SLB, a global energy technology company, has launched the OnWave autonomous logging platform, a first-of-its-kind solution designed to improve the efficiency and safety of formation evaluation in all well conditions.
The OnWave platform operates without the need for a wireline unit or cable. Its cable-free design allows it to be deployed in less than half the time of traditional wireline systems. It also permits drill pipe rotation and mud circulation during operations, reducing the risk of stuck pipe incidents and boosting overall well safety.
“The OnWave platform marks the beginning of a new era in formation evaluation,” said Frederik Majkut, president of Reservoir Performance at SLB. “By streamlining how we gather high-fidelity measurements downhole, we are opening up key opportunities for our customers to integrate data-driven decision making into their workflows across the well life cycle — from exploration through to production and recovery, he added.
The platform can be used in any well trajectory and does not require an SLB crew onsite. It autonomously handles key downhole tasks that would normally need surface-based engineers, including data acquisition and quality control. Uniquely, it maintains continuous communication with the surface, confirming tool status and position in real time — something most wireless logging systems cannot do. This ensures data quality and avoids the need for repeat runs.
The OnWave platform has been deployed successfully in various regions, including the United States and the Middle East. In South Texas, it cut landing time to total well depth from hours to just 27 minutes, a 70% reduction compared to traditional methods. Data processed at the surface delivered high-quality petrophysical and acoustic insights, enabling better completion and stimulation design, and helping to derisk field development for the operator.
Woodside Energy has assumed operation of assets in the Bass Strait following a historic agreement with ExxonMobil Australia, unlocking potential development of additional gas resources.
From completion, Woodside will assume operation of the offshore Bass Strait production assets, the Longford Gas Plant, the Long Island Point gas liquids processing facility and associated pipelines.
As operator, Woodside will take on the responsibility for asset planning and execution activities, pursuing a value maximisation strategy that targets further production and reliability improvements. This move combines Woodside’s existing global operations with ExxonMobil’s experience workforce in the Bass Strait who will transfer to the operator.
The agreement also created flexibility to realise future development opportunities that meet Woodside’s capital allocation framework. The operator has identified four potential development wells that could deliver up to 200 petajoules of sales gas to the market. Under the agreement, Woodside can solely develop these opportunities through the Bass Strait infrastructure subject to the further technical maturation and a final investment decision.
Woodside EVP and COO Australia, Liz Westcott, said, “As a proudly Australian company, Woodside support essential domestic energy needs in both Western Australia through the North West Shelf, Pluto and Macedon operations, and on the east coast through its equity participation in Bass Strait.
“Taking operatorship of Bass Strait demonstrates Woodside’s continued commitment to meeting Australia’s domestic energy demand while maximising the value of existing infrastructure.”
L&T Energy Hydrocarbon Offshore has received a substantial order from a major client in the Middle East.
The company made the announcement on 29 July, explaining that the order covers numerous offshore packages, including engineering, procurement, construction, and installation of offshore structures, as well as upgrades to existing facilities. The order is worth more than US$1.7bn, according to a press statement issued by the company.
L&T did not name the client or the country it will be operating in.
Calling it an 'ultra-mega' order, L&T said that its hydrocarbon offshore vertical helps the offshore oil and gas industry in a significant manner, and is the main provider of engineering, procurement, construction, installation, and commissioning (EPCIC) solutions.
With strong in-house engineering capabilities, cutting-edge manufacturing yards, and a dedicated fleet of marine vessels, L&T has a proven track record in both shallow and deep-water field development.
Over the last three decades, it has completed complicated projects requiring permanent platforms, subsea pipes and structures, brownfield renovations, and decommissioning.
L&T added that "this ultra-mega order demonstrates the speed and precision with which the Hydrocarbon Offshore business vertical delivers complex projects around the world while complying to world-class safety standards."
Larsen & Toubro is a US$30bn Indian multinational that specialises in EPC projects, high-tech manufacturing, and services across different regions.
In March this year, the company had bagged another ultra-mega project from QatarEnergy LNG.
Qatar had awarded L&T an offshore contract for the North Field Production Sustainability Offshore Compression Project (NFPS COMP), making it the largest single contract ever received by the company at the time.
The scope of work included the engineering, procurement, fabrication, installation, and commissioning of two offshore compression complexes, each consisting of large offshore platforms with compression and power generation facilities, living quarters, flare platforms, interconnected bridges, and other associated structures to be located approximately 80 km off the northeast coast of Qatar.
