Competition between viscous and capillary forces triggers diversity of fluid distribution and imbibition modes

Spontaneous imbibition is the process in which the wetting phase displaces a non-wetting phase under the action of capillary forces. However, variations in interfacial properties, imbibition directions, and fractures result in different imbibition modes, posing challenges to a comprehensive understanding of the process. In this study, microfluidic chips representing matrix and fracture–matrix systems were designed. Imbibition agents with varied interfacial properties were selected to conduct experiments under counter-current and co-current conditions. A flow factor ( γ ), related to fracture geometry and imbibition direction, was defined and used together with the microscopic capillary number ( Ca micro ) to characterize the imbibition process. Three distinct imbibition modes were observed for different Ca micro and γ , clearly separated by γ – Ca micro boundaries. During co-current imbibition, an unusual capillary-driven displacement process was observed, leading to fingering in the fracture–matrix model and leaving a large area of macroscale remaining oil. Smaller Ca micro and fracture development will facilitate this process. In addition, various forms of microscale remaining oil, caused by bypass flow snap-off and Saffman–Taylor instability/Rayleigh–Taylor instability, were also observed across different imbibition processes. This study elucidates the imbibition mechanisms under the combined influence of capillary and viscous forces, providing deeper insights into the imbibition process in porous media.

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Publication Details

Journal
Petroleum Science
Published
2025-10-07
DOI
https://doi.org/10.1016/j.petsci.2025.09.043
Citations
1
Primary Topic
Enhanced Oil Recovery Techniques
Type
article
Field-Weighted Citation Impact
1.15
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Competition between viscous and capillary forces triggers diversity of fluid distribution and imbibition modes

Zheyu Liu, Xuechen Tang, Tao Song, Jinxin Cao et al.
1 citations
Petroleum Science
Enhanced Oil Recovery Techniques
1.15
article

Competition between viscous and capillary forces triggers diversity of fluid distribution and imbibition modes

Zheyu Liu, Xuechen Tang, Tao Song, Jinxin Cao, Qihang Li, Yaqian Zhang, Yuling Zhang, Yiqiang Li
article en
1 citations

Abstract

Spontaneous imbibition is the process in which the wetting phase displaces a non-wetting phase under the action of capillary forces. However, variations in interfacial properties, imbibition directions, and fractures result in different imbibition modes, posing challenges to a comprehensive understanding of the process. In this study, microfluidic chips representing matrix and fracture–matrix systems were designed. Imbibition agents with varied interfacial properties were selected to conduct experiments under counter-current and co-current conditions. A flow factor ( γ ), related to fracture geometry and imbibition direction, was defined and used together with the microscopic capillary number ( Ca micro ) to characterize the imbibition process. Three distinct imbibition modes were observed for different Ca micro and γ , clearly separated by γ – Ca micro boundaries. During co-current imbibition, an unusual capillary-driven displacement process was observed, leading to fingering in the fracture–matrix model and leaving a large area of macroscale remaining oil. Smaller Ca micro and fracture development will facilitate this process. In addition, various forms of microscale remaining oil, caused by bypass flow snap-off and Saffman–Taylor instability/Rayleigh–Taylor instability, were also observed across different imbibition processes. This study elucidates the imbibition mechanisms under the combined influence of capillary and viscous forces, providing deeper insights into the imbibition process in porous media.

Petroleum ScienceVol. 23(2)
Southwest Petroleum University (CN), China University of Petroleum, Beijing (CN), Daqing Oilfield General Hospital (CN), China National Petroleum Corporation (China) (CN)
Openalex Percentile: Top 18%
Enhanced Oil Recovery Techniques
1.15
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