The LNG Market in 2025-2026

Introduction

The LNG market is in the midst of the most significant capacity expansion in its history, transforming the United States from a marginal exporter into the world's largest LNG supplier and reshaping global gas trade flows. After four years of tight markets following Russia's invasion of Ukraine in 2022, the combination of massive new US capacity, Qatari expansion, and growing supply from Africa and Asia is expected to push the global LNG market from scarcity to ample availability by 2026. For energy investment bankers, this expansion generates deal flow across the entire energy value chain: liquefaction project finance, upstream gas supply agreements, midstream pipeline and processing expansions, and cross-border offtake advisory.

US LNG export capacity is on track to increase from approximately 17 Bcf/d at end-2025 to over 19 Bcf/d in 2026, with three major projects driving the growth.

Plaquemines LNG (Venture Global): The most consequential new US LNG facility, Plaquemines LNG began exports in late 2024 and shipped 16.4 million tons in 2025 alone during its ramp-up phase. Located in Plaquemines Parish, Louisiana, the facility's accelerated commissioning has already created persistent spot and forward basis premiums at key Southeast Louisiana gas delivery hubs, as feed gas demand concentrates pipeline flows toward the facility. Phase 2 is progressing toward 2027 completion.

Corpus Christi Stage 3 (Cheniere Energy): Cheniere's third-stage expansion of its flagship Corpus Christi, Texas plant is adding 10 million tons per annum (mtpa) of capacity, with full operations expected by end-2026. Cheniere is the largest US LNG exporter and operates the most diversified offtake portfolio, with long-term sale and purchase agreements (SPAs) spanning European, Asian, and Latin American buyers.

Golden Pass LNG (QatarEnergy/ExxonMobil): The 15.6 mtpa Golden Pass facility in Sabine Pass, Texas is one of the two largest LNG projects starting up globally in 2026. This joint venture between QatarEnergy and ExxonMobil represents the strategic convergence of Middle Eastern gas reserves, capital, and US infrastructure expertise, with the first train entering service in 2026. The project has experienced timeline delays due to construction challenges, but remains on track for substantial completion.

Liquefaction Capacity (mtpa and Bcf/d)

LNG facility capacity is measured in millions of tons per annum (mtpa) of liquefied natural gas or in billions of cubic feet per day (Bcf/d) of feed gas intake. One mtpa of LNG requires approximately 0.13 Bcf/d of feed gas. A large-scale LNG train typically has 4-6 mtpa of capacity, requiring significant pipeline infrastructure to deliver feed gas. The US is adding approximately 37 mtpa of total new capacity in 2025-2026 across multiple projects, representing one of the largest simultaneous buildouts in global LNG history.

The IEA projects that 2026 will be the single biggest year for new LNG production capacity in history, with approximately 57 mtpa of new liquefaction coming online globally. Combined with the 37 mtpa that entered service in 2025, the market is shifting from the supply tightness that characterized 2022-2024 toward a multi-year period of ample supply.

On the demand side, European LNG imports remain elevated as the continent continues its structural diversification away from Russian pipeline gas. European TTF natural gas prices remain structurally above Henry Hub (typically $8-12 per MMBtu versus $3-4 at Henry Hub), reflecting the continent's dependence on seaborne LNG imports and its willingness to pay a premium for energy security. Asian demand growth is led by China (which continues to build regasification capacity and sign long-term SPAs with US and Qatari suppliers) and emerging importers in Southeast Asia (Vietnam, Philippines, Thailand) where growing economies are transitioning from coal to cleaner gas-fired generation. India is also expanding its regasification infrastructure, though price sensitivity has historically limited Indian LNG purchasing to spot cargoes during periods of low prices.

However, the pace of demand growth globally is not keeping up with the supply additions coming online in 2025-2027, leading multiple forecasters to project a supply glut that could push global LNG spot prices (JKM, the Asian benchmark) lower through 2027. Qatar's North Field Expansion alone will add approximately 48 mtpa of new capacity by 2029, representing one of the largest single-source LNG expansions ever undertaken.

The looming supply glut has important implications for commodity pricing. While more LNG export capacity supports Henry Hub prices by creating structural demand for US gas, the oversupply in global LNG markets could depress international LNG prices, narrowing the margin between US production costs and international sales prices. This margin compression matters for project economics and for energy bankers evaluating the feasibility of next-wave LNG projects that have not yet reached final investment decision.

LNG expansion generates advisory and capital markets revenue at every stage of the value chain, making it one of the most mandate-rich themes in energy banking.

Project finance. Each LNG facility requires $5-15 billion in construction capital, typically structured as non-recourse project finance debt backed by long-term offtake contracts and supported by sponsor equity. Banks with strong project finance capabilities (JPMorgan, Citi, MUFG, Societe Generale, Credit Agricole) compete for lead arranger mandates on these financings.

Upstream gas supply. New LNG capacity creates demand for dedicated gas supply, driving upstream M&A and development in gas-rich basins. The Haynesville Shale, located proximate to Louisiana LNG terminals, is the primary beneficiary. Gas-weighted E&P M&A and A&D transactions in the Haynesville are directly linked to LNG demand growth.

Midstream infrastructure. Pipeline expansions, gas processing plants, and interconnection facilities are required to transport feed gas from production basins to coastal liquefaction terminals. Energy Transfer, Williams Companies, and other large midstream operators are investing in capacity that serves LNG export demand, creating advisory mandates for expansion capital raises and bolt-on acquisitions.

Offtake advisory. Structuring and negotiating SPAs between LNG producers and international buyers is specialized advisory work that generates significant fees. These long-term contracts (typically 15-20 years) involve complex pricing mechanisms (Henry Hub-linked, oil-linked, or hybrid), take-or-pay obligations, destination flexibility provisions, and credit structures that require deep market knowledge. The trend toward portfolio optimization (where traders like Shell, TotalEnergies, and BP aggregate offtake from multiple sources and sell to end-users with customized delivery profiles) adds another layer of complexity and advisory opportunity. Banks active in LNG advisory include Citi, JPMorgan, Goldman Sachs, and specialist advisors like Tudor Pickering Holt.