Germany’s growing renewable electricity surplus has created an increasingly expensive challenge for grid operators. As wind and solar generation outpaces transmission capacity in certain regions, particularly in northern Germany, renewable electricity is frequently curtailed to maintain grid stability.
While this process prevents network congestion, it also results in wasted clean energy and rising compensation costs for producers whose electricity is never delivered to consumers.
A new study suggests that redirecting this otherwise curtailed electricity toward hydrogen production could significantly improve both grid efficiency and hydrogen economics, although the benefits depend heavily on electricity pricing and market design.
Electricity systems require a constant balance between supply and demand. Excess generation can overload transmission infrastructure, while shortages threaten system reliability. Because renewable generation is inherently variable and geographically uneven, Germany increasingly relies on redispatch measures that reduce renewable output in oversupplied regions while increasing generation elsewhere to satisfy demand.
This balancing mechanism has become more important as renewable penetration has expanded. However, redispatch carries economic costs. Renewable generators are typically compensated even when their output is curtailed, while replacement electricity must often be sourced from more expensive generation assets located closer to demand centers.
To address this inefficiency, Germany introduced regional redispatch markets in 2024. Rather than curtailing renewable electricity entirely, the system allows excess electricity that cannot be transported through congested transmission lines to be sold locally. Flexible electricity consumers located within those constrained regions can purchase this otherwise unused renewable power, creating value from energy that would previously have been wasted.
Hydrogen production is particularly well suited to this model because electrolyzers do not necessarily require continuous operation. Unlike many industrial processes, hydrogen production can be scheduled to coincide with periods of abundant and inexpensive electricity. Electrolyzers can ramp production up or down depending on renewable availability, allowing operators to capitalize on temporary periods of extremely low electricity prices.
Researchers examined whether integrating redispatch electricity into electrolyzer operations could reduce the cost of green hydrogen production. Their analysis found that relying exclusively on redispatch electricity is not economically viable because electricity availability is too unpredictable to support efficient plant utilization. Electrolyzers represent capital intensive assets, and prolonged idle periods significantly increase hydrogen production costs.
The study instead found that hybrid operating strategies provide a more practical solution. Combining redispatch electricity with dedicated renewable generation allows electrolyzers to maintain higher utilization while still benefiting from periods of exceptionally low priced surplus electricity.
Under the most favorable conditions, where redispatch electricity is available at €0 per megawatt hour, hydrogen production costs could decline by €0.90 to €1.96 per kilogram, depending on hydrogen storage costs. Given that green hydrogen production commonly ranges between €6 and €8 per kilogram, the potential savings represent a meaningful reduction in operating costs.
The results also illustrate the sensitivity of hydrogen economics to electricity market design. As redispatch electricity prices increase, the financial advantage declines rapidly. Higher prices reduce the incentive for developers to locate electrolyzers in grid constrained regions where they could help absorb excess renewable generation and reduce curtailment.
This creates a policy challenge. Market based pricing encourages efficient allocation of electricity resources, but higher redispatch prices weaken one of the principal economic arguments for colocating hydrogen production with renewable energy surpluses. The researchers argue that maintaining relatively low redispatch prices, potentially through price caps or other market mechanisms, could simultaneously improve hydrogen competitiveness and reduce renewable energy waste.
The findings also highlight that transmission constraints are becoming an increasingly important factor in hydrogen deployment. Much of Europe’s renewable energy expansion is occurring faster than transmission infrastructure can be reinforced. As a result, grid congestion has emerged as both a technical limitation and a potential commercial opportunity for flexible electricity consumers.
For hydrogen developers, project location may increasingly be determined not only by renewable resource quality but also by proximity to transmission bottlenecks and regional electricity market dynamics. Electrolyzers capable of operating flexibly could evolve from purely industrial production assets into grid balancing resources that provide additional value by consuming electricity that would otherwise be curtailed.
