Evaluation of CO₂-Fluid-Rock Interaction in Enhanced Geothermal Systems: Field-Scale Geochemical Simulations

Table 1

Hydrologic parameters, initial, and injection/production boundary conditions used for 3D simulations of a 5-spot well pattern.

Properties
Fractured rock permeability	m^2 (0.25 mD)
High granite permeability	m^2 (0.01 mD)
Fracture spacing	50 m
Fracture volume fraction	2%
Fracture porosity	0.50
Granite porosity	0.08
Fracture tortuosity	1.0
Thermal conductivity	2.51 W/m°C
Rock specific heat	1000 J/kg°C
Rock grain density	2650 kg/m^3
Initial condition
Reservoir fluid	All water
Initial temperature	200°C at the layer of production well with 40°C/km geothermal gradient
Initial pressure	Hydrostatic pressure with 20 Mpa at the layer of production well
Production/injection condition
Injection/production	707 m
Well distance
Injection pressure	Initial +1.25 MPa
Injection temperature	50°C
Production pressure	Initial −1.25 MPa