Capillarity in porous media: Recent advances and challenges

Capillarity refers to the phenomenon of fluids imbibing into fine pores or porous rocks and materials due to surface energy, through the action of capillary pressure. The capillary pressure causes the deformable interfaces formed between two phase fluids in contact with each other, such as a liquid and a vapor. Capillarity and its importance have been widely recognized in various fields, including civil engineering, soil science, hydrology, carbon storage, and petroleum engineering. More than a century ago, the classical Young–Laplace equation and Lucas-Washburn equation laid the foundation for the description of the capillary-driven flow of fluids in porous structures. With the rapid development of computational and experimental techniques, the research on capillarity is advancing at an unprecedented level and provides insight and opportunities for further effort in what is already a flourishing field of research. Four papers on capillarity in porous media are collected in this special issue and are summarized in the following paragraphs: In the paper “Shale adhesion force measurements via atomic force microscopy” [1], Mitiurev et al. used the AFM (Atomic Force Microscopy) technique to measure the adhesion force between cantilever and sample surface at nanoscale for shale. They used topographical analysis, SEM (Scanning Electron Microscopy) and EDS (Energy Dispersive Spectroscopy) to accurately locate the measurement points on a sample surface and obtained consistent adhesion force measurements for quartz grain inclusions. The adhesion forces were determined to equal the water– air capillary pressure under the test conditions. These measurements and results have potential to create a path towards much higher accuracy–wettability measurements and consequently better reservoir-scale predictions and improved underground operations. In the paper “A modified cell-to-cell simulation model to determine the minimum miscibility pressure in tight/shale formations” [2], Sun and Li developed a new oil-gas minimum miscibility pressure calculation algorithm, which couples the effects of capillary pressure and confinement in the original cell-to-cell simulation model to predict the oil-gas minimum miscibility pressure in a confined space. By the algorithm, the effects of temperature, pore radius, and injection gas impurity on the confined oil gas minimum miscibility pressure calculations are studied in detail. They found that the oil gas minimum miscibility pressure is reduced in confined space and the degree of this reduction depends on the pore radius. For all the tested pore radii, the confined minimum miscibility pressure first increases and then decreases with an increasing temperature. Compared to pure carbon dioxide injection, the addition of methane in the injection gas increases the oil gas minimum miscibility pressure in confined nanopores. It is recommended to control the content of methane in the injection gas in order to achieve a more efficient gas injection design. In the paper “Capillarity and phase-mobility of a hydrocarbon gas–liquid system” [3], Gao et al. applied X-ray computed microtomography to image the pore level gas and liquid distribution in 3D while lowering the pressure below the bubble point or while injecting gas. The pore level gas and liquid distribution gives direct access to the connectivity of the gas and hence its mobility. Respective (connected pathway) relative permeability is directly computed from the imaged gas and liquid distribution using lattice Boltzmann-based flow simulation. The gas relative permeability follows a classical non-wetting phase drainage relative permeability curve when re-scaling the saturation endpoint to the critical gas saturation. The liquid relative permeability is compatible with both a wetting phase imbibition and drainage relative permeability. Their study provides fundamental insight into the gas dynamics in two-component systems that fall below the bubble point pressure and gas is nucleated. In the paper “Analytical modeling and correction of steady state relative permeability experiments with capillary end effects – An improved intercept method, scaling and general capillary numbers” [4], Andersen presented Capillarity in Porous Media: Recent Advances and Challenges Jianchao Cai, Pål Ø. Andersen, Shuangmei Zou (Guest editors)