In The Spotlight
Iraq is working to increase oil production. (Image source: Adobe Stock)
Iraq’s Basra Oil Company (BOC) and Halliburton have signed a five-year integrated management contract for the Bin Omar and Sindbad fields in the Basra region, according to a Ministry of Oil Statement
Oil Minister Bassem Mohammed Khudair Al-Abadi said at the signing ceremony that the contract comes in the context of the ministry’s plans and strategy to increase oil and gas production.
The Minister indicated that over the five years, crude oil production in the Ben Omar field will be increased to 150,000 barrels per day, in addition to the production of 300 million standard cubic feet per day of associated gas. He added that production rates in the Sindbad field will be developed to reach 80,000 to 100,000 barrels per day, and the associated gas capacity will be increased from 240 to 260 million standard cubic feet per day, which will provide a flexible supply of gas to the country’s power sector, which currently relies heavily on imported gas.
The Minister affirmed that the Ministry is proceeding with signing contracts with major international companies, especially American companies, and that it will provide support and remove obstacles to “achieve the goals and the public interest”, noting the longstanding involvement of Halliburton in Iraq, where it has been working since 2003.
According to Reuters, Iraq’s Cabinet has approved the Basra Oil Company (BOC), to sign a heads of agreement (HoA) and a non-disclosure agreement (NDA) with a consortium comprising US-based Capital TI and Chevron, alongside Qatar’s UCC, to study strategic oil export pipeline projects. Under the agreements, the consortium will conduct technical and financial feasibility studies for proposed pipeline routes aimed at enhancing Iraq’s crude export infrastructure. The routes under evaluation include the Basra–Haditha–Kirkuk–Ceyhan corridor, which would connect southern Iraq to Turkey’s Mediterranean port of Ceyhan, and the Basra–Haditha–Baniyas route, linking Basra to Syria’s Mediterranean port of Baniyas.
The Cabinet has also authorised Basra Oil Company to sign a consultancy services contract with US engineering firm KBR for the proposed Basra–Haditha oil pipeline project, supporting the technical development of the planned export route.
The proposed pipelines are part of Iraq’s efforts to diversify its crude oil export routes and reduce reliance on the country’s southern export terminals and the Strait of Hormuz.
Iraq, OPEC’s second largest producer, has a sustainable capacity of 4.9mn bpd and is reported to have ambitions to raise production to 7mn bpd. Under economic pressure due to the suspension of oil exports through the Strait of Hormuz during the recent hostilities, and with the oil and gas sector still accounting for 53% of GDP, 88% of revenues and 91% of exports according to the World Bank, Iraq is reported to be lobbying for an increase in its OPEC quota, currently standing at 4.3mn bpd. Major development and rehabilitation of oilfields is underway with the participation of international oil companies; last year ExxonMobil signed an agreement with the Iraq government to develop the supergiant Majnoon oilfield, bp signed an agreement for the redevelopment of oilfields at Kirkuk, and Chevron is looking to take over from Lukoil as operator of the West Qurna Field.
The project will boost gas output from the Bahr Essalam gas field. (Image source: Adobe Stock)
Eni, in partnership with the Libyan National Oil Corporation (NOC) through the Mellitah Oil & Gas joint venture, has started hydrocarbon production enabled by the Sabratha Compression Project, a strategic offshore development designed to boost gas output from the Bahr Essalam gas field, located around 100 km off the coast
The Sabratha Compression Project consists of the installation of a new 1,600-ton compression module on the Sabratha platform, equipped with new compression trains, providing an overall compression capacity of about 440 MMscfd.
The new module enables production under low-pressure conditions, offsetting the natural decline of the Bahr Essalam field and maximizing gas recovery, ensuring increased volumes of gas of about 800 million cubic metres per year and associated condensate. This additional production will play a critical role in sustaining national power generation, thus contributing to Libya’s energy security, and supporting export to Italy via the Greenstream pipeline.
Exploration activities yielded positive results in March 2026 with the Bahr Essalam South 2 (BESS 2) and Bahr Essalam South 3 (BESS 3) offshore discoveries. Preliminary estimates indicate that these discoveries jointly contain more than 1 Tcf of gas in place. Their proximity to the existing production facilities of the Bahr Essalam field will ensure a fast-track development.
Two additional strategic projects are presently in execution in the country: Bouri Gas Utilization Project, whose tie-in and commissioning activities are currently underway after the recent installation of the Bouri Gas Recovery Module, and Structures A&E, involving the development of two offshore gas fields.
Eni has been present in Libya since 1959 and is the country’s leading international operator, with an equity production of approximately 162,000 barrels of oil equivalent per day in 2025 and three development projects currently in execution for a total investment of about US$10bn.
Libya’s efforts to boost oil and gas production following years of civil war have met with considerable success. Sirte Oil Company for Production and Manufacturing of Oil and Gas has recently successfully returned well J-03 in the Metkhendoush field to production. This follows the completion of the installation and commissioning of an electric submersible pump (ESP) artificial lift system, as part of the company’s efforts to maintain production rates and increase the production capacity of its oil fields, through well development and rehabilitation programmes, as well as improved operational efficiency.
