Natural gas holds a central position in Egypt’s energy system. It fuels much of the country’s electricity generation, supports industrial production, supplies homes and businesses, and has periodically created valuable export income. Egypt also owns infrastructure that gives it a wider regional role, including offshore pipelines, a national transmission network, liquefied natural gas facilities, and access to major Mediterranean and Red Sea shipping routes.
However, the balance of the sector has changed. The rapid development of offshore fields created a production revival during the second half of the 2010s, but output later weakened as mature fields declined and technical problems affected major assets. At the same time, electricity use, industrial demand, and a growing population continued to increase domestic gas requirements.
Egypt is therefore operating as both a gas producer and a major importer. Its future position will depend on whether new discoveries can be developed quickly enough to slow production decline while imported gas supports the domestic market.
Zohr Changed Egypt’s Natural Gas Position
The modern Egyptian gas story is closely linked to offshore development in the Mediterranean Sea. Egypt had produced natural gas for decades, particularly from the Nile Delta and Western Desert, but the discovery of the Zohr field in 2015 changed expectations for the sector.
Located offshore in the Shorouk block, Zohr was the largest natural gas discovery made in the Mediterranean at the time. Development moved rapidly, with production beginning in 2017. The field helped Egypt overcome a serious domestic gas shortage, reduce LNG imports, and return to the LNG export market.
Zohr was supported by other offshore projects, including Nooros, Atoll, and Baltim South West. Together, these developments increased supply and strengthened the idea that Egypt could become the main natural gas center of the Eastern Mediterranean.
That production revival did not create a permanent surplus. Technical issues affected output from Zohr, while production at several older fields began to decline. The limited number of large new projects entering operation during the early 2020s made it difficult to replace lost volumes.
Egypt still has important gas resources, experienced offshore operators, and extensive supporting infrastructure. Eni, BP, Shell, Chevron, and other international companies continue to participate in exploration and production. The central problem is no longer whether gas exists offshore, but whether discoveries can be converted into commercial production quickly and at a scale that keeps pace with demand.
Electricity Demand Absorbs Much of Egypt’s Gas Supply
Natural gas is deeply connected to Egypt’s electricity system. Gas-fired plants provide the majority of national power generation, making the fuel essential during periods of high demand.
This dependence becomes especially important during the summer. Air-conditioning use rises sharply as temperatures increase, placing additional pressure on power plants and the gas network. When domestic production is insufficient, Egypt must choose between importing more gas, reducing industrial supply, using more liquid fuels in power stations, or accepting pressure on electricity availability.
Industry is another major source of demand. Fertilizer plants, petrochemical facilities, cement producers, metals companies, and other large users depend on reliable energy supplies. Natural gas is not only burned as a fuel but also used as an industrial feedstock, particularly in fertilizer and chemical production.
The residential gas network has also expanded. More homes and commercial buildings are connected to pipeline gas, reducing dependence on bottled liquefied petroleum gas but adding to national consumption.
This demand structure explains why Egypt’s gas position can change quickly. A country with large offshore fields and LNG export terminals may still experience a domestic shortage when production falls or electricity consumption rises. Export volumes are therefore closely linked to local market conditions rather than being supported by a guaranteed long-term surplus.
Energy pricing also affects consumption. Subsidized or regulated energy prices have historically encouraged high use while limiting the financial return available for some producers. Reforms have gradually adjusted domestic prices, but the government must balance investment incentives with electricity affordability and industrial competitiveness.
LNG Infrastructure Has Shifted Back Toward Imports
Egypt began exporting LNG in 2005 through facilities at Idku, near Alexandria, and Damietta. These plants gave the country a capability that its Eastern Mediterranean neighbors did not possess: the ability to liquefy gas and sell it into global markets.
The Idku complex includes two liquefaction trains, while Damietta has another major LNG production unit. Together, these facilities allowed Egypt to serve buyers in Europe and other international markets when sufficient gas was available.
The same infrastructure story now includes a growing import function. As domestic production fell below consumption, Egypt returned to the international LNG market and expanded its use of floating storage and regasification units. These vessels receive LNG, convert it back into gaseous form, and deliver it into the national pipeline system.
