Mechanistic understanding and mathematical advancements of spontaneous imbibition and fluid saturation measurement: A comprehensive review

Abstract

Accurate prediction of the imbibition of fluid in pores would help to properly estimate the oil/gas recovery. This study is focused on imbibition estimation, considering the influences of various rock matrix properties. We summarized the mathematical models and the impact of parameters that strongly influence the imbibition. Also, it includes imbibition mechanisms that incorporate intrinsic petrophysical parameters. This review highlights the importance of considering different methods for analyzing the effect of imbibition on hydrocarbon production, thereby providing valuable insights into reservoir engineering and petrophysics. Failing to account for the pore interconnectivity in the model can result in significant discrepancies between predictions and historical data. The findings show that a higher volume of oil pores in a formation minimizes the capillary pressure. Integrating various physical and chemical mechanisms into a single numerical model allows for a comprehensive understanding of spontaneous imbibition in clay-rich shale. By addressing complex pore structures and interactions, presented models provide valuable insights for improving hydrocarbon recovery in unconventional reservoirs.

Keywords

Spontaneous imbibition / Capillary trapping / Improved oil recovery / Multi-phase flow / Fracking imbibition

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