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Experimental Investigation of Factors Influencing Spontaneous Imbibition in Shale Reservoirs
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Experimental Investigation of Factors Influencing Spontaneous Imbibition in Shale Reservoirs
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Journal Article
Experimental Investigation of Factors Influencing Spontaneous Imbibition in Shale Reservoirs
2025
Overview
The flowback rate of fracturing fluid in shale reservoirs is often notably low, primarily due to the spontaneous imbibition of the water-based fracturing fluid. Despite their significance, the factors influencing spontaneous imbibition in shale reservoirs remain insufficiently understood. Moreover, whether spontaneous imbibition is ultimately beneficial or detrimental to shale reservoirs is still a subject of debate. This study investigates the spontaneous imbibition process in shale, the factors (the bedding, contact area, porosity, initial water saturation, and fluid type) affecting it, and its impact on shale porosity and permeability. The results reveal that the spontaneous imbibition process can be categorized into three distinct stages: the rapid imbibition stage, the transitional stage, and the stable stage. It is observed that bedding significantly influences the imbibition rate, and the imbibition rate in the parallel bedding direction is greater than that in the vertical bedding direction. The imbibition capacity increases with larger contact area and higher porosity, while it decreases with higher initial water saturation. Furthermore, the imbibition capacity varies with the type of fluid, following this order: distilled water > 5% KCl solution > kerosene. The maximum imbibed volume per unit pore volume of shale in distilled water is twice that in kerosene. Lastly, spontaneous imbibition is found to enhance the porosity and permeability of shale. After three instances of imbibition, the porosity of the matrix and fractured sample increased by 0.85% and 1.68%, and the permeability increased by 0.636 mD and 0.829 mD, respectively.
Publisher
MDPI AG
Subject