The NOC’s crude oil production has now reached around 1.3-1.4mn bpd, the highest level since 2013, and well on the way to its goal of producing 1.6mn bpd by the end of 2026, rising to 2mn bpd in the medium term.
Demand for LNG is forecast to rise sharply. (Image source: Adobe Stock)
Shell’s LNG Outlook 2026 highlights the strong growth in global LNG demand as well as the increased resilience of the LNG market
Global demand for liquefied natural gas (LNG) is expected to increase to nearly 700 million tonnes a year by 2050, an increase of around 65% from 2025 levels, according to the Outlook,
LNG remains a core pillar of the global energy system, with demand driven by Asian economic growth and intensifying energy security risks.
Disruption to shipping through the Strait of Hormuz as a result of the Middle East crisis has shut in around one fifth of the world’s monthly LNG supply since the conflict started, pushing up prices on the spot market and adversely affecting some countries in Asia.
This loss of supply has been partially offset by the ramp up of new liquefaction facilities in North America, improved performance at existing plants and reduced Asian imports of LNG. As a result, total LNG trade in 2026 could be similar to last year, when 422mn tonnes of LNG was traded, if shipping through the Strait of Hormuz returns to normal this summer, before returning to growth in 2027.
“The conflict created a system-wide shock with disruption cascading across all segments of the economy, but the LNG industry has proved resilient and able to adapt to changing market conditions,” said Cederic Cremers, President of Integrated Gas at Shell. “While more investment in both supply and demand infrastructure is needed, the long-term outlook remains strong and LNG will continue to be a stabilising force in the global energy system.”
Supply growth
Around 180 million tonnes of annual new supply is forecast to enter the market by 2030, improving the availability and affordability of gas and opening up demand in new markets. The USA continues to lead new LNG supply growth.
However, the ability to benefit from new supply will depend on the availability of infrastructure in importing countries, including regasification capacity and pipeline connectivity, especially in South and Southeast Asia.
Those regions are forecast to account for around 40% of global LNG imports by 2050 to meet rapidly growing demand for energy with lower emissions than coal. In more mature Asian markets such as Japan, data centres are emerging as a new source of power demand.
Emerging segments of demand are also growing rapidly. According to forecasts, LNG bunkering will grow seven-fold to 27 million tonnes by 2035. LNG will continue to have a vital role to deliver energy security to Europe, to balance intermittent renewables as domestic gas production declines.
To meet the growing demand, significant additional investment will be needed in new LNG liquefaction plants through the 2030s and 2040s, with around 200 million tonnes a year of new supply needed, in addition to projects already under construction.
A more resilient market
Although spot prices of LNG in Asia increased to more than US$20 per million British thermal units (MMBtu) at the peak of the Middle East crisis, they remained significantly lower than in 2022 when gas supplies were disrupted following the Russian invasion of Ukraine, reflecting the greater resilience of the LNG market now.
With long-term supply agreements accounting for around two thirds of total LNG trade, the average price that buyers paid for LNG in May was around US$11-12 per MMBtu, compared to US$7-11 in January before the conflict began.
SLB will establish a facility in Ahmadi Innovation Valley. (Image source: SLB)
SLB has been awarded a seven-year contract by Kuwait Oil Company (KOC), which will see the company work with KOC to evaluate, test and deploy advanced technologies across its operations as well as establishing a new facility in Ahmadi Innovation Valley (AIV)
The agreement, under the AIV initiative, will support applied research, technology deployment and digital innovation programmes aligned with Kuwait's long-term energy objectives. Areas of focus include artificial intelligence (AI), industrial internet of things (IIoT) applications, production optimisation, reservoir technologies, water management and energy transition initiatives.
Ahmadi Innovation Valley is KOC's flagship innovation initiative that brings together industry, academia and technology providers to address strategic upstream technical challenges, with specialised facilities and technical teams focused on applied research, advanced technologies and operational excellence.
Under the agreement, SLB will establish a dedicated Ahmadi Innovation Valley facility in Kuwait, with construction expected to begin in 2026 and opening planned for 2028.
"Ahmadi Innovation Valley represents an important step in advancing technology leadership across Kuwait's energy sector," said Ahmad Jaber Al-Eidan, chief executive officer, Kuwait Oil Company. "Through collaboration with leading technology partners, we are accelerating technology deployment, strengthening local capabilities and expanding knowledge transfer to support Kuwait's energy industry."
"The energy industry has no shortage of technology. The challenge is deploying it at scale and turning innovation into operational impact," said Olivier Le Peuch, chief executive officer, SLB. "Ahmadi Innovation Valley brings together technology providers, researchers and operational teams to accelerate the evaluation, deployment and scaling of new solutions across KOC's operations. We are proud to contribute our technology, domain expertise and global experience while helping strengthen local capabilities and support the next generation of Kuwaiti talent."
