Exploration and Infrastructure Integration

The North Sea oil and gas discovery is positioned approximately 145 kilometers west of Bergen, an area where Equinor already manages active production sites, including the Oseberg South and Tune fields. Because of this location, the project team is currently evaluating the feasibility of connecting Grimsnes to the Oseberg South platform.

By utilizing existing subsea infrastructure, the partners aim to streamline the development process. This subsea tie-back approach is designed to leverage current processing capacities rather than constructing new, standalone platforms. Before this can proceed, the project requires thorough technical verification, including assessments of pressure, temperature, available processing capacity and fluid composition.

Timeline and Future Assessments

The partnership intends to move forward with project evaluations, with a potential investment decision anticipated by the summer of 2027. If the project meets internal technical and economic milestones, production could potentially commence as early as 2029.

The current estimate of 19 to 50 million barrels of oil equivalent represents the total energy content of the find. However, further studies are necessary to determine the specific proportion of recoverable resources and the commercial viability of the extraction.

Strategic Value in Mature Fields

The Grimsnes find underscores a broader strategy in the North Sea oil and gas sector: prioritizing exploration near mature fields where production infrastructure is already established. Integrating new discoveries into existing networks allows companies to maximize the utility of available platforms and subsea systems.

As Equinor, Petoro, and TotalEnergies continue their assessments, the focus remains on confirming whether the Grimsnes reservoir can be efficiently linked to the Oseberg complex. While the initial proximity offers a logistical advantage, the ultimate path toward production will be defined by the results of upcoming technical evaluations and the collective decision-making process of the participating firms.

This discovery follows another exploration development made by Equinor in the North Sea in March 2026, with findings in the Troll area and the Sleipner area.

The awarded acreage spans the Campos, Santos and Ceará basins, alongside onshore exploration areas. Under the concession round, Petrobras secured 12 offshore exploration blocks in the Campos Basin. The company also partnered with QatarEnergy to win seven blocks in the Ceará Basin, located along Brazil’s northeastern Equatorial Margin.

Petrobras will operate these Ceará blocks with a 70% participating interest, while QatarEnergy will hold the remaining 30%. The seven awarded blocks are CE-M-471, CE-M-473, CE-M-475, CE-M-477, CE-M-537, CE-M-539 and CE-M-665. Beyond offshore acreage, the concession round allocated exploration blocks in the onshore Potiguar, Tacutu, Recôncavo, Parnaíba and Tucano Sul basins. Successful bidders in these areas included Eneva, PetroRecôncavo, Aguila, Alvopetro, Origem, Petrom and Tucano Serviços.

Pre-Salt Awards Bring International Energy Companies Into Partnership

The production-sharing round accounted for seven additional pre-salt exploration blocks across the Santos and Campos basins. Norway’s Equinor and Portugal’s Galp jointly secured the Rodocrosita block in the Santos Basin, with Equinor holding a 70% operating interest and Galp retaining the remaining 30%.

Equinor also won the Rubi block. Meanwhile, China’s CNOOC Petroleum and Sinopec secured the Jade block, with CNOOC holding a 70% operating interest and Sinopec taking the other 30%. Petrobras obtained the Azurita block in the Campos Basin and Cruzeiro do Sul in the Santos Basin, securing full interests in both areas.

Brazilian oil company Prio Forte also secured two blocks, Magnetita and Hematita, in the Campos Basin, with 100% interests in each. The awards add to the 56 offshore blocks and other exploration areas allocated through Brazil’s latest licensing process, bringing together domestic and international companies across concession-based and production-sharing arrangements.

Largest Production-Sharing Award Cycle Since System Introduction

According to ANP, the production-sharing auction delivered the largest number of blocks awarded in a single cycle since the permanent offering system was introduced. The outcome exceeded the five blocks awarded in 2025, marking a new high for this licensing mechanism. However, the winning companies must still complete the remaining administrative procedures before the contracts can be signed.

Contract signing is expected by February 26, 2027. The 56 offshore blocks and associated exploration awards therefore remain subject to completion of these formalities, with the scheduled signing date establishing the next milestone in the licensing process.

This shift toward localized intelligence is a fundamental change in how the industry handles information in remote environments. Oil & Gas Advancement observes that by placing high performance computing clusters directly on the seabed or within subsea production modules, operators can analyze sensor data and control systems without waiting for a round trip to the cloud.

This capability is becoming essential as deepwater projects become more sophisticated and rely more heavily on robotics and automated subsea trees.

