristian Johansen, CEO of TGS.
"Our customers have always wanted to take this data further into their workflows. Enverus gives them the platform to do that."
The acquisition follows Enverus' recent purchase of PDS Energy Information's exchange assets and reflects the company's wider strategy of bringing together subsurface, operational and commercial data within a single platform to support energy companies across the asset lifecycle.
DeepOcean has completed the recovery of the remaining subsea wellhead protection structure at the Spirit Energy-operated Seven Seas field and disconnected subsea infrastructure at the nearby Grove West field in the southern North Sea, using proprietary decommissioning tooling developed in-house.
The project included onshore engineering, project management and offshore execution by DeepOcean, with the company's high-specification construction vessel Edda Freya deployed to recover the wellhead protection structure, which weighed more than 100 tonnes, along with associated subsea infrastructure. All recovered materials have been transported for reuse, recycling or responsible disposal. The work was managed and carried out by DeepOcean's Aberdeen-based operations in the UK.
The activities form part of Spirit Energy's broader decommissioning programme for the Seven Seas and Grove West fields, with both scopes completed in preparation for an upcoming rig campaign.
"The wellhead protection structure at Seven Seas has served the field since 2011 and remains in very good shape. The piles were cut three metres below the seabed and the subsequent retrieval of the structure was conducted. We were delighted to support Spirit Energy on this project and look forward to working with Spirit Energy on future scopes of work," said Robin Mawhinney, Executive Vice President for DeepOcean's EMEA region.
The project also involved disconnecting a spool from a subsea Christmas tree at Grove West. The operation was carried out using a remotely operated vehicle (ROV) together with specialised tooling, eliminating the need for diver intervention that would traditionally be required for this type of work.
Spirit Energy's Decommissioning Manager, Ceri Wheaton, said: "We are committed to maximising material recovery and minimising waste throughout our decommissioning activities. By working closely with specialist contractors such as DeepOcean and leveraging the UK supply chain, we have safely recycled more than 95% of materials from decommissioned assets and infrastructure. This approach not only reduces environmental impact but also improves efficiency through streamlined logistics and the responsible reuse of valuable resources."
"At Grove West, we disconnected two subsea flanges using methodologies and proprietary tooling developed during the Gryphon Alpha FPSO removal project last year. This project adds to DeepOcean's growing track record of meeting project objectives across subsea decommissioning campaigns," said Øyvind Mikaelsen, Chief Executive Officer at DeepOcean.
The Seven Seas wellhead protection structure was located approximately 80 km offshore the East Yorkshire coast in water depths of around 33 metres, while the Grove West infrastructure is situated about 130 km east of the UK coastline in water depths of approximately 40 metres.
Australia’s offshore oil and gas sector is entering a major decommissioning phase, driven by ageing infrastructure, stricter regulations and growing environmental accountability
According to a Xodus report, the decommissioning liability for all assets in Australian Commonwealth waters is estimated at UA$43.6bn through 2070, or AU$66.8bn when adjusted for inflation. This encompasses more than 700 wells, 7,600 of pipelines and 520 subsea structures. Around 55% of the decommissioning (AU$25bn) will occur before 2040, with the remaining decommissioning activities mainly occurring by 2050.
Offshore Network has issued a new report entitled “The Decommissioning Landscape in Australia in 2026”, which:
The report concludes that the industry’s success will depend on collaboration across stakeholders, regulatory alignment and investment in domestic capability, along with the adoption of best practice and enabling technologies, incorporating learnings from more mature basins. That being the case, Australia can look forward to the prospect of a robust, safe, responsible and economically sound decommissioning industry characterised by mature, repeatable execution models in the long term.
The report can be downloaded here.
Aquaterra Energy and James Fisher and Sons plc (James Fisher) have entered into a global strategic partnership aimed at improving the delivery of offshore decommissioning projects by providing operators with a more integrated approach to well abandonment and infrastructure removal
The collaboration brings together Aquaterra Energy's expertise in front-end engineering and well access with James Fisher Energy's capabilities in subsea operations and offshore execution. By combining these services under a single delivery framework, the partnership is designed to simplify project execution, reduce the number of contractor interfaces and provide greater certainty throughout the decommissioning lifecycle.
Rather than following traditional multi-contractor models, the alliance integrates engineering, project planning, well access and offshore execution from the earliest stages of project development. This approach is intended to minimise handovers, improve accountability and provide operators with greater flexibility to respond to changing project requirements while maintaining efficient execution.
