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.”
RH Petrogas has commenced drilling operations at the Northwest Klagagi-1 (NWK-1) well under the Kepala Burung Production Sharing Contract (PSC) in Southwest Papua, Indonesia, marking another step in its ongoing gas development and exploration programme.
The well was spudded on 25 June 2026 by Petrogas (Basin) Ltd., the company's 82.65%-owned subsidiary. Located in the Arar block, around 15 km northeast of the Arar production cluster, NWK-1 is planned to reach a total depth of approximately 6,700 ft (2,000 m).
Drilling activities are being carried out using RH Petrogas' own rig, with the operation expected to take approximately 36 days to complete.
NWK-1 has been planned as a combined development and exploration well. Its primary objective is to support the development of gas resources within the upper Kais Formation. Once the development phase is completed, drilling will continue into deeper formations to assess additional hydrocarbon potential in the lower Kais Formation, the Oligocene-aged Sirga Formation and the underlying Devonian-aged Basement.
The drilling campaign forms part of the firm's work commitment under the Kepala Burung PSC and is intended to advance both near-term production opportunities and longer-term resource evaluation within the contract area.
Mr. Francis Chang, Group CEO and Executive Director, commented, "NWK-1 aims to advance the development of existing gas resources while evaluating additional growth opportunities within the contract area. Although drilling of the well has commenced later than initially planned, the delay created an opportunity to deploy the rig for well intervention activities in the nearby Arar block. Workovers were carried out on three wells, all of which were successful and delivered incremental production gains."
The successful workover programme in the nearby Arar block provided additional production before the drilling rig was mobilised for the NWK-1 campaign, supporting the company's strategy of optimising existing assets while pursuing further exploration potential within the PSC.
SLB has delivered the first reverse circulation cleanout using the powered downhole measurements system within its ACTive real-time downhole coiled tubing services, in an operation carried out on the Clair Ridge well in the UK North Sea.
The intervention was required by bp to support hydraulic fracturing operations at the field. The well presented a complex set of challenges, including pressure management, multiple zonal isolation requirements and internal diameter restrictions in the lower completion. Conventional reverse circulation cleanouts had offered limited real-time downhole visibility, raising the risk of pressure excursions, inefficient debris removal and nonproductive time.
To address this, SLB deployed a coiled tubing intervention incorporating the ACTive powered downhole measurements system, representing the first application of the technology during a reverse circulation cleanout. Continuous downhole pressure, temperature and casing collar locator measurements allowed for improved pressure management and earlier detection of screenout conditions.
Accurate casing collar correlation supported precise sleeve shifting and pressure testing, reducing the number of confirmation runs required and minimising time spent in the well. Controlled run-in-hole speeds and optimised operating procedures further reduced the risk of tool damage and debris accumulation.
As detailed in SLB’s case study, reverse circulation parameters were adjusted in real time based on downhole measurements, improving sand and proppant recovery while reducing total fluid volumes pumped. Enhanced debris removal at lower return rates supported efficient wellbore cleaning and subsequent post-fracture intervention activities.
Real-time collaboration was enabled through SLB’s InterACT secure wellsite data-delivery solution, improving alignment between offshore and onshore teams and supporting faster decision-making. The integrated approach established a repeatable workflow and benchmark for future offshore well interventions.
The Centre of Decommissioning Australia (CODA) has launched a Women in Decommissioning Special Interest Group (SIG), a new forum to support connection, visibility and collaboration across the decommissioning sector.
The group is designed to strengthen career pathways, knowledge sharing and mentoring opportunities for women working across the multidisciplinary decommissioning workforce, including engineering, environment, regulation, marine, logistics, commercial and related fields.
The SIG will be chaired by Carrie McIntosh of Xodus, supported by CODA General Manager Rean Gilbert as the CODA representative for the group, with Simona Chady of CB&I joining as a committee member.
“Decommissioning is going to need a broad and capable workforce, and that means drawing on the full talent pool available to the industry,” said CODA’s CEO Francis Norman.
“The Women in Decommissioning SIG is an important step in making sure the contribution of women in this sector is visible, supported and connected, while also strengthening the industry as a whole.”
Unlike CODA’s other Special Interest Groups — which include Well Abandonment, Decommissioning Project Management and Hazardous Materials Management — membership in the Women in Decommissioning SIG is open to CODA Partners and non-partners alike.
