AF Offshore Decom has signed a contract with Ithaca Energy for decommissioning work in the UK sector of the North Sea
The contract scope includes the engineering receipt, cleaning, dismantling and recycling of a FSU weighing approximately 24,000 metric tons.
Lars Myhre Hjelmeset, EVP Offshore at AF Gruppen, said, “We are very pleased to have been awarded a second major contract by Ithaca Energy following the award of the FPF-1 asset in December 2025. As a result of the awards, AF Environmental Base Vats will receive close to 50,000 tons of floating production and storage facilities from Ithaca energy in 2026.
“The two units will, after initial preparations, be loaded onto our yard in a combined gloat over and load in operation, consistent with earlier similar projects at AFEBV. The units will be cleaned, dismantled and thereafter the steel will be repurposed, upcycled and recycled creating several circular material solutions for the agriculture, construction and civil industries in the Nordic region.”
The contract has been valued in the range of NOK350-400mn (approximately US$36-41mn).
Malaysia’s Vantris Energy continues its corporate transformation after rebranding from Sapura Energy in 2025 with work on projects in support of the country’s offshore sector.
Its indirect wholly-owned subsidiary, Sapura Offshore Sdn Bhd, has been awarded work orders for offshore transportation and installation (T&I) services in Malaysia by Petronas Carigali Sdn Bhd.
The awards comprise the provision of T&I services for offshore facilities at the Sepat Integrated Redevelopment Project and the Belud South Greenfield Development Project.
Work on both is set to commence early this year by the group’s engineering and construction (E&C) arm, with Belud South anticipated for completion by the end of 2027, and Sepat by the third quarter of 2029.
The company said in a statement that it also marked a “strategic shift” towards opportunities with lower-risk contracting models.
“These contracts demonstrate Vantris Energy’s offshore T&I capabilities, and our continued focus to deliver sustainable performance across our core businesses, prioritising opportunities aligned with our capabilities, regional strengths, and risk appetite,” said Vantris Energy CEO Muhammad Zamri Jusoh.
With a stronger balance sheet following its restructuring in late 2025, the company is keen to strengthen its business across all areas of operation.
Vantris Energy is also active in numerous other areas, including oil well intervention and decommissioning.
The company also last month announced the divestment of its 40% equity interest in L&T-Sapura Shipping Pvt. Ltd., which owns and operates the LTS3000 heavy-lift and pipelay vessel.
The company sold up to its joint-venture partner, Larsen & Toubro Limited (L&T), in a deal valued at US$30.5mn, consisting of equity consideration and the full repayment of the outstanding shareholder’s loan and accrued interests owed to the group.
It marked another step in Vantris Energy’s ongoing efforts to streamline, strengthen and optimise its asset portfolio, according to Jusoh.
The outlook for well support, interventions and other associated services across West Africa should be buoyed by the prospect of high levels of wildcat drilling this year.
According to analysis by Rystad Energy, the global upstream sector is set to carry strong momentum into 2026, with high-impact drilling activity expected to remain elevated following a solid 2025.
Africa is set to continue leading global activity, it estimates, accounting for around 40% of planned high-impact exploration wells, driven largely along the Atlantic margin, with exploration expected to focus on the Orange Basin in southern Africa and the Gulf of Guinea in West Africa, reinforcing the region’s role in global high-impact drilling.
Wells are designated as high-impact based on a variety of factors: the size of the potential resources, whether they could open new hydrocarbon plays in frontier or emerging basins, and their significance to the operator.
Such activity in 2026 is expected to drive exploration momentum higher in specific basins and countries, with 42 such wells identified globally — close to half of them in Africa.
Last year, the success rate for high-impact wildcat wells rose to 38% from 23% in 2024, while total discovered volumes increased by 53% year on year to around 2.3 billion barrels of oil equivalent (boe), according to Rystad Energy.
What we are seeing in 2026 is a clear shift in which where operators are willing to deploy capital, according to Aatisha Mahajan, Rystad Energy’s Head of Exploration, Oil & Gas Research.
“Ultra-deepwater and frontier plays remain capital-intensive, but they also offer scale and material upside at a time when conventional opportunities are increasingly limited,” Mahajan said.
“Africa stands out because it still combines geological potential with the prospect of large, commercially meaningful discoveries, particularly for operators looking to secure long-life resources in a tightening global supply environment.”