SLB and KOC have a long history of collaboration going back more than 85 years. Most recently Kuwait Oil Company awarded SLB a US$1.5bn, five-year integrated contract in February this year for the Mutriba field, including design, development and production management. The work builds on SLB’s subsurface characterisation of the Mutriba field to support development planning and execution across deeper, technically demanding reservoir conditions. The contract covers development of high-pressure, high-temperature reservoirs with sour conditions.
Expanding the use of digital technologies
Kuwait Oil Company (KOC) is committed to expanding the use of digital and advanced technologies. In an interview with Oil Review Middle East, KOC’s CEO Ahmad Jaber Al- Eidan, said KOC has established an Innovation and Digitalization Team to co-ordinate enterprise- wide initiatives, including the integration of AI, advanced analytics, real-time monitoring, workflow automation and remote operations across the upstream value chain. For example, AI- powered drilling optimisation tools and predictive models for equipment reliability and well performance have been deployed to improve operational outcomes.
The Kuwait Integrated Digital Field (KwIDF) system has enabled real-time surveillance and faster data-driven decision making across operations. Smart field solutions are also being scaled across key assets.
A dedicated AI centre has been launched to optimise operational planning, assist in reservoir modelling, forecast ESP and equipment failures, enhance drilling performance and improve supply efficiency, while generative AI and advanced analytics are being embedded into workflows, supported by partnerships with leading technology providers.
“Looking ahead we are focused on piloting and scaling advanced digital solutions across all areas of our business, embedding those innovations within our operations and planning frameworks to ensure long-term scalability and aligned with our broader innovation and sustainability goals,” Al-Eidan said.
Assembly of a TAKRAF conveying system at F’Derick iron ore project, Mauritania.
With major mining investments underway across the region, the demand for efficient and robust material transport is growing. Long-distance conveyors play a key role in reducing reliance on truck haulage and improving operational performance in challenging environments
As major mining investments gain momentum across the Middle East, operators are increasingly focused on how to move large volumes of material efficiently across vast and often remote project sites.
In this context, material transport is no longer seen as a secondary consideration, but as a strategic component of overall mine design. Long-distance conveying systems are emerging as a compelling alternative to traditional truck haulage, offering a scalable and energy-conscious solution that supports both operational performance and the region’s growing emphasis on efficiency and infrastructure development.
Large-scale mining projects today are defined by greater distances, higher throughputs and more complex site conditions. From high-altitude operations to desert environments with extreme temperatures and dust exposure, material handling infrastructure must deliver consistent performance under demanding conditions. Conveyor systems, particularly overland and in-pit crushing and conveying (IPCC) solutions, are increasingly being engineered to meet these challenges as integrated components of the overall mine design.
One of the key advantages of conveying lies in its ability to provide continuous, electrified transport. Compared with truck haulage, conveyors can significantly reduce fuel consumption, operating costs and associated emissions, particularly over long distances and high volumes. This makes them an attractive option for mining regions investing in new infrastructure and seeking to improve the sustainability of their operations.
As conveying distances and installed power increase, however, the performance of the drive system becomes a critical factor. Conventional drive arrangements, typically based on high-speed motors and gearboxes, can approach their technical and practical limits in large-scale applications. This has led to growing interest in gearless drive technology, which replaces the traditional drivetrain with a slow-running synchronous motor directly coupled to the conveyor pulley.
By eliminating the gearbox, gearless drives simplify the mechanical system and reduce the number of wear components. This results in lower maintenance requirements, improved reliability and reduced downtime — particularly valuable in remote or difficult-to-access locations. In addition, the absence of gearbox losses and the high efficiency of synchronous motors contribute to improved overall energy performance, especially under partial load conditions where conveyors typically operate.
Modern gearless drive systems are also closely integrated with digital control platforms, enabling precise control of conveyor speed, optimised load sharing and advanced condition monitoring. These capabilities support predictive maintenance strategies and help operators maintain consistent performance across the entire material handling chain.
From a system perspective, advances in conveyor design are equally important. The use of horizontal curves, for example, allows conveyors to follow natural terrain and reduces the need for multiple transfer points, improving system availability and lowering maintenance requirements. Fully enclosed conveying solutions such as pipe conveyors can further support environmental performance by minimising dust emissions and material spillage.
While gearless drives are not required for every application, their value becomes clear in high-capacity, long-distance and high-lift scenarios where reliability, efficiency and lifecycle cost are critical. In these cases, a project-specific evaluation often shows that reduced operating expenditure and improved system availability can offset higher initial investment.
As mining development continues to accelerate across the Middle East, the need for efficient, reliable and future-ready material transport solutions will only grow. In this evolving landscape, conveying systems—supported by advanced drive technologies — are increasingly being recognised as a strategic enabler of large-scale project success. By reducing reliance on conventional haulage and aligning with broader goals around efficiency and infrastructure optimisation, they offer a practical pathway for operators looking to build resilient operations that can meet the demands of both today’s projects and those still to come.
