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Arcius Energy, the bp and XRG joint venture focused on Egypt gas development, has announced the Final Investment Decision (FID) to develop the Harmattan gas field in the El Burg Offshore concession area, one of the joint venture’s first projects in Egypt

The investment, estimated at around US$500mn, aims to increase natural gas production to meet domestic market needs and follows hard on the heels of Arcius’s acquisition of the El Burg Offshore concession area in February 2026, which lies approximately 2.5 km north of Ras El-Barr in Damietta. Arcius plans to develop the field through drilling of up to three wells and the installation of a fixed offshore platform, connected by a 50-km pipeline to onshore processing facilities located near Port Said. Expected start-up of production is in 2028. The project aims to produce approximately 150mn cubic feet of gas and 3,300 barrels of condensates daily.

Pharaonic Petroleum Company (PhPC), acting on behalf of El Burg Offshore Petroleum Company, has awarded the Engineering, Procurement, Construction, and Installation (EPCI) contract to ENPPI, with Petroleum Marine Services and Petrojet as subcontractors.

Naser Al Yafei, chief executive officer of Arcius, commented, “The Final Investment Decision to develop the Harmattan field marks an important milestone in advancing one of our first projects in Egypt toward production. It reflects our confidence in the potential of Egypt’s energy sector and our commitment to close cooperation with the Egyptian government, EGAS, and our execution partners to strengthen Egypt’s natural gas supply, support energy security, and reinforce Egypt’s position as a regional energy hub in the Eastern Mediterranean.”

Arcius Energy was established in December 2024 as a regional gas platform focused initially on the development of gas assets in Egypt and the wider Eastern Mediterranean, with bp holding 51% and XRG, ADNOC’s international investment arm, holding 49%. It holds 10% of Shorouk which contains the producing Zohr field; 100% of North Damietta which contains the producing Atoll and Qattameya fields; 100% of El Burg Offshore which contains the Harmattan field; 100% of the North El Tabya exploration concession, and 50% of the Bellatrix–Seti East and North El Fayrouz exploration concessions.

The agreement, signed at the Egypt Energy Show held in Cairo from 30 March-1 April, comes as Egypt is pushing to boost its oil and gas production in a bid to reverse recent declines and reduce energy imports. Recent discoveries are helping to achieve this aim, and there are plans to drill 480 new exploration wells over the next five years at a cost of around US$5.7bn.

On the sidelines of the Egypt Energy Show, majors such as bp, Chevron and Eni confirmed their commitment to make further investments in the market, acknowledging the efforts made by the Egyptian government to improve the investment environment. bp, which was recently awarded the licence for the North-east Alamein Offshore concession, signed an agreement with South Valley Egyptian Petroleum Holding Company (GANOPE) to carry out exploration in the Red Sea.

“We are excited about bringing the drillship, Valaris DS-12, back to Egypt to embark on a multi-well campaign to produce, develop and explore for more gas resources,” said William Lin, executive vice president for Gas and Low Carbon Energy in a LinkedIn post.

Also signed at the Egypt Energy Show was an MoU between slb and Ganope to design and deploy cost-effective geophysical solutions that derisk exploration and unlock new resource potential in the Red Sea.

As an uneasy ceasefire takes hold, huge questions remain about the resumption of traffic through the Strait of Hormuz and the time it will take for Middle East operators to restore production

The 11mn bpd of upstream production currently shut-in across the Middle East can only be restored when export logistics normalise, says energy consultancy Wood Mackenzie.

"A 'workable system' of transit and shipowner confidence in the security of the transiting vessels is essential," said Alan Gelder, SVP Refining, Chemicals and Oil Markets at Wood Mackenzie. "This includes availability of insurance for transiting vessels, facilitating commercial trade financing, sustained outbound vessel transits through the Strait of Hormuz making current oil on water available to the global refining market, and sustained inbound vessel transits through the Strait making ballasting vessels available to load crude at Gulf load ports. There also needs to be confidence in viability of transit during and beyond the current two-week ceasefire."

"Ballasting vessels are unlikely to enter via the Strait of Hormuz any sooner than a 'just in time' logistics basis, at risk of becoming trapped if hostilities resume," Gelder added. "Onshore storage drawdown remains constrained by over-the-jetty load rates, onshore inventories cannot be instantaneously transferred to ballasting vessels."

As export volumes ramp up, freed up storage capacity will allow upstream production and refining operations to resume. The level of storage varies from around a month for Saudi Arabia and the UAE, to less than two weeks for Iraq and Kuwait.