Ain Sokhna on the Gulf of Suez has become particularly important for LNG imports. Egypt has developed receiving, storage, regasification, and pipeline connections around the port area to move imported fuel into the national grid. Additional floating units have been chartered to increase supply flexibility and prepare for periods of peak summer demand.
This creates an unusual gas system. Egypt owns fixed LNG export plants on the Mediterranean coast while also importing LNG through floating terminals. The direction of trade depends on production levels, seasonal demand, imported pipeline volumes, and international prices.
The return to large-scale LNG imports carries a financial cost. Cargoes purchased from the global market can be expensive, particularly when competition is strong in Europe or Asia. Foreign currency requirements also place pressure on the wider Egyptian economy. Restoring domestic production is therefore not only an energy objective but also a fiscal and trade priority.
Israeli Gas Has Become Part of Egypt’s Supply Balance
Pipeline imports from Israel have become increasingly important to Egypt. Gas from the Tamar and Leviathan fields can move through offshore connections into the Egyptian network, where it may be consumed domestically or processed through LNG facilities.
These imports support power generation and industrial demand while allowing Egypt to use infrastructure that might otherwise operate below capacity. They also strengthen Egypt’s commercial position as the only Eastern Mediterranean country with established LNG export plants.
However, dependence on Israeli supply creates exposure to regional instability and offshore production interruptions. Disruptions at Israeli fields can quickly reduce deliveries to Egypt, especially during periods when domestic demand is already high.
Long-term agreements connected to Leviathan are intended to provide larger and more predictable volumes. These arrangements could help cover Egypt’s domestic deficit, but they also underline how far the market has shifted from the earlier expectation that Egyptian production alone would supply both domestic users and LNG exports.
Egypt’s network also links with the Arab Gas Pipeline, which connects the country to Jordan and, in principle, markets farther north. Although regional flows have changed over time, the system remains an important part of Egypt’s position between North Africa, the Middle East, and the Mediterranean.
Cyprus Could Support Egypt’s Export-Hub Strategy
Cyprus offers a different opportunity. Offshore discoveries in Cypriot waters have created potential gas supply, but Cyprus does not have its own large-scale liquefaction infrastructure.
An agreement involving Egypt, Cyprus, and Eni would allow gas from the Cronos discovery to move to Egyptian facilities. The proposed system would use existing infrastructure associated with Zohr before sending processed gas to the Damietta LNG plant for export.
This approach could reduce development costs because it avoids constructing a complete new processing and export system in Cyprus. For Egypt, it could provide additional feed gas for LNG facilities even when domestic production is under pressure.
The project illustrates the strongest part of Egypt’s hub strategy. Egypt does not need to produce every unit of gas that passes through its system. Its value also comes from pipelines, processing plants, LNG terminals, ports, technical experience, and access to international shipping.
The success of this model will depend on stable regional relationships, commercially competitive transport terms, reliable infrastructure, and enough imported supply to serve both Egyptian consumers and export customers.
New Discoveries Must Move Quickly Into Production
Egypt is continuing to promote offshore exploration, brownfield investment, and development around existing infrastructure. Near-field discoveries may be particularly valuable because they can be connected to pipelines and processing facilities faster than remote projects.
The Denise W discovery announced in 2026 shows the importance of this approach. Located in the Temsah concession, the discovery is close to existing offshore infrastructure and contains an estimated two trillion cubic feet of gas initially in place. Its location could support a faster development schedule than a completely isolated field.
A single discovery will not resolve Egypt’s full supply gap. Mature-field decline continues, while electricity and industrial demand remain high. The sector needs a steady sequence of new wells, field upgrades, compression projects, tiebacks, and larger developments.
Investment conditions will also be decisive. International operators require reliable payment, commercially workable gas prices, access to equipment, and confidence that development agreements will remain stable. Delays in payments or project approvals can slow drilling and reduce production growth.
Egypt is likely to remain one of the Eastern Mediterranean’s most important natural gas markets because it combines domestic demand, production resources, international operators, pipelines, and LNG facilities. Its role, however, is changing. The immediate priority is no longer maximizing exports. It is restoring the domestic gas balance while preserving the infrastructure and regional relationships that could support a renewed export position in the future.