Of around 17 potential high-impact wells across Africa during 2026, nearly all are offshore, with just a few onshore.
The continent scores twice as many proposed wells as Asia, the next busiest region, followed by South America and Europe.
Subsea pipelines used by the oil and gas industry may contain naturally occurring radioactive materials, mercury, hydrocarbons, and heavy metals that pose a risk to human health and the environment, a parliamentary inquiry into decommissioning offshore oil and gas infrastructure has heard.
Appearing before the Legislative Council Environment and Planning Committee’s inquiry into decommissioning oil and gas infrastructure, Fern Cadman, Fossil Fuel Industry Campaigner at the Wilderness Society warned that Gippsland’s offshore region has around 800 km of subsea pipelines.
“Even if buried, eventually they will degrade, and all that is going to end up in the environment,” she told the Committee.
Stan Woodhouse from environmental organisation Friends of the Earth told the hearing that some contaminants can bioaccumulate and move through the food chain.
“If we leave it on the seabed, it will end up on our dinner plates,” he said.
The Committee is investigating the scale and legal ownership structure of the infrastructure, including offshore wells, pipelines, high-pressure transmission and low-pressure distribution systems and relevant projects in Commonwealth waters.
The environmental groups advocated for removing the pipelines before they have a chance to corrode.
“Industry says it’s too hard to remove them, but engineers say almost anything can be done, you just have to be prepared to pay for it and use the right tools,” Cadman added.
Instead, Victoria should treat the pipelines and other infrastructure as a potential resource and an opportunity to boost domestic steel recycling and cut emissions.
Jerusha Beresford, Sustainability Adviser at the Australian Steel Institute (ASI), urged the Committee to recognise the value of infrastructure such as oil platforms that have reached the end of their life.
“We are strongly recommending that the scrap steel recovered from the decommissioning of the Bass Strait oil and gas infrastructure is recognised as a valuable national resource and prioritised for local recycling into domestic steel manufacturing and not exported,” Beresford told the Committee.
According to ASI, the first tranche of decommissioning will yield 60,000 tonnes of high-grade steel from 12 retired platforms, with significantly more expected over the next decade.
“Demand for steel for renewable infrastructure alone is forecasted to be about 400,000 tonnes per year through to 2030…retaining scrap locally is essential to meet that demand,” he added.
The benefits extend beyond supply security. Using scrap steel in manufacturing dramatically reduces carbon intensity compared to primary production and can support Australia’s transition to low-emission steelmaking.
Beresford told the hearing that both electric arc furnaces and blast furnaces rely heavily on scrap, with the former using up to 90% recycled content.
Economic modelling also points to strong local gains.
ASI cited analysis showing that every 10,000 tonnes of scrap steel that’s processed domestically creates 37 jobs and $4.8mn in value-add, compared to just $1.3mn if exported.
“Scrap use lowers the carbon intensity of steelmaking by reducing reliance on primary resources like iron and coal…It is crucial in meeting Australia’s capability to manufacture low-emission steel products,” Beresford said.
However, he warned that without regulatory intervention, contractors may opt to export scrap for short-term financial gain.
“Unfortunately, the past has showed that sometimes scrap is exported because it is perceived to be an easier way to get rid of the waste and the contractor gets paid for it,” he added.
With Australia’s steel industry employing 100,000 people and generating $30bn annually, Beresford said the decommissioning pipeline represented a ‘once-in-a-generation' chance to strengthen domestic manufacturing, create jobs and advance the circular economy.
The Asia-Pacific offshore decommissioning market is steadily gaining importance within the wider global offshore decommissioning industry.
Although the region still lags behind North America and Europe in terms of total market value, it is expected to record strong growth over the coming years. This expansion is being driven by aging offshore oil and gas infrastructure, evolving regulatory frameworks, and rising environmental concerns, all of which are pushing operators and governments to prioritise end of life asset management.
Market research indicates that the APAC offshore decommissioning market in 2024 was valued at around US$1.5bn, with expectations that it will grow to more than US$3.5bn by 2035 at a CAGR approaching 7.8 % from 2025 to 2035. Major offshore producing nations including China, India, Japan, South Korea, Malaysia, Thailand, and Indonesia are playing a central role in this expansion. According to GM Insights, the Asia-Pacific market alone is forecast to grow at a CAGR of over 6 % through 2034, supported by the ageing of offshore assets and stronger regulatory oversight.
