In August, Edith Cowan University (ECU) in Perth announced what its newsroom called a “green hydrogen goldmine” beneath Western Australia. The claim rests on a peer-reviewed study in the International Journal of Hydrogen Energy: when magnetite, the iron oxide that makes up much of the Pilbara’s banded iron formations, reacts with hot, pressurised water, it releases hydrogen gas. The ECU team went one step further and showed that hydrogen production can be stimulated by injecting a solution into the rock, and that how much hydrogen you get depends less on how much magnetite there is than on how well water reaches fresh mineral surfaces through fractures, pores and permeable pathways.
Associate Professor Alireza Keshavarz spoke of a “massive, untapped energy reserve” with enough hydrogen for Australia to benefit “for generations”. That is the kind of sentence that travels well. It is also the kind of sentence that deserves a closer look, because the distance between a 60-day experiment in a pressure vessel and a hydrogen industry is long, and because the study touches a question that matters for Power-to-X in Europe as much as for mining in Australia: where will the cheapest low-emission hydrogen come from, and what does that mean for everything we plan to make from it?
What the researchers actually did
The chemistry is not new. Magnetite (Fe₃O₄) contains iron in two oxidation states. When it meets water at elevated temperature, part of that iron is oxidised further to hematite (Fe₂O₃), and the oxygen for that step is taken from the water molecule. What is left over is hydrogen. In simplified form: 2 Fe₃O₄ + H₂O → 3 Fe₂O₃ + H₂. The same family of reactions, running on iron-rich mantle rock, is thought to be behind most of the natural hydrogen seeps that have been documented from Mali to Oman and the French Lorraine.
What ECU adds is geometry. The team, led by doctoral researcher Kaveh Moghanirahimi with Keshavarz and Professor Stefan Iglauer, exposed magnetite samples to water at 200°C and high pressure for 60 days to mimic conditions deep underground, and measured how the hydrogen yield varied with the mineral’s exposed surface. Their conclusion is that production is controlled by access, not just abundance: a banded iron formation with fractures and connected pores will generate hydrogen where a dense block of the same rock will not. From that follows the practical idea of injecting a fluid to open pathways and wet fresh surfaces, which is the part the university describes as a way to “stimulate” production.
Iglauer frames the work as bridging the gap between laboratory experiments and real geological systems. That is a fair description of what a study like this can do. It is not a resource estimate, a well test or a cost calculation, and the press release does not offer any of the three.
Green, white, gold or orange: the colour matters less than the arithmetic
ECU calls the product green hydrogen. In the colour taxonomy that the hydrogen debate has settled into, that label is normally reserved for hydrogen from renewable electricity via electrolysis. Hydrogen that seeps out of the ground on its own is called white or gold; hydrogen that is deliberately produced by injecting water into iron-rich rock has acquired the name orange. The Pilbara concept sits squarely in the last category.
From a Power-to-X perspective, the label is a side issue. What counts is the life-cycle footprint of the molecule, the energy that has to be spent to get it out of the ground and into a usable form, and whether the resource is additional to, or in competition with, the renewable electricity we need elsewhere. Orange hydrogen scores well on the first point if the reaction really runs on geological heat and the wells are powered cleanly. Whether it scores well on the second and third is exactly what nobody knows yet.
The open questions, in order of size
Anyone who has followed the natural hydrogen story since the Bourakébougou well in Mali began powering a village in 2012 knows the pattern: headline reserve figures, a wave of exploration licences, then a long wait for production data. Several exploration companies are now drilling in South Australia, the United States and Europe, and estimates of the global geological hydrogen endowment range from modest to enormous, with the caveat that most of it is expected to be too deep, too dispersed or too far from demand to recover. The ECU study does not change that picture; it adds a mechanism that could eventually enlarge it. Before it does, four things need answering.
