In The Spotlight
Fatih Birol, IEA executive director. (Image source: IEA)
The 32 Member countries of the International Energy Agency have agreed to make 400 million barrels of oil from their emergency reserves available to the market, the largest release of emergency oil stocks in the Agency’s history, to address the loss of supply stemming from the war in the Middle East and the effective closure of the Strait of Hormuz
In a statement, IEA executive director Fatih Birol noted that the conflict in the Middle East is having a significant impact on global oil and gas markets, with major implications for security, affordability and the global economy.
The conflict in the Middle East that began on 28 February 2026 has impeded oil flows through the Strait of Hormuz, with export volumes of crude and refined products currently at less than 10% of pre-conflict levels. Without sufficient routes to market and without sufficient storage, regional operators have been forced to shut in or curtail a substantial amount of production. They are also experiencing attacks on their energy and energy-related infrastructure.
An average of 20 million barrels per day of crude oil and oil products transited the Strait of Hormuz in 2025, or around 25% of the world’s seaborne oil trade. Options for oil flows to bypass the Strait of Hormuz are limited.
Refinery operations are also being disrupted, with implications for the jet fuel and diesel supplies.
“The situation of the natural gas markets is challenging, with few options to replace LNG cargoes from Qatar and the UAE. These have been reduced by 20%, leaving balances even tighter than for oil,” Birol remarked. Asia has been the most profoundly affected, and is forced to compete with other markets for LNG cargos.
“The oil market challenges we are facing are unprecedented in scale, therefore I am very glad that IEA Member countries have responded with an emergency collective action of unprecedented size,” said Birol. “Oil markets are global, so the response to major disruptions needs to be global too. Energy security is the founding mandate of the IEA, and I am pleased that IEA Members are showing strong solidarity in taking decisive action together.”
While this will alleviate the immediate disruption, the most important thing is to stabilise flows and allow traffic to resume through the Strait of Hormuz, he said.
The emergency stocks will be made available to the market over a timeframe that is appropriate to the national circumstances of each Member country and will be supplemented by additional emergency measures by some countries.
IEA members hold emergency stockpiles of over 1.2 billion barrels, with a further 600 million barrels of industry stocks held under government obligation. The coordinated stock release is the sixth in the history of the IEA, which was created in 1974. Previous collective actions were taken in 1991, 2005, 2011, and twice in 2022.
The IEA Secretariat will provide further details of how this collective action will be implemented in due course. It will also continue to closely monitor global oil and gas markets and to provide recommendations to Member governments, as needed.
“The IEA will continue its mission of upholding energy security, as we have done today for the oil markets, and will continue to do across the entire energy sector,” Birol concluded.
Brent and WTI prices pushed past US$115 a barrel on 9 March 2026. (Image source: GlobalData)
As Brent and WTI prices pushed past US$115 a barrel on 9 March 2026, the world was in for a major supply shock
“The latest price spike indicates that the market is rapidly transitioning from pricing in a logistics disruption to factoring in a potential supply shock. Initially, traders reacted to maritime risks in the Strait of Hormuz, which raised shipping costs and delayed cargoes. However, recent developments suggest that actual production and export volumes across key Gulf producers are now at risk, fundamentally tightening global supply expectations," said Jaison Davis, economic research analyst at GlobalData, an intelligence and productivity platform.
He went on to explain how the sharp price rise exposed the market’s spare capacity buffer. "Even relatively small disruptions to Gulf production can trigger outsized price movements because the region accounts for a disproportionate share of globally traded crude," Davis said.
“The current surge in prices also reflects the concentration risk within the global oil system. A large share of exports from Saudi Arabia, Iraq, Kuwait, and the UAE passes through the Strait of Hormuz, leaving global energy supply exposed to geopolitical disruptions in a single maritime corridor. Financial markets have already begun pricing in the broader macroeconomic consequences of the oil shock, including rising inflation expectations, currency volatility, and pressure on equity markets across energy-importing economies," he said.