The partnership will support projects worldwide, with an initial focus on the North Sea, Asia-Pacific (APAC) and the Middle East, where increasing numbers of offshore assets are approaching the end of their operational life. According to the North Sea Transition Authority, 153 wells in the UK Continental Shelf have exceeded decommissioning consent deadlines, while an estimated £44 billion remains to be invested in decommissioning activities. In Australia, government forecasts suggest offshore decommissioning liabilities could reach approximately £48 billion over the next 30 to 50 years, while globally more than 2,500 offshore structures are expected to require decommissioning by 2040. These trends are driving demand for delivery models that improve efficiency, coordination and execution.
Matt Marcantonio, Head of Engineering at Aquaterra Energy, said: "Decommissioning programmes are increasingly moving away from simple, isolated scopes. The next generation of projects will require tight engineering control, early integration and the ability to adapt quickly as conditions change. By aligning our expertise with James Fisher from the outset, we can shape more efficient scopes, prevent downstream redesign and ultimately reduce offshore duration. We see this as a way to give operators the confidence to take on decommissioning programmes that are becoming more technically demanding and commercially pressured, while keeping the agility needed to respond as projects evolve."
Mark Stephen, Product Line Director - Decommissioning & CFE at James Fisher Energy, commented: "What operators are looking for now is delivery confidence, predictable execution, fewer interfaces and teams who already understand how to work together. By combining our subsea operations capability with Aquaterra Energy's early engineering and well access expertise, we can remove many of the common friction points that slow projects down offshore. This model gives operators a scalable, field-proven approach that directly supports safer, more efficient execution as global decommissioning activity accelerates."
The companies will operate the partnership on a project-by-project basis, tailoring team structures according to individual project requirements. This will include the deployment of cross-trained personnel where appropriate to reduce the number of people required offshore and minimise operational risk. While both organisations will continue to operate independently, they will collaborate under an agreed framework designed to promote early engagement, coordinated planning and aligned project delivery.
The partners are already working with operators on a number of upcoming offshore decommissioning opportunities across multiple international markets.
As Australia's offshore decommissioning industry grows, lifting operations are becoming more frequent, more complex and potentially more hazardous.
That is one of the core messages from an article in the latest issue of The Regulator, the journal of the National Offshore Petroleum Safety and Environmental Management Authority (Nopsema).
Removing ageing platforms, subsea equipment and heavy structures presents risks that go beyond routine operations, making careful planning, maintenance and decision-making more important than ever.
“Analysis from Nopsema and international regulators shows that lifting incidents have increased over the past decade, even as safety systems have improved,” the article notes.
“This trend reflects changes in the offshore environment. Even though the number of cranes used offshore has not increased over the past 10 years, operations are becoming more complex, with heavier lifts, more simultaneous activities and increased use of large-scale equipment. Offshore decommissioning and the growth of offshore wind have also contributed to a rise in lifting activity.”
The articles cites the example of a 40-tonne subsea module dropping to the seabed after a degraded crane wire failed, demonstrating the consequences of deferred maintenance — an issue that becomes more significant as operators dismantle ageing offshore infrastructure.
“Ageing infrastructure is another factor,” the article notes. “As assets mature, maintaining structural integrity and equipment performance becomes more challenging, particularly where inspection and maintenance tasks are deferred.”
As well as ageing assets, with equipment and structures that may have deteriorated over decades, several other key points are particularly relevant to decommissioning in terms of offshore lifting.
These include the tendency toward heavier and more unusual lifts — decommissioning often involves removing large modules, pipelines and subsea infrastructure that were never designed to be lifted again.
Changing conditions are also significant factors, as corrosion, marine growth and structural degradation can make lifts more complex than engineering drawings might suggest.
Commercial pressures, with projects often operating to tight schedules and budgets, creates a further challenge.
But the biggest threat in offshore lifting is often a combination of human behaviour, the Nopsema article notes, alongside production pressure and failures to follow safety controls, which can quickly turn routine lifts into serious incidents.
As offshore decommissioning accelerates in Australia over the coming decades, lifting safety will be a defining challenge.
Success may hinge not only on engineering and technology, but on robust planning, maintaining lifting equipment, and fostering a culture where workers not only adhere to strict safety protocols, but are empowered to stop operations when something does not look right.
SBM Offshore has signed the project financing of FSO Chalchi for a total amount of US$465mn, backed by a consortium of international banks and institutional investors.