The goal is to reduce the volume of data that needs to be transmitted while increasing the speed at which the system can act on that data. This localized processing capability is also becoming a cornerstone for safety applications, such as AI driven mud monitoring, which requires immediate fluid analysis to prevent drilling incidents.

Subsea edge computing provides a robust solution for managing the immense data volumes generated by modern offshore seismic and production sensors. In a typical deepwater environment, thousands of sensors monitor everything from pressure and temperature to the structural integrity of the riser system. Processing this information at the edge allows for the immediate identification of anomalies, which is vital for preventing equipment failure and ensuring environmental safety. The ability to filter and analyze data locally ensures that only the most relevant insights are sent to the surface, optimizing the use of limited communication channels.

Driving Efficiency in Autonomous Oilfields

The development of autonomous oilfields depends on the ability of subsea equipment to make independent decisions based on real time environmental input. Subsea edge computing enables this autonomy by providing the necessary processing power to run advanced algorithms near the wellhead. This is particularly important for autonomous underwater vehicles that perform inspections and light interventions. These machines need to process high resolution video and sonar data in real time to navigate complex subsea infrastructure without human intervention.

When processing occurs locally, the latency associated with remote control is virtually eliminated:

• This allows for more precise movements and faster reaction times when a vehicle encounters an unexpected obstacle or a change in water currents.
• The integration of edge intelligence also supports the longevity of these autonomous systems by reducing the power consumed during data transmission.
• Operators can now deploy fleets of drones that stay submerged for longer periods, significantly lowering the cost of routine maintenance and inspection tasks in deepwater regions.

The rise of digital transformation in the oil and gas sector is accelerating the adoption of these technologies. Market analysts have observed a significant increase in spending on digital infrastructure, with the digital transformation market in the industry reaching approximately 72.18 billion dollars in 2026. This investment is directed toward creating more resilient and efficient operations that can withstand the economic pressures of a volatile energy market. Subsea edge computing is a central pillar of this strategy, as it directly impacts the reliability of remote assets.

Optimizing Offshore Data Processing

Offshore data processing at the edge is not just about speed. It is also about the intelligent management of data lifecycle. In the past, much of the data collected from subsea sensors was simply discarded or stored without analysis because it was too difficult to transmit to the shore. Edge computing changes this by allowing for on site data reduction and feature extraction. This means that instead of sending a raw stream of vibration data from a subsea pump, the edge system can send a simple status report indicating that the pump is operating within normal parameters.

This selective transmission significantly reduces the burden on satellite networks and other offshore communication links. It also ensures that onshore experts are not overwhelmed with trivial data, allowing them to focus on high level strategic decisions rather than basic monitoring. The use of edge nodes also provides a layer of redundancy. If the communication link to the surface is lost, the subsea systems can continue to operate safely using their local intelligence to manage production and protect the wellbore.

As the adoption of these systems grows, the overall edge computing market is seeing substantial growth. Revenues are anticipated to reach approximately 55 billion dollars in 2024 and climb to 68 billion dollars in 2025. This broader trend toward edge intelligence is being mirrored in the subsea sector, where the demand for low latency processing is at its highest. Energy companies are partnering with technology providers to create ruggedized edge servers that can operate reliably in the extreme pressure and low temperatures of the deep ocean floor.

Enhancing Oil and Gas Exploration Capabilities

Deepwater oil and gas exploration is an inherently risky and expensive endeavor. The success of an exploration campaign often hinges on the ability to accurately interpret seismic data and well logs in a timely manner. Subsea edge computing enhances these capabilities by allowing for faster evaluation of potential reservoirs. When sensors in the drill string or on the seabed can process data locally, exploration teams can adjust their drilling parameters in real time to optimize the trajectory of the well and avoid hazardous formations.

This real time insight is particularly valuable when drilling in complex geological settings where the risk of pressure kicks or lost circulation is high. By analyzing the data at the source, the system can detect subtle changes in rock properties and fluid composition long before they would be visible to a surface operator.

This proactive approach to well control significantly improves the safety and efficiency of deepwater drilling operations. It also reduces the time required to complete a well, which can save operators millions of dollars in rig costs.

The integration of subsea energy tech is also fostering a more sustainable approach to exploration:

• By improving the accuracy of drilling and reducing the likelihood of incidents, edge computing helps minimize the environmental footprint of offshore activities.
• The ability to monitor subsea habitats and water quality in real time using edge enabled sensors provides an extra layer of environmental protection.
• This is becoming a critical requirement for companies as they face increasing scrutiny from regulators and the public regarding their environmental performance.

