Green Hydrogen Trading: Switzerland's Commodity Houses Enter the Future Energy Market

Every major energy transition creates an opportunity for commodity traders before it creates a commodity. The traders who built infrastructure for LNG in the 1990s dominated LNG trading in the 2020s. The traders who built biofuel supply chains in the 2000s dominated biofuel compliance markets when mandates arrived. Green hydrogen — the energy carrier produced by electrolysing water using renewable electricity — is the current version of this infrastructure-ahead-of-market investment thesis. And Switzerland’s commodity houses are making the bet.

The timing requires patience. Green hydrogen is not yet an economically competitive commodity. Production costs remain substantially above those of natural gas — the energy source it is most directly intended to replace — in most global markets. Transport infrastructure for hydrogen is nascent. Demand commitments from industrial buyers, while growing, remain primarily at the pilot scale rather than commercial scale. Yet every major Geneva trading house with serious energy transition ambitions has hired hydrogen specialists, developed conceptual trading frameworks, and invested in relationships along the emerging hydrogen supply chain.

Understanding why requires understanding both the physics and economics of hydrogen, and the institutional logic of early-mover positioning in energy commodity markets.

The Hydrogen Spectrum: Green, Blue, and Grey

Not all hydrogen is created equal from a climate perspective, and the distinctions matter enormously for trading economics and policy support.

Grey hydrogen — the dominant form of hydrogen production today — is produced from natural gas through a process called steam methane reforming (SMR). Grey hydrogen production emits CO2 as a byproduct without capture. Approximately 95% of global hydrogen production is currently grey. Grey hydrogen costs approximately $1-3 per kilogram depending on local natural gas prices, making it cheap but climate-incompatible in a net-zero scenario.

Blue hydrogen is produced from natural gas via SMR but with carbon capture and storage (CCS) applied to capture the CO2 byproduct. Blue hydrogen can achieve emissions reductions of approximately 85-95% compared to grey hydrogen if the CCS system operates as designed. Production costs are higher than grey — approximately $2-4 per kilogram depending on gas prices and CCS costs — but substantially lower than green. Blue hydrogen is controversial in some environmental circles because of residual methane leakage and questions about long-term CO2 storage integrity, but is supported by some governments as a transition technology.

Green hydrogen is produced by electrolysis — using electrical current to split water into hydrogen and oxygen — powered by renewable electricity. Electrolysis produces no direct CO2 emissions; the climate performance depends entirely on the carbon intensity of the electricity used. Green hydrogen produced from solar or wind electricity in a renewable-rich location can achieve close to zero lifecycle emissions. Production costs are currently approximately $4-8 per kilogram in most locations, declining as electrolyser costs fall and renewable electricity costs continue their long-run downward trajectory.

The cost trajectory for green hydrogen is the central question for the trading thesis. Multiple independent analyses project green hydrogen costs falling to $2-4 per kilogram by 2030 and approaching parity with grey hydrogen (on a low-carbon-adjusted basis, accounting for carbon price) by the early 2030s in locations with excellent renewable resources — Chile’s Atacama Desert, Australian solar zones, Middle Eastern sun belts. This cost convergence, if it materialises, creates the commercial foundation for a global green hydrogen trade.

Why Commodity Traders Are Entering Hydrogen

The Geneva trading houses are not entering hydrogen because they expect to generate trading profits in 2025. They are entering because they expect hydrogen to be a large, globally traded commodity by 2035, and they understand that the institutional infrastructure — relationships, logistics knowledge, price risk management frameworks — that will define who dominates hydrogen trading needs to start being built years before the market reaches commercial scale.

Vitol announced the establishment of a hydrogen and ammonia trading desk in 2022, staffing it with specialists from both the energy and chemical industries. Trafigura has similarly established hydrogen trading and origination capabilities, leveraging its existing LNG logistics knowledge and its Impala Terminals port infrastructure as potential foundation assets for hydrogen supply chains. Mercuria has built hydrogen activities within its broader energy transition portfolio, connecting its carbon market capabilities with hydrogen’s role as a carbon-reducing fuel.

The institutional logic is compelling. Physical commodity trading is fundamentally a logistics, relationship, and risk management business — and all three of those competencies transfer directly from existing commodities to hydrogen. A trading house that knows how to charter vessels, negotiate long-term supply agreements with producers, manage price risk through derivatives, and intermediate between producers and consumers in a global market has precisely the capabilities that hydrogen trading will require.

