bp and Eni venture, Azule Energy, has announced start-up of gas production from the Quiluma field, part of the New Gas Consortium (NGC) in Angola, which is initially expected to reach 150 mn standard cu/ft per day and ramp up to 330 mn standard cu/ft per day by the year end.
A first for Angola's non-associated gas development, the NGC project is driven by gas produced from the shallow water offshore Quiluma field. This gas is directed for export from the Angola LNG plant following treatment at an onshore processing facility.
Azule Energy is operator of the NGC, with a 37.4% participation, in partnership with Cabinda Gulf Oil Company (CABGOC) with 31%, Sonangol E&P with 19.8% and TotalEnergies with 11.8% and ANPG as the National Concessionaire.
Gordon Birrell, bp’s executive vice president for production and operations, and Azule board member, said, "The safe delivery of the NGC project is another example of bp’s strategic progress and demonstrates what strong partnerships and collaboration can deliver. This project marks an important step for Angola’s energy system and strengthens the country’s energy mix as it looks to enhance its position as a global player in the natural gas market.”
This development comes following the inauguration the project’s gas treatment plant in November 2025. The NGC start-up is the latest in a series of upstream advancements such as the Agogo field at the Agogo Integrated West Hub (Agogo IWH) project, in block 15/06, offshore Angola, and the Ndungu start-up in February 2026.
Energy technology company, SLB's joint venture, OneSubsea, has signed an agreement to initiate the acquisition of Norway-based Envirex Group AS' subsea business.
The transaction makes Envirex's subsea segment part of SLB OneSubsea, with the former's specialised technologies and research and development expertise adding to the latter's global technology portfolio. This timely launch in a ever-dynamic subsea market will advance the deployment of new technology solutions, providing global clients with a diverse range of innovative services to choose from.
"This agreement represents a natural next step in a collaboration that has developed over more than a decade,” said Mads Hjelmeland, chief executive officer of SLB OneSubsea. “Once completed, the transaction would strengthen our technology portfolio and enhance the value we deliver to our customers."
The transaction is expected to close in the first half of 2026, subject to regulatory approvals and other customary closing conditions.
Based in Oslo and Houston, SLB OneSubsea is a joint venture by SLB, Aker Solutions and Subsea7. The joint venture is working to define a new era of subsea services by leveraging technology and innovation for a sustainable offshore industry.
Equinor has commenced drilling operations for one of Brazil’s most significant natural gas projects
The Raia project in the pre salt of the Campos Basin, Brazil, which represents Equinor’s largest international investment to date, has recoverable reserves exceeding one billion barrels of oil equivalent, and is due to start up in 2028.Once completed, the project, operated by Equinor (35%), in partnership with Repsol Sinopec Brasil (35%) and Petrobras (30%) will have the capacity to export up to 16 million cubic metres of natural gas per day, potentially representing 15% of Brazil’s natural gas demand.
The drilling campaign, which is being carried out by the Valaris DS-17 drillingship, includes six wells in the Raia area, located around 200 kilometres offshore Brazil in water depths of around 2,900 metres. Wells will be connected to an FPSO, which will treat produced oil/condensate and gas, with natural gas being transported via pipeline to Cabiúnas, in the city of Macaé, Rio de Janeiro state.
Drilling activities build on the companies’ combined competence in deepwater operations, including previous experience on the Bacalhau field, where the DS 17 also took part in the drilling campaign.
“Raia is Equinor’s largest project under execution and marks the deepest water depth operation in our portfolio. Together with our partners and suppliers, we are applying world-class technology and decades of offshore expertise. While drilling takes place, integration and commissioning activities on the FPSO are progressing well putting us on track towards a safe start of operations in 2028,” said Geir Tungesvik, executive vice president, Projects, Drilling and Procurement at Equinor.
Brazil represents a key growth area for Equinor, which has a diversified oil and gas portfolio in the country as well as expanding activities in renewable energy, with US$25bn set to be invested in the market by 2030.
