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.
ExxonMobil Australia has issued a decommissioning update charting the activities of the Valaris 107 jack-up rig in the Bass Strait.
In a 30 January update on its LinkedIn social media page, Richard Perry, Project Manager, called the rig “one of the hardest working mobile offshore assets currently active in Bass Strait.”
Esso Australia’s Bass Strait decommissioning team reached several major milestones in 2025, the post noted, including investing nearly $3bn in early decommissioning works, safely sealing more than 200 wells in the Bass Strait, and removing and recycling over 10,000 tonnes of steel.
“A key enabler of this progress is the heavy duty Valaris 107 jack-up rig, which has been supporting activities across our operations since the end of 2024,” said Perry.
A jack-up rig is a mobile offshore platform with a floating hull and long, extendable legs that can be lowered to the seabed, lifting the entire platform above the waves to create a stable base for drilling or decommissioning wells or other underwater works.
To date, the Valaris 107 has safely sealed 26 wells across eight former oil and gas production facilities, Perry added.
He described the delivery of a campaign of such size and complexity on a single rig as a “remarkable achievement” and a “clear demonstration of the scale, ambition, and progress of Esso’s multi-year decommissioning programme in [the] Bass Strait, the largest of its kind in Australia.”
In addition to carrying out decommissioning work, the Valaris 107 is also supporting Esso Australia’s investment to deliver more gas to Australia.
Last year the rig drilled and installed the new Kipper 1b well, which started producing gas for Australian households and businesses near the end of 2025.
Its next task will be to start drilling wells for the Turrum Phase 3 project.
This $350mn project involves drilling five new wells in the Turrum and North Turrum gas fields to access currently undeveloped gas resources.
Turrum Phase 3 will be one of the largest gas developments on the east coast this decade and continues Esso Australia’s long history of reliably supplying gas to the domestic market for over 50 years, Perry noted.
Turrum is expected to come online before winter in 2027.
“As we continue our decommissioning journey, we remain focused on safety, environmental responsibility, and supporting local employment,” he added.
“We’re proud of what we’ve achieved so far—and even more excited about what’s to come.”
Australia's offshore oil and gas sector is entering a critical phase of decommissioning, as ageing infrastructure in regions like the Bass Strait and Western Australia reaches the end of its productive life.
With maturing fields driving activity, the industry faces substantial challenges in safely removing platforms, pipelines, and wells while minimising environmental impact and ensuring financial accountability.
Recent analysis by global energy consultancy Xodus, commissioned by the Australian Government, estimates the total decommissioning liability in Commonwealth waters at AUD43.6bn through 2070, or AUD66.8bn when adjusted for inflation.
This figure represents a significant reduction from the 2020 estimate of AUD61.8bn, attributed to improved efficiencies and better understanding of decommissioning processes.
The scope encompasses over 700 wells, 7,600 km of pipelines, and 520 subsea structures, with approximately 55% of the work anticipated before 2040.
Separately, the Centre of Decommissioning Australia (CODA) projects US$40bn in offshore activity over the next 50 years, emphasising well plugging and pipeline removal as primary costs.
Key projects illustrate progress. ExxonMobil Australia's Bass Strait programme, the nation's largest decommissioning effort, advanced significantly in 2025.
The team permanently sealed more than 200 wells and processed over 10,000 tonnes of steel and concrete for recycling or disposal.
Retired platforms have entered "stasis mode," secured and prepared for removal, with the Allseas Pioneering Spirit vessel scheduled to commence lifting operations in 2027.
Woodside Energy has also made strides in Western Australia.
Offshore decommissioning at the Enfield field, which began in 2022, is nearing completion.
While physical removal works are complete, post-decommissioning environmental obligations are still ongoing. According to Woodside, an annual report is scheduled for December 2026.
The Nganhurra Riser Turret Mooring was recovered in November 2023, and deconstruction achieved over 95% reuse or recycling by March 2024.
Ongoing work at the Griffin and Stybarrow fields includes the Griffin Riser Turret Mooring recovery in December 2024.