China currently holds the largest share of the regional market, supported by strict environmental standards and a significant number of ageing offshore installations. India is also emerging as a strong growth market, driven by supportive policies and shifts in national energy strategies. Meanwhile, Japan and South Korea are placing greater emphasis on advanced technologies and safety focused decommissioning methods, while countries such as Malaysia, Thailand, and Indonesia continue to develop their decommissioning capabilities as offshore fields mature.
Technological progress including robotics and remotely operated vessels, along with closer collaboration between stakeholders, is helping to reduce costs and address logistical challenges. Despite hurdles such as high execution costs and regulatory complexity, increasing environmental scrutiny and scheduled asset retirements position the APAC offshore decommissioning sector as a key growth area through 2035, creating long term opportunities for service providers and technology innovators.
Syria has taken a significant step towards reviving its energy sector after signing a landmark agreement to develop its first offshore oil and gas field.
The memorandum of understanding was signed this week between the Syrian Petroleum Company, US energy major Chevron, and Qatar based Power International Holding.
The signing took place in Damascus and was attended by senior officials, including the US special envoy to Syria, Tom Barrack. According to Syria’s state news agency SANA, the agreement focuses on offshore exploration and the development of oil and gas resources within Syria’s territorial waters. It also aims to encourage wider investment and long term growth across the country’s energy sector.
The deal marks Syria’s first formal move into offshore energy exploration and reflects the government’s efforts to attract foreign partners and rebuild hydrocarbon production after years of decline. Youssef Kabalawi, CEO of the Syrian Petroleum Company, said, “Before the summer, God willing, we will start mobilization and drilling.”
He added that reaching the gas reserves could take up to four years, underlining the long term nature of the project.
Syria’s oil and gas industry has suffered severely due to nearly fifteen years of conflict, which resulted in widespread damage and the loss of hundreds of thousands of lives. Before unrest began in 2011, oil production stood at around 380,000 barrels per day, with exports generating more than $3 billion in 2010. At that time, oil revenues made up roughly a quarter of the government’s budget.
Recent developments may improve the outlook. Syrian government forces regained control of large areas in the north east and oil rich eastern regions last month, potentially opening the door to renewed exploration in some of the country’s most valuable energy zones.
Since coming to power in December 2024 after the removal of Bashar Assad, Syria’s new authorities have prioritised economic recovery. The offshore agreement with Chevron and Power International Holding signals a clear intention to rebuild the energy sector and re establish Syria as a regional player in oil and gas development.
DOF Group ASA has secured a significant new contract from Shell Offshore Inc., strengthening its position in the North American offshore energy market.
The agreement covers the delivery of hydraulic subsea well intervention services and falls within DOF’s substantial contract category, valued between US$mn and US$50mn.
The work will be handled by DOF’s subsea team based in North America, which will oversee the project from planning through to offshore execution. This includes full responsibility for project management, engineering, the intervention vessel, and all surface and subsea services required to inject chemical fluids into selected subsea wells. The contract highlights DOF’s capability to provide fully integrated solutions for complex offshore operations.
Offshore activities are expected to begin in the second quarter of 2026. Vessel operations in the United States Gulf are planned to span between 75 and 120 days, reflecting a strong level of utilisation and a well defined operational schedule.
Mons S. Aase, CEO DOF Group ASA, said, “I am delighted to see how DOF is continuously expanding our portfolio of services and adding value to our clients and other stakeholders.”
This contract represents another step forward for DOF as it continues to broaden its service offering and deepen relationships with major international energy companies. It also underlines the company’s focus on delivering reliable, high quality subsea services while supporting efficient and safe offshore operations in one of the world’s most active energy regions.
Energy services provider Expro has unveiled a new high-debris single shear and seal ball valve system, designed to provide enhanced flexibility, functionality, and safety for subsea well access in the global oil and gas sector
By replacing the traditional requirement for two valves with just one, the system transforms subsea well access operations, reducing risk and complexity while supporting more cost-effective subsea intervention technologies.
Tested and validated according to API Std 17G, the system is the first fully NACE MR0175-compliant fail-close, bi-directional high-debris ball valve capable of shearing and sealing on wire and coiled tubing.
Expro’s new equipment can be applied in both riser and open water environments across the full well lifecycle – from exploration and appraisal to completion intervention, plug and abandonment, and decommissioning.