Commenting on the Qatari development, S.N. Subrahmanyan, Chairman and Managing Director – L&T had commented, “Securing QatarEnergy LNG’s Ultra Mega Offshore Contract – largest single order in our history, is a landmark achievement. This prestigious project strengthens our global energy portfolio while supporting Qatar’s energy security objectives. We look forward to setting new benchmarks in project execution that will reinforce Qatar’s position as a global LNG leader.”
Saipem and Subsea7 have entered into a binding merger agreement to create a global leader in energy services, reaffirming the terms outlined in their February 2025 Memorandum of Understanding.
Both companies provide well upgrades and other services.
The new combined entity, to be called Saipem7, will be headquartered in Milan and listed on both the Milan and Oslo stock exchanges.
With an estimated annual revenue of €21bn, EBITDA exceeding €2bn, and a combined project backlog of €43bn, Saipem7 aims to position itself as a dominant force in offshore energy projects.
The merger brings together two highly complementary businesses, combining their geographic footprints, technologies, fleets and client portfolios.
No single entity will represent more than 15% of the overall backlog, underscoring the diversified nature of the business.
On completion, expected in the second half of 2026, shareholders of Saipem and Subsea7 will each own 50% of the new entity.
Subsea7 shareholders will receive 6.688 new Saipem shares per share held and a €450mn extraordinary dividend prior to closing.
Leadership will reflect a balanced governance structure: Mr Kristian Siem is expected to chair the board, while Mr Alessandro Puliti is set to become CEO. The Offshore Engineering & Construction business will be managed under a separate company, Subsea7 – a Saipem7 company – with Puliti and Subsea7’s John Evans leading as Chairman and CEO respectively.
The deal is backed by major stakeholders Eni, CDP Equity and Siem Industries, who have signed a shareholders’ agreement and committed to vote in favour.
The merger is expected to deliver €300mn in annual synergies, with added benefits to clients through enhanced project scheduling, expanded fleet capabilities, and integrated life-of-field services across oil, gas, and carbon capture.
Esso Australia has spent more than US$2.5bn in early decommissioning works in the Bass Strait so far as it dismantles infrastructure in the area — with the Barry Beach Marine terminal as integral to future work as it was in the establishment of the region’s offshore industry decades earlier.
The spend so far includes the permanent plug and abandonment of more than 200 wells, according to Richard Perry, a project manager for the company.
“This work will continue through to 2027, when we will then be ready to decommission by removing the platforms and transporting them to shore for dismantling and recycling,” he wrote in a recent update.
The group’s work in the Bass Strait represents perhaps Australia’s biggest decommissioning project.
The Strait is home to 19 offshore platforms that have produced oil and gas that has played a vital role in powering Australian homes and businesses and supported the nation’s energy security since the late 1960s.
Today, it supplies much-needed gas to south-east Australia from only six of these facilities.
“While ongoing investments will see us maintain our reliable supply of gas from Bass Strait into the 2030s, we are also decommissioning the 13 offshore facilities that are no longer producing oil and gas,” noted Perry.
However, decommissioning an offshore platform is a complex, multi-stage process, he added in a community outreach note.
“It begins with well plug and abandonment, which permanently seals the wells underneath the platform that have provided access to the oil and gas resources below the seafloor. Some of our platforms have up to 37 wells, while others have only a few. We then carry out essential maintenance including cleaning and disconnecting all pipelines from the platform.”
The Pioneering Spirit, the world’s largest construction vessel, will cut, lift and transfer the topsides and jackets from offshore platforms, onto barges for transport to the Barry Beach Marine Terminal, where they will be offloaded for dismantling and recycling.
For nearly 60 years, the terminal has played a central role in supporting Esso Australia’s Bass Strait operations, and will continue to do so as the emphasis shifts to decommissioning.
“The terminal has played a critical role in our safe completion of over US$2.5bn in early decommissioning works, including the permanent plug and abandonment of more than 200 offshore wells,” said Perry.
That incudes the safe recycling and disposal over 10,000 tonnes of steel and concrete at the terminal — around as much as the Eiffel tower weighs.
“As we move into the next phase of decommissioning, the terminal will continue to serve as our primary marine base, supporting both ongoing gas production and the safe, environmentally responsible and efficient removal of offshore infrastructure.”
The Middle East and Africa well intervention market, valued at US$2.4bn in 2024, is projected to reach US$4.6bn by 2034, driven by a 6.4% CAGR, fueled by the region's focus on ageing oilfields and rising energy demands.
These figures, published by Global Market Insights (GMI), also reveal that this growth is evident in recent activities across Saudi Arabia, the UAE, and Egypt, where advanced well intervention techniques are enhancing oil and gas production. According to GMI, the offshore segment in this industry is expected to grow by 7% between 2025 and 2034.