Australian marine services provider Bhagwan Marine Limited has secured a contract from a major oil and gas operator to remove oil tanker moorings and navigation buoys at Barrow Island, marking a strategic step into a wider offshore decommissioning programme.
The award is seen as an entry point into a broader pipeline of asset retirement projects linked to ageing infrastructure in the region. The scope of work will allow the company to demonstrate its technical capabilities in nearshore and shallow-water environments, where demand for efficient removal solutions is expected to grow.
Bhagwan Marine said it is developing a removal methodology that could be replicated across similar projects, positioning the firm to capitalise on a rising number of decommissioning campaigns. Many offshore operators face comparable challenges as legacy infrastructure reaches the end of its operational life, particularly in mature basins.
The company has been steadily building its credentials in this segment. In 2024, it completed the Thevenard Island project, one of Australia’s largest offshore decommissioning undertakings. The campaign involved the removal of nine platforms and required approximately 180 offshore personnel, with more than 850,000 hours worked. The project underscored Bhagwan Marine’s ability to manage complex operations while maintaining safety and efficiency standards.
Since then, the company has expanded its portfolio through additional assignments, including work on Northern Endeavour operations in the Timor Sea, as well as projects involving the Harriet Alpha and Angel platforms offshore Western Australia. These engagements have strengthened its presence in the evolving decommissioning market.
Industry projections indicate that Australia is entering a prolonged phase of offshore asset retirement, driven by ageing oil and gas infrastructure. Estimates suggest total decommissioning liabilities could reach US$60bn, with the bulk of activity concentrated in Western Australia and the Gippsland Basin. Assets slated for removal include platforms, pipelines, wells and subsea installations, creating sustained demand for specialised marine contractors.
Bhagwan Marine’s leadership believes the latest contract reinforces its long-term strategy to expand in this space. Managing director Loui Kannikoski said the company has been positioning itself to capture emerging opportunities across Australia’s offshore basins.
He added that the development of scalable and cost-effective removal techniques will be critical as decommissioning activity accelerates over the coming decade. With its fleet, engineering expertise and operational experience, Bhagwan Marine aims to secure a larger share of what is expected to be a multi-billion-dollar market.
Expro has introduced Solus, a new solution designed to simplify subsea well control operations while improving efficiency and reducing operational risk.
The system addresses longstanding challenges in in-riser subsea well intervention, where conventional methods typically rely on two separate valves, one for shearing and another for sealing coiled tubing.
Traditionally, this dual-valve approach increases operational time and introduces additional complexity, along with higher risk due to the use of multiple tools. As operators continue to prioritise streamlined processes and safer well intervention campaigns, the demand for more integrated technologies has grown. Solus responds to this need by combining shearing and sealing into a single ball-valve system capable of performing both functions in one operation.
Enhanced well control capabilities
Solus has been tested and validated to API Std 17G and is fully compliant with NACE MR0175 standards. It is designed as a fail-close, bi-directional sealing system with high debris tolerance, capable of shearing and sealing braided wireline, slickline and coiled tubing. The system can be integrated into a subsea test tree assembly or deployed in open water applications, providing a primary and independent barrier for well isolation during testing or intervention activities while also helping to mitigate emissions risks.
The system has been qualified using a 15% sand slurry, demonstrating its ability to operate effectively in environments with high levels of debris, aggressive media and entrained solids. This makes it particularly suitable for wells where reservoir fracturing has taken place or where challenging fluid conditions are present.
Driving operational efficiency
Solus is engineered for both in-riser and open water operations, offering faster performance compared to conventional manual systems. Its modular design enables operators to isolate and disconnect from the well in a manner similar to traditional subsea test tree systems. In addition, its compact and lightweight configuration supports the industry’s transition towards smaller, next-generation blowout preventer stacks.
