SUCCES (Stored Up-valued Concentrated Cold Energy System)

在依赖间歇可再生能源发电的可持续电力网络中，储能是平衡供需差异的一项基本技术。能量可以以电、热和化学的形式储存在一种可持续的燃料中，并以不同的时间和大小尺度储存。使用电池可以有效地管理电网中的短期变化，但电池技术对于满足大量长期存储需求来说过于昂贵，无法平衡季节之间的需求变化和延长的低可再生发电量周期。对于这些应用，首选响应速度较慢、往返效率较低但资本基础较低的技术。液体空气储能(LAES)是海威特电力公司正在开发的一种长效储能技术。能量有三种储热方式：在液态空气和靠背床蓄热式冷库中以冷的形式储存；在熔盐热储库中以热的形式储存。空气液化器被用来为LARS设备充电。LAES在大规模(50兆瓦)上有一个甜蜜点，因为这项技术的工厂效率提高，相对成本随着规模的扩大而降低。但是，如果LAES电厂能够以较小(50兆瓦)的规模有效地部署，会发生什么？然后，这项技术可以与能源网络中需要在低温下冷却的其他方面相结合，例如长期储存生物甲烷和绿色氢气。在这个项目中，我们将研究一座中小型LAES工厂与液化本地产生的沼气的整合，这些废物来自农业、受管理的草地(如公园和运动场)和污水处理系统。同样，连接到当地可再生发电机的中小型电解槽产生的氢气需要存储解决方案。我们建议在80-90K的温度下对氢气进行冷、加压存储，这可以将存储气体所需的压力降低2到3倍(对于相同的能量密度)，并避免在20K进行高能耗的低温存储。LAES与甲烷和氢气存储的集成开辟了新的收入来源，并将经济转向更小的工厂，为当地社区服务，如大型农场、地方政府和管理污水废物的自来水公司。我们提出了本地而不是中央解决方案，因为(A)用于生物甲烷生产和储存的原料的能量密度较低，可避免运输效率低下(B)类似的氢气本地生产和消费避免了将冷加压气体输送到散装储存设施，然后再输送到消费者的需要，以及(C)将LAES工厂的核心电能储存嵌入更靠近最终用户的位置，有利于减少传输网络的负荷。

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.