Method for determining connected and non-connected porosities
Systems and methods for determining a connected porosity and a non-connected porosity in a fluid-saturated hydrocarbon reservoir are disclosed. The methods include obtaining at least one rock sample from the fluid-saturated hydrocarbon reservoir, determining, using a petrophysical sample analyzer, at least one petrophysical parameter of the rock sample, and measuring at least one of an elastic wave velocity and an elastic wave attenuation for each of a plurality of wave frequencies. The methods further include determining, using a computer processor, the connected porosity and the non-connected porosity of the rock sample using a dual-porosity single-permeability model based, at least in part, on at least one petrophysical parameter and at least one of the elastic wave velocity and the elastic wave attenuation.
1. A method for determining a connected porosity and a non-connected porosity in a fluid-saturated hydrocarbon reservoir, comprising:
obtaining at least one rock sample from the fluid-saturated hydrocarbon reservoir;
determining, using a petrophysical sample analyzer, at least one petrophysical parameter of the rock sample;
measuring at least one of an elastic wave velocity and an elastic wave attenuation for each of a plurality of wave frequencies;
determining, using a computer processor, the connected porosity and the non-connected porosity of the rock sample using a dual-porosity single-permeability model based, at least in part, on at least one petrophysical parameter and at least one of the elastic wave velocity and the elastic wave attenuation
determining a hydrocarbon reservoir development plan for the hydrocarbon reservoir using a reservoir simulator based, at least in part, on the connected porosity and on the non-connected porosity; and
drilling a wellbore to produce hydrocarbons from the hydrocarbon reservoir based, at least in part, on the hydrocarbon reservoir development plan.
2. The method of claim 1 , wherein measuring the elastic wave velocity comprises:
exciting elastic waves on a first surface of the rock sample;
detecting elastic waves on a second surface of the rock sample;
determining a propagation time of the elastic waves from the first surface to the second surface; and
determining the velocity of the elastic waves based on the propagation time and a spatial distance between the first surface and the second surface.
3. The method of claim 1 , wherein determining the connected porosity and the non-connected porosity, further comprises minimizing a metric of misfit between the measured and predicted elastic wave velocities and the measured and predicted elastic wave attenuations, wherein the predicted elastic wave velocities and predicted elastic wave attenuations are calculated using the dual-porosity single-permeability model.
4. The method of claim 3 , wherein the metric of misfit comprises a least-squares misfit function.
5. The method of claim 1 , wherein the elastic waves are compressional elastic waves.
6. The method of claim 1 , wherein at least one petrophysical parameter is selected from the group consisting of a Young's modulus, a bulk modulus, Poisson's ratio, a Skempton's coefficient, a Biot's coefficient, a permeability, and a tortuosity.
7. A non-transitory computer readable medium storing instructions executable by a computer processor, the instructions comprising functionality for:
determining, using a petrophysical sample analyzer at least one petrophysical parameter of a fluid-saturated rock sample;
measuring at least one of an elastic wave velocity and an elastic wave attenuation for each of a plurality of wave frequencies; and
determining, using a computer processor, a connected porosity and a non-connected porosity of the rock sample using a dual-porosity single-permeability model based, at least in part, on at least one petrophysical parameter and the at least one of the elastic wave velocity and the elastic wave attenuation
wherein measuring the elastic wave velocity comprises;
exciting elastic waves on a first surface of the rock sample,
detecting elastic waves on a second surface of the rock sample,
determining a propagation time of the elastic waves from the first surface to the second surface, and
determining the velocity of the elastic waves based on the propagation time and a spatial distance between the first surface and the second surface.
8. The non-transitory computer readable medium of claim 7 , wherein determining the connected porosity and the non-connected porosity, further comprises minimizing a metric of misfit between the measured and predicted elastic wave velocities and the measured and predicted elastic wave attenuations, wherein the predicted elastic wave velocities and predicted elastic wave attenuations are calculated using the dual-porosity single-permeability model.
9. The non-transitory computer readable medium of claim 8 , wherein the metric of misfit comprises a least-squares misfit function.
10. The non-transitory computer readable medium of claim 7 , wherein the elastic wave is a compressional elastic wave.
11. The non-transitory computer readable medium of claim 7 , wherein at least one petrophysical parameter is selected from the group consisting of a Young's modulus, a bulk modulus, Poisson's ratio, a Skempton's coefficient, a Biot's coefficient, a permeability, and a tortuosity.
12. A system, comprising:
a petrophysical sample analyzer, to measure at least one petrophysical parameter of a fluid-saturated rock sample;
an ultrasonic measurement cell, to measure at least one of an elastic wave velocity and an elastic wave attenuation of the fluid-saturated rock sample;
a computer memory device configured to:
receive at least one petrophysical parameter of the fluid-saturated rock sample;
receive at least one of an elastic wave velocity and an elastic wave attenuation for each of a plurality of wave frequencies; and
determine a connected porosity and a non-connected porosity of the rock sample using a dual-porosity single-permeability model based, at least in part, on at least one petrophysical parameter and the at least one of the elastic wave velocities and the elastic wave attenuation
a reservoir simulator for determining a hydrocarbon reservoir development plan based, at least in part, on the connected porosity and on the non-connected porosity; and
a drilling system to drill a wellbore to produce hydrocarbons from the hydrocarbon reservoir based, at least in part, on the hydrocarbon reservoir development plan.
13. The system of claim 12 , wherein measuring the elastic wave velocity comprises:
exciting the elastic wave on a first surface of the rock sample;
detecting the elastic wave on a second surface of the rock sample;
determining a propagation time of the elastic wave from the first surface to the second surface; and
determining the elastic wave velocity based on the propagation time and a spatial distance between the first surface and the second surface.
14. The system of claim 12 , wherein determining the connected porosity and the non-connected porosity further comprises minimizing a metric of misfit between the measured and predicted elastic wave velocities and the measured and predicted elastic wave attenuations, wherein the predicted elastic wave velocities and predicted elastic wave attenuations are calculated using the dual-porosity single-permeability model.
15. The system of claim 14 , wherein the metric of misfit comprises a least-squares misfit function.
16. The system of claim 12 , wherein the elastic wave is a compressional elastic wave.
17. The system of claim 12 , wherein at least one petrophysical parameter is selected from the group consisting of a Young's modulus, a bulk modulus, Poisson's ratio, a Skempton's coefficient, a Biot's coefficient, a permeability, and a tortuosity.