For more information on TAKRAF Group’s conveying systems capabilities, visit www.takraf.com
Dana Gas is pursuing a US$100mn investment programme in Egypt. (Image source: Dana Gas)
Dana Gas PJSC, the Middle East’s regional private sector natural gas company, has announced encouraging results from its Egypt drilling programme, together with the receipt of additional payments totalling AED 79 million (US$21.5 million), marking the full settlement of all overdue receivables in Egypt and the continuation of payments by the Egyptian Government
The progress achieved in Egypt reflects the combination of an improved fiscal framework under the Consolidated Concession Agreement, constructive cooperation with the Egyptian Government, the closure of all overdue receivables, and Dana Gas' continued investment in its asset base. The full settlement of overdue receivables and continued timely payments have strengthened the business’ confidence in further investment in Egypt, alongside the Government’s ongoing efforts to encourage upstream investment, increase domestic gas production and reduce reliance on imported LNG.
Dana Gas has been actively executing its US$100mn investment programme, focused on stabilising production and restoring growth across its Nile Delta portfolio. The company delivered a return to production growth in the first quarter of 2026, with average production increasing 4% year-on-year to 13,060 boepd, marking the first increase in output since 2017.
In 2025, the company successfully drilled four wells and carried out workovers across three additional wells, adding approximately 30 MMscf/d of production and 36 Bcf of reserves.
More recent drilling activity has delivered results significantly above expectations. The latest well has identified an estimated 10 Bcf of gas reserves, significantly exceeding the original prognosis of 3 Bcf. The result opens up additional development and exploration opportunities across the licence area and has the potential to contribute approximately 12 Bcf of future gas resources once developed. Dana Gas plans to drill four further wells before the end of 2026.
Richard Hall, chief executive officer, said, “The Egyptian Government’s settlement of all outstanding receivables and the return to full, timely payments are important developments that give us greater confidence to continue investing in Egypt. Combined with the progress we have made operationally over recent months, this demonstrates the benefits of the investment programme that we continue to execute.
"We are already seeing tangible operational results. Production returned to growth in the first quarter for the first time since 2017, and our latest well results have exceeded expectations.
"The most recent well has identified significantly more gas resources than originally anticipated, highlighting both the quality of our acreage and the opportunities that remain across our portfolio. The result opens up additional development and exploration potential and further strengthens our confidence in the long-term outlook for the Egypt business."
Hall also acknowledged the support of the Ministry of Petroleum and Mineral Resources, EGPC and EGAS, and their efforts to encourage investors in the energy sector to increase domestic gas production and reduce country’s dependence on gas imports.
These efforts are paying off, with a number of discoveries being made recently. They include the oil and gas discovery by Agiba Petroleum Company, the joint venture between the Egyptian General Petroleum Corporation (EGPC) and Eni, in the Western Desert; a gas discovery made by Eni in the Nile Delta region, following its gas and condensate discovery in the Temsah concession in the Eastern Mediterranean; and a gas discovery by the USA's Apache, in collaboration with EGPC, in the Western Desert.
the crisis and the increased focus on energy security are renewing interest in hydrogen and hydrogen-based fuels. (Image source: Adobe Stock)
The conflict in the Middle East has disrupted global production and trade in hydrogen-based products such as fertilisers, fuels and industrial feedstocks, exposing vulnerabilities in supply chains, according to the latest edition of the IEA’s Global Hydrogen Review
The report finds that the crisis and the increased focus on energy security are renewing interest in hydrogen and hydrogen-based fuels, although low-emissions hydrogen remains at a relatively small scale.
Demand for hydrogen worldwide surpassed 100 million tonnes in 2025, according to the report, while production of low-emissions hydrogen grew by 20% to almost 1 million tonnes. However, persistent barriers including high costs, uncertain demand, complex regulations and a lack of infrastructure continue to slow the development of low-emissions hydrogen, putting 2030 targets announced by governments increasingly out of reach.
"The current crisis has highlighted how deeply economies around the world depend on trade in hydrogen-based products and the significant role of the Middle East in those supply chains," said IEA executive director Fatih Birol. "Countries are looking for ways to make their energy systems more resilient and diversified. Low-emissions hydrogen can play an important role in those efforts over time, but stronger policy support and much faster deployment will be needed before it can make a meaningful contribution at scale."
Fertiliser markets have been particularly affected by the conflict in the Middle East, which is home to around one-sixth of global hydrogen production, the majority dedicated to the production of chemicals, fertilisers and refined oil products. The region accounts for more than 10% of global refining capacity, ammonia and urea production, and close to 17% of methanol production.
The region makes up over one-quarter of global trade in ammonia, almost 40% of urea trade and almost 45% of methanol trade, and one-third of its refining capacity is export-oriented. The closure of the Strait of Hormuz has severely disrupted the supply of all these products. The production of hydrogen-based fuels outside the Middle East has also been affected, particularly in Asia, where countries are very dependent on natural gas imports from the Middle East.