Overcoming Technical Challenges in Deepwater Environments

Implementing subsea edge computing is not without its technical hurdles:

• The equipment must be housed in pressure tolerant enclosures that can withstand thousands of pounds of force per square inch.
• It also requires efficient cooling systems to dissipate the heat generated by high performance processors in an environment where access for maintenance is extremely difficult and costly.
• Engineers are developing innovative thermal management solutions that use the surrounding seawater to keep the edge nodes within their optimal operating temperature range.

Power supply is another major consideration. Subsea edge clusters need a reliable source of electricity to function continuously. This is often provided through umbilicals from a surface platform or a subsea power grid.

However, there is growing interest in using renewable energy sources such as wave or tidal power to supply electricity to remote subsea nodes. This would further enhance the autonomy of the system and reduce the reliance on traditional power infrastructure.

Reliability is the most important factor in the design of subsea electronics. Since a single failure can lead to expensive intervention missions using remotely operated vehicles, every component must be rigorously tested for long term durability.

The industry is moving toward more modular designs that allow for easier replacement of specific modules without disturbing the entire system. This approach to maintenance is essential for making subsea edge computing a viable long term solution for the deepwater sector.

The Future of Subsea Energy Tech

The future of subsea energy tech will be defined by the convergence of edge computing, high speed communication, and advanced robotics. We are seeing the emergence of subsea data centers that can serve multiple fields, providing a shared infrastructure for localized processing.This collaborative model could significantly lower the barrier to entry for smaller operators and encourage the development of marginal fields that were previously considered uneconomical.

As artificial intelligence continues to advance, the capabilities of subsea edge systems will expand even further. We can expect to see systems that can not only detect problems but also predict them before they occur.

Predictive maintenance powered by edge AI will allow operators to schedule repairs during planned downtime, avoiding the massive costs associated with unplanned production halts. This transition from reactive to proactive management is the key to achieving a truly intelligent subsea environment.

The ongoing digitalization of the offshore sector is expected to yield massive savings. A significant portion of these savings will come from improved efficiency in drilling, logistics, and subsea operations enabled by edge computing. As companies continue to push the boundaries of what is possible in deepwater, Oil & Gas Advancement believes that subsea edge computing will remain a critical enabler of success in the most challenging environments on the planet.

References

• Saipem
• Oceaneering International and TotalEnergies
• SLB
• Chevron

The program will combine artificial intelligence with TotalEnergies’ extensive geoscience expertise and subsurface data to improve how complex information is analyzed and interpreted. In particular, the partnership will use the latest advances in artificial intelligence, including agentic AI, to work with next to 10 petaflops of data alongside nearly a century of knowledge, know-how and expertise accumulated by TotalEnergies in geosciences and reservoir engineering. The companies aim to create frontier models capable of integrating, processing and interpreting large volumes of information and generating multiple scenarios for developing exploration opportunities. The models are also intended to help optimize and extend the life of existing projects.

Joint Laboratory to Develop Tailored AI Solutions

As part of the initiative, TotalEnergies and Mistral will establish a joint scientific laboratory. The facility will bring together the subsurface know-how and expertise of TotalEnergies’ subsurface teams with the scientific and technological capabilities of Mistral, a European AI champion. The collaboration is designed to develop solutions tailored to the specific needs of the Company’s businesses, while strengthening the use of AI across activities involving reservoir exploration and reservoir engineering. By combining its subsurface expertise and data with Mistral’s AI capabilities, TotalEnergies intends to develop tools that can support experts when dealing with complex datasets and evaluating different development scenarios.

Strengthening a European AI and Digital Ecosystem

The partnership with Mistral will also strengthen TotalEnergies’ AI solutions ecosystem through the development of proprietary models within a European digital ecosystem. The arrangement will allow TotalEnergies to leverage its strategic subsurface data while supporting Mistral’s further development as a European AI champion.

“Exploration and reservoir engineering are among the areas where artificial intelligence can create the greatest value for our activities. By combining a century of geoscience data, the expertise of our teams and Mistral’s capabilities, we aim to develop a new generation of tools capable of supporting our experts in analyzing the most complex data and in their decision-making. This partnership also illustrates our commitment to contributing to the development of a high-performing European digital ecosystem, supporting our competitiveness” said Patrick Pouyanné, Chairman and Chief Executive Officer of TotalEnergies.

