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Electrochemical Hydrogen Production Powered by PV/CSP Hybrid Power Plants: A Modelling Approach for Cost Optimal System Design

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  • Andreas Rosenstiel

    (Deutsches Zentrum für Luft- und Raumfahrt, Institute of Future Fuels, Linder Höhe, 51147 Köln, Germany
    Institute of Power Engineering, Faculty of Mechanical Science and Engineering, TU Dresden, 01062 Dresden, Germany)

  • Nathalie Monnerie

    (Deutsches Zentrum für Luft- und Raumfahrt, Institute of Future Fuels, Linder Höhe, 51147 Köln, Germany)

  • Jürgen Dersch

    (Deutsches Zentrum für Luft- und Raumfahrt, Institute of Solar Research, Linder Höhe, 51147 Köln, Germany)

  • Martin Roeb

    (Deutsches Zentrum für Luft- und Raumfahrt, Institute of Future Fuels, Linder Höhe, 51147 Köln, Germany)

  • Robert Pitz-Paal

    (Deutsches Zentrum für Luft- und Raumfahrt, Institute of Solar Research, Linder Höhe, 51147 Köln, Germany)

  • Christian Sattler

    (Deutsches Zentrum für Luft- und Raumfahrt, Institute of Future Fuels, Linder Höhe, 51147 Köln, Germany
    Institute of Power Engineering, Faculty of Mechanical Science and Engineering, TU Dresden, 01062 Dresden, Germany)

Abstract

Global trade of green hydrogen will probably become a vital factor in reaching climate neutrality. The sunbelt of the Earth has a great potential for large-scale hydrogen production. One promising pathway to solar hydrogen is to use economically priced electricity from photovoltaics (PV) for electrochemical water splitting. However, storing electricity with batteries is still expensive and without storage only a small operating capacity of electrolyser systems can be reached. Combining PV with concentrated solar power (CSP) and thermal energy storage (TES) seems a good pathway to reach more electrolyser full load hours and thereby lower levelized costs of hydrogen (LCOH). This work introduces an energy system model for finding cost-optimal designs of such PV/CSP hybrid hydrogen production plants based on a global optimization algorithm. The model includes an operational strategy which improves the interplay between PV and CSP part, allowing also to store PV surplus electricity as heat. An exemplary study for stand-alone hydrogen production with an alkaline electrolyser (AEL) system is carried out. Three different locations with different solar resources are considered, regarding the total installed costs (TIC) to obtain realistic LCOH values. The study shows that a combination of PV and CSP is an auspicious concept for large-scale solar hydrogen production, leading to lower costs than using one of the technologies on its own. For today’s PV and CSP costs, minimum levelized costs of hydrogen of 4.04 USD/kg were determined for a plant located in Ouarzazate (Morocco). Considering the foreseen decrease in PV and CSP costs until 2030, cuts the LCOH to 3.09 USD/kg while still a combination of PV and CSP is the most economic system.

Suggested Citation

  • Andreas Rosenstiel & Nathalie Monnerie & Jürgen Dersch & Martin Roeb & Robert Pitz-Paal & Christian Sattler, 2021. "Electrochemical Hydrogen Production Powered by PV/CSP Hybrid Power Plants: A Modelling Approach for Cost Optimal System Design," Energies, MDPI, vol. 14(12), pages 1-22, June.
    • Handle: RePEc:gam:jeners:v:14:y:2021:i:12:p:3437-:d:572660
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    References listed on IDEAS

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    1. Buttler, Alexander & Spliethoff, Hartmut, 2018. "Current status of water electrolysis for energy storage, grid balancing and sector coupling via power-to-gas and power-to-liquids: A review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 82(P3), pages 2440-2454.
    2. Catalina Hernández Moris & Maria Teresa Cerda Guevara & Alois Salmon & Alvaro Lorca, 2021. "Comparison between Concentrated Solar Power and Gas-Based Generation in Terms of Economic and Flexibility-Related Aspects in Chile," Energies, MDPI, vol. 14(4), pages 1-20, February.
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    Cited by:

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    2. Laetitia Uwineza & Hyun-Goo Kim & Jan Kleissl & Chang Ki Kim, 2022. "Technical Control and Optimal Dispatch Strategy for a Hybrid Energy System," Energies, MDPI, vol. 15(8), pages 1-19, April.
    3. Mohideen, Mohamedazeem M. & Subramanian, Balachandran & Sun, Jingyi & Ge, Jing & Guo, Han & Radhamani, Adiyodi Veettil & Ramakrishna, Seeram & Liu, Yong, 2023. "Techno-economic analysis of different shades of renewable and non-renewable energy-based hydrogen for fuel cell electric vehicles," Renewable and Sustainable Energy Reviews, Elsevier, vol. 174(C).
    4. Abdulrahman Joubi & Yutaro Akimoto & Keiichi Okajima, 2022. "A Production and Delivery Model of Hydrogen from Solar Thermal Energy in the United Arab Emirates," Energies, MDPI, vol. 15(11), pages 1-14, May.
    5. Adoum Abdoulaye, Mahamat & Waita, Sebastian & Wabuge Wekesa, Cyrus & Mwabora, Julius Mwakondo, 2024. "Optimal sizing of an off-grid and grid-connected hybrid photovoltaic-wind system with battery and fuel cell storage system: A techno-economic, environmental, and social assessment," Applied Energy, Elsevier, vol. 365(C).
    6. Jarosław Gryz & Krzysztof Król & Anna Witkowska & Mariusz Ruszel, 2021. "Mobile Nuclear-Hydrogen Synergy in NATO Operations," Energies, MDPI, vol. 14(23), pages 1-12, November.
    7. Timo Roeder & Kai Risthaus & Nathalie Monnerie & Christian Sattler, 2022. "Non-Stoichiometric Redox Thermochemical Energy Storage Analysis for High Temperature Applications," Energies, MDPI, vol. 15(16), pages 1-21, August.
    8. Francesco Calise, 2022. "Recent Advances in Green Hydrogen Technology," Energies, MDPI, vol. 15(16), pages 1-4, August.

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