The additional factor is shipping infrastructure. LNG tankers are purpose-built cryogenic vessels — and the technology for liquid hydrogen shipping (at -253°C, even colder than LNG’s -162°C) shares fundamental engineering principles with LNG. Trading houses with LNG shipping expertise and relationships are better positioned to adapt to hydrogen logistics than industrial companies or utilities without commodity shipping experience.

The Ammonia Problem: Hydrogen’s Transport Carrier

Green hydrogen in its pure molecular form (H2) presents severe transport challenges. Hydrogen has an extremely low energy density by volume — a characteristic that makes long-distance maritime transport in liquid form very expensive. Liquefying hydrogen requires cooling to -253°C (very close to absolute zero), which is technically demanding and energy-intensive. Compressed gas hydrogen transport is efficient only for short distances.

The solution that has emerged as the most commercially viable pathway for long-distance hydrogen trade is not shipping hydrogen itself, but converting it to ammonia (NH3). Ammonia — a molecule comprising one nitrogen atom and three hydrogen atoms — can be produced from green hydrogen by combining it with nitrogen from air in the Haber-Bosch process. Ammonia can be liquefied at -33°C (compared to hydrogen’s -253°C), making it far easier and cheaper to ship using modified versions of existing chemical tankers. Crucially, the ammonia shipping infrastructure already exists — global ammonia trade routes carry approximately 20 million tonnes per year for agricultural fertiliser markets.

At the destination, green ammonia can either be used directly (as a fuel for shipping engines, as a source of nitrogen for agriculture, or as a chemical feedstock) or converted back to hydrogen through ammonia cracking. The economics of the ammonia pathway — including the energy losses in the ammonia conversion and cracking steps — currently make it more expensive than simply using electricity directly for most end-use applications, but for long-distance maritime trade routes, ammonia is the dominant carrier technology under active commercial development.

For commodity traders, the ammonia pathway is attractive precisely because it connects green hydrogen to existing commodity trade infrastructure. Ammonia tankers, existing port handling facilities, and established trade routes between chemical-producing and chemical-importing regions provide a starting point for hydrogen trade logistics that pure hydrogen shipping cannot yet match.

Geneva trading houses with existing exposure to agricultural commodities — including nitrogen fertilisers — have an informational advantage: they already understand ammonia markets, trade routes, and pricing dynamics. The transition from grey ammonia (produced from fossil gas via SMR) to green ammonia (produced from green hydrogen via electrolysis) does not fundamentally change the logistics of ammonia trading — it changes the production economics and the carbon intensity.

Switzerland’s Hydrogen Strategy

The Federal Council adopted Switzerland’s hydrogen strategy in January 2023, establishing a framework for Switzerland’s role in the emerging hydrogen economy. The strategy identifies hydrogen as a significant component of Switzerland’s long-term energy system, particularly for applications where direct electrification is technically challenging: heavy industry, long-distance transport, seasonal energy storage.

Switzerland’s hydrogen strategy is notable for its focus on imported hydrogen rather than domestic production. Switzerland has excellent hydropower resources but limited solar and wind capacity relative to its industrial energy needs, and land constraints limit large-scale renewable expansion. The strategy therefore emphasises Switzerland’s role as a transit and consumption hub for green hydrogen imported from regions with superior renewable resources — North Africa, the Middle East, or potentially the North Sea via pipeline.

This import-focused orientation plays directly to the strengths of Geneva’s trading houses. If Switzerland’s hydrogen supply will come primarily from imports, then the companies best positioned to originate, transport, and distribute that hydrogen are those with existing global commodity trading infrastructure — which is precisely what the Geneva houses possess.

German Demand: The H2Global Mechanism

Germany is the most important demand anchor for European green hydrogen markets. As Europe’s largest industrial economy and the country most dependent on phasing out natural gas for industrial heat, Germany has committed to substantial hydrogen imports as a core element of its energy transition strategy.

The H2Global mechanism — an innovative auction-based procurement instrument designed by the German government and operated by the HINT.CO (Hydrogen Import) private limited company — creates a double auction: H2Global purchases hydrogen and hydrogen derivatives (primarily green ammonia) internationally through long-term contracts, then resells them into the German market at shorter-term contracts, with the government subsidising the price gap. The mechanism is designed to stimulate supply development in exporting countries while managing the price risk of nascent market development.

