Numerical Simulation of Fracture-flooding with Virtual Element Method in a Continuous Damage Model

doi:10.19596/j.cnki.1001-246x.8538

Abstract

Abstract:

Based on Biot linear elastic theory, we established constitutive equations of interaction between fluid. A rock and virtual element method was employed to solve the discrete seepage equations. Meanwhile, in a continuous damage model, a damage factor was introduced and corresponding failure criterion was established to describe quantitatively the fracture propagation. Furthermore, influence factors of fracture-flooding in a low permeability reservoir were investigated in typical well patterns. It shows that the coupled method simulates fracture propagation effectively during the fracture-flooding process. It also revealed that large water injection improves effectively oil-water seepage capacity in the matrix, expands the water flooding area, and improves significantly recovery rate of the well pattern. Additionally, fracture-flooding activates quickly the nature fracture system in the formation of an effective propagation system. Early fracture-flooding maintains a higher formation pressure, increases the cumulative oil production and reduces the rate of decline in production, thereby improving the ultimate recovery rate of the reservoir.

Key words: fracture-flooding, virtual element method, continuous damage model, numerical simulation

Luming CHA, Qihong FENG, Sen WANG, Shiqian XU, Gaowen LIU, Wenhuan HUANG. Numerical Simulation of Fracture-flooding with Virtual Element Method in a Continuous Damage Model[J]. Chinese Journal of Computational Physics, 2023, 40(1): 81-90.

Figures/Tables 13

Fig.1 A schematic of contacting continent model

Fig.2 flow chart of the implementing coupling method

Table 1 Parameters in the model

参数	数值	单位
杨氏模量，E	30	GPa
泊松比，v	0.3	无因次
基质孔隙度，φ	0.12	无因次
基质渗透率，k	0.01	μm²
地层压力，p_wf	30	MPa
流体密度-水相，ρ_w	1 000	kg·m^-3
流体密度-油相，ρ_o	900	kg·m^-3
流体粘度-水相，μ_w	0.001	Pa·s
流体粘度-油相，μ_o	0.015	Pa·s
日注入量，Q	500	m³·d^-1

Fig.3 Verification of fracture propagation

Fig.4 A physical model for fracture-flooding simulation

Fig.5 Numerical simulation results

Fig.6 Cumulative production rate as functions of daily injection rate

Fig.7 Physical properties as functions of daily injection rate

Fig.8 A natural fracture system

Fig.9 Simulation results considering natural fractures

Fig.10 Production rate of a oil well considering natural fracture (a) injection rate Q=10 m3 ·d-1; (b) injection rate Q=200 m3 ·d-1

Fig.11 Oil production rate under different fracture-flooding timing

Fig.12 Cumulative oil production rate under different fracture-flooding timing

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