The system has already been deployed for a new in-riser completions project in the Gulf of America and installed in an open water system for a North Sea plug and abandonment campaign. It provides shear and post-shear sealing for gas and liquids on slickline, braided electrical cable, and coiled tubing, delivering bi-directional sealing even after pump-through operations.
It is also integrated into Expro’s lightweight open water intervention riser system. By achieving shear and seal in a single valve, the system allows more efficient operations in open water applications.
The modular design enables isolation and disconnection from the well, while its compact size and flexibility align with the industry’s move toward smaller blowout preventer stacks and streamlined supply chain management. The fail-close configuration reduces emissions risk and provides an additional well safety barrier. Expro’s integrated approach gives users confidence and simplifies operations by replacing a two-valve system with just one.
The system offers superior high-debris flexibility, handling solids up to 15% ingress qualification size, making it suitable for a wide range of subsea well lifecycle challenges.
Daniel More, Vice President Subsea Well Access at Expro, said:
“In introducing this system, Expro now offers the subsea engineering market a distinctive new solution that provides the ultimate integrated shear and seal on coiled tubing and wire using just a single valve. It cuts through operational complexity. Simple to use, flexible, with a compact design for smaller BOP stack sizes, this is the latest in fail-safe technology developed by the experts of valve technology and systems integration.
“When there’s no room for error, the system is designed to provide the assurance of an independent well safety barrier, combined with the surety and confidence that comes from Expro’s integration experience and expertise at the ‘whole system’ level. It’s the latest example of Expro’s engineering excellence and deep understanding of customer needs to move our industry forward.”
The system is available in Expro’s landing string assembly equipment offering, and can be deployed in-riser as a single valve, a single valve with a latch mechanism, within a subsea test tree, or within an open water intervention riser system.
Energy technology company, Baker Hughes, has secured a multi-year contract from North America’s natural gas producer, Expand Energy, to deploy its Leucipa automated field production solution that will cover multiple gas-producing wells in the region.
The deployment of Leucipa will empower North America’s natural gas supply chain while advancing production optimisation for Expand Energy. Equipped with artificial intelligence-powered Production Management and Field Optimizer services, Leucipa will make a big difference in Expand Energy's operational efficiencies by generating advanced workflows. It will establish seamless connection across a diverse portfolio of gas-producing wells, driving more informed, data-driven decisions.
Expand Energy will also launch a pilot of Lucy, the Leucipa AI Production Assistant, which provides real-time analysis of production data through a generative AI-powered conversational interface to simplify decision-making in the field.
“This collaboration illustrates how digital technologies are reshaping the economics of natural gas production,” said Amerino Gatti, executive vice president of Oilfield Services & Equipment at Baker Hughes. “By providing comprehensive, real-time insights for wells, fields, and basins across the United States, Expand Energy can achieve greater efficiency, reliability, and sustainability across the natural gas value chain.”
Leucipa will be deployed as SaaS on Amazon Web Services (AWS), providing Expand Energy a secure, scalable environment for broad deployment and simplified management across their nationwide portfolio.
This agreement will co-develop new workflows that integrate seamlessly with Expand Energy’s existing digital tools. Workflows for gas nominations and field forecasting will provide more certainty for contract commitments and scenario modeling. Leucipa’s flexible architecture will also help integrate Expand Energy’s edge, on-prem and cloud-based systems into a unified framework.
“This collaboration marks a significant step forward in the digital transformation of our upstream operations,” said Josh Viets, executive vice president & chief operating officer at Expand Energy. “By deploying AI-powered systems across our nationwide network of wells, Expand Energy will enhance the value of our assets through more efficient and reliable delivery of energy to our customers.”
Advanced technologies and solutions from SLB are set to help drive production efficiency and maximise recovery at Oman’s largest oil and gas concession.
Petroleum Development Oman (PDO) has awarded SLB two five-year contracts for the supply of wellheads and artificial lift technologies for operations in Block-6, which contains over 75% of Oman's remaining crude oil reserves.
The contracts include the provision of low-pressure, high-pressure, and thermal wellheads, as well as electric submersible pumps (ESPs) and progressive cavity pumps (PCPs). These solutions are expected to increase recovery rates and extend the productive life of Block-6 assets. The contracts will involve expanding local manufacturing capabilities and introducing made-in-Oman gate valve production within six months of commencement.
