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The Future of Hydrogen Chapter 2: Producing hydrogen and hydrogen-based products supply chain as “fossil” or “non-fossil”. The operator of the CO2 capture facility would be credited with lower emissions for their process compared with the same process without CO2 capture. Sources: Bennett, Schroeder and McCoy (2014), “Towards a framework for discussing and assessing CO2 utilisation in a climate context”, Irlam (2017), “Global costs of carbon capture and storage: 2017 update”; Ericsson (2017), “Biogenic carbon dioxide as feedstock for production of chemicals and fuels: A Techno-economic assessment with a European perspective”; Hannula (2016), “Hydrogen enhancement potential of synthetic biofuels manufacture in the European context: A techno-economic assessment”; Keith et al. (2018), “A process for capturing CO2 from the atmosphere”; Fasihi and Breyer (2017), “Synthetic methanol and dimethyl ether production based on hybrid PV-wind power plants”; Fasihi, Efimova and Breyer (2019), “Techno-economic assessment of CO2 direct air capture plants”. Production costs Figure 22. The main cost components for the production of ammonia and synthetic hydrocarbons are the CAPEX and the hydrogen costs, together with the electricity costs if the hydrogen is produced through electrolysis and, for synthetic hydrocarbons, the CO2 feedstock costs. Capital costs constitute around 30–40% of the total production costs for ammonia and synthetic hydrocarbons if the hydrogen is produced from electricity. CAPEX costs are dominated by the costs of the electrolyser, while the synthesis process and other equipment components have a smaller impact.14 Learning effects could roughly halve the CAPEX costs of the different production pathways in the long term, thereby bringing down the cost of production (Figure 22). Indicative production costs of electricity-based pathways in the near and long term Notes: NH3 = ammonia.; renewable electricity price = USD 50/MWh at 3 000 full load hours in near term and USD 25/MWh in long term; CO2 feedstock costs lower range based on CO2 from bioethanol production at USD 30/tCO2 in the near and long term; CO2 feedstock costs upper range based on DAC = USD 400/tCO2 in the near term and USD 100/tCO2 in the long term; discount rate = 8%. More information on the underlying assumptions is available at www.iea.org/hydrogen2019. Source: IEA 2019. All rights reserved. Future cost reductions for hydrogen-based products from electricity will depend on lowering the cost of electricity, with cost reductions for CO2 feedstocks also being critical for synthetic hydrocarbons. 14 For example, for ammonia production from electrolytic hydrogen, the synthesis process and the air separation unit account for less than 5% of the total CAPEX. PAGE | 60 IEA. All rights reserved.PDF Image | The Future of Hydrogen 2019
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