Duration remains the most influential determining factor at this point. While prices may find balance if stability is restored in the Strait of Hormuz, it can easily lead to a structural supply deficit situation if there's no end in sight for the conflict.
“At the same time, should GCC states, along with Turkey, manage to influence the US and international diplomatic channels toward de-escalation, markets may begin to unwind some of the current geopolitical risk premiums. Tanker flows through the Strait of Hormuz could stabilise, insurance and freight costs could moderate, and production cuts could be reversed, gradually pushing oil prices closer to pre-crisis levels. Residual volatility would likely persist, but a credible ceasefire or mediation effort could alleviate worst-case supply fears and ease pressure on energy-importing economies.
"Nonetheless, oil markets will remain acutely sensitive to developments in the Gulf region. Pricing dynamics are increasingly shaped by security conditions and the resilience of export routes through the Strait of Hormuz. Even with short-term stabilisation in shipping, any lingering disruption to production, infrastructure, or tanker traffic risks sustaining elevated volatility, as well as renewed inflationary pressures for oil-importing countries,” said Davis.
New developments have driven oil prices sharply higher
A wave of force majeure declarations has swept through the Middle East's energy sector this month as the ongoing US-Israel war with Iran disrupts production, shipping, and exports across the Gulf region, writes Sania Aziz.
The declarations, which relieve companies from contractual obligations due to unforeseen events beyond their control, stem from Iranian retaliatory attacks on facilities, threats to maritime routes, and the near-total blockage of the Strait of Hormuz, which is a vital chokepoint for one-fifth of global oil supplies.
QatarEnergy, the world's largest liquefied natural gas (LNG) exporter, was among the first to act. On 4 March, the state-owned firm declared force majeure on LNG shipments after halting production at key facilities in Ras Laffan and Mesaieed following Iranian drone strikes.
The company cited attacks on its infrastructure and the inability to operate safely, with sources indicating restarts could take weeks or longer to avoid equipment damage.
Qatar supplies around 20% of global LNG, and the move has sent shockwaves through Asian and European markets reliant on these deliveries.
Kuwait Petroleum Corporation (KPC) followed suit on 7 March, declaring force majeure on crude oil and product exports while slashing output.
The decision was prompted by explicit Iranian threats to shipping safety in the Strait of Hormuz, ongoing regional attacks, and a severe shortage of available vessels in the Gulf.
KPC, a major naphtha and jet fuel supplier to Asia and Europe, cited these factors as making normal operations impossible.
Bahrain's Bapco Energies joined the list today, 9 March, announcing force majeure on group operations after an Iranian strike set its Sitra refinery ablaze, which is the kingdom's sole refining complex.
The company assured that domestic supplies remain secure under contingency plans, but exports and broader activities are severely impacted by the conflict.
Aluminium Bahrain (Alba), operator of one of the region's largest smelters, declared force majeure earlier in March on shipments.
Unlike others, Alba stressed that its facilities remain undamaged; the issue lies solely in halted shipping through the Strait of Hormuz, preventing outbound metal deliveries despite continued production.
The ripple effects extend beyond Gulf producers. China's Wanhua Chemical declared force majeure on for supplies to Middle East customers, blaming severe regional shipping disruptions.
These developments have driven oil prices sharply higher and raised fears of prolonged supply shortages.
Analysts warn that further escalations could prompt additional declarations from Saudi Arabia, the UAE, and others as storage fills and export routes remain blocked.
The situation remains fluid, with global energy markets on high alert.
The acoustic MP-FWI imaging implementation has demonstrated significant uplifts. (Image source: DUG)
Technological advancements in geoscience are often incremental—small steps that help refine our ability to understand the subsurface. But occasionally, we witness a genuine leap. DUG Technology’s Chief Geophysicist, Tom Rayment, considers the impact of elastic MP-FWI imaging and asks, "Is traditional seismic processing finally a thing of the past?"
