Rock-fluid interfacial tension at subsurface conditions: Implications for H2, CO2 and natural gas geo-storage
ORCID : 0000-0002-8080-1590
International Journal of Hydrogen Energy
School of Engineering / Centre for Sustainable Energy and Resources
China Scholarship Council
In H2, CO2 and natural gas geo-storage, rock-fluid interfacial tension (γrock−fluid) is a key parameter which influences pore-scale fluid distribution and reservoir-scale gas storage capacity and containment security. However, γrock−fluid data is seriously lacking because of the inability to measure this parameter experimentally. Therefore herein, a semi-empirical method is used to calculate γrock−fluid at geo-storage conditions. Additionally, effects of organic acid and silica nanofluid on γrock−fluid are studied. The following results are obtained. γrock−gas decreases with pressure, temperature, organic acid concentration and carbon number increase, while γrock−H2O increases with organic acid concentration and carbon number increase; γrock−gas first increases and subsequently decreases with silica nanofluid concentration increase, while γrock−H2O first decreases and then increases with silica nanofluid concentration increase; for same thermo-physical and rock surface chemistry conditions, γrock−gas follows the order H2 > CH4 > CO2. These insights provide pivotal guidance on gas geo-storage and thus aids in the implementation of a more sustainable energy supply chain.
Pan, B., Yin, X., & Iglauer, S. (2021). Rock-fluid interfacial tension at subsurface conditions: Implications for H2, CO2 and natural gas geo-storage. International Journal of Hydrogen Energy, 46(50), 25578-25585. https://doi.org/10.1016/j.ijhydene.2021.05.067