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The Future of Hydrogen Chapter 6: Policies to boost momentum in key value chains capture to up to 0.6 MtH2/yr for industrial use in Rotterdam, the Netherlands (PoR, 2018); and the HyNet project in North West England, which proposes 0.2 MtH2/yr capacity for industrial use and injection into the gas grid (Cadent, 2018). Several of these projects plan to use domestic natural gas resources and store the CO2 under territorial waters, but in some cases the project proponents intend to import natural gas for local hydrogen production and re-export the CO2 for storage, for example in the Norwegian continental shelf. Another alternative is to import the hydrogen from hydrogen production close to the overseas CO2 storage site. Policies and public funding conditions can be instrumental in determining which approach is followed, for example by supporting only local hydrogen supplies. The North Sea already hosts 13 GW of offshore wind, and national targets for 2030 could take this above 50 GW. By creating new demand for electricity on the coast, electrolysers can prevent the power generated by offshore wind going to waste where electricity grid connections are not sufficient to transmit all of the output to demand centres at windy times. If 5% – the level of wind electricity subject to curtailment in Germany today – of the targeted North Sea offshore wind output in 2030 were used to produce hydrogen, around 0.2 MtH2/yr of low-carbon hydrogen could be supplied. This could satisfy more than 10% of the today’s industrial hydrogen demand around the North Sea. Several proposals have already been made to link offshore wind output to industrial clusters and, as part of this, to make use of large-scale hydrogen storage, including in North East England (H21, 2018), Northern Netherlands (EnergyStock, 2019; ReNews, 2019) and facilities on an artificial island (NSWPH, 2019). In the longer term, pairing renewable electricity capacity with hydrogen production for transport and industry could be attractive for matching electricity demand with supply. Sources: H21 (2018), H21 North of England; NIB (2018), “The green hydrogen economy”; PoR (2018), “H-Vision: Blue hydrogen for a green future”; Cadent (2018), HyNet North West: From Vision to Reality; EnergyStock (2019), “The hydrogen project HyStock”; ReNews (2019), ; NSWPH (2019), “Planning the future today”. North Sea hydrogen demand capacity by sector and pipeline infrastructure, 2018 Notes: This map is without prejudice to the status of or sovereignty over any territory, to the delimitation of international frontiers and boundaries and to the name of any territory, city or area. Tjeldbergodden in Norway, which consumes 0.1 MtH2/yr for methanol, not shown on map. Sources: Air Liquide (2019), “Supply modes”; CF Industries (2017), More Ways to Win: 2017 Annual Report; Integraal waterstofplan Noord-Nederland (2019), Investeringsagenda Waterstof Noord-Nederland; Roads2Hy.com (2007), “European hydrogen infrastructure atlas” and “Industrial surplus hydrogen and markets and production”; Yara (2018),”Annual production capacity”; data provided directly to IEA by Port of Rotterdam. There is already substantial demand for hydrogen in North Sea industrial clusters. PAGE | 180 IEA. All rights reserved.PDF Image | The Future of Hydrogen 2019
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