For the past century, seismic data has been an invaluable tool for detecting hydrocarbons. Although methods have become more sophisticated, the fundamental workflow for turning acquired data into interpretable products largely remains the same. The advent of elastic multi-parameter full waveform inversion (MP-FWI) imaging represents a significant shift away from the traditional approach.
The acoustic MP-FWI imaging implementation has demonstrated significant uplifts without needing conventional time-processing, model-building, or depth-migration techniques. Elastic MP-FWI imaging is a further step-change, also deriving rock properties and effectively rendering the amplitude variation with angle (AVA) inversion workflow redundant. The approach will soon make conventional workflows obsolete, if it hasn't already.
Despite this monumental leap, the technology is still young, with ample room for more progress. Most FWI implementations use a single component of the acquired data (hydrophone for marine, vertical geophone/accelerometer for land). However, additional components offer complementary information that can further constrain results. Recent developments show that two-component towed streamer and ocean-bottom seismic MP-FWI imaging can further improve results and accelerate convergence.
The logical next step is to include horizontal components. Shear waves provide valuable subsurface information, especially in areas of strong P-wave absorption like gas bodies. Recent DUG projects are already demonstrating that the benefits of converted-wave processing can be realised with elastic MP-FWI imaging. Furthermore, on land, exploiting shear waves in the form of ground roll is now viable. What was once noise is now a useful signal, inverted via elastic FWI to provide high-resolution shear-wave-velocity models. Capturing near-surface complexity is crucial for successfully illuminating deeper targets.
Another benefit is the seamless integration of expertise. Processing, imaging, and quantitative interpretation geophysicists can now work simultaneously on a project, abandoning the siloed conventional workflows. Closer collaboration fosters better understanding, which translates to optimal results. This will soon extend beyond AVA inversion into reservoir characterisation and modelling. Elastic MP-FWI imaging will produce a suite of outputs, providing a rich model space for reservoir engineers to make probabilistic predictions that honour both seismic and well data.
This technological leap was first conceived by the FWI pioneers in the 1980s. Its reality today is thanks to the skills of research and development teams and modern high performance computing. This essential work continues in earnest at DUG; as the technology evolves, it will continue to extend what is possible with seismic data, ultimately allowing the industry to make better, faster decisions.
AD Ports Group remains fully operational.
AD Ports Group has reported continuation of all operations across its clusters without any disruption given current regional developments
The Group has already taken precautionay measure with the activation of its crisis management and business continuity protocols, as it remains in constant coordination with the authorities concerned in the UAE to safeguard its workforce, partners and stakeholders.
All UAE ports and terminals managed and operated by the Group’s Ports Cluster, in addition to related services remain fully operational.
While inaccessibility of the Strait of Hormuz will affect vessel calls at Khalifa Port, services at the port will go on uninterrupted. Closure of the Strait of Homruz will be compensated by increased volumes from the Group's diversified global maritime network, as it shifts trading routes.
Across the Group’s Maritime & Shipping Cluster, the majority of its 122 shipping vessels including container, bulk, Ro-Ro, and multipurpose vessels are operating outside the Strait of Hormuz. Those currently within the Strait continue to operate intra-Gulf services. Overall, the impact on the Maritime & Shipping Cluster is expected to be limited. The Group’s Economic Cities & Free Zones and Logistics Clusters are likewise expected to experience limited impact.
Captain Mohamed Juma Al Shamisi, Managing Director and Group CEO of AD Ports Group, said: “Global trade has historically demonstrated resilience during periods of geopolitical tension. Through disciplined execution, operational excellence and proactive risk management, AD Ports Group remains well positioned to support supply chain stability and uphold its commitments to customers across its global network, in line with vision with our wise leadership.’’
Oil is now a question of access, geography and timing.
