Fully coupled fluid-solid productivity numerical simulation of multistage fractured horizontal well in tight oil reservoirs

ZHANG Dongxu,ZHANG Liehui,TANG Huiying,ZHAO Yulong

Table 1. Basic model parameters

Parameter Value Parameter Value Parameter Value Reservoir size 1000 m× 600 m×18 m Matrix initial permeability 0.12×10-3 μm2 Matrix elastic modulus 18 GPa Horizontal well length 600 m Natural fracture initial porosity 0.08% Natural fracture elastic modulus 12 GPa Artificial fracture length 160 m Natural fracture initial permeability 1.5×10-3 μm2 Poisson ratio 0.27 Artificial fracture height 18 m Natural fracture compression coefficient 0.15 MPa-1 Maximum horizontal principal stress 38.5 MPa Artificial fracture opening 2.884×10-4 m Wellbore radius 0.05 m Minimum horizontal principal stress 35.5 MPa Artificial fracture number 7 Initial formation pressure 30 MPa Channeling coefficient 1 Artificial fracture compression coefficient 0.06 MPa-1 Bottom hole pressure 20 MPa Biot coefficient 1 Artificial fracture porosity 100% Fluid viscosity 8 mPa•s Fluid bulk modulus 1×104 MPa Matrix initial porosity 10% Fluid density 960 kg/m3 Rock skeleton bulk modulus 6.5×104 MPa