Context and Chronology

H2 Mobility’s public chart shows steadily rising network tonnage, but decomposing the totals reveals a different story: aggregate volume growth has been driven in part by pruning underperforming sites rather than a step‑change in retail demand. The company’s monthly dispensing figure of roughly 59 tonnes translates to about 30 kg per station per day when spread across ~72 stations — roughly 7–10 passenger refuels daily per site and well below passenger‑station design targets.

H2 Mobility’s 2023 accounts make the arithmetic explicit: about €7.6M in revenue against roughly €34.5M of operating costs produced an approximate €26M loss. On a network basis this equates to near €72,000 revenue and roughly €330,000 cost per station per year — an average site shortfall around €250,000.

Network optimisation has improved average throughput primarily by shrinking the denominator: station closures reduced the count from about 105 to 72, concentrating limited demand into fewer sites. That statistical lift in kg/station disguises persistent fixed‑cost drivers — capital intensity, compression and chilling energy, and specialist maintenance — that keep unit economics far from break‑even.

The H2 Mobility situation sits within a wider pattern identified across Europe: physically complete hydrogen pipelines in Germany and elsewhere currently lack suppliers or credible customers, meaning technical assets exist without matching commercial flows. This creates a fiscal and regulatory dilemma because regulated‑return assets can earn money despite moving few or no molecules — a dynamic that risks socialising stranded capital unless growth is strictly contract‑backed.

A closely related contradiction emerges between production‑side cost appraisals and observed delivered prices. Some studies put delivered green hydrogen production near $4/kg in favourable scenarios, yet small‑scale retailing and low utilization push dispenser or trucked prices substantially higher. Local cases — for example municipal hydrogen bus depots in the UK which ran at ~30% of design duty and reported delivered prices near £20–25/kg — show how low throughput multiplies unit costs.

Policy and regulatory choices further change the demand outlook. RFNBO and fuel‑obligation frameworks that reward energy shares, substitution credits and refinery procurement can direct capital toward crediting routes rather than physical retail hydrogen, meaning headline on‑road delivery metrics are an unreliable proxy for durable, contract‑backed offtake.

Taken together, the evidence suggests the near‑term evolution will be consolidation of retail sites, selective reinforcement of heavy‑duty corridors where throughput can approach station design thresholds, and concentration of hydrogen deployment around industrial clusters and contract‑backed uses. Large, diversified energy incumbents and refiners are best placed to underwrite the optionality value of networks; independent retail operators face acute balance‑sheet pressure.

Implications for policy are immediate: avoid creating forced‑demand subsidies that would implicitly socialise underused network costs via tariffs; instead prioritise contract‑led growth, clear decision gates for speculative assets, and reallocation of public support toward grid reinforcement, multi‑hour storage and electrification where those options are demonstrably cheaper. Without a disciplined pivot, the system risks continued headline growth masked by deteriorating unit economics and mounting fiscal exposure.