The oil market is no longer asking how much crude is being produced. It is asking who gets it, and when
Over the past week, attention has focused on the number of strikes across ports, refineries, power plants and LNG facilities in the Gulf. Depending on assumptions, the direct loss of wellhead, pipeline and refinery liquids to market may already exceed 1 million barrels per day. That figure alone is significant. But it remains secondary to the larger question hanging over the Strait of Hormuz.
Even if Hormuz begins to flow again in something close to normal volumes, the region’s infrastructure is clearly vulnerable. The market is now being forced to price not just a temporary blockage, but the risk of ongoing disruption to oil and gas facilities. Each passing hour of uncertainty adds incremental supply chain strain, and Brent has begun to reflect that reality.
There are various scenarios between full closure and full normalisation. Even a return to 75% of normal transit would present a severe logistical challenge. Insurance costs, naval escorts and rerouting all reduce effective supply. Freight markets are already reacting accordingly. Prompt tanker rates are surging, sharply raising landed crude procurement costs.
In this environment, traditional pricing logic begins to break down. The landed price of crude grades becomes less relevant when freight cannot be reliably fixed and spot premiums are difficult to establish. The market shifts from price optimisation to access management.
The West is relatively long crude and less dependent on Arabian Gulf supply than the East. It also holds freight advantages. Asia, by contrast, is more exposed to Gulf flows. As a result, refining runs in Asia are more at risk than in Europe or the United States. That divergence is already appearing in product markets via East-West spreads.
Brent-Dubai spreads may widen further regardless of freight direction. There is effectively no competition for the marginal Western barrel into Asia if Gulf supplies are constrained. In that context, Dubai-linked pricing can tighten independently of freight economics, while Brent can move in ways that do not necessarily align with historical arbitrage logic.
Freight costs themselves are becoming a direct transmission mechanism. Aframax rates to Europe imply roughly $9 per barrel to move WTI into the Atlantic Basin, pushing prompt WTI-Brent spreads wider. VLCC routes to Asia are similarly expensive. Yet benchmark differentials do not always adjust cleanly to reflect this because physical flows are constrained by risk, not simply by economics.
The longer the stand-off persists, the more structural these shifts become. Refiners must make procurement decisions based on security of supply rather than margin optimisation. Strategic reserves in the US, Europe, China, Japan and South Korea provide buffers measured in months, but releasing stocks is a policy decision. Governments may choose to loan or auction volumes to smooth disruption, but those tools are not immediate substitutes for steady Gulf exports.
Infrastructure risk now extends beyond crude production. There are concerns around storage capacity, with reports suggesting some export terminals may face tank-top pressures if flows remain restricted. Ullage becomes part of the conversation. Even if Hormuz reopens, infrastructure security will remain in question for some time.
Products will increasingly act as the demand-adjustment valve. Refining margins may need to rise to justify higher crude procurement costs and ensure available barrels flow eastward. Natural gas pricing is already signalling potential substitution toward fuel oil and crude in power generation where possible.
For now, the market’s priority is evidence that Hormuz can move safely and consistently, including clarity on insurance and escort arrangements. Without that, prices will continue to reflect supply chain risk rather than just supply loss.
This is no longer simply a production story. It is a logistics and allocation story. In a fragmented and risk-sensitive market, oil does not disappear evenly. It becomes a question of access, geography and timing. And that is where volatility truly begins.
The writer of the article is Neil Crosby, AVP Oil Analytics at Sparta
Location of Ras Tanura
An official source at Saudi Arabia’s Ministry of Energy has confirmed that the Ras Tanura oil refinery sustained limited damage on Monday morning after debris from intercepted drones fell in its vicinity.
According to the Saudi Press Agency, the incident occurred at approximately 7:04 AM local time when two drones were intercepted near the facility. Falling fragments reportedly caused a small fire within the refinery complex.
Emergency response teams acted swiftly to contain the blaze, preventing any escalation. Authorities said the fire was brought under control in a short period of time, and no injuries or fatalities were recorded as a result of the incident.
