TY - GEN
T1 - Relative permeability measurement and numerical modeling of two-phase flow through variable aperture fracture in granite under confining pressure
AU - Watanabe, Noriaki
AU - Sakurai, Keisuke
AU - Ishibashi, Takuya
AU - Tsuchiya, Noriyoshi
PY - 2012/12/1
Y1 - 2012/12/1
N2 - Relative permeability measurement of decane-water two-phase flow was conducted in a fracture, created in granite, at confining pressures of 5 MPa and 10 MPa. Non-wetting phase (decane) relative permeability decreased with decreasing capillary pressure, indicating significant phase interference due to capillarity in two-phase flow through a rock fracture under confining pressure. Moreover, the relative permeability was much smaller at the same capillary pressure for the higher confining pressure, indicating that the phase interference became much more significant at a higher confining pressure. Consequently, the X model and the viscous coupling model, ignoring any phase interference and phase interference due to capillarity, respectively, were expected to be inappropriate for a fracture under confining pressure, emphasizing importance of evaluating two-phase fracture flow characteristics under confining pressure. However, it is difficult to measure phase saturation within a fracture under confining pressure. Consequently, a numerical non-steady-state two-phase fracture flow model, which considers influences of both viscosity and capillarity, was developed to determine a relative permeability-saturation-capillary pressure relation for the fracture aperture distribution under confining pressure. The model, which could be verified by experimental results, provided a non-wetting relative permeability curve, which was entirely different from the X model, the viscous coupling model, and even the Corey model. Moreover, an application of the model for air-water two-phase fracture flow provided a similar conclusion.
AB - Relative permeability measurement of decane-water two-phase flow was conducted in a fracture, created in granite, at confining pressures of 5 MPa and 10 MPa. Non-wetting phase (decane) relative permeability decreased with decreasing capillary pressure, indicating significant phase interference due to capillarity in two-phase flow through a rock fracture under confining pressure. Moreover, the relative permeability was much smaller at the same capillary pressure for the higher confining pressure, indicating that the phase interference became much more significant at a higher confining pressure. Consequently, the X model and the viscous coupling model, ignoring any phase interference and phase interference due to capillarity, respectively, were expected to be inappropriate for a fracture under confining pressure, emphasizing importance of evaluating two-phase fracture flow characteristics under confining pressure. However, it is difficult to measure phase saturation within a fracture under confining pressure. Consequently, a numerical non-steady-state two-phase fracture flow model, which considers influences of both viscosity and capillarity, was developed to determine a relative permeability-saturation-capillary pressure relation for the fracture aperture distribution under confining pressure. The model, which could be verified by experimental results, provided a non-wetting relative permeability curve, which was entirely different from the X model, the viscous coupling model, and even the Corey model. Moreover, an application of the model for air-water two-phase fracture flow provided a similar conclusion.
KW - Confining pressure
KW - Fracture
KW - Geothermal reservoir
KW - Granite
KW - Numerical modeling
KW - Relative permeability
KW - Two-phase flow
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M3 - Conference contribution
AN - SCOPUS:84876210344
SN - 9781622764341
T3 - Transactions - Geothermal Resources Council
SP - 583
EP - 587
BT - Geothermal Resources Council Annual Meeting 2012, GRC 2012 - Geothermal
T2 - Geothermal Resources Council Annual Meeting 2012 - Geothermal: Reliable, Renewable, Global, GRC 2012
Y2 - 30 September 2012 through 3 October 2012
ER -