LNG infrastructure 2026 is facing a structural mismatch: North American supply is expanding faster than the world can build capacity to receive it. The US share of global LNG supply is projected to rise from 25 percent in 2025 to 33 percent by 2030, driven by a wave of final investment decisions that sanctioned five major projects in 2025 alone — Louisiana LNG, Corpus Christi Trains 8 and 9, CP2 Phase 1, Rio Grande LNG Train 4, and Port Arthur Phase 2.
The supply side of the equation is settled. The infrastructure required to absorb that volume is not.
The FID Wave and What It Means for Receiving Terminals
Each project sanctioned in 2025 adds to a delivery pipeline that will begin flowing in volume before the end of the decade. Demand growth is expected to come primarily from Asia, with secondary markets across Europe and Latin America investing in import infrastructure to handle increased cargo flows. The pressure lands squarely on regasification terminals, floating storage and regasification units, and onshore storage networks — assets that typically require five to seven years from FID to commissioning.
Brazil illustrates the dynamic directly. The country has doubled its regasification capacity to 5.1 Bcf/d in recent years as part of a deliberate build-out to capture US and Atlantic Basin LNG flows. That kind of targeted infrastructure investment is the template other import markets will need to follow. The Brazil LNG regasification expansion demonstrates what committed capital can deliver within a single market cycle.
Europe faces a more complex picture. Post-2022 FSRU deployments added floating capacity rapidly, but permanent onshore infrastructure has lagged. The Qatar Force Majeure event in early 2026 exposed how quickly an unplanned supply interruption can stress a system with limited buffer storage.
LNG Infrastructure 2026: The Storage Bottleneck
The bottleneck is not liquefaction capacity — it is the full chain from ship to grid. Receiving terminals require sufficient LNG storage tanks, sendout systems, and pipeline connections to handle cargo at the rate modern Q-Flex and Q-Max vessels deliver it. A terminal that cannot turn a vessel around within its contractual window creates demurrage costs that erode the economics of the entire supply chain.
New projects sanctioned outside the US in 2025 add further complexity to infrastructure planning. Chevron committed $2 billion to Gorgon Stage 3 off Australia’s northwest coast, adding backfill supply for an existing export operation. Shell’s Crux field drilling programme will feed backfill volumes to the Prelude FLNG vessel. In the eastern Mediterranean, Chevron sanctioned the Leviathan expansion to support a $35 billion gas export agreement between Israel and Egypt — a supply route that will require corresponding import and storage infrastructure on the Egyptian side.
Each of these projects produces volumes that must land somewhere. The world’s largest LNG terminals are already operating at or near capacity during peak demand periods. New receiving infrastructure is not optional — it is the rate-limiting step on global LNG trade growth.
LNG as the Transition Fuel — and the Infrastructure Commitment That Requires
LNG produces approximately 30 percent less CO₂ than heavy fuel oil and near-zero sulfur oxides, which positions it as the pragmatic transition fuel for markets that cannot yet support hydrogen or ammonia at scale. That case is strengthened by the established supply chain, proven storage technology, and the fact that LNG accounted for over 70 percent of alternative-fuel newbuild orders in the marine sector through 2025.
The transition fuel argument, however, only holds if the infrastructure exists to deliver it. Markets that invest in regasification and storage now will be able to access competitively priced US and Australian LNG volumes when they arrive. Markets that do not will either pay spot premiums or remain dependent on pipeline gas from less stable supply sources.
The supply wave is already in motion. LNG infrastructure 2026 investment decisions made in the next 12 to 24 months will determine which markets benefit from it and which are still building when the cargoes start arriving. Sempra’s Port Arthur and Cameron LNG projects are among the facilities at the centre of that export build-out — and the receiving infrastructure on the demand side needs to keep pace.
For a detailed breakdown of the terminals at the centre of global LNG trade, see our ranking of the top LNG terminals by capacity.
Why is LNG infrastructure struggling to keep pace with supply growth in 2026?
North American LNG export capacity expanded sharply following a wave of final investment decisions in 2025, adding projects including Louisiana LNG, CP2 Phase 1, and Port Arthur Phase 2. Receiving terminal construction, which takes five to seven years from FID to commissioning, has not kept pace with the speed of the supply build-out.
Which new LNG projects reached final investment decision in 2025?
Five major US projects were sanctioned in 2025: Louisiana LNG, Corpus Christi Trains 8 and 9, CP2 Phase 1, Rio Grande LNG Train 4, and Port Arthur Phase 2. Outside the US, Chevron committed $2 billion to Gorgon Stage 3 in Australia and sanctioned the Leviathan field expansion in the eastern Mediterranean.
What is the US share of global LNG supply expected to reach by 2030?
The US share is projected to rise from approximately 25 percent in 2025 to 33 percent by 2030, driven by the volume of export capacity currently under construction or recently sanctioned.
What role does LNG storage capacity play in global trade flows?
Onshore LNG storage tanks at receiving terminals act as the buffer between cargo delivery and pipeline sendout. Insufficient storage forces terminals to turn away or delay vessels, creating demurrage costs and constraining the economics of the entire supply chain.
Which regions are investing most heavily in LNG receiving infrastructure in 2026?
Asia is the primary growth market for LNG imports, with secondary investment in Europe and Latin America. Brazil has doubled its regasification capacity to 5.1 Bcf/d. European markets added FSRU capacity rapidly post-2022 but permanent onshore infrastructure has lagged behind.