“We are delighted to take our collaboration with TotalEnergies to the next level. This project demonstrates the ability of our models to support complex industrial processes and adapt to the most demanding scientific and energy challenges. It also highlights the strength of Europe’s industrial ecosystem and the importance for large enterprises of adopting state-of-the-art, customizable AI solutions that protect and respect their intellectual property,” said Arthur Mensch, Co-founder and CEO of Mistral.

The new block 17 discovery will be integrated into existing production infrastructure through a tieback arrangement to the Pazflor floating production, storage and offloading vessel. This connection is expected to deliver an additional 6,000 barrels per day of production capacity, leveraging already-established facilities to optimize development efficiency and reduce capital requirements.

Operational Partnership and Stakeholder Structure

France-based TotalEnergies maintains operational control of Block 17 with a 38 percent working interest. The project encompasses a diverse international consortium, reflecting the collaborative nature of modern offshore oil and gas development. Norway’s Equinor ASA holds a 22.16 percent stake, while the United States-based Exxon Mobil Corporation retains 19 percent. The Azule Energy joint venture, equally owned by Britain’s BP and Italy’s state-backed Eni, maintains a 15.84 percent position. Angola’s national petroleum company, Sociedade Nacional de Combustíveis de Angola EP (Sonangol), owns a five percent stake in Block 17.

Recent Exploration Momentum Across Angola Portfolio

“Acacia-5 is the second exploration success recorded in 2026 across TotalEnergies’ Angolan portfolio, following the recent Block 0 discovery in the prolific Lower Congo Basin, where TotalEnergies holds a 10 percent interest alongside Chevron, operator”, TotalEnergies stated in a press release, commenting on the new block 17 discovery.

The Block 0 discovery demonstrated a hydrocarbon column exceeding 600 meters within the primary Pinda reservoir, with net pay exceeding 90 meters and exceptional reservoir characteristics, according to Chevron’s announcements.

Development discussions for the Block 0 discovery are exploring a tieback arrangement to Chevron’s existing infrastructure for the 105-4X find. Production from Block 0 has already commenced through the Mafumeira developments.

Expansion of Exploration Acreage

Concurrent with the new block 17 discovery announcement, TotalEnergies finalized concession agreements with Angola’s National Agency for Petroleum, Gas and Biofuels (ANPG).

“These promising blocks benefit from extensive existing 3D seismic coverage and offer access to several prospective geological plays”, TotalEnergies said.

“They are located close to existing facilities in TotalEnergies-operated Blocks 17 and 32, where six FPSOs are currently producing, therefore allowing for future tie-backs and cost-efficient development of additional resources through existing facilities,” it added.

Additionally, TotalEnergies entered a preliminary agreement with ANPG and ExxonMobil targeting exploration blocks 40, 41, 42, and 58 in the Benguela Basin. Under the arrangement, TotalEnergies would assume a 35 percent working interest in these prospective acreage positions.

Strategic Vision and Market Positioning

“Exploration is a key pillar of our ambition in Angola, supported by the incentives introduced to encourage investment”, said TotalEnergies chair and chief executive Patrick Pouyanné.

“Together with our partners, we aim to explore further and unlock new resources, sustaining a strong exploration effort to identify new opportunities across Angola’s offshore basins,” he added.

Geological Findings and Technical Details

The Vicango East-01 well encountered approximately 25 metres of high-quality, hydrocarbon-bearing sandstone with a porosity measurement of 22%. This Angola offshore discovery was drilled in 940 metres of water depth using the Valaris DS-9 drillship, positioned roughly 370 kilometres northwest of Luanda. The geological characteristics indicate substantial commercial potential for the region’s continued energy development.

This latest Angola offshore discovery marks the 20th confirmed find within Block 15 across a 30-year exploration and production timeline. Over this extended period, the block has yielded more than 2.7 billion barrels of hydrocarbons, establishing its significance within Angola’s energy infrastructure.

Long-Term Production and Development Impact

“After more than 23 years of successful production from Block 15, this discovery demonstrates the continued potential of Angola’s offshore resources and reflects our ongoing commitment to exploration and development in the country. Block 15 has been one of Angola’s most significant deepwater developments, and discoveries like this help increase the value of existing infrastructure while supporting future production opportunities,” said Brian Unietis, President and General Manager of ExxonMobil Angola.