It also includes partial insurance cover from China Export & Credit Insurance Corporation. The project financing will be drawn during the construction period and will become non-recourse after the FSO has started operations. The loans have a maximum tenor of 14 years post completion.
Right now undergoing construction, FSO Chalchi has been secured for a 20-year lease and operate contracts with Woodside Energy through its affiliate in Mexico, Woodside Petróleo Operaciones de México, S. de R.L. de C.V. (Woodside). Woodside is the Operator with 60% interests, while Petróleos Mexicanos enjoys rest of the 40% that makes up the Trion project joint venture.
Designed to hold around 950,000 barrels of crude oil, the new build FSO is based on a Suezmax-type hull and will be equipped with a Disconnectable Turret Mooring system designed by SBM Offshore.
To be moored in water depth of about 2,500 meters, the FSO will be deployed at the Trion field, located 180 km off the Mexican coastline and 30 km south of the US/Mexico maritime border.
Douglas Wood, CFO of SBM Offshore, said, “We welcome the signing of the project financing of FSO Chalchi, marking our first transaction combining commercial banks, institutional investors and support from an export credit agency. This financing structure demonstrates SBM Offshore’s ability to deliver innovative, long-term funding solutions for our clients and provides a scalable solution for potential new lease and operate projects.”
Upstream production and development company, Jadestone Energy, has brought online the first well at ~3,000 bopd as part of its 2026 Malaysia infill drilling campaign on the PM323 PSC.
Currently, the company is focussing on drilling the third contingent well which was confirmed for operations after the first two wells originally planned for the campaign. Identified in the 2023 infill programme, this well targeted the southwest extension of the East Belumut field.
The first of the two firm wells reported strong performance while the second was drilled on the basis of encouraging subsurface results. The Group's 2026 capital expenditure guidance[1] of US$50-80 million remains unchanged.
The company achieved 20% cost savings for operations in the first well, even though it was the longest well drilled on the East Belumut field. It involved tackling complex operations, targeting a 1,200 metre horizontal reservoir section in the well at a total measured depth of 4,866 metres.
T Mitch Little, Chief Executive Officer of Jadestone, said, "Our established operating capabilities in Malaysia, combined with our refreshed focus on operational excellence, have been further validated by the outcome of the EBA-18ST3 well. The result is an excellent start to this year's drilling campaign and will significantly increase our Malaysia production in the near-term against the backdrop of strengthened Brent oil prices, with our most recent Malaysia oil sales attracting a US$14/bbl premium to Brent.
"Following on from the significant progress on our Vietnam project earlier this year and the successful debt refinancing, this is further evidence of a business that is executing on its plan and strategy. We look forward to updating the market further on the second well in the campaign in the near-future."
Australia's biggest decommissioning and abandonment summit powered by Offshore Network, D&A 2026 AUS that was held in partnership with the Centre of Decommisioning Australia (CODA) saw engaging exchanges and knowledge sharing on industry hot topics
With CEO and Managing Director Francis Norman, General Manager Rean Gilbert, and Brand Leader Pawel Rybczynski, among others, CODA's esteemed presence on the exhibition floor was hard to miss.
As Australia's decommissioning challenges continue to grow, operators are having to adapt to smoothly deliver complex campaigns. There were insightful sessions led by spokespersons from the Department of Industry, Science and Resources; Chevron; ExxonMobil and Woodside Energy, who shared first hand experiences on the challenges of tackling complex projects such as FPSO removal or onshore reception centre development, to name a few.
Industry experts from the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), Unity and Archer to name a few, spoke on their challenges while delivering plug and abandonment projects. In such cases operators have to bear in mind the tactful balancing of factors such as costs, risks and regulations.
Representatives from NOPSEMA spoke on how the body's expectations are evolving with the needs of an ever-changing industry. There were talks on South Australia’s environmental liability management policy and a closer look at the regulatory updates from the NCS.
There were insightful sessions on regulatory priorities shaping P&A programmes, proven intervention strategies from real campaigns, and technologies improving efficiency and well integrity.
The conference reflected how Australia is building a robust, safe, responsible and economically sound decommissioning industry characterised by mature, repeatable execution models in the long term.
Global energy technology firm SLB has successfully secured a significant seven-year contract with the Kuwait Oil Company (KOC).
The landmark agreement, formed under the auspices of KOC’s flagship Ahmadi Innovation Valley (AIV) initiative, designates SLB as the very first contracted technology partner for the ambitious programme. This strategic alignment is explicitly designed to support applied research, the deployment of advanced technologies, and comprehensive digital innovation programmes that are closely aligned with Kuwait's long-term energy objectives.