The solution is applicable across the full well lifecycle, from exploration and appraisal through to completion, intervention and eventual decommissioning. It supports a wide range of activities including subsea engineering, offshore drilling, well control and supply chain operations, helping operators enhance overall efficiency.
Proven field deployment
Solus has already demonstrated its capabilities in real-world applications. It has been successfully deployed in an in-riser completions development project in the Gulf of Mexico and has also been commissioned for an open water plug and abandonment campaign in the North Sea. These deployments highlight its adaptability across different offshore environments and operational requirements.
Read the complete story here: www.expro.com/media-hub/blog
Two Malaysian companies are coming together to support the growth of offshore energy services locally and across the region.
Oil and gas services provider Handal Energy and BumiRaya Petroleum have signed a joint venture agreement to establish a special purpose vehicle that will support the offshore crane services market.
Offshore lifting and other specialist services will play an integral role in the ongoing development of Malaysia’s energy sector, and the wider region, supporting projects and maintenance on new and existing platforms in all areas from well interventions through to decommissioning.
A statement posted to the Malaysian stock market noted that the joint venture expects a “big order book” from the oil and gas sector, as it targets “hundreds of offshore platform opportunities” across the Asia-Pacific region.
The collaboration aims to combine Handal’s financial strength and technological foundation as a listed company with BumiRaya’s flexibility in professional engineering services and market expansion, said BumiRaya managing director Taha Sheikh Mohammad.
“Through our partnership with Handal, BumiRaya will enhance its corporate image and share the advantages of a listed company in financing, such as private placements, rights issues, or bond financing, which will provide the financial impetus for future large-scale expansion.”
Handal will hold a 60% stake in the joint venture, while BumiRaya will hold 40%.
Taha Sheikh Mohammad added that BumiRaya recently completed a RM1 million (US$252,000) crane project from Petra Energy, and currently has 63 similar potential contracts, which it plans to transfer to the joint venture for execution.
According to the statement, there are currently 420 offshore cranes in the region.
Handal, which has experience in manufacturing, refurbishment, repair, leasing and engineering services, owns 15 cranes ready for immediate operation, supporting various offshore platforms.
BumiRaya, a private company established in 2012, holds 12 Petronas operating licenses and is focused on providing specialised technical services, including project management for offshore pedestal cranes and lifting equipment.
Its track record includes work on numerous large-scale projects off Malaysia, Thailand and Brunei, with clients such as Hess and Petronas.
“Looking ahead, with oil prices expected to remain high in the coming years, Handal and BumiRaya are optimistic about order growth,” the statement concluded.
“Both parties believe that this joint venture will more effectively integrate resources, providing a one-stop solution from crane upgrades, such as hydraulic and electrical system updates, to crane leasing, fully capitalising on the golden opportunities presented by the oil and gas industry's recovery.”
The global well intervention market is entering a period of steady growth, with projections indicating it will rise from US$15.1bn in 2025 to nearly US$22.11bn by 2032 according to a recent report from Maximise Market Research.
In the Middle East, expansion is being driven by a clear need to maintain ageing oilfields while improving efficiency across both onshore and offshore operations.
Across the region, operators are increasingly turning to smarter and more flexible solutions. AI driven platforms and digital workflows are helping companies monitor wells more accurately, predict maintenance needs, and reduce downtime. At the same time, rigless offshore services are gaining traction as they offer a more cost effective and less disruptive way to carry out interventions, especially in mature fields that require regular upkeep.
The Middle East remains one of the most important oil producing regions in the world, and many of its fields have been active for decades. This creates consistent demand for intervention services that can extend well life and maximise output. Technologies such as wireline, coiled tubing, and hydraulic workovers are becoming more common as they provide efficient solutions without the need for heavy infrastructure.
However, the market is not without its challenges. Strict regulatory frameworks and high investment costs for advanced offshore technologies can slow down project timelines. In addition, the global push towards cleaner energy and net zero targets is placing pressure on traditional oilfield operations. Despite this, many companies in the region are adapting by investing in lower emission technologies and more sustainable intervention practices.