As a precaution, certain operational units at the refinery were temporarily shut down while safety checks were carried out. Officials stressed that the measures were taken to ensure the continued protection of personnel and infrastructure.
Despite the disruption, the Ministry of Energy confirmed that the incident has not affected the supply of petroleum products to domestic markets. Fuel deliveries and distribution channels are continuing as normal, with contingency protocols ensuring stability in local supply chains.
Ras Tanura is one of the Kingdom’s key refining hubs, playing a central role in processing and distributing petroleum products. While the reported damage was described as limited, the event underscores the importance of protective and rapid-response measures at critical energy infrastructure sites.
Authorities have not released further details regarding the origin of the drones or the broader security context surrounding the interception. However, officials reiterated that safeguarding energy facilities remains a top priority, with emergency and security teams maintaining heightened vigilance.
The situation remains under monitoring, with the Ministry indicating that updates will be provided if necessary.
The agreement relates to exploration in Oman's offshore Block 18. (Image source: Adobe Stock)
PC Oman Ventures Ltd (PCOVL), a subsidiary of PETRONAS, has signed a Concession Agreement with the Government of the Sultanate of Oman and OQ Exploration and Production Batinah Offshore LLC (OQEP) for the exploration of oil and gas in Block 18
Block 18 is a large offshore exploration area located in Northeast Oman, spanning more than 21,000 sq km and offering significant frontier exploration potential across diverse geological settings, from shallow to ultra-deep water. Under the concession agreement, PCOVL will become operator of Block 18 in partnership with OQEP.
PCOVL has been active in the Sultanate of Oman since 2018 and currently holds a participating interest in Block 61. This collaboration builds on the Memorandum of Understanding (MoU) signed between PETRONAS and OQEP in October 2025, strengthening the strategic partnership between both companies and reinforcing PETRONAS’ long-term presence in the Sultanate of Oman.
The partnership supports PETRONAS’ aspiration to enhance its competitive upstream portfolio by aligning its offshore exploration capability with OQEP’s regional expertise, laying the foundation for a mutually beneficial venture.
"Building on our technical strengths and successes, PETRONAS continues to expand its exploration activities into new frontiers. Through our innovative exploration approaches and OQEP’s basin expertise, we aim to jointly unlock the potential of Block 18, contributing to Oman’s long-term energy security. The addition of Block 18 aligns with our commitment to disciplined portfolio expansion, providing strategic optionality across our international portfolio," said Mohd Redhani Abdul Rahman, vice president of International Assets, PETRONAS.
The wells are located around 85 km off the coast. (Image source: Adobe Stock)
Mabruk oilfield onshore Libya, located in concession C17, around 130 km south of Sirte. (Image source: TotalEnergies)
Envorem’s modular sludge remediation system installed in Saudi Arabia. (image source: Envorem)
Envorem, the UK-based developer of oily sludge remediation technology, has installed its treatment system in Saudi Arabia
The global oil industry discards around 1% of all crude oil as waste, generating approximately 120 million tonnes of oily sludge every year, with legacy deposits exceeding 1.8 billion tonnes worldwide.
Envorem’s technology is designed to rapidly and efficiently treat oily sludge and hydrocarbon-contaminated waste streams. The process separates viscous sludge into oil, water and solids, enabling valuable materials to be recovered while significantly reducing the volume of hazardous waste that requires disposal.
In January and February 2026, the Envorem team assembled a UK-built treatment system on a site near Jubail, Saudi Arabia, where it is ready for use. The system provides a mobile platform to treat oily sludge and hydrocarbon-contaminated waste streams directly at source, creating opportunities for future remediation projects across the Middle East.
Successful pilots
The latest deployment follows a successful pilot project with Petroleum Development Oman (PDO0 where oil and water was recovered from sludge while significantly reducing waste volumes and emissions.