H2Global auctions have attracted supply bids from projects in Chile, Namibia, Egypt, and several other countries with strong renewable resources. The mechanism has already awarded several contracts, creating real commercial transactions in green ammonia trade — a significant step beyond purely conceptual market development.

For Geneva trading houses, H2Global creates both a direct commercial opportunity (participating in auctions either as direct bidders or as intermediaries) and a market signal — demonstrating that there is bankable demand for green ammonia at commercial volumes. The H2Global model has also inspired similar demand-pull mechanisms in other European countries, gradually expanding the pool of contracted hydrogen demand that can support supply investment.

Swiss Industrial Infrastructure: Electrolyser Manufacturers

Switzerland is home to several companies that are significant participants in the electrolyser manufacturing industry — the technology that produces green hydrogen from water and electricity.

ABB, the Zurich-headquartered industrial technology company (now listing on the Swiss Exchange), has significant capabilities in power conversion and electrical infrastructure that underpin electrolyser systems. While ABB itself does not manufacture electrolysers, its power electronics technology is embedded in multiple electrolyser supply chains.

Hitachi Energy, established through the combination of ABB’s power grids division with Hitachi’s energy business and headquartered in Zurich, is a major supplier of high-voltage power infrastructure — including the large-scale power conversion systems required for industrial-scale electrolysers. As electrolyser plants scale to gigawatt capacity, the power infrastructure requirements become increasingly sophisticated, creating demand for exactly the industrial electrical technology that Hitachi Energy specialises in.

Switzerland’s broader industrial technology sector — precision engineering, process technology, heat exchangers — provides additional supply chain links to the hydrogen economy. The Sulzer Chemtech and Burckhardt Compression businesses, both Swiss, have products relevant to hydrogen compression and handling.

These industrial connections give Switzerland a participation in the hydrogen supply chain that extends beyond pure trading — a potential anchor for Geneva’s aspiration to be a hydrogen trading hub, not merely a location from which trades in hydrogen produced elsewhere are intermediated.

Cost Parity Trajectory: Green vs. Grey Hydrogen

The commercial viability of large-scale green hydrogen trade depends critically on the cost trajectory for green hydrogen production. In 2025, green hydrogen production costs range from approximately $3.50-8.00 per kilogram depending on location (solar radiation and wind resources), electricity costs, electrolyser capital costs, and operating parameters. Grey hydrogen at current European gas prices (post-2022 normalisation) costs approximately $1.50-2.50 per kilogram.

The gap is substantial but narrowing. Electrolyser capital costs have been falling rapidly as the technology scales — from approximately $1,500-2,000 per kilowatt of capacity in 2020 to below $600/kW in 2024 for leading manufacturers, with further reductions expected as gigawatt-scale manufacturing facilities are established. Renewable electricity costs continue their long-run decline.

Incorporating a carbon price — either through EU ETS exposure for grey hydrogen production, or through a hydrogen production tax credit (as in the US Inflation Reduction Act) for green hydrogen — significantly alters the cost comparison. At a €100/tonne carbon price applied to unabated SMR, the economics of green versus grey hydrogen shift considerably. The IRA’s Production Tax Credit for clean hydrogen has created particularly compelling economics for US-based green hydrogen production, potentially making US-origin green hydrogen economically competitive by 2028-2030 for export markets.

The consensus among energy sector analysts is that green hydrogen will reach cost competitiveness with grey hydrogen (including carbon pricing) in the best renewable-resource locations by approximately 2028-2032. Swiss traders positioning now are betting that this cost parity will materialise on this timeline, and that the infrastructure and relationships built in advance will define the commercial landscape when it does.

The Geneva Trading Advantage in Hydrogen

The Geneva commodity houses bring specific advantages to hydrogen trading that industrial companies and utilities cannot easily replicate:

LNG infrastructure knowledge: the engineering challenges of cryogenic storage and shipping are analogous across LNG and liquid hydrogen. Trading houses with LNG expertise understand the operational and commercial framework for cryogenic commodity logistics.