In Saudi Arabia, the well intervention market is expected to reach US$510mn by 2034, propelled by extensive proven oil reserves and a focus on mature fields. In July 2024, Saudi Aramco announced discoveries in the Eastern Province, including two unconventional oil deposits, a light oil reservoir, and multiple gas fields, with the Al-Ladam field’s Ladam-2 well producing 5,100 barrels of very light Arabian oil and 4.9 million standard cubic feet of gas daily. These discoveries necessitate well intervention techniques like hydraulic fracturing and acid stimulation to optimise output from low-pressure wells and shale reserves, addressing the increasing presence of such assets.
In the UAE, ADNOC’s US$1.7bn contract awarded to ADNOC Drilling Company in May 2024 for 144 unconventional oil and gas wells is actively progressing this year. Well intervention services, including coiled tubing and wireline logging, are critical for maintaining well integrity and boosting production efficiency in these unconventional resources, reflecting the region’s shift toward complex geological challenges.
In Egypt, BP Egypt’s discovery of a substantial gas reservoir near its Temsah offshore operations in September 2024 spurred increased well intervention activities by July 2025. Companies deployed advanced logging services to assess reservoir changes and optimise production, driven by rising energy consumption and urbanisation. These efforts align with the region’s growing focus on deep and ultra-deep-sea explorations, where well intervention is essential for sustaining output.
Technological advancements are pivotal. In February 2024, Odfjell Technology opened a 10,000 sq m facility in Saudi Arabia’s Eastern Province, enhancing wellbore maintenance and intervention operations. By June 2025, this facility supported expanded drilling and intervention with new machinery and workforce growth. Strategic partnerships and mergers are also strengthening market positions, with companies investing in R&D for innovative intervention tools tailored to mature fields.
Government initiatives are fostering growth. Policies in Saudi Arabia and the UAE prioritise developing mature fields, with the zonal isolation segment expected to generate significant revenues by 2034. These efforts reflect a regional strategy to meet energy demands while extending the life of existing oil and gas assets through advanced well intervention techniques.
The newly rebranded MENA WELLS 2025 is set to bring together the Middle East and North Africa’s leading well operations professionals on 9–10 September 2025 at the Bab Al Qasr Hotel, Abu Dhabi.
Previously known as OWI MENA, the event has been refreshed to cover the entire well lifecycle — from integrity and intervention to decommissioning and productivity — reflecting the evolving needs of the industry across both onshore and offshore assets.
This year’s agenda is packed with more than 25 expert presentations, 10 live technology demos, and five dedicated networking sessions, offering valuable insight and opportunities to connect. Delegates will also benefit from exclusive access to PDO’s Workover Journey Workshop and the IMCA Regional Meeting, making it one of the most comprehensive well-focused gatherings in the region.
Senior engineers, technical leads, and decision-makers from organisations including ADNOC, Petrobel, PDO, and EGPC will take the stage to share real-world case studies and practical lessons. Topics include advanced well diagnostics, expanding the use of glass plug and steel patch technologies, managing legacy assets, and improving diver safety during subsea decommissioning.
New sessions will also highlight how AI, data analytics, and next-gen materials are reshaping maintenance planning and enhancing long-term well integrity. Whether you’re involved in drilling, completions, production, or abandonment, MENA WELLS 2025 delivers timely, relevant content to help teams boost performance while meeting rising safety and sustainability expectations.
The event is designed to support collaboration and knowledge exchange — from the technology showcase hall to the VIP meeting area, where sponsors, operators, and solution providers can discuss projects and build strategic partnerships in a focused setting.
"It was an amazing conference where we learned about new technologies and some very good presentations on production optimization and plug and abandonment." said Muhammad Farooqn Zubair, Senior Completion and Workover Engineer, ADNOC.
Early bird rates are available until 8 August 2025, so now is the time to secure your place. For full information, download the brochure at https://events.offsnet.com/MENAWells2025#/Brochure
Petrobras operations offshore Brazil at water depths of around 1,500 m saw the deployment of thermoplastic composite pipes by Strohm as part of its first field trials.
Conducted last month in the Campos Basin, the testing and engineering assessments have reflected exceptional durability under harsh offshore environment following a smooth installation process in lines with the standard flexible pipe installation vessels which Petrobras' fleet are originally equipped with.
During the trial run, Strohm's TCP followed the exact methodologies that drive conventional flexible pipes, while keeping the Brazilian market in mind.
