Global hydrogen demand surpassed 100 million tonnes in 2025, yet low emissions hydrogen still accounted for only slightly more than 1% of production.
The gap between hydrogenโs strategic importance and the pace of clean supply development is reviving interest in an alternative source that does not require large quantities of renewable electricity: naturally occurring, or geologic, hydrogen.
Often called white or gold hydrogen, geologic hydrogen is generated underground through geological processes and can accumulate in subsurface reservoirs. Its attraction is straightforward. Instead of using electricity to split water, developers would extract hydrogen that has already been generated naturally, potentially reducing both energy requirements and production costs.
But the resource opportunity is considerably better established than the commercial case. The central question for the emerging industry is no longer whether hydrogen exists naturally in the Earth’s crust. It does. The question is whether sufficiently large, concentrated and productive accumulations can be found often enough to support an industrial supply chain.
That distinction is critical as the conventional clean hydrogen sector confronts a slower deployment trajectory than the announcements of the early 2020s suggested.
Green hydrogen’s implementation gap remains significant
The slowdown in green hydrogen is real, although describing the sector as having simply stalled would obscure substantial progress. The International Energy Agency estimates that global hydrogen production reached almost 100 million tonnes in 2024, while less than 1% came from low emissions technologies. In 2025, low emissions production approached 1 million tonnes, with another increase expected in 2026.
The more significant problem is the distance between announced capacity and projects that actually reach operation.
A Nature Energy analysis tracking 190 green hydrogen projects found that only 7% of the capacity announced for 2023 was ultimately installed and operational on schedule. Of the 4.3 GW initially announced, only 0.3 GW was realized on time. The researchers also found that 86% of projects announced in 2021 were delayed by 2023, while 14% disappeared altogether.
The IEA’s more recent assessment points to the same structural issue. Only a small fraction of the announced low emissions hydrogen pipeline is considered realistically capable of operating by 2030, with typical project development cycles of three to six years and roughly half of announced projects facing delays relative to their original schedules.
High electricity requirements are one part of the problem. Green hydrogen requires renewable power, electrolyzers, water, compression, storage and transport infrastructure, while projects also need sufficiently strong offtake agreements to justify investment. Where renewable electricity can be used directly, converting it into hydrogen can introduce additional energy losses.
Geologic hydrogen potentially removes the electrolyzer and much of the electricity requirement from the production equation. That does not automatically make it cheap, but it changes the cost structure.
A 2025 review in Nature Reviews Earth & Environment estimated that the Archaean continental crust alone generated enough hydrogen over the past billion years to contain an energy equivalent to approximately 170,000 years of present day global oil consumption. The figure is deliberately not an estimate of recoverable reserves. The researchers emphasize that the quantity of hydrogen preserved in commercially relevant accumulations remains unknown.
Separate modeling by the U.S. Geological Survey produced an even wider range, estimating total in place geologic hydrogen resources at between 10ยณ and 10ยนโฐ million tonnes, with a most probable modeled value of approximately 5.6 million tonnes expressed in the study’s resource framework. The USGS cautions that much of the modeled hydrogen is likely to be too deep, offshore or otherwise uneconomic to recover. Even a relatively small recoverable fraction, however, could theoretically represent a substantial supply.
The important implication is that geological hydrogen does not suffer from the same fundamental resource constraint as renewable hydrogen production. It is not necessary to build an enormous renewable electricity system specifically to manufacture every tonne of hydrogen.
But replacing an electricity constraint with a geological exploration constraint is not necessarily an easier proposition.
Natural hydrogen is generated through several geological mechanisms, including reactions between water and iron bearing minerals and the radiolysis of water involving naturally radioactive elements. The processes can occur over very different timescales, from thousands or millions of years to tens or hundreds of millions of years.
The hydrogen must migrate through the subsurface, accumulate in a reservoir and remain trapped. Because hydrogen is highly mobile and reactive, a geological system needs an effective combination of source, migration pathways, reservoir characteristics and sealing structures.
Research on the Bourakebougou field in Mali illustrates the complexity. The field contains several hydrogen bearing reservoirs, with gas from the main shallow reservoir reported at approximately 98% hydrogen. Studies have identified dolerite formations and aquifers as important components of the trapping system.
Bourakebougou is consequently important as proof that naturally occurring hydrogen can accumulate and be produced, rather than as proof that commercial scale production has already been demonstrated.
