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The Future of Hydrogen Chapter 5: Opportunities for hydrogen in transport, buildings and power Figure 64. 10 000 1 000 100 10 Levelised costs of storage as a function of discharge duration liquid ammonia tank with a diameter of 50 metres and a height of 30 metres, as typically used in the fertiliser industry, can store energy amounting to 150 GWh, comparable to the annual electricity consumption of a city with a population of 100 000. To store the same amount of electricity with batteries would require around 1 150 times the installation of the Australian Hornsdale Battery Reserve, the largest lithium-ion battery storage today in the world with a capacity of 129 MWh. All the alternatives have advantages and disadvantages. For shorter discharge durations below a few hours, hydrogen and ammonia are much more expensive than pumped-hydro storage or battery storage. With longer discharge durations, compressed hydrogen and ammonia become more attractive, benefitting from their relative low capital costs for energy storage volumes (the investment costs to develop underground salt caverns or storage tanks). Among the different storage technologies considered here, compressed hydrogen becomes the most economic option for discharge durations beyond 20–45 hours. Electricity input costs USD 50/MWh 10 000 1 000 100 10 Electricity input costs USD 0/MWh 0.1 1 10 100 1000 Discharge duration (h) 0.1 1 10 100 1000 Discharge duration (h) Li-Ion PHES CAES Compressed hydrogen Ammonia CCGT with CCUS Notes: PHES = pumped-hydro energy storage; CAES = compressed air energy storage; Li-Ion = lithium-ion battery. Compressed hydrogen storage refers to compressed gaseous storage in salt caverns, ammonia storage to storage in tanks. Source: IEA 2019. All rights reserved. Depending on the costs of the stored electricity, compressed hydrogen storage becomes the most economic storage option at discharge durations longer than 20–45 hours. Hydrogen as an electricity storage option could also be combined with other uses of hydrogen in the interests of competitiveness. In the United States, for example, the Three-State Generation and Transmission utility is considering producing ammonia from electricity for the domestic fertiliser market. Situated in an area with low-cost electricity from wind, solar and hydropower, the project would use a reversible solid oxide electrolyser cell (rSOEC) to produce hydrogen when the cost of electricity is less than USD 25/MWh (which is 85% of the time), turning it into ammonia for sale on the market, while storing some of it for electricity generation in the rSOEC during peak hours, thus improving its overall utilisation rate. This approach may be an alternative to installing new electric generation resources that are expected only to be needed during peak load times. It may not be necessary to use large-scale storage of hydrogen-based fuels to cover the full storage cycle, i.e. taking electricity as input and converting it in the end back into electricity. PAGE | 159 IEA. All rights reserved. USD/MWh USD/MWhPDF Image | The Future of Hydrogen 2019
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