Centralised vs Distributed Hydrogen Production Systems. Comparing the Strengths and Limitations

Key Takeaways of this article

• The ideal hydrogen production system depends on cost, infrastructure readiness, and regulatory alignment, not just plant capex. 
   
• In the short term, distributed hydrogen production often best fits early industrial volumes where infrastructure is incomplete. 
   
• Centralised hydrogen production gains strength in industrial clusters and ports with shared storage, pipelines, and logistics. 
   
• Renewable hydrogen production costs in Europe are reported at around €4.1/kg at the low end and around €6.6/kg on average, depending on assumptions. 
   
• Pipeline transport is often referenced at roughly €0.3/kg per 1,000 km as an indicative value, though actual costs depend on project design. 
   
• Alkaline electrolysis is still the more mature and cost-competitive option for many large-scale hydrogen production system configurations. 
   
• Over the long term, backbone infrastructure such as the proposed European Hydrogen Backbone could shift economics toward hub-based systems. 
   

The Real Question Behind Every Hydrogen Production System 

When evaluating a hydrogen production system in Europe, many discussions begin with electrolyser efficiency, capex per megawatt, or stack pricing. These metrics matter, but they rarely decide the final investment decision on their own. 

The more decisive factor is delivering hydrogen cost under real operating conditions. This includes infrastructure constraints, electricity pricing, utilisation rates, regulatory compliance, and long-term security for the offtaker. A technically sound hydrogen production system can still struggle economically if pipelines are delayed, grid tariffs are high, or demand materialises more slowly than expected. 

The choice between centralised hydrogen production and distributed hydrogen production is therefore strategic.

It shapes risk allocation, financing structures, and long-term competitiveness across refining, ammonia, methanol, steel, chemicals, power balancing, and export-oriented projects. 

Defining the Architecture: Types of Hydrogen Production Systems  

Clarity is essential before comparing models. A hydrogen production system is not just an electrolyser or a reformer. It encompasses production, compression, purification, storage, and interface with transport or end-use. 

Centralised Hydrogen Production: Pros & Cons

Centralised hydrogen production benefits from scale. Large plants can reduce unit capex and Opex by spreading fixed costs across a higher throughput. In industrial clusters, continuous demand improves utilisation. Higher utilisation directly reduces the €/kg cost because fixed costs are amortised over more operating hours. Where low-carbon hydrogen is considered, centralised hydrogen production also helps carbon capture at scale. CO₂ transport and storage infrastructure is rarely economical for isolated small facilities. 

However, centralised hydrogen production introduces dependencies. If pipelines or terminals are delayed, production may need to be curtailed. Transport energy penalties and logistics costs can increase delivered hydrogen costs beyond first expectations. There is also a concentration risk. An outage at a large hub can affect multiple industrial users simultaneously. 

A centralised hydrogen production system typically consists of a large-scale plant located in an industrial cluster or port area. Hydrogen is then transported to users via: 

• Dedicated hydrogen pipelines 
• Blended or repurposed gas networks when permitted 
• Liquefaction and trucking 
• Conversion to carriers such as ammonia 

In short, centralised hydrogen production systems allow shared infrastructure. Compression, storage, water treatment, grid connection, and in some cases CO₂ transport and storage can serve multiple offtakers. This pooling effect can lower unit costs and simplify permitting within designated industrial zones. 

In Europe, this model is linked to the concept of hydrogen hubs and backbone pipelines. 

Distributed Hydrogen Production: Pros & Cons 

Distributed hydrogen production reduces reliance on transport infrastructure. Producing hydrogen directly at the refinery, ammonia plant, or steel site avoids pipeline tariffs and compression losses. This model supports incremental growth. Capacity can be expanded in modular steps as demand increases. In early market conditions, this reduces exposure to uncertain offtake. Operational resilience is another advantage. A failure at one site does not affect the wider system. 

The trade-off lies in scale. Smaller units typically face higher capital costs. Grid connections, water treatment, and permitting must be replicated at each site. Electricity tariffs and congestion can materially affect cost. For many projects in the 2020 to 2030 period, distributed hydrogen production offers a practical bridge while broader infrastructure develops. 

A distributed hydrogen production system places generation close to the point of consumption. This may include: 

• On-site electrolysis at a refinery or ammonia plant 
• Hydrogen production is integrated directly into a steel facility 
• Smaller reforming units with carbon capture 
• Modular electrolysers added incrementally as demand grows 

Historically, most hydrogen has been produced in this manner, directly next to industrial use. For the clean hydrogen transition, distributed hydrogen production offers a pragmatic pathway where infrastructure is not yet in place. Rather than choosing between two extremes, many projects now assess hybrid hydrogen production system designs that combine local production with optional access to future hubs. 

European Constraints: The System Design 

The architecture of a hydrogen production system is deeply influenced by regulation and infrastructure development. 

Regulatory Definitions and Compliance Pathways 

The Renewable Fuels of Non-Biological Origin European framework (RFNBO), defines conditions under which hydrogen can qualify as renewable. A complementary delegated regulation. 

In 2024, the Hydrogen and Decarbonised Gas Market Package entered into force, providing rules for hydrogen networks and market operation.  

In July 2025, the European Commission adopted a delegated act defining a method for low-carbon fuels, including low-carbon hydrogen. 

These definitions influence hydrogen production system design in several ways. 

