The liquefied natural gas market in the Eastern Mediterranean has entered a period of structural transformation as geopolitical tensions, shifting global gas flows, and new infrastructure investment converge to redefine how gas reaches Europe and Southeast Europe. The regional LNG system—linking offshore gas production in Israel and Egypt with import hubs in Greece and Türkiye and the expanding LNG demand of Europe—has evolved from a peripheral supply corridor into a strategic balancing mechanism within the broader global gas market. The interaction between regional supply developments, European import demand, and global LNG trade flows is increasingly shaping gas pricing, power generation economics, and infrastructure investment decisions across Southeast Europe.
A recent escalation of tensions in the Persian Gulf dramatically illustrated the vulnerability of LNG markets to geopolitical shocks. Following a coordinated military strike on Iran by United States and Israeli forces in late February 2026, Iranian retaliatory drone attacks triggered security concerns around Qatar’s gas production infrastructure and LNG shipping routes through the Strait of Hormuz. Qatar temporarily halted gas production operations for security reasons, and LNG vessel traffic through the strait became uncertain. The result was an immediate surge in global gas prices. Europe’s benchmark gas price at the Dutch TTF hub jumped more than 50 percent during intraday trading, closing the day 39 percent higher at €44.52/MWh, before climbing further to €55.85/MWh within two days, representing a 74.4 percent increase in an extremely short period.
Such price movements underline the degree to which global LNG markets are now interconnected and responsive to geopolitical risk. The European gas system, which has become increasingly dependent on LNG imports since the reduction of Russian pipeline deliveries, is particularly sensitive to supply disruptions in the Middle East. LNG cargoes traveling from Qatar, the United States, and other producers must traverse long shipping routes that are exposed to both geopolitical events and logistical constraints, meaning disruptions can quickly propagate through the global market.
While geopolitical shocks dominate headlines, the deeper structural change in the LNG market has been unfolding over the past several years as global supply expands and Europe restructures its gas procurement strategy. In 2025, global LNG production increased by roughly 7 percent, equivalent to approximately 38 billion cubic meters (bcm) of additional supply. Much of that expansion occurred during the second half of the year as new liquefaction capacity came online. A major contributor to this supply increase was the Plaquemines LNG project in Louisiana, which alone accounted for over 60 percent of the increase in global LNG supply during 2025.
The supply expansion helped ease global gas market tightness that had persisted through early 2025, although regional supply disruptions continued to influence the balance. Russian LNG exports declined by roughly 7 percent year-on-year, equivalent to approximately 3 bcm, partly due to sanctions affecting smaller export terminals and maintenance at larger facilities. Norway also experienced supply interruptions that reduced LNG exports by nearly 35 percent, equivalent to more than 2 bcm. These reductions coincided with declining pipeline gas deliveries to Europe, further tightening the European gas market.
The European Union has been restructuring its gas supply system since the disruption of pipeline imports from Russia. LNG has emerged as the primary alternative supply source. In 2025, Europe’s LNG imports increased by approximately 30 percent, representing an additional 40 bcm of imported liquefied gas. Total LNG imports exceeded 175 bcm, marking the highest level in the region’s history. LNG now represents a growing share of Europe’s natural gas supply mix, rising from 30 percent of primary gas supply in 2024 to 38 percent in 2025.
The United States has become the dominant incremental supplier of LNG to Europe. American LNG deliveries to the European market increased by roughly 60 percent during 2025, filling the supply gap left by declining Russian pipeline flows. Russian LNG exports to Europe declined modestly, by around 10 percent, although Russia still remained the second-largest LNG supplier to the continent. Imports of Russian LNG have been concentrated in a few European markets, particularly Belgium, France, and Spain, which together accounted for more than 85 percent of Russian LNG imports into Europe during the year.
Looking ahead, European LNG demand is expected to continue expanding. LNG imports could reach more than 185 bcm in 2026, driven by increased gas storage injection requirements and the continuing phase-out of Russian pipeline gas. The European Union has formally committed to eliminating Russian gas imports entirely by November 2027, a decision that will further reinforce LNG’s role in the continent’s gas balance.