The Envorem System was also tested at Saudi Aramco’s Shaybah Gas Oil Processing Station to process 1,300 cubic metres of sludge, recovering 2,080 barrels of oil and 920 cubic metres of treated water for reuse. Previously, this material had to be transported more than 800 km for disposal, at significant cost and environmental impact. By using Envorem, the station reduced residual waste by 97%, while avoiding 332 tonnes of CO₂ emissions associated with transporting the waste for disposal.
“Having our first full-scale industrial deployment in Saudi Arabia is a major step forward for Envorem,” said Mark Batt-Rawden, managing director of Envorem. “The Envorem System is now fully commissioned and ready for oily sludge remediation projects in Saudi. This is a real credit to the team and our investors who’ve supported us to get here.
“Alongside that progress, our patent, is now secured in Canada, following earlier grants in Europe and the United States. This strengthens our global IP position, and gives us greater confidence as we scale internationally to provide the oil industry with a faster, cleaner and more economical way to deal with the enormous global legacy of oily sludge.”
Envorem has showcased its technology internationally at major industry events, including provided operators, engineers and environmental specialists with the opportunity to see the technology in action and understand how the Envorem System can treat sludge at source.
Aramco alone accounts for nearly 40% of the total market value of all listed companies in the region. (Image source: Aramco)
Oil prices remain high due to the US/Iran war. (Image source: Adobe Stock)
The new collaboration aims to scale up the development of CTC technology. (Image source: KAUST)
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.”
Vitol Bahrain EC has a long-standing presence in Uganda's downstream sector.
The companies will explore capital investments to upgrade and diversify production. (Image source: Adobe Stock)
The acoustic MP-FWI imaging implementation has demonstrated significant uplifts. (Image source: DUG)
Technological advancements in geoscience are often incremental—small steps that help refine our ability to understand the subsurface. But occasionally, we witness a genuine leap. DUG Technology’s Chief Geophysicist, Tom Rayment, considers the impact of elastic MP-FWI imaging and asks, "Is traditional seismic processing finally a thing of the past?"
For the past century, seismic data has been an invaluable tool for detecting hydrocarbons. Although methods have become more sophisticated, the fundamental workflow for turning acquired data into interpretable products largely remains the same. The advent of elastic multi-parameter full waveform inversion (MP-FWI) imaging represents a significant shift away from the traditional approach.
The acoustic MP-FWI imaging implementation has demonstrated significant uplifts without needing conventional time-processing, model-building, or depth-migration techniques. Elastic MP-FWI imaging is a further step-change, also deriving rock properties and effectively rendering the amplitude variation with angle (AVA) inversion workflow redundant. The approach will soon make conventional workflows obsolete, if it hasn't already.
Despite this monumental leap, the technology is still young, with ample room for more progress. Most FWI implementations use a single component of the acquired data (hydrophone for marine, vertical geophone/accelerometer for land). However, additional components offer complementary information that can further constrain results. Recent developments show that two-component towed streamer and ocean-bottom seismic MP-FWI imaging can further improve results and accelerate convergence.
The logical next step is to include horizontal components. Shear waves provide valuable subsurface information, especially in areas of strong P-wave absorption like gas bodies. Recent DUG projects are already demonstrating that the benefits of converted-wave processing can be realised with elastic MP-FWI imaging. Furthermore, on land, exploiting shear waves in the form of ground roll is now viable. What was once noise is now a useful signal, inverted via elastic FWI to provide high-resolution shear-wave-velocity models. Capturing near-surface complexity is crucial for successfully illuminating deeper targets.
Another benefit is the seamless integration of expertise. Processing, imaging, and quantitative interpretation geophysicists can now work simultaneously on a project, abandoning the siloed conventional workflows. Closer collaboration fosters better understanding, which translates to optimal results. This will soon extend beyond AVA inversion into reservoir characterisation and modelling. Elastic MP-FWI imaging will produce a suite of outputs, providing a rich model space for reservoir engineers to make probabilistic predictions that honour both seismic and well data.
