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The Future of Hydrogen Chapter 6: Policies to boost momentum in key value chains Curtailed and under-remunerated renewable electricity. Although curtailment in China is declining, over 100TWh of solar, wind and hydro output were curtailed there in 2017 (IEA, 2018c), roughly equivalent to the level of electricity consumption in the Netherlands. In Germany, 5.5TWh of power were curtailed in 2017 (Bundesnetzagentur, 2018). Redispatching and curtailment costs amounted to USD 1.2 billion in Germany in 2017 and USD 1.1 billion in the United Kingdom in 2018 (Bundesnetzagentur, 2018; National Grid, 2019). There would be obvious benefits from making productive use of curtailed output. In 2018 three German grid operators announced plans for a 100MW electrolyser in Lower Saxony where there is regularly too much offshore wind energy for the existing grid, with refuelling stations cited as providing potential hydrogen demand (Tennet, 2018). Besides curtailment, some renewable electricity installations receive less revenue when they produce most energy because spot prices fall in response to high output from wind or solar or both. To hedge this risk, project developers – including hydropower operators that sometimes have “spill” water – could contract with off-takers at an agreed price. However, the incentives and power prices would have to be very attractive to offset the reduced number of hours the electrolyser can operate on this power source (Chapter 2) and the costs of buffer hydrogen storage to manage variability. Inflexible power plants. Some co-generation plants overproduce electricity at times of high heat demand when the local power grid does not have sufficient power demand. This is the case in North East China, for example, where the inflexibility of coal plants caused by heat loads was a factor in the curtailment of 40 TWh of wind power in 2017. Until the heat demand in these regions is met by other sources of energy, production of hydrogen via electrolysis could potentially be used to avoid curtailment of either coal or renewable electricity if sufficient full load hours of the electrolyser are possible at low power prices. In the longer term any use of coal to produce hydrogen would need to be coupled with CCUS in order to deliver emissions reductions. By-product and vented hydrogen. Some industries produce hydrogen as a by-product that they do not need (for example steam crackers, chlor-alkali electrolysers and propane dehydrogenation). Merchant hydrogen suppliers collect and purify some of this hydrogen for sale to refineries, chemical plants and others. However, up to 0.5MtH2 worldwide is currently vented to the air from these processes. Another 22 MtH2 is used for relatively low- value applications such as heat and power generation without purification. In combination, this theoretically represents enough hydrogen to power 180 million cars. Renewable gas. Biogas from anaerobic digesters, dairy farms and landfill is often used for relatively low-value local heat applications. By treating the gas, these resources can be injected in the gas grid and, if accounting systems are in place as in California, sold “virtually” to operators of existing hydrogen production plants running on natural gas. These resources are not available in all places, but where they are available they could reduce emissions and the need for new investment, potentially decreasing co-ordination challenges. Sources: IEA (2018b), Market Report Series: Renewables 2018; Bundesnetzagentur (2018), Monitoring Report 2018 – Key Findings; National Grid (2019), Monthly System Balancing Reports; Tennet (2018), “Gasunie, TenneT and Thyssengas reveal detailed, green ‘sector coupling’ plans using power-to-gas technology”. PAGE | 174 IEA. All rights reserved.PDF Image | The Future of Hydrogen 2019
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