"The initial recovery from major fields will be more than sufficient to meet the ramp-up of export volumes. Shipping logistics will remain the constraint on upstream recovery for several weeks," said Fraser McKay, head of Upstream Analysis at Wood Mackenzie. "Thereafter, as those constraints begin to ease, the constraints on supply will shift to the upstream production, and this will expose the different challenges each country faces. More than half of most field's previous supply levels could be restored before shipping constraints ease. Thereafter, different recovery profiles will emerge."

McKay noted that it will take countries like Iraq as long as six to nine months  to reach prior production levels given the complexities involved, due to both reservoir management and resource constraints.

In other countries, while there is little damage to upstream infrastructure, refineries could require repair. So even though exports will ramp up, previous production highs will take much longer to reach, although ultimately most, but not all production will be restored to prior levels. Restoring production too rapidly could risk doing more long-term damage, however, warned McKay.

Gas recovery

As for LNG supply, even if LNG cargoes are able to exit the Strait of Hormuz, relieving some of the pressure on the gas market, for there to be real structural change in supply the Ras Laffan site in Qatar would need to restart its operable trains, according to Tom Marzec-Manser, Europe Gas and LNG Wood Mackenzie.

Wood Mackenzie assumes that if QatarEnergy began restarting Ras Laffan at the start of May, it would take until the end of August for the 12 trains to return to full service. A restart of just the 41mtpa North site would take just over a month. However the South site which originally had a 36mtpa capacity has sustained damage. These two additional trains will not return to service for a number of years and reduce the site's capacity to 24 mtpa.

Wood Mackenzie assumes the ADNOC's 5 mtpa Das Island LNG plant in the UAE will be able to return to service fairly quickly.

"Outside LNG, domestic gas infrastructure in the UAE has been harder hit than oil, and that recovery process could require longer-term repair work," Marzec-Manser added. "Sustained disruption at Habshan would have wide-ranging implications for domestic gas availability, compelling the UAE to reduce reinjection volumes or increase piped imports via the Dolphin pipeline."

Aramco, Honeywell and King Abdullah University of Science and Technology (KAUST) are collaborating to scale up the development of Crude-to-Chemicals (CTC) technology in a bid to maximise the value of crude oil and reduce costs associated with CTC conversion 

The new CTC pathway will entail converting crude oil directly into light olefins and other high-demand chemicals, resulting in improved fuel efficiency, carbon utilisation, and process economics—allowing for more efficient and cost-effective production at scale.

The collaboration aligns with Saudi Arabia’s Vision 2030 by helping to advance economic diversification, build national research and technology capabilities, and strengthen the Kingdom’s position in the global chemicals market, combining academia and industry expertise to accelerate technology development and national capabilities.

Dr. Ali A. Al-Meshari, Aramco senior vice president of technology oversight & coordination, said, “This collaboration with Honeywell UOP and KAUST furthers Aramco's efforts to drive innovation and shape the future of petrochemicals. By harnessing the power of cutting-edge technologies, we aim to enhance energy efficiency and unlock increased value from every barrel of crude. This novel Crude-to-Chemicals process is aligned with our vision of supporting the global transition towards cleaner, high-performance chemical production. Moreover, this initiative demonstrates our focus on contributing to the growth of a vibrant ecosystem, where the deployment of innovative technologies can create lasting value for our stakeholders, our communities, and the environment.”

Rajesh Gattupalli, Honeywell UOP president, added, “This agreement marks a defining moment in our strategic collaboration with Aramco and KAUST – and in the global evolution of Crude-to-Chemicals technology. With Honeywell UOP’s deep expertise in catalytic process design and commercial scale-up, we’re well positioned to drive this innovation forward.”

Halliburton is strengthening its drilling automation services offering with the acquisition of Sekal, a leader in advanced drilling automation solutions

The acquisition of Sekal, formerly a subsidiary of Sumitomo Corporation, combines Halliburton’s LOGIX automation and remote operations with Sekal’s advanced DrillTronics automation platform and services to deliver a comprehensive and industry-leading drilling automation portfolio. These solutions can also be combined with Halliburton’s LOGIX Automated Geosteering service, which combines automation, real-time intelligence and advanced geological modelling to optimise well placement, maximise recovery and improve operational efficiency. This integration supports seamless automated control and optimisation of drilling operations, integrating well placement, wellbore hydraulics, and rig operations in real time.