This technological leap was first conceived by the FWI pioneers in the 1980s. Its reality today is thanks to the skills of research and development teams and modern high performance computing. This essential work continues in earnest at DUG; as the technology evolves, it will continue to extend what is possible with seismic data, ultimately allowing the industry to make better, faster decisions.
The new pumps integrate modern sensor technology and proprietary motor control. (Image source: KNG)
The Goktepe field will be connected to Phase 3 FPO. (Image source: Subsea7)
Oil and gas operations in the Middle East span harsh deserts, sprawling refineries and high-risk offshore environments. (Image source: Adobe Stock)
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.
Competence is a must for high-risk tasks. (Image source: Adobe Stock)
The event will address the security challenges in the Middle East oil and gas sector, and how Pelco solutions can help.
Progress has been reported in developing action plans to reduce methane emissions and end routine flaring. (Image source: Adobe Stock)
Coinciding with COP30, significant progress has been reported in driving forward the aims of the Oil & Gas Decarbonization Charter (OGDC) launched at COP28
The Oil & Gas Decarbonization Charter (OGDC), a global coalition of leading energy companies championed by the CEOs of ADNOC, Aramco, and TotalEnergies and supported by the Oil and Gas Climate Initiative (OGCI), highlights expanded reporting coverage, strengthened action plans for emissions reduction and enhanced collaboration to accelerate industry decarbonisation in its 2025 Status Report: Implementing Action.
The Charter now brings together 55 signatories operating across more than 100 countries, representing around 40% of global oil production. Signatories invested approximately US$32bn in low-carbon solutions including renewables, carbon capture, hydrogen and low-carbon fuels in 2024.
This year, for the first time, the companies shared emissions data based on the OGCI Reporting Framework, laying the foundation for consistent reporting across 55 companies. 50 of the 55 signatories submitted data for this year’s report, covering 98% of OGDC operated production, most of which has received third-party assurance.
Forty-two signatories have now set interim Scope 1 and 2 emissions reductions ambitions for 2030, and 36 have developed corresponding action plans, reflecting tangible progress since the Charter’s 2024 Baseline Report, with six more companies sharing interim ambitions and seven more developing corresponding action plans on methane and flaring.
Extensive collaboration programme
An extensive collaboration programme is underway, with a focus on methane, flaring and reporting. TotalEnergies for example is sharing its AUSEA technology with several national oil companies to strengthen methane detection and measurement. Peer-to-peer exchanges, regional partnerships and technical workshops have strengthened capacities, while engagement with OGCI, the United Nations Environment Programme, the World Bank and many others, are helping scale practical solutions. At the company level, OGDC is helping to embed tailored, industry-specific training programmes.
Dr Sultan Ahmed Al Jaber, managing director, Group CEO of ADNOC, COP28 president and OGDC CEO Champion, said, “Two years ago, at COP28 we came together to create the world’s first truly industry-wide coalition to decarbonise at scale. Together, we are turning the Charter’s words into action by delivering tangible progress, scaling innovation and reporting transparently against our shared commitments.”
Patrick Pouyanné, chairman and CEO of TotalEnergies and OGDC CEO Champion, added, “OGDC is about action and collective delivery. This year we moved from baseline to implementation, with almost all signatories reporting data that covers 98% of operated production and more companies setting 2030 targets backed by plans. This reflects that progress starts with what we measure and a shared reality that this is a journey where we advance faster together. Our focus now is clear. We must cut methane, end routine flaring and report progress consistently. We invite all IOCs and NOCs to join and show measurable results by the next COP.”
Bjørn Otto Sverdrup, head of the OGDC Secretariat, said, “With OGDC, we have established a platform for companies willing to take action and collaborate across North, South, East, West, to share best practices and accelerate decarbonisation – particularly towards reducing methane and zero flaring by 2030.”
“We are encouraged by the progress made, and we look forward to the work ahead.”