The Ahmadi Innovation Valley serves as Kuwait Oil Company’s premier innovation platform. It has been strategically constructed to bring together industry leaders, academic institutions, and leading technology providers. The primary aim of this collaborative ecosystem is to address and overcome strategic technical challenges within the upstream energy sector. By fostering a cooperative environment, the initiative provides KOC with a highly flexible and structured approach to evaluate, pilot, and eventually deploy emerging technologies across its extensive operational network to ensure maximum efficiency.
Ahmad Jaber Al-Eidan, the chief executive officer of Kuwait Oil Company, highlighted the strategic importance of this new collaborative framework and its projected impact on the nation's broader industrial goals.
"Ahmadi Innovation Valley represents an important step in advancing technology leadership across Kuwait's energy sector," said Ahmad Jaber Al-Eidan. He further elaborated on the broader implications for the region, adding, "Through collaboration with leading technology partners, we are accelerating technology deployment, strengthening local capabilities and expanding knowledge transfer to support Kuwait's energy industry."
Under the newly established terms of the seven-year agreement, SLB will work intimately with KOC to evaluate, test, and deploy a multitude of advanced technological solutions. The scope of this partnership is vast, encompassing nearly 100 distinct projects that span a wide array of operational and strategic priorities. Key areas of focus for these ongoing projects include the integration of artificial intelligence (AI), industrial internet of things (IIoT) applications, production optimisation, advanced reservoir technologies, sustainable water management, and critical energy transition initiatives.
By leveraging these advanced digital systems, the collaboration aims to significantly improve upstream operations and mitigate execution risks. The utilisation of real-time sensor networks and advanced technological frameworks will enable the Kuwait Oil Company to process operational data more efficiently, optimise critical production parameters, and manage essential resources with a heightened focus on long-term sustainability.
Olivier Le Peuch, the chief executive officer of SLB, underscored the practical challenges of modernising the energy sector and the unique value that this dedicated partnership brings to the table.
"The energy industry has no shortage of technology. The challenge is deploying it at scale and turning innovation into operational impact," said Olivier Le Peuch. Reflecting on the collaborative nature of the new initiative, he added, "Ahmadi Innovation Valley brings together technology providers, researchers and operational teams to accelerate the evaluation, deployment and scaling of new solutions across KOC's operations. We are proud to contribute our technology, domain expertise and global experience while helping strengthen local capabilities and support the next generation of Kuwaiti talent."
To properly support the extensive technical requirements of the Ahmadi Innovation Valley initiative, SLB has also committed to establishing a permanent physical footprint within the region. As a core component of the overarching agreement, SLB plans to construct a dedicated Ahmadi Innovation Valley facility situated directly in Kuwait. The construction of this specialised technological centre is officially expected to begin in the year 2026, with the facility's grand opening planned for 2028. Once fully operational, this site will serve as a centralised hub for applied research and technology management, spanning multiple business lines and technology domains.
This newly awarded contract represents a major milestone in the enduring relationship between the two entities. It builds upon a robust foundation of collaboration between SLB and the Kuwait Oil Company that dates back more than 85 years. As the upstream energy sector continues to face complex transitional challenges, this renewed partnership ensures that both organisations are exceptionally well-positioned to drive digital innovation, enhance operational efficiency, and support the sustainable evolution of Kuwait’s vital energy infrastructure for the future.
Sonardyne, a specialist in underwater technology, has signed a MoU with international advanced engineering company, AMOG, to provide a complete subsea asset monitoring service for offshore energy infrastructure operators.
The partnership will combine Sonardyne’s underwater monitoring, positioning and communication technologies, with AMOG’s engineering assessment expertise to unlock asset insight, reduce downtime and enable life extension. The partnership will cover floating offshore wind and oil and gas moorings, as well as pipelines and risers.
The collaboration effort will include use of Sonardyne’s Observer wireless intelligent subsea asset integrity monitoring solutions.
Dr. Hayden Carcollo, Director of AMOG, said, “Combining high quality subsea data, processes at source on Observer, with advanced engineering assessment, will provide asset owners with more actionable, near real-time insight into the condition and behaviour of critical subsea infrastructure through a single solution.
“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, commented, “By integrating on-demand and long-term monitoring data from subsea environments with engineering models and analytics, there is 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.”