A 2026 analysis of natural hydrogen flow rates makes that distinction particularly important. It found that the only publicly documented wellhead flow data extending over several years comes from Bourakebougou, where the reported flow corresponds to roughly 45 tonnes of hydrogen per year. The study concludes that the field demonstrates the existence of a productive natural hydrogen system but remains roughly two orders of magnitude below the flow rates that would be required for economic production at larger scale.
That finding cuts through some of the more optimistic resource narratives. A trillion tonne theoretical resource has little commercial value if the hydrogen cannot be concentrated in reservoirs capable of sustaining high production rates.
Exploration is becoming the new bottleneck
The industry is therefore beginning to resemble an early stage upstream resource business more than a conventional hydrogen production sector.
The USGS says more than 40 companies were exploring for geologic hydrogen by the end of 2023, four times the number in 2020. Exploration is now underway in countries including Albania, Australia, Canada, Colombia, France, Finland, Korea, Spain and the United States.
The development of geological prospectivity mapping is another indication that the sector is moving from conceptual research toward systematic exploration. In 2025, the USGS released its first continental scale map identifying areas in the United States with geological characteristics potentially favorable for hydrogen accumulations. The map does not identify proven resources, but it provides a framework for prioritizing exploration.
Australia offers another illustration of the industry’s current maturity. Geoscience Australia describes natural hydrogen as a prospective resource whose extent remains poorly understood. The country drilled its first dedicated natural hydrogen wells on the Yorke Peninsula in 2023, while its only reported contingent natural hydrogen resource in 2025 was the Mt Kitty project in the Amadeus Basin, with 7.9 petajoules, equivalent to about 22 billion cubic feet or 66,000 tonnes of hydrogen.
Those figures are important precisely because they are much smaller and more concrete than global theoretical resource estimates. They show where the sector currently stands: geological potential is extensive, but proven commercial reserves remain limited.
Even if exploration succeeds, geologic hydrogen would not automatically bypass the infrastructure and demand constraints that have slowed green hydrogen.
Hydrogen still has to be processed, compressed, transported and delivered to users. New pipelines, storage systems and industrial conversion equipment may be required depending on the location and purity of a resource. The economics therefore depend not only on the cost of extracting hydrogen from the ground, but also on proximity to industrial demand and existing infrastructure.
This could favor geological hydrogen projects near established industrial clusters. Unlike green hydrogen developments that can be located according to renewable resource quality and then connected to demand, natural hydrogen exploration is constrained by geology. The best reservoir may not be close to a steel plant, refinery, ammonia facility or pipeline network.
There is also a regulatory distinction that could become increasingly important. The Nature Reviews Earth & Environment assessment explicitly argues that continental natural hydrogen should not automatically be classified as renewable because the systems identified today do not necessarily regenerate on decadal or centennial timescales.
That does not make geologic hydrogen high carbon. It means that resource classification and sustainability claims will require evidence about generation rates, reservoir depletion and recharge rather than assumptions based simply on the origin of the gas.
The real opportunity is diversification, not substitution
The case for white hydrogen therefore rests less on replacing green hydrogen than on creating another low emissions supply pathway for applications where hydrogen has a defensible role.
Global hydrogen demand remains concentrated in refining, ammonia, methanol and other established industrial uses. New applications accounted for less than 1% of demand in 2024, according to the IEA.
That matters because the emerging natural hydrogen industry does not need to create an entirely new hydrogen market to establish demand. Existing industrial consumers already provide potential offtakers, provided the resource can meet their specifications at a competitive delivered cost.
For hard to abate sectors such as iron and steel, hydrogen can serve as a reducing agent rather than simply as a combustion fuel. That distinction strengthens the potential value of low carbon hydrogen where direct electrification cannot readily replace the chemical function of hydrogen.
The commercial race is consequently moving toward a much narrower question than the headline resource estimates suggest. Can exploration companies repeatedly identify reservoirs with sufficient concentration, pressure, flow rates and long term production characteristics, and can they do so close enough to demand centers to compete with both fossil based hydrogen and renewable hydrogen?
If the answer is yes, geologic hydrogen could become a meaningful addition to the low emissions hydrogen mix without requiring every new tonne of supply to be manufactured through electrolysis.
If the answer is no, the enormous quantities of hydrogen generated naturally throughout geological history will remain primarily a geological curiosity rather than an industrial resource.
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