Rate versus stock. A reservoir is worth something because gas has accumulated over geological time. A generation process is worth something only if it runs fast enough to be harvested at a commercial rate. The reaction in the ECU experiment ran for 60 days at 200°C; the release does not say how much hydrogen per tonne of rock or per unit of time, and that number decides whether a stimulated banded iron formation behaves like a gas field or like a very slow chemistry set.
Depth and heat. At typical continental geothermal gradients, 200°C is reached several kilometres down. Drilling to that depth in hard Precambrian rock, keeping a fracture network open and circulating fluid through it is essentially the engineering problem of enhanced geothermal systems, with a long track record of being harder and more expensive than the models suggest. Hydrothermal hot spots would change the calculation, but the Pilbara is ancient, cold crust.
Water and location. The Pilbara is one of the driest inhabited regions on earth. Injecting a solution at scale means either desalinated seawater piped inland or competing with mines and communities for groundwater. It also means producing hydrogen a long way from any consumer, which brings back the familiar export question: compress it, liquefy it, convert it to ammonia or methanol, or use it on site to make something that ships more easily.
Losses and purity. Hydrogen is the smallest molecule there is. It migrates through rock, dissolves in water and is eaten by microbes. Whatever reaches a wellhead will arrive mixed with nitrogen, methane and water vapour and will need separation before it is worth anything. None of this is a reason not to try. All of it is a reason to treat “enough for generations” as an aspiration rather than a figure.
What it means for Power-to-X
Geological hydrogen is not Power-to-X. It does not start with renewable electricity, and it does not need an electrolyser. But it lands on the same market and feeds the same downstream chain. Every synthetic fuel, every tonne of e-methanol and e-SAF, every batch of green ammonia is hydrogen plus something, and the hydrogen is usually the largest single cost item. If a new source turned out to deliver clean hydrogen more cheaply than electrolysis, that would be good news for the X in Power-to-X even if it were bad news for electrolyser manufacturers.
The conditions do not change. For fuels, one condition remains non-negotiable from a Power-to-X perspective: e-fuels only make climate sense when the carbon they contain is recycled CO₂ from biogenic, atmospheric or industrial sources, and when that recycling displaces fossil carbon instead of providing a reason to burn more of it. Where the hydrogen comes from is a question of cost and footprint; where the carbon comes from is a question of whether the fuel is defossilised at all.
There is also a sobering lesson in the timelines. Electrolysis is a hundred-year-old technology whose main obstacle today is not physics but the price of electricity and the absence of firm demand. Stimulated geological hydrogen is a promising 60-day experiment whose main obstacles are physics, geology and money. Betting the defossilisation of aviation, shipping and chemicals on the second while the first is available would be a strange kind of technology openness.
The view from Switzerland
Switzerland has no banded iron formations and will not be drilling for hydrogen in the Jura. Its interest in the ECU result is indirect but real. Switzerland will import a large share of the renewable molecules it needs, and every credible new supply route lowers the long-run import price and the geopolitical risk of relying on a handful of producer regions. Australia has been positioning itself as a hydrogen exporter for a decade, mostly on the strength of cheap solar and wind; if part of that export could one day come from the rock instead of the grid, the country’s case gets stronger, not weaker.
For Swiss policy, the practical conclusion is the one SPIN has argued for years: regulate the outcome, not the recipe. Rules that define low-emission hydrogen by its life-cycle footprint rather than by the colour of its production route leave room for a surprise like this one, without lowering the bar. The Western Australian study is a genuine scientific contribution and a reminder that the earth still has options we have not priced. It is not yet a supply. The difference between the two is measured in wells, tonnes and francs per kilogram, and none of those numbers exist today.
Sources: Edith Cowan University, “Green hydrogen goldmine: ECU researchers discover hidden energy source”, 12 August 2026, via TechXplore; K. Moghanirahimi et al., “Geometry-driven controls on hydrothermal natural hydrogen generation from magnetite mineral”, International Journal of Hydrogen Energy, 2026.
🤖 AI transparency: This text and its visual were created using AI, reviewed and approved by a human.