Within this evolving global system, the Eastern Mediterranean has emerged as an increasingly important regional supply and trading corridor. The discovery of significant offshore gas reserves in Israel, Egypt, and Cyprus has reshaped the energy landscape of the region. These discoveries have allowed countries that were once major gas importers to become producers with export potential, while simultaneously encouraging the development of cross-border infrastructure that links regional gas fields to international LNG markets.
Israel’s offshore gas sector has been central to this transformation. The Leviathan and Tamar gas fields, located in the eastern Mediterranean basin, have become major pillars of the country’s energy system. Israel’s natural gas production reached approximately 27 bcm in 2025, although growth was constrained by maintenance outages and temporary shutdowns during regional conflicts. Production is expected to increase to around 30 bcm in 2026 as expansion projects at both Leviathan and Tamar come online.
A significant portion of Israel’s gas output is exported to neighboring markets, particularly Egypt, via pipeline connections. These exports play a crucial role in Egypt’s gas supply system. In the first eleven months of 2025, Israel delivered approximately 8.4 bcm of pipeline gas to Egypt, covering roughly 15 percent of Egyptian gas demand. The cross-border gas trade reflects the growing integration of Eastern Mediterranean energy markets.
Egypt occupies a unique position within the regional LNG system because it hosts the Eastern Mediterranean’s only operational LNG liquefaction plants. Two major facilities, located at Damietta and Idku, process natural gas from Egyptian domestic production as well as imported pipeline gas from Israel. These plants liquefy the gas for export to global LNG markets, including Europe and Asia. As a result, Egypt effectively serves as the LNG processing hub for the Eastern Mediterranean.
Despite its role as an LNG exporter, Egypt has experienced declining domestic gas production in recent years. In 2025, Egyptian gas output fell by approximately 15 percent year-on-year, equivalent to nearly 7 bcm. As domestic production declined and electricity demand remained strong, Egypt was forced to increase LNG imports. The country imported roughly 12.5 bcm of LNG in 2025, compared with approximately 3 bcm in 2024. The United States supplied nearly 80 percent of these LNG imports, illustrating the growing role of American LNG in regional energy systems.
At the same time, Egypt’s LNG export volumes have been limited by domestic consumption requirements. LNG exports from the country were estimated at approximately 1 bcm in 2024 and declined further to roughly 0.5 bcm in 2025, as domestic power generation needs took priority over export commitments.
Cyprus represents another potential contributor to the Eastern Mediterranean gas supply system, although its development remains at an earlier stage. Several gas discoveries have been made in Cyprus’s offshore exclusive economic zone, including the Aphrodite and Cronos fields. However, the country currently lacks the infrastructure required to produce and export natural gas at commercial scale. Development plans focus on transporting Cypriot gas via pipeline to Egypt, where it could be liquefied at the existing Damietta and Idku facilities before being exported to international markets. If these projects proceed according to current plans, the first exports of Cypriot LNG could begin around 2027.
While upstream gas production in the Eastern Mediterranean remains relatively modest compared with major LNG exporters such as Qatar or the United States, the region’s strategic importance lies in its geographic position. The Eastern Mediterranean sits at the intersection of Middle Eastern production systems and European demand centers, making it a natural bridge between supply and consumption.
This strategic positioning is particularly evident in Greece and Türkiye, which have been rapidly expanding their LNG import infrastructure. Greece has positioned itself as a gateway for LNG entering Southeastern Europe. The country already operates the Revithoussa LNG terminal, which has played a central role in diversifying Greek gas supply away from pipeline imports. More recently, the Alexandroupolis floating storage and regasification unit (FSRU) began commercial operations in late 2024, providing additional capacity for LNG imports in northern Greece.