Regulatory Framework and Investor Incentives

ANPG Chairman Paulino Jerónimo attributed the continued success of exploration efforts to recent adjustments in Angola’s legal and fiscal environment. The Angola offshore discovery was facilitated partly through policy reforms designed to encourage ongoing investment and resource development.

“This discovery is partly the result of adjustments to the legal framework and the incentives that the Angolan State has provided to investors. The extension of the Block 15 licence until 2032, Decree 8/24 on Incremental Production, as well as Decree 5/18 on the legal regime allowing exploration within and in proximity to development areas, are examples of this,” added Jerónimo.

Operational Partnership Structure

ExxonMobil affiliate Esso Exploration Angola (Block 15) Limited serves as the operator with a 36% interest. Azule Angola Limited maintains 24% ownership, Azule Angola BV holds 18%, Equinor Angola Block 15 A.S. carries 12%, and Sonangol E&P manages 10%. ANPG functions as the concessionaire.

The MoU was signed in Mexico City after a meeting between the chief executive officers (CEOs) of the two companies, Woodside’s Westcott and Pemex’s Juan Carlos Carpio Fragoso.

Under the terms of the Gulf of Mexico deepwater oil exploration MOU, both organizations will conduct comprehensive analysis of potential hydrocarbon prospects suitable for development in the Gulf of Mexico’s deep waters. The agreement also encompasses the exchange of technical expertise, operational knowledge, and industry best practices between the two energy companies, fostering a collaborative approach to offshore resource development.

Strategic Partnership and Leadership Support

Liz Westcott, Woodside’s CEO, said, “This MOU builds on the strong relationship between Woodside and Pemex and our joint efforts to develop oil and gas resources in Mexico’s ultra-deepwater. The agreement strengthens our relationship and opens the door to explore future opportunities to work together in Mexico’s deepwater.”

“We are grateful to Pemex and Secretary of Energy Luz Elena González Escobar for their continued support and commitment to the development of Mexico’s deepwater resources,” he added.

Current Joint Development: Trion Oil Project

The two companies are currently collaborating on the Trion oil project, a landmark ultra-deepwater development located approximately 180 kilometers offshore Mexico’s coast and 30 kilometers south of the U.S.-Mexico maritime boundary. Operating at depths of 2,500 meters beneath the ocean surface, Trion is positioned to become Mexico’s inaugural ultra-deepwater oil development, with initial production targeted for 2028.

As of 30th June 2026, the Trion project had achieved 64% overall completion, with a projected total capital investment of $7.2 billion throughout its development lifecycle. Woodside operates the project and maintains a 60% ownership interest, while Pemex retains a 40% stake in the venture.

Significant Economic and Energy Impact

The Trion development is anticipated to generate substantial economic benefits for Mexico, with projections indicating over $10 billion in combined taxes and royalties throughout the project’s operational lifespan. Beyond financial contributions, the Gulf of Mexico deepwater oil and gas development is expected to strengthen Mexico’s energy security positioning and domestic energy supply capabilities.

Tupinambá Adds to Brazil Exploration Portfolio

Tupinambá is situated in the pre-salt Santos Basin, approximately 400 kilometers offshore Brazil, in water depths of around 2,300 meters. BP obtained the block in December 2023 during Brazil’s second production-sharing Permanent Offer cycle, where it was the sole bidder for the acreage.

Shell’s participation increases its position in one of Brazil’s most important offshore producing regions. At the same time, the transaction enables BP to share the cost and exploration risk associated with drilling Tupinambá. Brazil has gained greater importance within BP’s exploration portfolio after the company’s Bumerangue discovery in the Santos Basin. BP announced the discovery in 2025 as its largest discovery in 25 years.

Shell Takes Stake in Conifer Prospect

In the U.S. Gulf, Shell will take 30% interests in five leases that cover the Conifer prospect within the deepwater Paleogene play. BP secured four of the leases through Lease Sale 259 in 2023, while the fifth was acquired through the BBG-1 lease sale in February 2026.

Conifer is positioned in the Keathley Canyon area, roughly 250 miles southwest of New Orleans, and is located near BP’s Kaskida development, according to industry reports. BP sanctioned the Kaskida project in 2024, making it the company’s first development in the Gulf’s Paleogene geological formation. The transaction gives Shell exposure to another of the BP exploration prospects while BP continues to hold the majority interest and operatorship. Drilling at Conifer is planned for 2027, placing Shell alongside BP ahead of the exploration programme.

