A Novel Equivalent Numerical Simulation Method for Non-Darcy Seepage Flow in Low-Permeability Reservoirs

Hui Xu, Nannan Liu (), Yan Chen, Yapeng Tian, Zhenghuai Guo, Wanjun Jiang and Yanfeng He
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Hui Xu: Jiangsu Key Laboratory of Oil-Gas Storage and Transportation Technology, School of Petroleum Engineering, Changzhou University, Changzhou 213164, China
Nannan Liu: Jiangsu Key Laboratory of Oil-Gas Storage and Transportation Technology, School of Petroleum Engineering, Changzhou University, Changzhou 213164, China
Yan Chen: Jiangsu Key Laboratory of Oil-Gas Storage and Transportation Technology, School of Petroleum Engineering, Changzhou University, Changzhou 213164, China
Yapeng Tian: School of Energy Resources, China University of Geosciences (Beijing), Beijing 100083, China
Zhenghuai Guo: Jiangsu Key Laboratory of Oil-Gas Storage and Transportation Technology, School of Petroleum Engineering, Changzhou University, Changzhou 213164, China
Wanjun Jiang: Tianjin Center, China Geological Survey (CGS), North China Center of Geoscience Innovation, Tianjin 300170, China
Yanfeng He: Jiangsu Key Laboratory of Oil-Gas Storage and Transportation Technology, School of Petroleum Engineering, Changzhou University, Changzhou 213164, China

Energies, 2022, vol. 15, issue 22, 1-14

Abstract: The low permeability and submicron throats in most shale or tight sandstone reservoirs have a significant impact on microscale flow. The flow characteristics can be described with difficultly by the conventional Darcy flow in low-permeability reservoirs. In particular, the thickness of the boundary layer is an important factor affecting the formation permeability, and the relative permeability curve obtained under conventional conditions cannot accurately express the seepage characteristics of porous media. In this work, the apparent permeability and relative permeability were calculated by using non-Darcy-flow mathematical modeling. The results revealed that the newly calculated oil–water relative permeability was slightly higher than that calculated by the Darcy seepage model. The results of the non-Darcy flow based on the conceptual model showed that the area swept by water in non-Darcy was smaller than that in Darcy seepage. The fingering phenomenon and the high bottom hole pressure in the non-Darcy seepage model resulted from the larger amount of injected water. There was a large pressure difference between the injection and production wells where the permeability changed greatly. A small pressure difference between wells resulted in lower variation of permeability. Consequently, the non-Darcy simulation results were consistent with actual production data.

Keywords: low permeability; non-Darcy flow; apparent permeability; relative permeability (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2022
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