The Halliburton-Sekal automation solution is currently deployed across a number of projects worldwide and provides real-time advanced models of subsurface, wellbore fluid, and pressure systems, along with smart directional drilling tools and automated rig controls, thereby facilitating accurate drilling and well placement along with automated tripping operations and enabling a reduction of up to 25% in well delivery times.

"This acquisition rapidly expands our automation capabilities and delivers industry-leading digital solutions that lower well construction costs, increase recovery, and reduce operational risks for our customers. By bringing together our field-proven technologies, we unlock the full potential of digital well construction and set a new standard for automated drilling operations", said Jim Collins, vice president, Halliburton Sperry Drilling.

Jarle Vaag, Sekal CEO, added, "Joining Halliburton is a natural evolution for Sekal. The team at Sekal has worked closely with our clients providing our technology and services to the industry regardless of the service providers. While we will continue to support this market, the opportunity with the combined expertise of Halliburton and Sekal to advance our technical capability and accelerate the adoption of digitally integrated well construction will deliver a unique automation solution to our new and existing customers worldwide."

In the oil and gas industry, where every second counts and every decision impacts profitability and safety, robust security is not just a luxury – it's a necessity

From protecting critical assets to safeguarding human lives, security systems must meet the highest standards of reliability and performance.

Pelco, a leader in video security, is uniquely positioned to address the challenges faced by oil and gas companies in the Middle East, offering a fresh perspective on how to optimise security systems seamlessly. With our upcoming online event, we invite you to explore how Pelco can help tackle worker safety, asset protection and operational efficiency in this complex industry.

Addressing oil and gas challenges head-on

Oil and gas operations in the Middle East span harsh deserts, sprawling refineries and high-risk offshore environments. Physical, environmental and digital threats are converging, and security systems must evolve to meet these overlapping demands. Our upcoming online event will focus on three critical areas where Pelco's expertise can make a difference:

1. Improve worker safety and HSE compliance

Ensuring worker safety is both a moral responsibility and a regulatory imperative. Health, Safety and Environmental (HSE) compliance is a top priority for oil and gas operations. Pelco's advanced portfolio is designed to help you meet these standards.

Edge-based analytics and intelligent video security can be valuable tools in supporting site safety. These systems can help detect safety incidents, such as slips or falls, especially in areas where oily surfaces, heat or dust create additional hazards. When incidents occur in remote areas, automated detection can prompt faster intervention, thereby closing the gap between the event and the response.

Personal Protective Equipment (PPE) compliance is another key safety concern. High temperatures in the Middle East can lead to discomfort, and in some cases, workers may be tempted to remove protective gear, such as hard hats or vests, for temporary relief. In this case, AI-enabled video analytics can help identify instances of non-compliance, enabling safety teams to address the issue before it becomes a liability.

Zone-based behavioural analytics can help detect when someone enters a restricted or hazardous area or remains in a dangerous zone longer than necessary. For example, loitering detection near flare stacks or storage tanks can support situational awareness and proactive incident mitigation.

2. Improve security and asset protection

From refineries in the desert to offshore rigs in corrosive marine environments, your assets operate under pressure, so your security systems must withstand these harsh conditions. In areas where explosive gases or dust particles may be present, even basic equipment can pose risks. That’s why choosing video solutions built for hazardous environments is critical.

ExSite Enhanced cameras, featuring 316L stainless steel construction and certifications such as ATEX and IECEx, are designed for use in hazardous atmospheres. Whether it’s observing pipeline manifolds, wellheads or chemical storage areas, these systems deliver dependable performance in high-risk environments. In corrosive coastal locations, such as LNG terminals or offshore rigs, Pelco’s anti-corrosion models withstand salt spray, humidity and chemical exposure without compromising visibility.

For perimeter defence, long-range Silent Sentinel cameras give security teams early warning of approaching threats, detecting vehicles, vessels or drones from kilometres away in fog, darkness or dust. These systems are especially valuable for remote desert pipelines or unstaffed offshore installations, where rapid detection is critical to prevent disruptions.

3. Minimise downtime and maximise uptime

Every minute of downtime impacts revenue. For oil and gas operations, the cost of unplanned outages is measured in millions of dollars. With Pelco, your video security can become an operational asset.
Radiometric thermal cameras can detect overheating in transformers, compressors and electrical panels, allowing teams to take action before equipment failure occurs. At the same time, Pelco’s camera image health analytics help ensure your video infrastructure is always performing at its best. Our cameras automatically detect issues such as lens obstructions, misalignment or tampering, reducing the need for manual inspections and helping ensure your security coverage is always clear, optimised and ready when it matters most.