Companies Align Exploration Interests

For BP, the decision to bring Shell into the two prospects supports its effort to concentrate capital while continuing to maintain exposure to potentially material exploration discoveries. The partnership also allows BP to retain operatorship of both Tupinambá and Conifer while reducing its share of the exploration cost and risk. For Shell, the transactions provide additional acreage in two regions where it already maintains substantial upstream operations. The company will gain interests in both BP exploration prospects without taking on operatorship. T

Comprehensive Drilling and Production Strategy

Eni outlined an ambitious drilling schedule as part of its Egypt energy investment framework, announcing plans to execute 30 exploration wells alongside 200 development wells during the coming operational period. These drilling activities will span the company’s concessions, with particular emphasis on the Mediterranean region and the Zohr field, a strategically important production asset.

The company intends to leverage advanced technologies in its 2026 and 2027 operational calendar, particularly for Mediterranean and Western Desert activities. Eni plans to employ seismic surveying capabilities and artificial intelligence technologies to enhance natural gas and crude oil production efficiency across its Egypt energy investment portfolio.

Regional Gas Hub Development and Strategic Partnerships

A significant component of the discussion centered on the potential connection of Cyprus’s Cronos gas field to Egyptian infrastructure. Descalzi emphasized that this infrastructure linkage would establish a collaborative model for regional gas cooperation, positioning Egypt as an increasingly important regional gas hub.

The Cronos project gained momentum in July when Eni and TotalEnergies announced a final investment decision for the development initiative. The partnership aims to deliver Cypriot gas to market through Egyptian facilities by 2028, with expected production reaching 500 million cubic feet per day. This interconnection represents a strategic advancement for energy infrastructure coordination across the Eastern Mediterranean region.

Government Support and Strategic Alignment

El-Sisi expressed Egypt’s commitment to Eni’s operations, welcoming the company’s Egypt energy investment initiatives and emphasizing the government’s intention to maintain cooperative relationships and facilitate continued growth. The President indicated that Egyptian authorities would continue providing operational support while addressing infrastructure and logistical challenges that may affect company activities.

Prime Minister Mostafa Madbouly and Karim Badawi, Minister of Petroleum and Mineral Resources, participated in the meeting alongside senior Eni management representatives, demonstrating the high-level governmental engagement with the project.

Ankara Deepens Energy Role in Syria

The agreements reflect Ankara’s ambition to become a leading partner in Syria’s reconstruction, building on its close relationship with the government that replaced Bashar Al Assad. Since Mr Al Assad was deposed in December 2024, Turkish officials have maintained more extensive engagement with Damascus than any other foreign government. Turkish President Recep Tayyip Erdogan has also developed close ties with Syria’s new President, Ahmad Al Shara, placing Ankara in a dominant position as Syria moves through its economic and political transition.

The latest plans add Syria to an expanding list of overseas frontiers for Türkiye’s state oil driller. TPAO is currently developing an exploration well off the coast of Somalia and earlier this year secured a licence for offshore blocks in Libya. Ankara has expanded its deep-sea drilling fleet as it works to secure energy resources overseas, while its planned activity in Syria further broadens its oil and gas exploration footprint.

Syria Seeks Investment to Rebuild Energy Sector

Syria was previously a significant oil and gas producer in the eastern Mediterranean, according to the US Energy Information Administration, but 14 years of civil war severely damaged the industry. Oil output has fallen by about 80 per cent from a prewar peak of 380,000 barrels a day. The Syrian Energy Ministry said crude production reached 14.8 million barrels in the first half of 2026, equal to about 82,000 barrels a day, according to the state-run Sana news agency on Tuesday. The government has estimated that more than $30 billion is required to rehabilitate the sector, presenting a potentially significant opportunity for foreign energy companies and increasing interest in oil and gas exploration.

Gulf Companies Also Target Syrian Energy Opportunities

Gulf energy companies are likewise assessing opportunities in Syria. The Abu Dhabi-listed Adnoc Drilling identified Syria as a growth market alongside Egypt and Iraq. Damascus has also secured an agreement with ConocoPhillips in partnership with Novaterra, a venture linked to Syrian-British billionaire Ayman Al Asfari. In addition, Syria reached a deal with the UAE’s Dana Gas following the lifting of US sanctions late last year. Gulf states pledged $28 billion in investment across the Syrian economy in 2025 alone. Türkiye and Syria are also expected to commission new infrastructure over the coming weeks that will triple electricity transmission capacity between the two countries to more than 800 megawatts, Mr Bayraktar said.