Optimization of cushion gas types and injection production parameters for underground hydrogen storage in aquifers

doi:10.19799/j.cnki.2095-4239.2023.0348

Abstract

Abstract:

The advancement of UHS (underground hydrogen storage) technology offers a viable solution to the volatility and intermittent nature of renewable energy. In increasing hydrogen production, the UHS must inject cushion gas to increase formation pressure and inhibit formation water flow. Since studies on cushion gas in the aquifer are limited and qualitative, the mechanism model of the hydrogen storage reservoir is established using a numerical simulation method that considers the effects of cushion gas injection types, different combinations, injection volumes, and injection rates on hydrogen recovery. The results showed that the impact of cushion gas injection on hydrogen recovery in the first injection-production cycle was more obvious, and the methane scheme increased the hydrogen recovery by 18.41%. Carbon dioxide as a cushion gas may have a poor effect because of the methanation reaction. The hydrogen recovery decreases with the increase in molecular weight of cushion gas and increases with the increase in injection amount of cushion gas. Moreover, the injection of cushion gas can increase formation pressure and inhibit formation water flow, reducing the influence of gravity segregation and increasing hydrogen recovery. In the early stage of hydrogen storage, the reasonable injection of cushion gas is crucial for the operation of hydrogen storage.

Key words: hydrogen storage, aquifer, cushion gas, hydrogen recovery

CLC Number:

TE 822

Yongmao HAO, Kan REN, Chuanzhi CUI, Zhongwei WU. Optimization of cushion gas types and injection production parameters for underground hydrogen storage in aquifers[J]. Energy Storage Science and Technology, 2023, 12(9): 2881-2887.

Figures/Tables 14

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参数	数值	参数	数值
网格大小	51×51×10	岩石压缩系数	2.0×10^-3 MPa^-1
网格尺寸	20 m×20 m×5 m	地层水压缩系数	4.5×10^-4 MPa^-1
顶深	800 m	初始地层温度	50 ℃
横向渗透率	100 mD^①	初始地层压力	8 MPa
纵横向渗透率比值	0.3	残余气饱和度	0.2
孔隙度	0.20

气体	临界压力/MPa	临界温度/℃	偏心因子	分子量	压缩因子	临界体积/(L/mol)
CO₂	7.28	31.05	0.225	44.010	0.2736	0.0940
N₂	3.35	-146.95	0.040	28.013	0.2905	0.0895
CH₄	4.54	-82.55	0.008	16.043	0.2876	0.0990
H₂	1.30	-239.96	-0.214	2.016	0.3199	0.0669

方案	累计注入氢气/10⁶ m³		累计采出氢气/10⁶ m³
方案	第一周期	第五周期	第一周期	第五周期
基础模型	3.478	17.392	1.428	11.375
CH₄作垫层气	3.478	17.392	2.068	12.673
CO₂作垫层气	3.478	17.392	1.663	11.218
N₂作垫层气	3.478	17.392	1.998	12.229

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