Join us to discover the Pelco advantage

We invite you to join our upcoming online event, where industry leaders and Pelco experts will dive deeper into these challenges and solutions. Together, we'll explore how Pelco can be the missing ingredient to supercharge your security and drive operational excellence in the Middle East oil and gas sector.

Don't miss this opportunity to gain actionable insights and position your operations for success. Register now and discover how Pelco can transform your approach to security.

The Middle East and North Africa (MENA) is set to become the world’s largest hydrogen exporter by 2060, while maintaining a dominant position in global oil and gas markets, according to DNV’s Oil & Gas Decarbonization in the Gulf Region report

The report highlights how Gulf Cooperation Council (GCC) countries are cutting the emissions intensity of their core oil and gas production while continuing to play a central role in global energy supply, presenting a picture of a region approaching the energy transition from a position of confidence and capital strength. Reductions in emissions intensity are occurring alongside continued hydrocarbon production and investment across renewables, electrification, hydrogen, methane abatement, digitalization, and carbon capture.

Since 2005, the GCC has produced nearly 18% of global oil and gas, a share expected to increase as investment continues in low-cost, advantaged resources. As global energy demand increasingly shifts toward Asia, the region’s location and cost competitiveness strengthen its position as a preferred supplier. At the same time, decarbonization measures are becoming an integral part of long-term competitiveness.

“The global energy transition will not progress at the same pace across regions, nor will it follow a single pathway,” said Brice Le Gallo, vice-president & regional director for Southern Europe, MEA & LATAM, Energy Systems at DNV. “In the Middle East, oil and gas remain central to economic stability and global energy security. The key challenge is to reduce their emissions footprint while accelerating investment in the technologies needed for a lower-carbon energy system.”

Electrification is being used to cut Scope 2 emissions from pumps, compressors, and offshore facilities, through grid connections, renewable power, and hybrid solutions. These efforts are supported by energy-efficiency measures and the use of digital tools and artificial intelligence to optimise drilling, reservoir management, and asset operations, reducing energy intensity and emissions per barrel produced.

Methane reduction remains one of the most immediate and cost-effective options for lowering emissions. Across the GCC, routine flaring is planned to be phased out by 2030 and leak detection and repair (LDAR) programmes are increasingly standard. National oil companies are also aligning with international methane initiatives, enabling continued production growth while reducing methane intensity in line with national net-zero targets.

GCC countries are realigning domestic energy systems to reduce oil and gas use domestically and free up volumes for export and low-carbon fuel production. Growth in renewables, electrification of transport and buildings, and efficiency gains are driving this shift. Investment in downstream industries, petrochemicals, and low-carbon fuels is also changing export profiles, moving beyond crude oil toward higher-value and lower-carbon energy products.

With access to low-cost natural gas, strong solar resources, and established industrial and export infrastructure, the region is well placed to scale both low-carbon hydrogen (produced from natural gas with carbon capture) and renewable hydrogen produced through electrolysis. By 2060, the Middle-East and North Africa region is projected to produce around 19 million tonnes of hydrogen and 13 million tonnes of ammonia per year, exporting about 50%, mainly toward Europe and advanced Asian economies.

“Hydrogen, ammonia, and carbon capture are becoming core elements of the GCC’s energy export model,” said Jan Zschommler, market area manager for the Middle East, Energy Systems at DNV. “As emissions requirements tighten, access to international markets will increasingly depend on carbon intensity. Integrating hydrogen production with renewable power, carbon capture, and existing industrial clusters allows the region to remain competitive while meeting these requirements.”

Carbon capture, utilization and storage (CCUS) is also set to grow. In January 2026, the UAE's Supreme Council for Financial and Economic Affairs has introduced Carbon Capture Policy as a further commitment to meeting their carbon reduction targets. Captured CO₂ volumes (including CO₂ removal) are expected to reach around 250 million tonnes per year by 2060, equivalent to roughly 8% of regional energy-related and industrial emissions.

Bioenergy with carbon capture (BECCS) and direct air capture (DAC) combined are expected to remove around 81 million tonnes of CO₂ per year by 2060, helping to offset emissions from sectors that are more difficult to decarbonise.

The full report is available at https://www.dnv.com/energy-transition-outlook/oil-and-gas-decarbonization-in-the-gulf-region/