At COP30, TotalEnergies announced a US$100mn commitment to Climate Investments Venture Strategy funds, which supports technologies that cut emissions across the oil and gas value chain. Climate Investments (CI) is an OGDC Partner.
GCC countries are realigning domestic energy systems. (Image source: Adobe Stock)
The fossil fueld sector is responsible for approximately one third of total global methane emissions. (Image source: Adobe Stock)
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TotalEnergies will support the refinery with its global oil and feedstock supply capacity. (Image source: Adobe Stock)
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HE Abdulsalam bin Mohammed Al Murshidi, the president of Oman Investment Authority (OIA)
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Comparison of conventional workflow with DUG MP-FWI imaging. (Image source: DUG)
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TotalEnergies and SONATRACH will develop gas resources in Algeria's north-east Timimoun region, (Image source: Adobe Stock).
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The new range has been launched in response to the demand for compact and lightweight lifeboats. (Image source: VIKING)
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The programme will optimise asset lifecycle, enhance machinery performance and improve overall reliability. (Image source: Adobe Stock)
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The programme is designed to strengthen leadership and safety culture in the oil and gas industry> (Image source: Adobe Stock)
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The expansion is expected to increase the plant’s processing capacity from 2.5 to up to 4 billion standard cubic feet per day (bscfd). (Image source: Aramco)
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Block 56 is targeted for commercialisation in 2024. (Image source: Canva)
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Over 4,000 km of SoluForce pipe has been installed around the world. (Image source: SoluForce)
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The system can activate notification and hazard mitigation equipment to notify workers and safeguard facilities. (Image source: MSA Safety)
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The use of blockchain in the oil and gas sector is set to increase substantially. (Image source: Adobe Stock)
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By using analytics to augment and empower the workforce, pipeline operators can optimise operations and improve asset availability. (Image source: Adobe Stock)
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Human factors need to be taken into account when addressing safety. (Image source: Adobe Stock)
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Operators have never needed to take safety and efficiency more seriously. (Image source: Adobe Stock)
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Source: SafeStart
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To improve differentiation, hard hats can be customised with different colours and logos. (Image source: MSA Safety)
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The partnership will enable HMi Elements to tap into Cobic-Ex’s global network. (Image source: HMi Elements)
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Among other services, KBR will offer proprietary equipment for NCIC's 1,200 metric tonnes per day ammonia plant. (Image source: Adobe Stock)
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Osama Oulabi, general manager, KSA and Middle East, Speedcast. (Image source: Speedcast)
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Aramco alone accounts for nearly 40% of the total market value of all listed companies in the region. (Image source: Aramco)
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The wells are located around 85 km off the coast. (Image source: Adobe Stock)
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Oil prices remain high due to the US/Iran war. (Image source: Adobe Stock)
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Mabruk oilfield onshore Libya, located in concession C17, around 130 km south of Sirte. (Image source: TotalEnergies)
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Envorem’s modular sludge remediation system installed in Saudi Arabia. (image source: Envorem)
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The new pumps integrate modern sensor technology and proprietary motor control. (Image source: KNG)
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Amin H. Nasser, president and CEO of Aramco. (Image source: Aramco)
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Fatih Birol, IEA executive director. (Image source: IEA)
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Brent and WTI prices pushed past US$115 a barrel on 9 March 2026. (Image source: GlobalData)
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New developments have driven oil prices sharply higher
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The Goktepe field will be connected to Phase 3 FPO. (Image source: Subsea7)
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The acoustic MP-FWI imaging implementation has demonstrated significant uplifts. (Image source: DUG)
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AD Ports Group remains fully operational.
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The tool ensures consistency for sizing across regions. (Image source: WEG)
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Oil is now a question of access, geography and timing.
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The contract will advance in-country value. (Image source: SLB)
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Shipping activity across the Strait of Hormuz has come to a standstill.
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Middle East Energy Dubai 2026 will provide practical insights. (Image source: Informa)
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Location of Ras Tanura
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