Numerical Simulation of the Dynamic Behavior of Low Permeability Reservoirs Under Fracturing-Flooding Based on a Dual-Porous and Dual-Permeable Media Model

Xiang Wang (), Wenjie Yu, Yixin Xie, Yanfeng He, Hui Xu, Xianxiang Chu and Changfu Li
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Xiang Wang: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Wenjie Yu: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Yixin Xie: School of Mechanical Engineering, Changzhou Institute of Technology, Changzhou 213032, China
Yanfeng He: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Hui Xu: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Xianxiang Chu: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Changfu Li: School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China

Energies, 2024, vol. 17, issue 23, 1-26

Abstract: In recent years, fracturing-flooding technology has achieved a series of successful practices in the development of low-permeability oil reservoirs. However, research on the dynamic behavior of fracturing-flooding remains limited. In this paper, a dual medium model considering anisotropic characteristics is established for the target blocks. Multiple sets of conventional water injection transitions and multi-cycle fracturing-flooding operations are designed for simulation to explore the subsequent optimal operational schemes. Simulations are conducted on the optimal transitions between conventional water injection and multi-cycle fracturing-flooding schemes for different reservoir models with varying physical properties to study the dynamic behavior of fracturing-flooding in oil reservoirs with different properties. The results indicate that, for conventional water injection schemes, the optimal transition time for both the target well group and other reservoirs with different properties corresponds to a formation pressure coefficient between 1.2 and 1.3, with the optimal injection–production ratio being 1:1. From the perspective of water cut, the accumulated oil production of multi-cycle fracturing-flooding is higher than that of conventional water injection. The optimal multi-cycle fracturing-flooding schemes for both the target well group and other reservoirs with different properties are to start fracturing-flooding when the formation pressure coefficient is around 0.8 and to begin production when it reaches 1.4.

Keywords: fracturing-flooding; numerical simulation; multi-cycle fracturing-flooding; dynamic behavior (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: 2024
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