Existing chemical commodity experience: ammonia as a hydrogen carrier is a chemical commodity with established trade routes. Geneva houses with agricultural commodities exposure have relevant market knowledge.

Financial risk management: long-term hydrogen supply contracts, electrolyser project finance, and hydrogen derivative instruments require sophisticated financial structuring capabilities. The Goldman-Sachs and investment-bank alumni that populate Geneva trading house management have exactly these skills.

Counterparty relationships: the industrial companies that will be the largest hydrogen buyers — steelmakers, cement producers, ammonia manufacturers, shipping lines — are already counterparties of the Geneva trading houses in existing commodity markets.

The risk, equally, is clear: green hydrogen’s commercial timeline has repeatedly been pushed back. Trading houses are investing in institutional capability for a market whose arrival remains uncertain in timing. The companies that build hydrogen desks in 2024 may find themselves waiting longer than expected for commercial-scale markets to develop — and sustaining that investment during the waiting period requires conviction and financial depth.

For Vitol, Trafigura, and Mercuria, the financial depth is not in question. The conviction is growing. And the conviction is backed by something more persuasive than optimism: the knowledge that in every previous energy transition, the traders who built infrastructure early defined who won the market.

Related Coverage

• Energy Transition Trading: How Swiss Trading Houses Are Pivoting from Oil to Green Energy
• Carbon Markets and Switzerland: How Swiss Traders Are Positioning in the Compliance and Voluntary Carbon Economy
• LNG Markets: How Geneva’s Traders Are Reshaping Global Gas Trade
• Mercuria Energy Group: Geneva’s Commodity Trader and Energy Transition Pioneer
• Trafigura’s Energy Trading Operations: Oil, LNG, and the Geneva-Singapore Axis

Frequently Asked Questions

What is green hydrogen and how is it produced?

Green hydrogen is hydrogen produced by electrolysis, using electrical current to split water molecules into hydrogen and oxygen. When the electricity used comes from renewable sources such as solar, wind, or hydro, the process produces no direct CO2 emissions. This distinguishes green hydrogen from grey hydrogen (produced from natural gas via steam methane reforming, with CO2 emissions) and blue hydrogen (also from natural gas, but with carbon capture applied). Green hydrogen is the only form fully compatible with net-zero targets.

Why is ammonia important for hydrogen trading?

Ammonia (NH3) is the primary transport carrier for green hydrogen in long-distance maritime trade routes. Pure hydrogen requires cooling to -253 degrees Celsius for liquid transport, making it very expensive to ship. Ammonia can be liquefied at -33 degrees Celsius and uses existing chemical tanker infrastructure, making it far more economically viable for international trade. At the destination, ammonia can be used directly as a fuel or feedstock, or converted back to hydrogen through ammonia cracking.

What is Switzerland’s role in the emerging hydrogen economy?

Switzerland’s Federal Council hydrogen strategy, adopted in 2023, positions Switzerland primarily as a hydrogen import and consumption hub rather than a production centre. Switzerland lacks the large solar and wind resources for cost-competitive domestic production at scale. The strategy emphasises hydrogen imports for industrial decarbonisation and seasonal energy storage, with contributions through Swiss industrial technology companies in the electrolyser supply chain and through Geneva-based commodity trading houses as potential hydrogen trading intermediaries.

When will green hydrogen reach cost parity with fossil-based hydrogen?

Most energy sector analyses project green hydrogen reaching cost parity with grey hydrogen, adjusted for carbon pricing, in the best renewable-resource locations by approximately 2028 to 2032. US IRA production tax credits have accelerated this timeline for US-origin green hydrogen. At European natural gas prices post-2022, green hydrogen parity may be achievable in some scenarios before 2030, though in renewable-poor locations parity will take longer.

Which Geneva trading houses have the most developed hydrogen capabilities?

Vitol established a dedicated hydrogen and ammonia trading desk in 2022, with staff drawn from both energy and chemical commodity sectors. Trafigura has built hydrogen origination capabilities leveraging its LNG logistics infrastructure and Impala Terminals port network. Mercuria has developed hydrogen activities within its energy transition portfolio, connecting carbon market and renewable energy trading capabilities. All three houses are in early commercial development rather than large-scale trading.

Donovan Vanderbilt is the founding editor of ZUG OIL. The Vanderbilt Portfolio AG, Zurich.