Opportunities remain strong, particularly in offshore developments and underexplored reserves. The integration of AI and remote monitoring systems is expected to play a key role in shaping the future of well intervention across the Middle East. In an example cited by the Maximise Market Research report, Aramco expanded its unconventional gas programme by integrating new AI-driven well intervention and drilling services. The initiative accelerates production cycles in complex shale reservoirs, boosting regional service demand. As companies continue to balance efficiency with environmental responsibility, the market is set to evolve into a more technologically advanced and sustainable sector.
Baker Hughes will supply critical gas compression, power generation equipment, and project development support to ST LNG’s proposed LNG export terminal offshore Texas.
As part of the agreement Baker Hughes will provide two LM6000PF gas turbine-driven centrifugal compressor trains and three NovaLT16 gas turbine generator packages to secure the necessary production capacity for the first phase of the project.
The project is expected to deliver 2.1 million tonnes per annum (MTPA) as part of a planned four-phase development which will provide 8.4MTPA once complete.
ST LNG CEO, Sharad Tak, said, “As we advance toward completion of the project’s first phase, selecting proven technology from a reliable partner with deep domain expertise is essential. Baker Hughes’ extensive experience across LNG projects, including complex offshore environments, provides confidence that the ST LNG facility will achieve first LNG in the second quarter of 2030. Their ability to deliver a comprehensive equipment solution, combined with their commitment to supporting project development, is a key enabler in advancing our deepwater LNG port.”
Baker Hughes’ Chairman and CEO, Lorenzo Simonelli, commented, “Our LNG solutions portfolio is designed to support a wide range of operational requirements, from large-scale onshore facilities to specialized offshore applications such as ST LNG’s. We look forward to working closely with ST LNG to deliver reliable, efficient and lower-carbon solutions.”
Saudi Arabia’s largest drilling contractor, ADES Holding, has temporarily suspended operations on a handful of its offshore rigs in the GCC region due to ongoing tensions.
The company described the suspensions as short-term and stated that it is working closely with clients to monitor the situation while prioritising the safety of personnel and assets.
ADES, which operates 123 rigs across 20 countries, remains confident in its outlook. It forecasts core earnings for 2026 to rise by as much as 44%, supported by its geographic diversification and synergies from the recent Shelf Drilling acquisition.
All its Saudi platforms serve Saudi Aramco as the client.
Borr Drilling also reported suspensions. Three of its jack-up rigs in Qatar and the United Arab Emirates were down-manned as a precautionary measure requested by customers following hostilities in the Arabian Gulf.
A fourth rig, Arabia III in Saudi Arabia, was affected by an incident on a customer-operated platform on 7 March 2026, leading to a safe shutdown and evacuation of personnel with no injuries reported. The rigs remain under contract.
Major national oil companies have implemented significant production adjustments.
Saudi Aramco has shut in or substantially reduced output from key offshore fields, including the supergiant Safaniya (the world’s largest offshore oil field) and Zuluf, contributing to an overall reduction in Saudi oil production.
Production has been rerouted via the Red Sea port of Yanbu amid disruptions in the Strait of Hormuz.
In the UAE, ADNOC has made temporary adjustments to output, with impacts reported on both onshore and offshore facilities.
Qatar has halted liquefied natural gas production, including at the Ras Laffan complex, following strikes that caused extensive damage and fires.
QatarEnergy has warned of potential delays to the North Field expansion project.
The broader regional conflict has led to the closure of key shipping routes and prompted precautionary measures across the GCC energy sector.
While direct attacks on offshore platforms have so far been limited, the situation has disrupted drilling activities and hydrocarbon flows.
Industry players continue to stress that the rig suspensions are expected to be brief once conditions stabilise.
Eni has announced two new gas discoveries offshore Libya following an exploration campaign carried out in recent months.