“This group gives women across the decommissioning sector a structured way to connect, share knowledge and build mentoring relationships, while also opening the door to broader participation across the industry,” said Rean Gilbert, CODA’s General Manager.
“While focused on supporting women in decommissioning, the SIG is open to all individuals, reflecting the role mixed teams play in shaping career pathways and opportunities across the sector.”
Talos Energy Inc has announced the execution of a definitive agreement to jointly acquire certain deepwater assets in the Gulf of America from Shell Offshore Inc, alongside an affiliate of Ridgewood Energy Corporation.
"We are pleased to announce the acquisition of these high-quality deepwater assets directly aligned with Pillar Two of our strategy. The bolt-on is highly accretive, materially enhances free cash flow, and includes Infrastructure-Led Exploration opportunities where our field life extension track record can unlock value beyond current reserves. We also see a clear pathway for operated development activity to compete for capital beginning in 2027, further supporting long-term value creation as we continue to advance our strategy to build a long-lived, scaled portfolio and become the leading pure-play offshore E&P," said Talos President and Chief Executive Officer, Paul Goodfellow.
Talos Executive Vice President and Chief Financial Officer, Zach Dailey said, "This strategic transaction in the Gulf of America is expected to be immediately accretive to key financial metrics and deliver long-term value while maintaining balance sheet strength and preserving financial flexibility. Importantly, the increased borrowing base reflects strong confidence from our lenders in the quality of the acquired assets, Talos's base business, and the financial framework that underpins our strategy. On a pro forma basis, we expect to maintain leverage consistent with our financial framework."
The acquisition holds highly accretive to key financial metrics for Talos as it will ensure low-cost, high-margin, oil-weighted production. It can potentially add proved reserves of approximately 23 million barrels of oil equivalent (MMBoe) and 10 MMBoe of probable reserves, with additional operated Infrastructure‑Led Exploration (ILX) opportunities supporting future growth. Production for the first quarter 2026 was 16 thousand barrels of oil equivalent per day (MBoe/d), ~77% oil.
In line with its previous guidance, Talos has also completed the Genovesa workover and returned the well to production late in the second quarter of 2026.
The first Monument development well was successfully drilled to its total measured depth of 32,250 feet and encountered 245 feet of net pay confirming pre-drill expectations. Drilling is set to commence on the second development well followed by completion operations on both wells. First oil is expected by late 2026.
The Company expects to update its 2026 operating and financial guidance for the Acquisition following closing.
Energy technology company, Baker Hughes, has been selected by ANOH Gas Processing Company (AGPC) for comprehensive lifecycle services, including parts, repair services and engineering advisory.
The company will also be delivering iCenter digital services for turbomachinery equipment at the greenfield ANOH Gas Processing Plant in Nigeria.
The agreement secures Baker Hughes’ role as a lifecycle solutions provider for one of the nation’s critical onshore gas projects. Baker Hughes services for the ANOH Gas Processing Plant goes back to 2019, when the company supplied an integrated power island solution for the facility, inclusive of two NovaLT 16 gas turbines – the first supplied in Sub-Saharan Africa – along with compressors and gears.
The service agreement covers essential maintenance and repairs for the plant’s critical equipment, including two NovaLT 16 gas turbines. In addition to providing local engineering support, Baker Hughes will deploy iCenter digital services, powered by Cordant, for remote monitoring and diagnostics to enhance equipment reliability, availability and optimized operations.
“It is a pleasure to collaborate with a globally trusted energy technology leader like Baker Hughes on this critical project,” said James Makinde, Managing Director at ANOH Gas Processing Company. “The reliable performance of critical turbomachinery equipment is essential to the successful operation of the ANOH Plant and to delivering on Nigeria’s domestic energy supply goals.”
“This long-term agreement is a testament to our successful collaboration with ANOH Gas Processing Company and the trust placed in our lifecycle service capabilities,” said Baker Hughes Chief Growth & Experience Officer and interim Executive Vice President of Industrial & Energy Technology Maria Claudia Borras. “We are leveraging our regional expertise and pairing it with our advanced digital technologies and services, supporting the delivery of reliable, efficient and affordable power solutions and helping Nigeria realize its goal to move to lower-carbon fuel sources.”
ADNOC Drilling has announced the delivery of its state-of-the-art AD-300 rig, which it calls the first AI-enabled, fully automated walking island rig.