Government reforms are also bolstering the framework.
In November 2025, the Department of Industry, Science and Resources (DISR) released a consultation paper on enhancing decommissioning planning, financial assurance, and compliance tools.
Additionally, the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Regulations 2025 have been remade, effective from 31 March 2026, to improve resource management.
As Australia transitions towards net-zero goals, these efforts underscore a commitment to responsible decommissioning, balancing economic realities with environmental stewardship. Industry collaboration, as highlighted in reflections on 2025's landscape, will be pivotal in navigating the ramp-up to 2027 and beyond.
President Bola Ahmed Tinubu has approved the gazetting of targeted, investment-linked incentives to support the proposed Bonga South West deep-offshore oil project by Shell and its partners.
The President also instructed the Special Adviser on Energy, Mrs. Olu Verheijen, to facilitate the gazette of the incentives in line with Nigeria’s legal and fiscal frameworks.
Speaking to a Shell delegation led by Global CEO Wael Sawan, President Tinubu said the incentives are disciplined, targeted, and globally competitive, aimed at attracting new capital without undermining government revenue.
He emphasised that the incentives are ring-fenced and investment-linked, focusing on new capital, incremental production, local content, and in-country value addition. “My expectation is clear: Bonga South West must reach a Final Investment Decision within the first term of this administration,” he said.
The President highlighted the strategic importance of Bonga South West to Nigeria’s economy, noting its potential to create thousands of jobs, generate foreign-exchange inflows, and deliver sustained government revenues. The project is also expected to deepen Nigerian participation in offshore engineering, fabrication, logistics, and energy services.
President Tinubu reaffirmed the administration’s commitment to policy stability, regulatory certainty, and speed, stressing that these reforms are vital for restoring investor confidence and positioning Nigeria as a preferred destination for large-scale energy investment.
Shell’s CEO, Wael Sawan, welcomed the developments, noting that Nigeria’s investment climate has improved significantly under the Tinubu administration and that Shell remains confident in long-term investment prospects in the country.
The Shell delegation included senior executives from both global and Nigerian leadership teams.
Transportation and installation work is set to begin for Shell's Kaikias Waterflood project off the Louisiana coast in the United States as Subsea7 signed a contract with Shell.
Subsea7 will be structuring subsea umbilicals, riser and a rigid flowline, all running 1,650 metres deep to support the offshore development project in the Mars-Ursa Basin. This will advance sustainable production from the Kaikas project, which is being developed by the waterflood method. The field will be subjected to oil recovery two times by water injection so that displaced oil becomes apparent to the nearby wells.
Subsea7 will be running contract operations from its base in Houston, Texas, initiating project management and engineering activities. This will be followed by offshore delivery in 2027.
Craig Broussard, Senior Vice President for Subsea7 Gulf of Mexico, said, “This award strengthens our long-standing and successful collaboration with Shell. We are bringing our deepwater experience to the Kaikias development and delivering cost-effective solutions that will support safe and efficient project execution, helping Shell maximise long-term value from the field.”
Shell's investment in the Kaikias Waterflood project will generate high-margin production for the oil major.
The Government of Guyana is progressing with plans to enhance governance and institutional capacity in the country’s growing oil and gas industry, according to Senior Minister in the Office of the President with Responsibility for Finance, Dr Ashni Singh.
During the Budget 2026 presentation, Dr Singh stated that the administration is working to create a modern and credible governance system for the oil and gas sector, which involves updating laws and regulations, strengthening key institutions, and continuously developing technical skills within the public sector.
In the past five years, the government has launched a wide-ranging legislative reform effort to align the petroleum sector with international standards. This includes enacting the Natural Resource Fund (NRF) Act and the Local Content Act (LCA) in 2021, the Petroleum Activities Act (PAA) in 2023 – which replaced the 1986 Petroleum Act – and the Oil Pollution Prevention, Preparedness, Response and Responsibility Act (OPPPRRA) in 2025 to address environmental risks and emergency protocols.