The finds are located within two nearby geological structures, Bahr Essalam South 2 (BESS 2) and Bahr Essalam South 3 (BESS 3). These were confirmed through drilling activities at the B2-16/4 and C1-16/4 wells, positioned around 85 km offshore in water depths of approximately 650 feet and about 16 km south of the Bahr Essalam gas field.
Both wells intersected gas bearing zones within the Metlaoui Formation, which is recognised as the primary producing reservoir in the region. Analysis of the data suggests a high quality reservoir, with strong productivity already verified through testing conducted on the first well.
Initial estimates indicate that the combined gas resources of the BESS 2 and BESS 3 structures exceed 1 trillion cubic feet (Tcf). Their close location to the Bahr Essalam field, Libya’s largest offshore gas field, operational since 2005, means development can be fast tracked by linking the discoveries to existing offshore infrastructure. The extracted gas is expected to serve both domestic demand in Libya and exports to Italy.
Eni has maintained a long standing presence in Libya since 1959 and remains the country’s leading international energy operator. In 2025, the company reported equity production of approximately 162,000 barrels of oil equivalent per day and is currently advancing three development projects, with two scheduled to come online in 2026.
IMI has secured a contract to deliver specialist control valves for an offshore development in the North Sea, supporting ultra-high-pressure injection systems.
The valves will operate in demanding environments where pressures exceed 600 bar (8,700 psi), enabling chemical injection processes that help maintain flow and optimise production from deepwater wells.
As part of the scope, IMI will supply its EroSolve Metamorphic Trim valve range, designed for precise pressure regulation under severe service conditions. The technology is capable of handling full pressure drops from more than 620 bar to near vacuum levels while maintaining stable low-flow control, a requirement for safe offshore operations.
The valves feature a multi-stage pressure reduction system, allowing energy to be dissipated in a controlled manner across the trim. This design helps to minimise wear on internal components and extend operational life in high-stress environments.
The award follows the successful completion of an extensive endurance testing programme, during which both balanced and unbalanced valve configurations were tested under conditions replicating long-term field operations.
Roby Buyung, President for Process Automation at IMI, said offshore developments are increasingly moving into deeper and higher-pressure fields, placing greater demands on equipment performance. He noted that the project required highly specialised valve technology capable of delivering consistent and accurate pressure control in challenging conditions.
Buyung added that IMI’s valve solutions are engineered specifically for critical applications, where reliability and repeatable performance are essential to maintaining safety and operational efficiency.
The contract forms part of a broader offshore development programme, with delivery progressing in line with the project schedule.
As part of phase three drilling programme offshore Gabon, Vaalco Energy has completed drilling the Etame West ET-14P exploration well.
The target zone was water bearing even though 10 meters of high-quality Gamba sands were encountered in line with pre-drill predictions. Awaiting partner approval, this finding can be further pursued by utilising the well bore part to sidetrack it in the upper portion of the well. This move is expected to support the drilling of the ET-14H development well in the Main Fault Block of Etame.
The lower portion of the well will be plugged and abandoned. Operations are expected to be completed in April.
George Maxwell, Vaalco’s chief Executive Officer, said, “When we committed to drilling the Etame West exploration well, we knew there was the geologic risk of not encountering commercial sands but the size of the potential reservoir made it a risk worth taking. Furthermore, we purposely designed the well so we could still utilise the well bore to drill a development well into a known productive area if the sands were non-commercial. This side-tracked well should be completed in April.”
Vaalco has also been spudding the ET-15 infill well on the Etame platform as part of Phase Three Drilling Programme offshore Gabon.
This infill well is anticipated to significantly add to the production generation capacity of the floating storage and offloading vessel (FSO) that is operational on the Etame Block since 2022 following an extensive transition and field reconfiguration process. While a low cost solution, the FSO boasts of a high storage capacity and improved operational performance. It has helped Vaalco reach operational excellence, and production uptime and enhancement.
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