Delivered nearly three months ahead of schedule, it combines automation, AI, digital technologies and hybrid power capability, with optional grid connectivity, to enhance safety, reduce downtime and improve well delivery efficiency, and will work offshore UAE for ADNOC.
“The delivery of AD-300 marks a step-change in how we execute large-scale, technology-enabled energy development,” said Abdulla Ateya Al Messabi, CEO of ADNOC Drilling.
“By integrating automation, artificial intelligence and robotics at scale, we are enhancing safety, improving efficiency and delivering more consistent, predictable performance.”
Standing 50 metres tall, the height of a 15-storey building, and weighing around 2,000 tons, AD-300’s advanced technology and energy features will enable more efficient and lower-emission operations, according to ADNOC Drilling.
Its automated walking capability allows it to move seamlessly between well locations without dismantling, while automation systems, such as automated pipe handling and AI-enabled monitoring, help minimise personnel exposure in complex operating environments.
Integrated data systems also provide real-time operational insights for performance optimisation and predictive maintenance.
It is the first of six next-generation rigs on order under a US$1.54bn drilling services contract.
“As the first of six rigs under this programme, AD-300 demonstrates our ability to deliver complex, high-value assets ahead of schedule, accelerating revenue generation while supporting ADNOC’s production capacity expansion and reinforcing the UAE’s leadership in advanced energy solutions,” said Al Messabi.
The first rig, AD-301, is currently being deployed, with the remaining rigs scheduled for delivery through 2027.
ADNOC Drilling hopes the early rig delivery will enable earlier revenue generation and accelerate the rollout of its next-generation rig programme.
“At a time when the world needs reliable energy at scale, the UAE stands ready to supply global customers,” said Tayba Abdulrahim Al Hashmi, CEO of ADNOC Offshore.
“AD-300 and our next-generation island rigs are accelerating our growth, expanding ADNOC's production capacity and delivering long-term value for our stakeholders and the nation.”
The International Marine Contractors Association (IMCA) has published new guidance designed to improve safety during subsea decommissioning and dismantlement projects, which could significantly benefit the Asutralian decommissioning industry given its relatively limited experience of large-scale dismantlement projects.
As offshore oil and gas assets around the world reach the end of their operational life, decommissioning activity is expected to increase significantly over the next decade. No more is this more so than in Australia, which is entering a sustained phase of decommissioning activity, as fields mature and infrastructure that has supported oil and gas production since the 1960s comes to the end of its productive life.
IMCA’s Guidance on diving operations in support of subsea decommissioning and dismantlement projects (IMCA D090) has been developed to help contractors, operators, and project teams better understand and manage the unique operational and safety challenges associated with dismantling ageing subsea infrastructure, which is creating an increasingly high-risk environment for commercial diving operations. Increased vessel activity, heavy lifting operations, subsea cutting, breaking containment, diver intervention and simultaneous operations taking place within restricted work areas all pose potential hazards.
Decommissioning projects frequently involve structures that were never designed to be removed. With ageing facilities, engineering records may be incomplete or inaccurate, and the actual subsea condition of assets can differ significantly from original drawings or assumptions made during project planning.
The IMCA warns that incidents during decommissioning are frequently linked to assumptions about asset condition or reliance on outdated information. The guidance therefore places strong emphasis on verifying “as found” conditions throughout the project lifecycle and ensuring effective transfer of historical information between all parties involved.
The document also recognises that conditions can evolve rapidly as dismantlement progresses, requiring continuous reassessment of hazards and control measures.
Particular emphasis is placed on the Management of Change (MOC) process, given that changes to scope, methodology, equipment, sequence of work or environmental conditions are common during decommissioning campaigns, and that failures to identify or properly manage those changes have contributed to a number of high-potential incidents.
The guidance reinforces the need for formal, disciplined MOC procedures supported by clear communication, documented verification processes, and a shared operational understanding across project teams.
It also suggests looking at alternatives to diver intervention such as remote systems or engineered alternatives wherever reasonably practicable.
Where diving operations are unavoidable, IMCA states they should only proceed with robust planning, verified information, clearly defined controls, and a safety culture that empowers personnel to question assumptions and exercise stop-work authority where concerns exist.The document also addresses a range of hazards commonly associated with subsea decommissioning activities, including subsea cutting techniques, lifting operations, residual hydrocarbons, stored energy, and contaminated environments.