For renewable hydrogen projects: 

• Co-location with renewable power can simplify compliance 

• Temporal and geographic correlation requirements affect operating strategy 

• Grid-connected electrolysis must consider certification complexity 

For low-carbon hydrogen projects: 

• Access to CO₂ transport and storage infrastructure is decisive 

• Scale is often needed to justify carbon capture systems 

In both cases, regulatory clarity affects financing and long-term offtake agreements. 

Infrastructure Maturity

Infrastructure readiness varies widely across Europe. The European Hydrogen Backbone initiative outlines a vision of approximately 39,700 km of hydrogen pipelines by 2040, with a large share based on repurposed natural gas pipelines. This stands for a coordinated industry vision rather than a guaranteed buildout. 

In practice, infrastructure development can lag production capacity. A centralised hydrogen production system may be technically ready before pipelines, storage caverns, or terminals are operational. This creates underutilisation risk. Distributed hydrogen production reduces exposure to this timing mismatch by aligning production directly with consumption. In early market phases, this can lower project risk even if unit production costs are higher. 

Economics: Beyond Plant-Gate LCOH 

A rigorous comparison between centralised and distributed hydrogen production must separate the plant-gate levelised cost of hydrogen from the delivered hydrogen cost. 

Recent European industry reporting places renewable hydrogen production costs at around €4.1/kg at the low end and around €6.6/kg on average, depending on project assumptions. These values are extremely sensitive to electricity prices and full-load hours.  Pipeline transport is sometimes referenced at roughly €0.3/kg per 1,000 km as an indicative value. Actual project economics depends on throughput, financing structure, and asset utilisation. A hydrogen production system should therefore be assessed using transparent assumptions, ideally supported by recognised LCOH tools and sensitivity analysis. 
 
Source: Hydrogen Europe, Clean Hydrogen Monitor, November 2024 edition. 

Sector Applications: Refining, Ammonia, Methanol, Steel, and Chemicals 

Industrial hydrogen demand in Europe is already concentrated on refining and ammonia production. In these sectors, hydrogen is typically consumed continuously and on-site. A distributed hydrogen production system that replaces grey hydrogen with electrolysis can integrate into existing process layouts with minimal transport requirements. This approach can simplify transition planning. In contrast, centralised hydrogen production becomes attractive where multiple large users are found within a defined industrial zone. Shared pipelines and storage reduce duplication and enable coordinated investment. 

For ammonia in particular, the link between hydrogen and the end product is direct. Europe already runs in significant ammonia capacity. If hydrogen is imported as ammonia, there are even more costs. Ammonia needs to be converted back into hydrogen, H₂, and nitrogen, N₂. Essentially, the reverse of ammonia synthesis, that is called “Cracking”.  Cracking costs must be included in the delivered hydrogen cost analysis. For users requiring high-purity hydrogen, cracking can represent a substantial cost component. 

Where green steel plants are found near planned hydrogen hubs, centralised hydrogen production connected by pipeline may offer scale advantages. If infrastructure is not yet ready, distributed hydrogen production at the steel site can reduce exposure to transport delays. 

Export-Oriented: Hydrogen Production Systems Design 

Export projects are inherently centralised. Large volumes, port terminals, ammonia synthesis, and storage require hub-based development. 

A centralised hydrogen production system designed for export must integrate: 

• Large-scale electrolysis or reforming 
• Conversion to ammonia or other carriers 
• Certification systems aligned with EU regulation 
• Port logistics and shipping 

But Europe is expected to rely on imported hydrogen derivatives as part of its demand. Import terminals and cracking facilities will therefore influence the domestic hydrogen production system economics. 

Distributed hydrogen production plays a complementary role by serving domestic industrial demand, potentially freeing hub capacity for export commitments. 

The Outlook: Short-Term and Long-Term  

2020 to 2030 

In the near term, distributed hydrogen production is likely to expand where: 

• Industrial demand is immediate 
• Hydrogen can be consumed on-site 
• Infrastructure is still under development 

Centralised hydrogen production will advance in port regions and established clusters with strong anchor offtake and credible infrastructure planning. Public support mechanisms, such as hydrogen auctions, help close the cost gap for renewable hydrogen. 

2030 to 2040 and Beyond 

If backbone pipelines, storage, and terminals develop as envisioned, centralised hydrogen production linked to a hydrogen backbone could achieve stronger economics through higher utilisation and shared assets. Regional specialisation may appear between renewable-rich areas and industrial demand centers. Even in that scenario, distributed hydrogen production will continue to serve captive industrial sites where transport adds unnecessary cost. 

Conclusion 

Selecting the right hydrogen production system requires: 

• Transparent LCOH modelling with clear assumptions 
• Delivered a hydrogen cost comparison across scenarios 
• Infrastructure readiness assessment 
• Regulatory compliance evaluation 
• Sensitivity analysis on electricity price and utilisation 

In many cases, a phased approach may combine distributed hydrogen production initially with optional integration into a future centralised network. At Stargate Hydrogen, we support industrial partners and EPC leaders in designing hydrogen production systems based on alkaline electrolysis that meet performance, cost, and regulatory expectations.  If you are evaluating hydrogen production, distributed or centralised, our team can help you assess the technical and economic trade-offs and define a configuration aligned with your project goals. Contact Stargate Hydrogen to discuss how to structure a hydrogen production system tailored to your industrial requirements and long-term strategy.