Disruptions to production, exports and shipping routes have contributed to shortages and price volatility across global markets with the increase in fertiliser costs posing risks for food supply chains, especially in import-dependent agricultural economies.
Low-emissions hydrogen
Low-emissions hydrogen production grew by 20% in 2025 to reach almost 1 Mt and is set to exceed 1% of global hydrogen production for the first time, but progress is concentrated in a small number of projects. However investment momentum weakened in 2025, with delays to final investment decisions and a shrinking pipeline of projects highlighting the challenges facing the sector.
Despite continued policy support in some markets, low-emissions hydrogen and hydrogen-based products remain significantly more expensive than conventional alternatives in most markets. The pipeline of announced projects for producing low-emissions hydrogen by 2030 has shrunk by around a quarter since last year to 27 million tonnes due to delays and cancellations, and the number of projects likely to become operational by 2030 has fallen significantly.
Demand uncertainty remains a key constraint for scaling up low-emissions hydrogen development, with offtake agreements at low level. This is cited by developers as one of the largest barriers to investment.
SAS is active in shallow-water offshore drilling operations.
Saipem has signed a legally binding sale and purchase agreement with ADES Saudi Limited Company, an indirect subsidiary of ADES Holding Company (ADES) for the sale of its entire shareholding (owned through its subsidiary Saipem International B.V.) in Saudi Arabian Saipem Limited (SAS)
SAS is active in shallow-water offshore drilling operations, with a fleet comprising three owned jack-up rigs (Perro Negro 7, Perro Negro 8, Perro Negro 10) and two leased jack-up rigs (Perro Negro 11 and Perro Negro 13).
In 2025, SAS recorded revenues of Saudi Arabian riyals 636 million, equivalent to US$170mn.
The value of the transaction amounts to US$285mn on a debt-free/cash-free basis and will be paid in cash at closing, subject to customary adjustment mechanisms.
The proceeds from the transaction will be used in line with the objectives of Saipem’s industrial plan.
Upon completion of the transaction, the parties will enter into a bareboat charter agreement that will allow Saipem to continue its ongoing operations in Mexico with the Perro Negro 10 rig and to ensure full compliance with its existing commitments.
The transaction represents a further step in the implementation of Saipem’s strategy aimed at focusing its portfolio on deepwater and harsh-environment offshore drilling, strengthening the Group’s positioning in higher-complexity, higher-value-added segments.
Completion of the transaction, indicatively expected by the third quarter of 2026, is subject to the satisfaction of customary conditions precedent, including the obtainment of applicable regulatory approvals.
In connection with the transaction, Saipem is advised by Moelis & Company UK LLP, acting as financial advisor and by Clifford Chance, together with AS&H Clifford Chance, as legal counsel.
The project will boost gas output from the Bahr Essalam gas field. (Image source: Adobe Stock)
The new concession will allow the development of large gas cap resources.
Blue Ocean Decom has officially launched to provide engineered, specialist subsea removal solutions for the offshore energy sector.
Blue Ocean Decom has officially launched to provide engineered, specialist subsea removal solutions for the offshore energy sector.
The offshore energy sector faces a monumental shift. Operators must dismantle and safely remove decades of ageing infrastructure from the ocean floor. Regulators increasingly demand timely compliance. Environmental responsibility now dictates every operational move. Decommissioning no longer represents a simple back-end obligation. The industry now treats it as a top strategic priority. Operators face immense pressure to execute these complex projects with absolute precision. Blue Ocean Decom has officially launched to address this exact challenge. The new business operates as a specialist subsea removal and decommissioning solutions provider.
Alfie Cheyne backs this new enterprise. Cheyne stands as one of the most recognised figures within the offshore industry. He holds a proven track record as a builder of successful international service companies. His impressive portfolio includes the creation and rapid growth of ACE Winches. Managing Director Ross Anderson leads Blue Ocean Decom on an operational level. Anderson brings an incredible amount of field and project leadership experience to the table. He has previously directed major offshore decommissioning campaigns around the world. His extensive background includes highly complex operations within the Middle East.
Strategic Global Expansion
The company seeks aggressive international growth immediately following its launch. Leadership has identified the Middle East as a key priority region. They have also named the Asia Pacific region and the UK offshore sectors as primary operational targets. Global decommissioning activity continues to accelerate at an unprecedented pace. Operators desperately seek out dependable partners to handle this massive workload. Clients require dedicated experts who can deliver engineered decommissioning solutions. They need specialist firms capable of mobilising highly tailored equipment packages quickly. Operators must also deploy deeply experienced technicians to the field. These technical specialists must fundamentally understand the schedule-critical nature of subsea removal operations. The leadership team built Blue Ocean Decom specifically to meet this exact operational requirement.
Chairman Alfie said: "I've spent my career backing and building specialist service businesses in the offshore sector, and the pattern is always the same: the market rewards focus. As decommissioning activity grows, subsea removal deserves the same level of specialist attention as any other critical path discipline. That's the gap Blue Ocean Decom has been built to fill, with Ross leading a team whose entire attention is on doing this one thing extremely well."
