A hydrogen fuel cell generator mounted on a floating barge has successfully charged a commercial electric vessel at the Port of Tilbury, marking the first time a UK port has demonstrated ship-to-shore power transfer using hydrogen-derived electricity without a grid connection. The 300 kW system, built around five Ballard fuel cells and operated by GeoPura, proves that hydrogen can serve as a mobile, zero-emission energy carrier for vessels that cannot wait for shore-side charging infrastructure to be built.
Why Tilbury and why now
The Port of Tilbury, located 25 miles east of London on the Thames, handles roughly 16 million tonnes of cargo annually and sits at the center of the UK’s Thames Freeport zone. Its operator, Forth Ports, has committed to net-zero operations by 2030 – a target that requires eliminating diesel generators currently used for ship assistance, quay cranes, and cold-ironing. Grid upgrades at the port are years away and constrained by London’s distribution network capacity. GeoPura’s hydrogen power unit (HPU) arrives as a containerized, transportable alternative: it can be craned onto a barge, towed to any berth, and operated without permitting a permanent hydrogen storage facility on land. The trial used green hydrogen supplied by BOC from its Avonmouth electrolyzer, trucked in tube trailers – a logistics chain that already exists for industrial gas customers across the southeast.
The vessel charged was a purpose-built electric workboat operated by the Port of London Authority (PLA), equipped with a 1.2 MWh battery pack and a 600 kW DC charging inlet. During the demonstration, the HPU delivered continuous 300 kW output for four hours, transferring 1.2 MWh – enough to replenish the workboat from 20% to 100% state of charge. Ballard’s FCmove-HD modules, each rated at 70 kW net, operated at 55% electrical efficiency (LHV) across the duty cycle, with waste heat rejected to the Thames via a keel-cooled heat exchanger. GeoPura reports the system achieved 98.5% availability over the test week, with zero unplanned shutdowns.
How this differs from shore-power and battery barge concepts
Shore-power (cold-ironing) installations at European ports typically cost €3-5 million per berth and require substation upgrades that take 18-36 months. Battery barges – such as the ZESpack system trialed in Rotterdam – store 2-4 MWh but must return to a grid charger, limiting range and creating scheduling conflicts. The hydrogen barge model inverts this: the energy carrier (hydrogen) is delivered by road to the waterside, converted to electricity on the water, and the only infrastructure needed is a mooring point and a DC charging cable. That points to a niche where hydrogen beats both grid-tied shore power and battery-only solutions: ports with constrained grid connections, seasonal or intermittent vessel traffic, and operations that cannot tolerate multi-hour charging windows. If this trend holds, we could see hydrogen barges deployed at UK ports like Immingham, Teesport, and Milford Haven – all of which have deep-water access, industrial hydrogen clusters nearby, and grid constraints that delay shore-power rollouts by years.
By comparison, a typical 2 MW shore-power installation at a UK container terminal costs roughly £4 million and draws 3.3 kV from the distribution network. The GeoPura HPU capital cost is approximately £1.2 million for the 300 kW unit (including fuel cells, balance of plant, and marine certification), plus hydrogen fuel at £8-12/kg delivered. At 55% efficiency, that translates to £0.45-0.65/kWh at the vessel inlet – higher than grid electricity at £0.12-0.18/kWh, but competitive with diesel generator rental at £0.50-0.70/kWh when carbon costs and emissions penalties are included. For a port operator facing £180/tonne CO2e UK ETS prices, the hydrogen barge avoids roughly 0.27 tonnes CO2e per MWh delivered versus marine gas oil.
Cross-sector implications: hydrogen logistics and maritime regulation
The trial also illuminates a regulatory gap. The UK Maritime and Coastguard Agency (MCA) currently has no specific code for hydrogen fuel cell systems on non-propulsion barges – the HPU was approved under a one-off “equivalent safety” assessment referencing the IGF Code (for gas-fueled ships) and ISO 22734 (hydrogen generators). That creates uncertainty for insurers and class societies. DNV and Lloyd’s Register are both developing class notations for “hydrogen power supply units” on floating platforms, but publication is not expected before late 2026. Until then, each deployment requires bespoke risk assessment, adding 3-6 months and £50-100k in engineering fees per project.
On the hydrogen supply side, the trial consumed roughly 540 kg of hydrogen over four hours – equivalent to three 180 kg tube trailers. BOC’s Avonmouth electrolyzer (10 MW PEM, commissioned 2024) produces ~4 tonnes/day, so this single charging event represented ~3.5 hours of plant output. Scaling to daily operations for a fleet of five electric workboats would require ~2.7 tonnes/day – 68% of Avonmouth’s capacity. That points to a near-term bottleneck: green hydrogen production in the Thames Estuary is limited to BOC’s 10 MW and ITM Power’s 5 MW at Rainham. The proposed 100 MW Thames Estuary Hydrogen Hub (BP/Ørsted, FID expected 2027) would alleviate this, but until then, hydrogen barge operations at Tilbury will compete with industrial offtakers for scarce molecules.
Who this affects
- Port infrastructure planners: Hydrogen barges offer a bridging solution for berths where grid upgrades are >3 years away; budget £1.5-2 million per deployment including marine certification and first-year hydrogen supply.
- Vessel operators (workboats, CTVs, pilot boats): Electric vessels with >1 MWh batteries can now operate zero-emission without waiting for shore chargers; factor £0.50-0.65/kWh delivered energy cost into TCO models versus £0.15/kWh grid shore-power.
- Hydrogen producers and logistics firms: Marine-adjacent demand creates a new offtake segment for electrolyzers within 50 km of ports; tube-trailer delivery economics work up to ~80 km radius before pipeline or liquid H2 becomes necessary.
- Regulators and class societies (MCA, DNV, LR): Urgent need for a harmonized UK code for floating hydrogen power units – without it, each project incurs bespoke approval costs that deter repeat deployment.
What to watch next
- MCA publication of MGN (Marine Guidance Note) for hydrogen fuel cell power supply units – expected Q4 2026; will determine whether 2027 deployments proceed under standard or bespoke approval.
- GeoPura’s planned 2026 deployment at the Port of Aberdeen – a 500 kW HPU on a catamaran barge for charging crew transfer vessels (CTVs) serving offshore wind farms; tests hydrogen logistics in a remote, high-wind environment.
- Thames Estuary Hydrogen Hub FID (BP/Ørsted) – if sanctioned in 2027, 100 MW electrolyzer could supply multiple port hydrogen barges and unlock economies of scale in delivered H2 cost.
- Ballard FCmove-HD marine certification timeline – type approval for 200 kW module (four 70 kW stacks) would halve balance-of-plant cost per kW for next-gen HPUs.
Bottom line
The Tilbury demonstration proves hydrogen barges can deliver grid-quality power to electric ships today – but only where hydrogen supply chains already exist and regulatory pathways are negotiated case-by-case. The economics work against diesel, not against grid electricity; the value is speed of deployment and geographical flexibility, not cost per kWh.
Read the full report at CleanTechnica
Note: facts and figures attributed above to reflect that outlet's original reporting. Broader context, cross-sector connections, and forward-looking scenarios reflect independent analysis by our editorial team.
About this article: Drafted by Energy Ai with AI-assisted research and writing based on public reporting, then reviewed under our editorial process before publication.
Leave a Reply