Fig. 1 ( a ) Geometry geothermal reservoir with single fracture, ( b ) boundary conditions, and ( c ) the meshed geometry More

Fig. 2 Comparison of the properties of SCCO 2 and water within the operating pressure and temperatures: ( a ) viscosity, Pa · s, ( b ) density, kg/m 3 , ( c ) heat capacity J/kg · K, and ( d ) thermal conductivity, W/m · K More

Fig. 3 Schematic of the solution process for fully coupled thermo-hydro-geomechanical model in the geothermal reservoir with fracture More

Fig. 4 Verification for the heat transfer in single fracture with analytical solution: ( a ) schematic of single fracture conceptual model, ( b ) temperature variation in fracture with time, and ( c ) temperature variation with time in fracture. More

Fig. 5 Spatiotemporal variation of temperature in the reservoir and fracture with different injection/production velocities when using SCCO 2 as geofluid at an initial pressure of 15 MPa, and injection temperature of 35 °C More

Fig. 6 Comparison of SCCO 2 and water as geofluids on the spatiotemporal variation of temperature in the reservoir and fracture at injection/production velocity of 0.1 m/s and initial pressure of 20 MPa, and injection temperature of 35 °C More

Fig. 7 Impact of injection/production velocities, initial reservoir pressure, and injection temperature on the production temperature when using SCCO 2 , and water as geofluids More

Fig. 8 Production temperature when using SCCO 2 as geofluid at different injection rates: ( a ) injection temperature = 35 °C, ( b ) injection temperature = 40 °C, and ( c ) injection temperature = 45 °C More

Fig. 9 Spatiotemporal variation of Von mises stress in MPa (aperture = 0.5 mm and Biot–Willis’s coefficient = 0.5, initial reservoir pressure = 20 MPa, and injection temperature = 40 °C) More

Fig. 10 Spatiotemporal variation of tresca stress in MPa (aperture = 0.5 mm and Biot–Willis coefficient = 0.5, initial reservoir pressure = 20 MPa, and injection temperature = 40 °C) More

Fig. 11 Spatial variation of different variants of strains after 10 years of injection and production operation (injection/production velocity = 0.05 m/s, aperture = 0.5 mm, Biot–Willis coefficient = 0.5, initial reservoir pressure = 25 MPa, and injection temperature = 45 °C) More

Fig. 12 Spatiotemporal variation of permeability, porosity, Young’s modulus, and effective thermal conductivity (injection/production velocity = 0.05 m/s, aperture = 0.5 mm, and Biot–Willis coefficient = 0.5), initial reservoir pressure = 20 MPa and injection temperature = 40 °C More

Fig. 13 Impact of injection/production velocities, initial reservoir pressure, and injection temperature on the reservoir flow impedance when using SCCO 2 and water as geofluids More

Fig. 14 Reservoir flow impedance when using SCCO 2 as geofluid at different injection rates: ( a ) injection temperature = 35 °C, ( b ) injection temperature = 40 °C, and ( c ) injection temperature = 45 °C More

Fig. 15 Impact of injection/production velocities, initial reservoir pressure, and injection temperature on the heat power when using SCCO 2 and water as geofluids More

Fig. 16 Reservoir flow impedance when using SCCO 2 as geofluid at different injection rates: ( a ) injection temperature = 35 °C, ( b ) injection temperature = 40 °C, and ( c ) injection temperature = 45 °C More

Fig. 1 Schematic diagram of thermal transmission between wellbore and formation during horizontal well drilling More

Fig. 2 Schematic diagram of meshing in the solution area More