Ross added: "The subsea removal phase is a defining element of any decommissioning campaign, influencing safety, schedule and overall project performance. As the industry scales up, it needs partners who treat this scope with the focus and precision it demands. That's exactly the focus we've built this business around."
Specialist Decommissioning Solutions
Ageing offshore infrastructure drives a massive surge in global decommissioning demand. Regulators push operators hard to remove redundant assets quickly. Energy companies face intense scrutiny regarding their planning certainty. Execution discipline remains paramount throughout the entire removal process. Environmental responsibility remains a constant requirement for all offshore operators. Blue Ocean Decom responds directly to this industry-wide shift.
The new company focuses exclusively on specialist decommissioning solutions. The firm provides specialised equipment packages to support complex platform and well cutting operations. The operational team handles the safe subsea asset removal of pipelines and risers. They also offer comprehensive services for seabed preparation and subsequent clearance. Subsea asset recovery represents another core component of their extensive service offering. The business delivers this highly focused approach through advanced engineering practices. The team consistently creates tailored project solutions to meet specific client needs. A dedicated group of professionals executes these complex offshore decommissioning projects.
Blue Ocean Decom places its equipment and personnel strategically across key global hubs. This international footprint allows the company to execute rapid mobilisation. The firm can guarantee project-specific deployment regardless of the geographic location. Effective subsea decommissioning must return the seabed to a completely safe and compliant condition. The team removes redundant structures efficiently. They ensure their work produces minimal environmental impact. Delivering this safe outcome remains central to the overarching purpose of the company.
Ross added: "A dedicated decommissioning partner to operators and Tier 1 contractors fits where the industry is heading. We've built this company to be exactly that."
The project will unlock more than 600 million standard cubic feet per day (scfd) of natural gas and associated gas liquids. (Image source: Adobe Stock)
Oil and gas continues to underpin much of the industry's revenue base.
The agreements will expand the chemicals ecosystem. (Image source: ADNOC)
TA’ZIZ, a joint venture between ADNOC and ADQ, has signed long-term agreements spanning offtake, feedstock and sales across its chemicals portfolio, valued at US$28.5bn (AED104.6bn)
Signed at the Make it in the Emirates Forum, the agreements, valued at US$28.5bn, secure both global offtake and reliable local feedstocks, allowing for large-scale chemical production within the UAE and reinforcing TA’ZIZ’s role in building a fully integrated domestic chemicals ecosystem. The deals include sale agreements with ADNOC and Proman for methanol; Emirates Global Aluminium (EGA) for caustic soda; Mitsubishi Corporation for ethylene dichloride (EDC), vinyl chloride monomer (VCM) and caustic soda; Mitsui & Co. for EDC and caustic soda; Sanmar Group for EDC and VCM; Tricon for PVC, EDC and caustic soda; and Vinmar for EDC and polyvinyl chloride (PVC).
ADNOC Gas secured a 25-year feedstock agreement to supply natural gas to the TA'ZIZ methanol project valued at over $5 billion (AED18.4 billion). TA’ZIZ also agreed a 20 year salt supply agreement with Abu Dhabi based Sama Salt to support production at its PVC complex.
Mashal Saoud Al-Kindi, CEO of TA’ZIZ, said, “These long term agreements represent a defining milestone for TA’ZIZ and for the UAE’s industrial growth ambitions. By securing both global demand and reliable local feedstock, we are translating vision into delivery, anchoring world scale chemicals production, strengthening domestic value chains and creating enduring economic value, jobs and supply chain resilience for the UAE.”
Together, these agreements leverage local resources to secure a reliable and sustainable supply of critical raw materials, further strengthening domestic value chains and advancing the UAE’s industrial self sufficiency.
TA’ZIZ is a manufacturing, industrial services, logistics and utilities ecosystem that enables the production of transition fuels and new products across the chemicals value chain, supporting ADNOC’s ambition to become a top three global chemicals player as well as the UAE’s industrial development and economic diversification ambitions.
The TA’ZIZ Industrial Chemicals Zone is set to produce 4.7 million tonnes per annum (mtpa) of chemicals once construction is completed in 2028. This includes a 1 mtpa ammonia plant, a 1.8 mtpa methanol plant and 1.9 mtpa of marketable products from its integrated polyvinyl chloride (PVC) complex. The PVC complex, which produces PVC, ethylene dichloride (EDC), vinyl chloride monomer (VCM), and caustic soda, will be one of the world’s top three largest single site PVC complexes.
Also at the Make it at the Emirates Forum, TA’ZIZ and Alpha Dhabi Holding announced a strategic collaboration agreement for around US$10 bn (AED36.7bn) in capital investment in new industrial chemicals in the TA’ZIZ industrial chemicals ecosystem in Al Ruwais Industrial City, Al Dhafra region of Abu Dhabi.