Bill Chilton, Diving Manager at IMCA, said, “Subsea decommissioning and dismantlement activities present a distinct and increasingly prevalent set of hazards for divers. Where incidents have occurred, experience shows many could have been avoided through better planning, more rigorous verification of conditions, and disciplined management of change procedures.
“Many offshore structures now reaching the end of their operational life were installed long before dismantlement was ever considered. They were designed to operate, not necessarily to be removed safely decades later. That creates a very different risk profile for diving teams working subsea.”
The guidance is available through the IMCA Technical Library.
Angus Energy plc, a UK AIM-listed independent oil and gas company, has reported significant operational progress in its interim results for the six months ended 31 March 2026, with its well intervention programme at the Saltfleetby Gas Field delivering a substantial increase in production
During the period, the company successfully completed workovers on two producing wells at Saltfleetby, its flagship gas asset. The intervention programme was carried out safely and efficiently, resulting in production rates increasing by approximately 30% compared with pre-workover levels. The improved output has been maintained beyond the reporting period.
Angus Energy said the production uplift is expected to support stronger revenues and cash flow generation, while the company continues to evaluate further opportunities to optimise field performance and maximise the value of its reserves.
The company is also progressing reservoir modelling activities and assessing future development opportunities aimed at extending the operational life of the Saltfleetby field.
Alongside its gas operations, Angus Energy reported continued improvements at the Brockham Oil Field. Following a series of operational optimisation measures, average production rates have nearly doubled compared with levels recorded in early 2025. The company also highlighted improved operational efficiency and a continued reduction in water cut, which has supported enhanced field performance.
Preparations are also underway for the planned return of the BRX4z well at Brockham to production from the Portland reservoir, which Angus Energy believes could further improve production and cash flow from the field.
The company has continued efforts to strengthen its financial position through the restructuring of its financial obligations. Discussions with creditors and stakeholders have progressed, with Angus Energy expecting the process to provide a stronger balance sheet, improved liquidity and a simplified capital structure.
The company has also expanded its gas hedging arrangements through to June 2027. The combined hedge portfolio now covers approximately 12.3 million therms at an average weighted price of around 100 pence per therm, providing greater revenue visibility while maintaining exposure to potential future gas price increases.
For the six-month period, Angus Energy generated revenue of £9.5 million (approx. US$12.8 million), EBITDA of £5.3 million (approx. US$7.1 million) and operating profit of £1.5 million (approx. US$2 million). The company also generated £4.4 million (approximately US$5.9 million) in net cash from operating activities.
Despite continued volatility in commodity markets, Angus Energy remains positioned as a significant UK onshore gas producer. The company noted that approximately 56% of forecast production remains unhedged, allowing it to benefit from favourable gas market conditions.
The company maintained safe operations throughout the period, reporting no health, safety or environmental incidents.
Looking ahead, Angus Energy’s priorities include completing the restructuring process, restoring trading in the company’s shares and building on operational improvements across its portfolio. The company plans to explore further organic and inorganic growth opportunities, including potential mergers and acquisitions.
TechnipFMC has been appointed by Azule Energy to supply flexible flowlines and risers for the Greater PAJ development offshore Angola.
The flowline and risers network will be manufactured and designed to connect wells in water depths approaching 2,000 meters to a new floating production unit.
Jonathan Landes, President, Subsea at TechnipFMC, said, “This award builds on expertise we have developed on large, deepwater projects in the region, including our proven flexible pipe technology. We are proud to be chosen to deliver a technically robust solution on an accelerated timeframe that creates value for our client.”
Previously, TechnipFMC had generated impressive profit from Nigeria's Bonga North deepwater project, delivered for Shell Nigeria Exploration and Production Company Limited. The company supplied Subsea 2.0 production systems for the project, with work covering the design and manufacture of subsea tree systems, manifolds, jumpers, controls and other services.
Shell’s Bonga North development off Nigeria is being developed as a subsea tie-back to the Bonga floating production storage and offloading (FPSO) facility, located in block OML 118, in water depths over 1,000 metres.
It includes drilling, completing and starting up 16 wells (eight production wells and eight water injection wells), modifications to the existing FPSO and the installation of new subsea hardware tied back to the facility.
Bonga North currently has an estimated recoverable resource volume of more than 300 million barrels of oil equivalent (boe) and will reach a peak production of 110,000 barrels of oil a day, with first oil anticipated by the end of the decade.
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