Additional LNG infrastructure projects are under development. Planned facilities include the Dioriga Gas FSRU near Corinth, the Argo FSRU near Volos, and a proposed Thessaloniki FSRU project backed by Elpedison. Together, these facilities could expand Greece’s LNG regasification capacity from approximately 12.5 bcm today to about 27.5 bcm by 2030, more than doubling the country’s ability to receive LNG cargoes.
The expansion of LNG infrastructure in Greece has also facilitated increased gas exports to neighboring countries. Natural gas exports from Greece—primarily regasified LNG transmitted through pipeline interconnections—rose sharply in 2025, increasing by 196 percent to reach 8.59 terawatt hours (TWh) compared with 2.90 TWh in 2024. This surge highlights Greece’s emerging role as a regional gas transit hub linking LNG supply to Southeast European markets.
Türkiye has also developed extensive LNG import capacity as part of its broader energy security strategy. The country operates multiple LNG receiving terminals, including both onshore facilities and floating regasification units. Combined regasification capacity exceeds 50 bcm per year, making Türkiye one of the largest LNG importers in Europe. LNG imports typically account for around 13–15 bcm per year, sourced from suppliers including the United States, Algeria, and other global exporters.
Türkiye is currently planning further expansion of its LNG infrastructure. New FSRU installations are being considered along the Mediterranean coast, including projects near Dörtyol and between Gazipaşa and Anamur, which would further enhance the country’s gas import flexibility and strengthen its role as a regional gas trading platform.
Beyond Greece and Türkiye, other Eastern Mediterranean countries display varying degrees of engagement with LNG infrastructure development. Jordan has already established an LNG import terminal at Aqaba, enabling the country to diversify its gas supply sources. Lebanon has considered FSRU projects but has yet to implement them. Syria’s LNG infrastructure remains undeveloped due to ongoing political instability.
Cyprus has attempted to develop its own LNG import terminal at Vasilikos, but the project has encountered significant setbacks. Construction was halted after the withdrawal of a Chinese contractor responsible for building the facility, leaving the future of the project uncertain.
While infrastructure development is expanding, LNG price formation in the Eastern Mediterranean remains influenced by a complex combination of factors. Local supply-demand balances play a role, particularly during periods of high electricity demand caused by extreme weather. Heatwaves in the Mediterranean region can drive significant increases in gas consumption for power generation, tightening regional gas markets and pushing LNG prices higher.
Shipping costs have also become a significant component of LNG pricing in the region. LNG cargoes delivered to Eastern Mediterranean terminals often travel long distances, particularly when sourced from the United States. Freight rates for LNG carriers fluctuate depending on vessel availability and seasonal demand. During periods of high global demand, shipping costs can increase sharply, raising the landed cost of LNG at import terminals in Greece and Türkiye.
The pricing structure of US LNG also affects regional market dynamics. American LNG exports are generally linked to the Henry Hub gas benchmark, with additional liquefaction and transportation costs added to the final price. In some cases, LNG cargoes imported from the United States have cost 50 percent more than regional gas price averages, increasing electricity generation costs in markets dependent on gas-fired power plants.
Ultimately, the Eastern Mediterranean LNG market reflects the interaction of global and regional energy systems. Price movements are influenced not only by local factors but also by global LNG demand, particularly in Asia, where competition for cargoes can redirect shipments away from Europe.
The Eastern Mediterranean is unlikely to become a dominant force in global LNG trade in the way that Qatar or the United States have become. However, its importance lies in its ability to provide an additional layer of supply flexibility for Europe. As the continent continues to restructure its gas supply system and reduce dependence on Russian pipeline imports, regional supply corridors such as the Eastern Mediterranean will play an increasingly important supporting role.
The region’s future LNG development will depend on continued investment in upstream gas production, the construction of new pipelines and LNG infrastructure, and stable political and regulatory conditions. If these conditions are met, the Eastern Mediterranean could evolve into a key component of Europe’s diversified gas supply architecture, linking regional gas production with the growing LNG demand of European energy markets while providing additional resilience to the global gas system.