The partnership could produce up to 14 new chemicals, delivering around 2.2mn tonnes per annum (mtpa) of additional chemical capacity in the TA’ZIZ industrial chemicals ecosystem in Al Ruwais Industrial City. The new chemicals, which include styrene and polystyrenes, acrylic acid and derivates, polyols, MDI, epoxy resins and linear alpha-olefins, are based on domestic demand and could substitute key products currently imported into the UAE, while strengthening local supply chain resilience. The partnership supports the UAE’s national industrial priorities, including the Make it in the Emirates (MIITE) initiative and the country’s industrial strategy, by strengthening domestic manufacturing capability and advancing self-sufficiency in strategically important chemical products.
Musaab Al Mulla (right) in conversation with Daniel Evans, VP, global head, fuels & refining, S&P Global Energy. (Image source: S&P Global Energy)
Demand could also drop in markets that have so far weathered the crisis. (Image source: Adobe Stock)
The upstream sector is at the forefront of IIOT adoption. (Image source: Adobe Stock)
The adoption of Industrial Internet of Things (IIOT) is accelerating throughout the value chain in the oil and gas sector, says intelligence platform GlobalData
GlobalData’s Strategic Intelligence report, “Industrial Internet in Oil & Gas,” reveals that artificial intelligence (AI) and digital twins will revolutionise the Industrial Internet in oil and gas, powering smarter connected assets across exploration, drilling, and production. This technology shift enables autonomous operations, predictive maintenance, enhanced efficiency, and the agility crucial for navigating volatile markets.
The upstream segment is at the forefront of Industrial Internet adoption, according to the report. Projects are increasingly capital intensive and geographically remote, facing new subsurface challenges and rising environmental, social, and governance (ESG) scrutiny. As a result, real-time monitoring and modelling can make a big difference to outcomes. Digital twins, AI-driven drilling optimization, and field-wide
IoT networks enable operators to simulate outcomes, remotely manage wells, predict equipment failures, and integrate new production more rapidly.
In the midstream segment, sensors on pipelines and tanks provide real-time data on pressure, flow, and integrity, enabling faster leak detection and improved responses to anomalies.
In the downsteam operations, real-time data collection and advanced process automation now underpin production optimisation, emissions control, and energy management. Digital twins are enabling continuous process modelling, rapid scenario testing, and proactive troubleshooting.
Ravindra Puranik, Oil and Gas Analyst at GlobalData, commented, “The oil and gas industry in 2026 faces unprecedented external pressures: high and volatile prices, supply uncertainty, climate change concerns, rising consumption of cleaner energy, and realigning global energy trade routes. Besides these, companies are facing significant operational challenges driven by factors such as US tariffs, the Iran conflict, sanctions, and protectionist policies. To secure future growth and resilience, operators are embracing the Industrial Internet across their businesses.
Puranik added, “Autonomous operations are rapidly becoming standard in digitally advanced oilfields, particularly in offshore environments such as fixed platforms and FPSOs, where remote and reliable management is both a logistical necessity and a cost imperative. Also, cloud-based analytics and AI systems connect the dots from raw input to final distribution, improving the accuracy of demand forecasting and inventory management even in volatile markets.”
According to Globaldata, the global Industrial Internet market is expanding rapidly, and is forecast to grow at a compound annual growth rate (CAGR) of 16% from 2024 to 2029, to reach US$552.7bn in revenue by 2029, of which the energy sector is expected to generate US$79bn.
Under the contact, Halliburton will deploy intelligent automation solutions for fracturing to optimise performance in real time and support disciplined implementation across multi-well campaigns.
The platform will show how Geoteric’s solutions for AI-based interpretation of seismic data can be connected with simulators from SINTEF. (Image source: Geoteric)
Competence is a must for high-risk tasks. (Image source: Adobe Stock)
How do complacency and human factors contribute to workplace injuries, and how can you prevent complacency-related injuries and incidents?
That is the subject of a webinar hosted by HSE Review in association with SafeStart, to take place on Wednesday 1st April 2026 at 2pm GST, which will shine a light on the neuroscience behind competence, complacency and human factors.
Safety professionals have known for years that “complacency is a silent killer.” They have also suspected that complacency was a contributing factor in almost every unintentional injury or incident. Unfortunately, from a neuroscience perspective, it is impossible to stop people from becoming complacent once they are competent. And for high-risks tasks in particular, competence is a must.
Even more unfortunately, many (most) companies do not know what to do to help their employees deal with complacency, which leads to mind not on task/risk.
In this session, participants will:
• Understand the neuroscience behind complacency and why it cannot be eliminated once competence is achieved
• Recognise the two stages of the complacency continuum and how human factors impact critical decision-making
• Learn practical skills to prevent complacency-related injuries, including attentive habits, looking for risk patterns in others, analysing close calls and small errors to prevent agonising over large ones, and using self-triggering skills, to deal with rushing, frustration and fatigue which, when combined with complacency, can cause fatalities
• Explore how concepts such as fail-safe can help compensate for complacency leading to mind not on task.