The pipe has undergone crushing and deep immersion performance (DIP) tests, as well as subsea first and second-end vertical connection tests. As part of the process, the pipe was installed in a catenary configuration in which it was kept for 24 hours to assess its behaviour under normal operational conditions.
The tested TCP is suitable for post-salt wells and the tests results provided valuable learnings that will support the qualification of TCPs for pre-salt applications as well. Since the technology is resistant to stress corrosion cracking caused by CO₂ - one of the major challenges in the area, it shows strong potential as a definitive solution for the pre-salt cluster offshore Brazil
Furthermore, TCP has a significantly smaller carbon footprint compared to conventional flexible pipes due to the materials used and its light weight, leading to lower transportation and installation costs. It can be installed using vessels currently available in the market, and further, due to its light weight, also enables simpler and more cost-effective installation methods to be deployed, such as the subsea pallet.
Renato Bastos, VP Brazil at Strohm, said, “This successful phase marks the culmination of a remarkable collaboration between Petrobras and Strohm throughout the last few months and the field trial results are proof of the innovation and quality that TCP brings to the industry. The technology has the potential to transform the global deepwater market and unlocks a huge potential for us in Brazil.
“This is the first offshore trial for Petrobras to include thermoplastic composite pipes, and it’s a testament to our companies’ longstanding relationship. The success of the field trial paves the way for wider adoption of our technology in the country, keeping us on track to fulfil our commitment to becoming the leading composite pipe supplier to Petrobras, as well as preparing for local production.”
Gustavo Calazans, Subsea Engineering General Manager, added, "This is an important milestone of our Subsea Industrialization Program in which Strohm is a key partner. This result strongly contributes to accelerate the installation of a new plant in Brazil bringing not only technological advances, but also competitiveness, an increase in local content, and cost reduction for Petrobras' projects. As the largest flexible pipe consumer in the world and with a strong demand forecast in the coming years, we welcome Strohm's entry into the Brazilian market with great expectations."
Decommissioning activities can be complex and challenging, and unexpected costs can often arise.
This is illustrated by some of the challenges faced by Woodside, which is currently executing multiple complex decommissioning activities offshore Australia. In its Q2 2025 report it outlines progress in the quarter.
“We successfully completed the plugging of the Minerva and Stybarrow wells. Removal of other equipment at the legacy Minerva, Stybarrow and Griffin assets has been impacted by unexpected challenges, with further engineering and alternative solutions required. Whilst this has had some cost impacts, we are applying learnings to improve planning and execution,” said Woodside CEO Meg O’Neill.
The company successfully completed the plug and abandonment of the three remaining wells at the Minerva field, offshore Victoria, as well as concluding the 10-well Stybarrow plugging campaign. It recovered around 45% of the Minerva pipeline across State and Commonwealth waters. However, activities had to be suspended due to challenges to pipeline recovery and adverse weather conditions, with recommencement depending on vessel availability.
Woodside continued decommissioning activities in the Bass Strait, including the submission of environmental approvals and plugging of 22 wells.
The company is currently evaluating decommissioning work plans for Minerva, Stybarrow and Griffin.
“The as-left condition on some closed sites has continued to present challenges for safe and efficient execution of decommissioning,” the company said, adding that these challenges have pushed up spend and cost estimates.
O’Neill said the company continued to demonstrate operational excellence and world-class project execution over the second quarter, with a focus on driving future growth and value.
On its website, Woodside underlines its commitment to executing decommissioning activities with a focus on safety and the environment, coupled with efficiency. “Decommissioning is integrated into project planning and operations, from the early stages of development through to the end of field life. This includes conducting assessments to inform our planning and decision making, which is underpinned by science and marine research. In the developing regulatory environment, we continue to listen, learn and respond to our stakeholders, while expanding our global decommissioning experience,” the company says.
Woodside’s decommissioning approach recognises the importance of reusing and recycling material from its decommissioning activities where possible. Its waste mitigation hierarchy prioritises reduction, reuse, recycling, and treatment over disposal.
The floating production storage and offloading (FPSO) vessels deployed for a significant deepwater gas development in the Turkish area of the Black Sea will be equipped with titanium stress joints (TSJ) over the next two years
The US$31mn deal has been bagged by precision engineering group, Hunting plc, who will be delivering six TSJs as part of phase three of the major project. These TSJs, which will be arriving from the company's Subsea Spring business unit in Houston, Texas, are backed by patented 'Direct Pull-thru Tube' technology. The TSJs will be used on the second and third vessels serving the project.
Hunting is also serving the phase two development contract that was reached last year, with completion awaited in 2026. The back to back awards have generated US$51.6mn in revenue for the company.
