This study investigates the methanation of green electricity from a combined wind and PV power plant with a peak capacity of 250 MW in three different countries (Chile, UAE, Tunisia) and the transport of the produced methane to Austria. The production costs were calculated through a simulation on an hourly basis over a span of 20 years. The economically ideal size of the conversion components were determined in a parameter study. The specific transport costs were calculated on an annual basis. An optimistic and a pessimistic scenario were defined to represent the uncertainty of costs and technical parameters as well as two years of initial investment (2030, 2040) to reflect the possible technical and economical improvement of elements along the chain. Transport from Chile and the UAE was assumed by ship in a liquefied state and from Tunisia by pipeline in a gaseous state. The resulting import costs from Tunisia were 140 - 271 €/MWh, from Chile 150 - 356 €/MWh and from the UAE 183 - 420 €/MWh.

Background: Strong expansion of intermittent renewable generation puts increasing pressure on distribution grids and requires significant grid enforcement measures. Electrolysis may act as an alternative to conventional grid enforcement to overcome grid constraints in a timely and effective manner as it creates additional flexible load and thus enables renewable production peaks to be absorbed. In doing this, conventional grid enforcement measures are avoided and additional value is created through the production of hydrogen.The focus of this work is on two aspects: First, a regulatory analysis is undertaken to develop feasible organisational models since DSOs are typically not allowed to engage in generation activities. Second, a techno-economic analysis is done for four case studies in the network area of 'Energienetze Steiermark' in Austria. Thereby, grid simulation determines the minimum grid-supportive operation and is combined afterwords with profit-maximising dispatch of the electrolysis against market prices. A technical simulation assures that non-linearities and minimum stable generation of the electrolysis are respected. In a cost-benefit analysis, the net benefit was compared against the costs of conventional grid enforcement measures. Results: The regulatory analysis reveals that ownership of electrolysis by DSOs is almost ruled out by European and Austrian legislation. Only after an exceptional permission from the regulatory authority following a negative tender, the DSO is allowed to operate the facility in a grid-supportive way only. The results of the techno-economic analysis show that the capacity factor for the electrolysis is below 5 % when operated in grid-supportive mode only but a hydrogen price above 6 EUR/kg incentivizes market based operation and contributes to resolving the grid congestion. Conclusions: Ownership of the electrolysis can be awarded to a market player and the flexibility service can be procured by the DSO. It is not economically viable to operate electrolysis for grid-supportive purposes only. In general, if the price of hydrogen is high enough, profit maximising behavior of the electrolysis partly resolves the grid congestion and the overall benefits outweigh the costs. This conclusion also holds when comparing the economic results of the electrolyzer against conventional grid enforcement measures.

In light of the strong expansion of renewables, electrolysis may act as an alternative to conventional grid enforcement to overcome grid constraints in a timely and effective manner, as it creates additional flexible load and thus enables renewable production peaks to be absorbed. This paper examines whether hydrogen electrolysis can serve as a cost-effective alternative to conventional grid reinforcement in Austrian electricity distribution networks. It goes beyond the current state of the art by using three real-world case studies in Styria, using an integrated techno-economic framework combining distribution-grid simulations, market optimisation, PEM electrolysis modelling and cost–benefit analysis to compare the grid-supportive electrolysis against conventional grid enforcement. The results demonstrate that grid-supportive electrolysis can become competitive under suitable hydrogen market conditions. When operated in grid-supportive mode only, the capacity factor for the electrolysis lies below 5%. Economic viability emerges only when electrolysers are allowed to combine grid-supportive operation with market-driven hydrogen production. Thereby, the hydrogen price proves to be the key determinant: a hydrogen price above approximately 6 EUR/kg incentivises market-based operation and naturally resolves grid congestion without further intervention by the DSO. In some locations, smaller electrolysers (around 20–60% of the theoretically required size) deliver the best economic performance, recovering most curtailed renewable energy while limiting investment costs compared to conventional grid extension.

The decarbonization of district heating systems requires flexible and dispatchable generation technologies capable of integrating high shares of renewable energy. This study investigates the techno-economic competitiveness of hydrogen-fuelled combined heat and power (CHP) plants embedded in a district heating network, using the Coastal Power Plant Kiel as a reference case. The existing natural gas-fired CHP units are assumed to be retrofitted for hydrogen operation, complemented by power-toheat, seawater heat pumps, a proton exchange membrane electrolyser, thermal storage, and hydrogen cavern storage.A two-stage modelling approach is applied, combining a detailed non-linear simulation model with a linear optimization framework using a rolling-horizon dispatch strategy. Historical electricity prices (2024) and a generic district heating demand profile serve as boundary conditions. A parameter study evaluates system operation under varying hydrogen prices (1–5 €/kg) and competing heat source (CHS) costs (20-80 €/MWh).Results show strong competition between hydrogen-fired CHP and seawater heat pumps. CHPs become increasingly competitive at hydrogen prices below 3 €/kg, while higher hydrogen prices shift dispatch toward heat pumps. With CHS costs of below 40 €/MWh the plant is increasingly outcompeted by the CHS. The findings indicate that future reductions in green hydrogen production costs could enable hydrogen-based CHP dispatch in district heating systems, particularly when combined with flexible heat pump integration to exploit electricity market volatility.

In light of strong expansion of renewables, electrolysis may act as an alternative to conventional grid enforcement to overcome grid constraints in a timely and effective manner as it creates additional flexible load and thus enables renewable production peaks to be absorbed. This paper examines whether hydrogen electrolysis can serve as a cost-effective alternative to conventional grid reinforcement in Austrian electricity distribution networks. It goes beyond the current state of art by using three real-world case studies in Styria, using an integrated techno-economic framework combining distribution-grid simulations, market optimization, PEM electrolysis modelling and cost-benefit analysis to compare the grid-supportive electrolysis against conventional grid enforcement. The results demonstrate that grid-supportive electrolysis can become competitive under suitable hydrogen market conditions. When operated in grid-supportive mode only, the capacity factor for the electrolysis lies below 5%. Economic viability emerges only when electrolysers are allowed to combine grid-supportive operation with market-driven hydrogen production. Thereby, the hydrogen price proves to be the key determinant: a hydrogen price above approximately 6 EUR/kg incentivizes market based operation and naturally resolves grid congestion without further intervention by the DSO. In some locations, smaller electrolysers (around 20–60% of the theoretically required size) deliver the best economic performance, recovering most curtailed renewable energy while limiting investment costs compared to conventional grid extension.