SUCCES (Stored Up-valued Concentrated Cold Energy System)

在依赖间歇性可再生能源发电的可持续电网中，储能是平衡供需差异的一项重要技术。能量可以以电能、热能和化学形式储存在可持续燃料中，并以不同的时间和规模储存。使用电池可以有效地管理电网的短期变化，但电池技术对于满足大量长期存储需求来说过于昂贵，无法平衡季节之间需求的变化和低可再生发电的延长期。响应速度较慢、往返效率较低、资金基础较低的技术是这些应用的首选。液体空气储能（LAES）是海维电力公司正在开发的一种长时间储能技术。能量以三种方式储存；在液体空气和背床蓄热器冷库中，温度与在熔盐冷库中一样低。空气液化器用于给LARS设备充电。随着电厂效率的提高和相对成本的降低，LAES在大规模（50兆瓦）规模上有一个最佳点。但是，如果LAES工厂可以有效地部署在更小的规模（<50MW）上，会发生什么呢？这项技术可以与其他需要低温冷却的能源网络相结合，比如生物甲烷和绿色氢的长期储存。在这个项目中，我们将研究一个中小型LAES工厂与当地从废物（如农业、管理的草地（如公园和运动场）和污水）中生产的生物甲烷液化的整合。同样，连接到当地可再生能源发电机的中小型电解槽产生的氢气也需要一个存储解决方案。我们建议在80-90K的温度下对氢气进行冷加压储存，这将储存气体所需的压力（对于等效能量密度）降低了2到3倍，并避免了20K低温储存的高能量成本。LAES与甲烷和氢气储存的整合开辟了新的收入来源，并将经济转向为当地社区服务的小型工厂，如大型农场、地方当局和管理污水废物的水务公司。我们提出了一个局部而非集中的解决方案，因为(a)生物甲烷生产的原料对当地生产和储存的能量密度低，避免了运输效率的降低(b)同样，氢气的本地生产和消费避免了将冷加压气体转移到大型储存设施，然后再转移到消费者手中的需要；(c)将LAES工厂的核心电能储存嵌入更靠近最终用户的地方，有利于减少传输负荷网络。

Energy storage is an essential technology for balancing the differences in supply and demand in a sustainable power network reliant on intermittent renewable generation. Energy can be stored as electricity, as heat and chemically in a sustainable fuel and at different temporal and size scales. Short time variations in the power grid can be effectively managed using batteries but the battery technologies are too expensive for servicing the bulk long term storage requirements to balance variations in demand between seasons and extended periods of low renewable generation. Technologies with a slower response, lower round trip efficiency but lower capital base are preferred for these applications. Liquid Air Energy Storage (LAES) is a long duration storage technology being developed by Highview Power. Energy is stored thermally in three ways; as cold in liquid air and in a backed bed regenerator cold store and as heat in a molten salt hot store. An air liquefier is used to charge the LARS device. LAES has a sweet spot at large (>50MW) scale as plant efficiency increases and relative cost reduces with scale for this technology. But what would happen if a LAES plant could be efficiently deployed at smaller (<50MW) scale? The technology could then be integrated with other aspects of the energy network that require cooling at cryogenic temperatures such as the long term storage of bio methane and green hydrogen. In this project, we will investigate the integration of a small to mid scale LAES plant with the liquefaction of locally produced bio methane from waste, such as agriculture, managed grass land (such as parks and sports fields) and sewerage. Similarly, hydrogen produced by small to mid size electrolysers connected to local renewable generators requires a storage solution. We propose cold, pressurised storage of hydrogen at 80-90K which lowers the pressure required to store the gas (for an equivalent energy density) by a factor of 2 to 3 and avoids the high energy cost of cryogenic storage at 20K.Integration of LAES with methane and hydrogen storage opens up new revenue steams and shifts the economics to favour smaller plant serving local communities such as large farms, local authorities and water companies managing sewage waste. We propose a local rather than central solution as (a) the feedstocks for bio-methane production have a low energy density to local production and storage avoids transportation inefficiencies (b) Similarly local production and consumption of hydrogen avoids the need to move cold pressurised gas to bulk storage facilities and then to consumers and (c) imbedding the core electrical energy storage of the LAES plant closer to the end user has benefits in reducing the load on the transmission network.