Speaking of the latest contract, Jim Johnson, Chief Executive, said, "Our continued success in the Turkish area of the Black Sea demonstrates the international demand and strength of Hunting's titanium stress joint product offering. This order continues the Group's run of success deploying this product line into key offshore regions including the Black Sea, Guyana, and the Gulf of Mexico.
"Our revenue opportunities have also been expanded with the acquisition of FES in June, which forms part of our 2030 Strategy to target revenue from the longer cycle segment of the industry, which is less impacted by short-term commodity price volatility."
Expro has launched its most advanced BRUTE High-Pressure, High Tensile Packer System to date.
This new system is built to perform in extreme deepwater well conditions, handling the highest differential pressures in the industry. It allows operators to set higher in the wellbore, helping save rig time, reduce operational risks, and meet regulatory requirements more easily.
A key part of this launch is the BRUTE Armor Packer, a major step forward in Expro’s BRUTE range. This system offers unmatched strength and flexibility, with the ability to fully support 20k deepwater projects. When paired with the BRUTE 2 Storm Valve, it forms the most highly rated Storm/Service Packer and Valve combo available in the market, according to the company.
This latest technology was first used in a high-spec 20k deepwater project in the Gulf of America for a major energy company. In April 2025, Expro successfully deployed the 12.25” BRUTE Armor Packer System rated to 12,850 psid. The test confirmed the system's ability to handle extreme downhole pressures, proving its reliability in demanding offshore settings.
Following this success, Expro also introduced a new 20”/22” BRUTE Packer System. This tool was designed to overcome previous challenges faced by retrievable mechanical packers in large casing sizes. Traditional systems often struggle with tight internal diameters in subsea wellhead housings and casing adapters. Expro’s new packer offers double the expansion of standard systems, improving casing isolation for testing, suspension, and squeeze operations—without limiting performance.
In June 2025, the new 20”/22” packer was successfully used in a major offshore campaign in the Gulf of America. It passed through tight wellhead areas and expanded fully in a larger ID section below. The system achieved pressure integrity on the first try, confirming its ability to reduce rig time and risk while improving efficiency.
Jeremy Angelle, Vice President of Well Construction at Expro, said,“This launch sets a new standard for deepwater packers. The BRUTE system offers top-level pressure and tensile performance with unmatched adaptability. It proves Expro is leading the way in supporting the future of 20k offshore developments. We're not just meeting the industry's toughest standards – we're defining them.”
Serica Energy plc, a UK-based independent upstream oil and gas company with a focus on the North Sea and a production portfolio comprising over 85% gas, has released an operational update reflecting its continued development.
Mitch Flegg, Chief Executive Officer of Serica Energy, commented, "I am delighted with the significant progress that Serica has continued to make during 2022. The impact of the substantial investment programmes undertaken in the last three years has seen increased production levels providing responsibly sourced gas to the UK domestic market, protecting security of supply, and reducing the UK’s reliance on imports as part of the transition to a lower carbon future.
Commodity prices have been exceptionally strong during the period with a resulting positive impact on income.
Serica has no debt, limited decommissioning liabilities and with growing cash reserves is well positioned to continue to invest in further projects and other opportunities to add shareholder value. We have just completed a well intervention campaign on Bruce that has boosted net production by over 3,000 boe/d and provides further evidence of the value in Serica’s assets that can be realised through measured and expert operatorship.
Operations have also commenced on the North Eigg exploration well with potential for transformational results, while we are now accelerating further well intervention work on Bruce and Keith following the success of the recently completed campaign.”
Bruce Field light well intervention results
Serica recently completed its inaugural Light Well Intervention Vessel (LWIV) campaign, which concluded safely and without any environmental issues. This campaign aligns with Serica’s strategy to enhance value and extend the operational lifespan of the Bruce facilities.
The first well (Bruce M1) was accessed for the first time since 1998. Following successful scale removal and water shutoff, extensive reperforation and new perforation activities were carried out, leading to a production increase from approximately 400 boe/d to over 1,800 boe/d as of July 2022.
A similar approach was implemented on Bruce M4, where production rose from around 450 boe/d to over 2,400 boe/d. The strong results from both wells surpassed expectations and are expected to positively impact independently assessed reserves. The successful execution of this programme has boosted confidence in the potential of future well interventions.
As capital investment in the Bruce and Keith fields qualifies for investment relief under the UK’s recently introduced Energy Profits Levy, Serica is now fast-tracking additional interventions on other Bruce and Keith wells, both subsea and platform-based.
Page 1 of 95
