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Increasing installable photovoltaic power by implementing power-to-gas as electricity grid relief – A techno-economic assessment

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  • Greiml, Matthias
  • Fritz, Florian
  • Kienberger, Thomas

Abstract

The integration of renewable electricity generation poses challenges for today's energy system. Since renewable potentials are geographically unevenly distributed, solutions to overcome bottlenecks such as grid congestion are necessary to raise as much renewable potentials as possible. In specific, a part of Austria is characterised with high photovoltaic installation inquiries and low electricity demand. Electricity grids are designed to cope with today's loads, therefore the integration of inquired photovoltaic would overstrain the built infrastructure. In this paper we investigate how power-to-gas can ease this photovoltaic related grid strain. The feed-in of hydrogen into natural gas transmission pipelines and the usage of hydrogen and biogas from local fermentation plants for methanation feeding synthetic natural gas (SNG) into local distribution grid is assessed in various scenarios. Based on the technical assessment results, an economic evaluation of each scenario is performed to determine generation costs of hydrogen or SNG. Depending on the electrolysers location in the electricity grid, the installable photovoltaic power can be increased significantly without causing electricity grid congestion. Costs for hydrogen and SNG vary across each scenario, mainly influenced by CapEx for electrolyser and methanation as well as electricity purchasing costs.

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  • Greiml, Matthias & Fritz, Florian & Kienberger, Thomas, 2021. "Increasing installable photovoltaic power by implementing power-to-gas as electricity grid relief – A techno-economic assessment," Energy, Elsevier, vol. 235(C).
    • Handle: RePEc:eee:energy:v:235:y:2021:i:c:s0360544221015553
    DOI: 10.1016/j.energy.2021.121307
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    References listed on IDEAS

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    2. Matthias Greiml & Florian Fritz & Josef Steinegger & Theresa Schlömicher & Nicholas Wolf Williams & Negar Zaghi & Thomas Kienberger, 2022. "Modelling and Simulation/Optimization of Austria’s National Multi-Energy System with a High Degree of Spatial and Temporal Resolution," Energies, MDPI, vol. 15(10), pages 1-33, May.
    3. Yang, Shuxia & Wang, Xiongfei & Xu, Jiayu & Tang, Mingrun & Chen, Guang, 2023. "Distribution network adaptability assessment considering distributed PV “reverse power flow” behavior - a case study in Beijing," Energy, Elsevier, vol. 275(C).
    4. Calise, Francesco & Cappiello, Francesco Liberato & Cimmino, Luca & Dentice d’Accadia, Massimo & Vicidomini, Maria, 2023. "Dynamic simulation and thermoeconomic analysis of a power to gas system," Renewable and Sustainable Energy Reviews, Elsevier, vol. 187(C).
    5. Son, Yeong Geon & Choi, Sungyun & Aquah, Moses Amoasi & Kim, Sung Yul, 2023. "Systematic planning of power-to-gas for improving photovoltaic acceptance rate: Application of the potential RES penetration index," Applied Energy, Elsevier, vol. 349(C).
    6. Francesco Calise & Francesco Liberato Cappiello & Luca Cimmino & Massimo Dentice d’Accadia & Maria Vicidomini, 2021. "Dynamic Simulation and Thermoeconomic Analysis of a Hybrid Renewable System Based on PV and Fuel Cell Coupled with Hydrogen Storage," Energies, MDPI, vol. 14(22), pages 1-20, November.
    7. Johannes Dock & Stefan Wallner & Anna Traupmann & Thomas Kienberger, 2022. "Provision of Demand-Side Flexibility through the Integration of Power-to-Gas Technologies in an Electric Steel Mill," Energies, MDPI, vol. 15(16), pages 1-22, August.

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