Register for the webinar here
Our speaker is Larry Wilson, a pioneer in the area of Human Factors in safety. He has been a safety consultant for over 25 years and has worked on-site with hundreds of companies worldwide. Larry is the author of SafeStart, an advanced safety and performance awareness programme, successfully implemented in more than 4,500 companies in 75 countries, with more than five million people trained. He is the moderator of the SafeConnection expert panels series and has authored and co-authored a number of books, the latest being “25 Years of Original Thought-Innovations in Safety, Human Error and Performance”. Larry is also an active keynote speaker at health and safety conferences around the globe (32 countries so far).
Participants are guaranteed an hour of engaging and thought-provoking interactive discussion and debate and will take away the understanding, skills and strategies to help prevent complacency-related injuries and incidents.
So don’t delay, register for the webinar here
SafeStart Trainer Certification – Global Training Series
Following strong demand last year and impact across global markets, we’re also launching the SafeStart Trainer Certification – Global Training Series, starting with Dubai on 7–8 April 2026.
This is a practical, human factors–based certification designed to help organisations reduce incidents, strengthen decision-making, and improve overall safety performance, on and off the job.
Find out more information and register here:
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The majority of projects are still at a feasibility stage. (Image source: GlobalData)
The global hydrogen economy is evolving and is entering a new inflection point in 2026 amid shifting market realities, policy uncertainties and execution challenges
That’s according to Hydrogen in Oil and Gas, a new report from leading intelligence platform GlobalData, which reveals that as of February 2026, active low-carbon hydrogen capacity stood at around 2.2 million tonnes per annum (mtpa), with over 460 projects in operation, compared to 104 in 2020. However, demand uncertainty and limited investment are barriers constraining the development of new low-carbon hydrogen projects, particularly in North America, where policy change has negatively impacted certain high-profile projects.
GlobalData projects that global hydrogen production capacity could reach 82.3 mtpa by 2030, taking into account the active under development projects, but around 57% of projects due to start by then are still at the feasibility stage, and are unlikely to be commissioned on schedule.
Ravindra Puranik, Oil and Gas Analyst at GlobalData, commented, “Despite an impressive increase in count of active low-carbon hydrogen projects, capacity additions remain far below the levels needed to meet the near-term targets set by the IEA Net Zero Emissions (NZE) scenario.”
GlobalData notes the scarcity of large-scale projects, with only 10 of the 2,335 upcoming projects worldwide having capacities exceeding 1 mtpa and a few others touching the 0.5 mtpa mark. Among the 10 high-capacity projects, nine are for green hydrogen, and one is for blue hydrogen.
Puranik continues: “Despite accounting for the bulk of the project numbers, the cumulative capacity of green hydrogen initiatives remains relatively modest. Thus, their output is not large enough to displace established energy sources, such as natural gas or utility-scale renewables. Developers face significant challenges in scaling up, including overcoming infrastructure constraints, securing long-term offtake agreements, and ensuring financial viability. Until more large-scale progress through the development pipeline, hydrogen’s share in the global energy mix will likely remain constrained.”
“Looking ahead to 2030, global low-carbon hydrogen capacity is expected to expand once demand picks up, backed by increased private investment and supportive policy frameworks, as it is a critical energy source to achieve corporate net-zero commitments. Nevertheless, achieving these ambitions will require overcoming persistent financial, regulatory, and infrastructure barriers in the near term to ensure that project announcements translate into operational capacity by the end of the decade.”
Among oil and gas majors, BP leads in green hydrogen, with nearly 3 mtpa of active and upcoming capacity with projects in Mauritania, Australia, and across Europe. TotalEnergies has also increased its focus on green hydrogen projects, alongside industrial gas leaders like Air Liquide and Air Products. Meanwhile, Shell and Equinor are expected to lead in blue hydrogen capacity by 2030.
Middle East developments
As for the Middle East, DNV forecasts that region is on track to become the biggest hydrogen exporter by 2060 — not only sustaining its share of global hydrocarbon supply but potentially expanding it. By 2060, the Gulf Cooperation Council (GCC) is projected to produce 19 million tonnes of hydrogen annually, alongside significant growth in ammonia exports, DNV’s Oil & Gas Decarbonisation in the Gulf Region report says. Integrating hydrogen production with CCUS, renewables and existing industrial clusters will enable “cost-competitive pathways” that support decarbonisation across domestic and international value chains, DNV adds.
Currently, hydrogen demand in the GCC is driven almost entirely by its role as an industrial feedstock, but it is now evolving to a strategic energy carrier. Despite this transformation, hydrogen and its derivatives are projected to contribute just 3.1% of the region’s total final energy consumption by 2060 – well below the global average of 6%, according to DNV, reflecting both the region’s slower initial update of hydrogen and its abundant low-cost fossil fuel resources.
See more on DNV’s Oil & Gas Decarbonisation in the Gulf Region report in the latest issue of Oil Review Middle East here
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