Sopuruchi Onwuka

The race by producers to meet rising demand for natural gas as the world prioritizes cleaner energy options is now raising concerns among investors who begin to spy imminent gloom for investors in high-cost unconventional terrains.

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According to multiple data sources including the International Energy Agency (IEA), the Energy Information Administration (EIA) and gas exporting countries, more than 300 billion cubic meters per year of new export capacity expected to come online between 2025 and 2030 from projects that have already reached final investment decision or are under construction.

The unprecedented wave of new capacity driven mainly by the United States, Qatar, and a handful of emerging suppliers promises to transform the balance of the global gas trade and address supply concerns. The emerging capacity surge also raises growing concerns that the world could soon be heading into a period of structural oversupply, which may depress prices, squeeze project returns, and test the resilience of producers heavily invested in LNG exports.

Over the past six years, between 2019 and September 2025, final investment decisions (FIDs) for LNG projects have surged to levels unseen in the industry’s history, with roughly 390 billion cubic meters of new LNG export capacity has been sanctioned, averaging nearly 60 billion cubic meters annually.

The capacity addition equals more than 40 percent of today’s global market or over 100 percent of the average rate of new capacity approvals recorded between 2014 and 2018.

The United States has been the dominant driver of this expansion, accounting for more than half of all LNG project FIDs since 2019. Qatar follows with less than 20 percent, while the rest is distributed among smaller players in Africa, South America, Asia Pacific, and the Middle East.

North America’s share of total global LNG project approvals reached 75 percent between 2022 and 2023, with the U.S. alone accounting for about 70 percent of sanctioned capacity. High gas prices, combined with strong demand from Europe and Asia seeking to diversify away from Russian pipeline gas, spurred investors to commit to new facilities across the U.S. Gulf Coast.

After a pause in 2024 caused by cost inflation, oversupply fears, and a temporary freeze on export permit approvals, the U.S. regained momentum in 2025 following the lifting of that regulatory suspension. By October, the country had already sanctioned over 83 billion cubic meters per year of new LNG capacity, representing more than 85 percent of all global FIDs for the year and making 2025 a record year for U.S. LNG investment.

Globally, more than 300 billion cubic meters per year of new LNG export capacity is expected to be added between 2025 and 2030 from projects that are already under construction or have reached FID, data from various agencies show. The figure excludes sanctioned but currently inactive developments such as Russia’s Arctic LNG 2 (27 bcm/yr), Mozambique LNG (18 bcm/yr), and Qatar’s North Field West expansion (22 bcm/yr). The projects remain stalled due to sanctions, security risks, or commercial uncertainties. If they resume, the scale of future supply could swell even further.

Based on current timelines, new liquefaction capacity additions are projected to rise gradually from about 33 billion cubic meters in 2025 to a peak of over 70 billion cubic meters in 2028, before tapering off toward the end of the decade.

More than half of the 2025 increase will come from the ramp-up of the first phase of the Plaquemines LNG project in Louisiana, which began producing late in 2024 and is expected to reach full capacity within a year. Other major contributors include the Golden Pass LNG joint venture between QatarEnergy and ExxonMobil, Port Arthur LNG, CP2 LNG, and the Rio Grande LNG trains 4 and 5, all in the U.S. There are also the Coral North FLNG in Mozambique and Argentina’s Southern Energy FLNG project.

Such a rapid buildout represents a monumental shift in the geography of global gas supply. For decades, LNG trade was dominated by a few producers: Qatar, Australia, and Malaysia. And by 2030, the United States alone could account for more than one-third of global LNG export capacity. North America as a whole could provide close to 40 percent, reshaping global pricing dynamics and contract structures, which traditionally favored long-term supply deals linked to oil benchmarks.

But while this expansion brings opportunity, it also risks flooding the market with more gas than demand can absorb. The International Energy Agency and several major consultancies have warned that if all under-construction projects are completed as scheduled, global LNG supply could exceed demand growth by as much as 50 billion cubic meters annually by 2028. The potential glut could push spot prices lower, undermining project economics—especially for high-cost producers.

The oversupply risk stems from several overlapping trends. In Europe, which became the largest buyer of LNG after Russia’s invasion of Ukraine, gas demand is expected to decline gradually after 2026 as renewable energy, efficiency measures, and decarbonization policies gain traction. Meanwhile, in Asia—the long-term anchor of global LNG growth—demand remains robust but uneven. China’s imports have rebounded strongly in 2025, but Japan and South Korea are both reducing LNG use due to nuclear restarts and a shift toward renewables. India and Southeast Asia represent potential growth markets, but infrastructure bottlenecks and price sensitivity could limit how quickly their demand can expand.

If these trends hold, the next few years could see LNG sellers competing fiercely for market share. U.S. exporters, with flexible contracts and low feedgas costs, may have an edge in adjusting to price swings, while state-backed suppliers such as QatarEnergy can sustain operations even at lower prices due to economies of scale. But smaller or newer players—particularly in emerging markets such as Mozambique, Mauritania, or Argentina—may struggle to secure buyers or financing amid a softer price environment.

The situation echoes previous market cycles. In the mid-2010s, a similar wave of new capacity from Australia and the U.S. led to a supply glut that drove spot prices below $5 per million British thermal units, prompting delays and cancellations of new projects. This time, however, the oversupply could be deeper and longer-lasting, given the scale of capacity being added simultaneously and the growing push for cleaner energy alternatives.

Some relief could come from delays, cost overruns, or geopolitical disruptions. Russia’s Arctic LNG 2 project has already been paralyzed by sanctions, while Mozambique LNG remains on hold due to regional security concerns. Qatar’s North Field West project, though approved, has yet to begin construction. If any of these major sources stay offline, the excess supply could be partially offset. Additionally, aging LNG plants in countries like Nigeria, Indonesia, and Australia are expected to see declining output later in the decade, which could help rebalance the market somewhat.

Even so, the overall direction is clear: the world is entering a period of abundant LNG. For consumers, this means greater energy security and potentially lower prices. For producers, it means tighter competition, narrower profit margins, and a renewed focus on operational efficiency and carbon intensity. The next five years will test which LNG exporters can adapt fastest—by lowering costs, capturing new markets, and integrating low-carbon technologies—to thrive in an increasingly crowded and volatile global gas landscape.