The contracts align with PDO’s ICV programme, which is a strong priority for PDO and supports the country’s industrial diversification under Oman Vision 2040. It has played a vital role in expanding local manufacturing capabilities, strengthening local supply chains, upskilling the workforce and creating jobs for Omani nationals.
“These awards reflect our deep commitment to Oman’s energy future and advancing in-country value through local manufacturing and talent development,” said Jesus Lamas, president, Middle East and North Africa, SLB. “By producing more equipment in country and investing in Omani expertise, we are ensuring that PDO’s strategic goals are met with sustainable, locally driven approaches. Our focus is on delivering innovative wellhead and artificial lift solutions that drive production efficiency and maximize recovery. Through our ongoing investment in advanced technologies and tailored services, we support our customers’ production and recovery goals with capabilities designed to meet their evolving operational needs.”
Wellheads will be produced at SLB’s Rusayl production center, and ESPs will be assembled at its Nizwa assembly, repair, and testing center, supporting hundreds of Omani employees. SLB will deploy advanced technologies including the 15k SOLIDrill modular compact wellhead system, ESP surveillance systems, and ESP permanent magnet motors, which reduce power consumption and enhance sustainability.
In its Fourth Quarter 2025 results, SLB comments that industry is prioritising production and recovery.
“As economics remain challenged, production and recovery activity is becoming a strategic priority for our customers in order to unlock incremental barrels at the lowest cost,” said CEO Olivier Le Peuch.” This is translating into higher demand particularly for intervention services, artificial lift, production chemicals and SLB OneSubsea.”
By signing a decommissioning definition engineering contract from QatarEnergy, a Houston-based company from the United States called McDermott will be facilitating the State of Qatar's inaugural offshore decommissioning initiative.
Services will include the development of a comprehensive technical and commercial framework followed by detailed techno-economic studies before the safe initiation of systematic retirement and removal of 27 aging offshore platforms. This will be covering a vast network of subsea infrastructure—including subsea cables and pipelines—located in the Al-Karkara, Idd El-Shargi and Maydan Mahzam fields.
With definition engineering set to start from its Doha base, McDermott's Senior Vice President representing Offshore Middle East, Mike Sutherland, said, "As the first decommissioning project of its kind in the country, and given the scale of assets to be retired, this award represents a significant milestone and an exciting new chapter for McDermott, QatarEnergy and the State of Qatar...We are uniquely positioned to deliver a landmark framework that will set new industry benchmarks and establish best-in-class standards for future decommissioning efforts in the region and beyond."
"McDermott has installed the majority of Qatar's offshore assets," added Neil Gunnion, Qatar Country Head and Vice President, Operations. "We are proud to apply decades of experience to continue delivering innovative, lifecycle-focused energy solutions through our long-standing, trusted partnership with QatarEnergy."
While originally from the United States, McDermott's global client base has not only earned it deep knowledge and expertise on offshore assets and their strategic decommissioning but also efficient project delivery with minimal operational risk and maximum environmental responsibility. The company leverages its years of understanding of the engineering, procurement, construction and installation (EPCI) phases for a smooth transition from decommissioning definition engineering to execution.
T7 Global Bhd secured a new offshore work order through its wholly owned subsidiary, Tanjung Offshore Services Sdn Bhd, marking another milestone in its growing relationship with PETRONAS Carigali Sdn Bhd.
In a filing with the bourse, the group said the contract covers integrated well plug and abandonment services together with project management team support for the Zuhal East well. The work order is scheduled to take effect from Nov 17, 2025 to March 31, 2026, positioning the group for steady activity over the coming period.
The latest award follows T7 Global’s earlier appointment as a panel contractor under PETRONAS Pan Malaysia contract. Under that programme, the group provides integrated well continuity services covering intervention, workover and abandonment, reinforcing its role across the upstream oil and gas value chain.
T7 Global said the new contract is expected to make a positive contribution to the group’s earnings and net assets for the financial year ending Dec 31, 2025 and beyond until the contract expires. This outlook aligns with the group’s broader strategy to strengthen long term revenue visibility in the energy services sector.
The announcement also comes shortly after a leadership transition. Slightly over a month ago, Azman Yakim was appointed group chief executive officer, taking over from Tan Kay Zhuin after three years in the role. Despite the upbeat developments, the group’s shares slipped half a sen or 1.69 percent to 29 sen at the noon break, valuing T7 Global at US$261.8million.
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