Dr Singh added that the government plans to update the First Schedule of the Local Content Act this year to expand the range of goods and services eligible under local content rules. The review of regulations under the Petroleum Activities Act is progressing, incorporating lessons from the Hammerhead Petroleum Production Licensing process, with finalisation and implementation of the regulations expected this year. Also expected this year are the implementation and rollout of coordinated compliance and enforcement measures.
Dr Singh emphasised the administration’s commitment to developing human capital within the petroleum governance framework, highlighting the importance of strengthening local skills for managing the petroleum economy effectively. In 2025, government agencies took part in targeted training sessions led by industry experts in areas such as market analytics, cost estimation, and scenario modelling, with further such sessions planned.
Guyana is seeing its offshore sector expand rapidly, which in turn is spurring significant economic growth in the country and creating much-needed jobs. ExxonMobil Guyana Limited and its Stabroek block co-venturers, Hess Guyana Exploration Limited, and CNOOC Petroleum Guyana Limited are progressing several offshore developments in Guyana’s offshore Stabroek Block. The consortium reached a new production milestone of 900,000 bopd in November 2025, following the ramp-up of Yellotail, Guyana’s fourth offshore project, and excellent operating performance from other assets. The Uaru and Whiptail projects, Guyana’s fifth and sixth projects, due to begin operations in 2026 and 2027 respectively, are each expected to produce approximately 250,000 bopd. Hammerhead, the seventh project, is expected to add approximately 150,000 bopd when production begins in 2029. An eighth project, Longtail, is currently undergoing regulatory reviews. Once approved, ExxonMobil Guyana expects to have total production capacity of 1.7mn bopd from the eight developments.
Halliburton and the Agency for Science, Technology and Research (A*STAR) in Singapore have announced the launch of the Next-Generation Energy Xccelerator Joint Lab, or NEX Lab.
This S$35mn initiative aims to accelerate the development and commercialisation of advanced well completion technologies for the energy industry.
“NEX Lab brings together Halliburton's global expertise in well completions and A*STAR's multidisciplinary research capabilities to advance cutting-edge technology that shapes the future of energy and the Future of Completions,” said Shawn Stasiuk, Senior Vice President of Halliburton’s Completion and Production Division.
“The combination of our strengths will deliver innovative solutions that support customers within the full spectrum of completion technologies, including low-carbon applications for the evolving energy landscape.”
In a statement, Halliburton said that NEX Lab will serve as a collaborative hub for research, engineering and testing.
The aim is to streamline the transition from early-stage innovation to field deployment by integrating design, prototyping and validation activities all under one programme.
“By integrating Halliburton’s global expertise with the local innovation ecosystem, NEX Lab will increase demand for specialists in high-value technical roles and build a more competitive, future ready talent pool for Singapore,” it noted.
The project is also supported by the Singapore Economic Development Board (EDB) with Alvin Tan, Singapore's Minister of State for Trade and Industry, officiating at the launch event.
Prof Lim Keng Hui, Assistant Chief Executive of A*STAR's Science and Engineering Research Council, said the collaboration with Halliburton will help to translate research into real-world solutions.
“Through NEX Lab, we will work with Halliburton to build advanced manufacturing and energy technology capabilities in Singapore and create opportunities for our scientific and engineering talent to deliver impact beyond the joint lab. NEX Lab will also help develop and qualify local suppliers, strengthening resilient, high-value energy supply chains.”
Halliburton has collaborated with A*STAR since 2019 through the A*STAR Advanced Remanufacturing and Technology Centre's industry consortium, investing more than S$2mn in R&D and embarking on projects focused on materials and design improvements, workflow and inspection automation, and sensor development.
Lim Wey-Len, Executive Cice President of EDB, said NEX Lab exemplifies Singapore's leadership in advanced manufacturing and innovation.
“We welcome more collaborations with global energy leaders like Halliburton, so that companies can develop breakthrough solutions from Singapore that strengthen their global competitiveness and advance the energy transition.
“This collaboration will also create meaningful upskilling and innovation opportunities for local enterprises and our workforce.”
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