Methods and systems for determining reservoir and fracture properties
Methods and systems for determining pore-volume of a fracture in a core plug. The method includes developing a grid block model constrained by fracture porosity estimated from a mechanical laboratory test, aperture calculation, and discrete fracture model validation. The method further includes determining the natural fracture porosity and pore volume from the equivalent medium for natural fractures, determining oil or gas reserves by calculating the fracture pore volume, and determining fracture porosity measurement from a test to calibrate 3D fracture models. The method also includes determining fracture porosity from a mechanical test, analyzing borehole image logs, developing a geomechanical model and fracture drivers, performing fracture model predictions, validating and calibrating the model, and determining fracture pore-volume of the core plug.
1. A method for determining properties of a subsurface formation comprising:
obtaining an intact core plug sample and a fractured core plug sample from the subsurface formation;
conducting a first mechanical laboratory test on the intact core plug sample that comprises performing a conventional core analysis for porosity and permeability of the intact core plug sample, and determining a matrix porosity and a matrix permeability sensitivity to stress for the intact core plug sample at confined pressure conditions;
conducting a second mechanical laboratory test on the core plug sample after it has been fractured, that comprises performing the conventional core analysis for porosity and permeability of the fractured core plug sample, and determining a total porosity and a total permeability sensitivity to stress for the fractured core plug sample at the pressure conditions;
determining a fracture porosity for the fractured core plug sample based on the matrix porosity and the total porosity;
determining a fracture permeability sensitivity to stress for the fractured core plug sample based on the matrix permeability sensitivity to stress and the fracture permeability sensitivity to stress;
obtaining a borehole image log interpreted by using an electrical imaging tool;
determining a plurality of fracture features for the subsurface formation by performing aperture calculations of the subsurface formation using the borehole image log;
determining a geomechanical model and one or more fracture drivers for the fractured core plug sample based on the plurality of fracture features and the fracture porosity;
performing, using the geomechanical model and the one or more fracture drivers, fracture model predictions for a plurality of discrete fracture network realizations to determine a fracture porosity model associated with the subsurface formation;
calculating a fracture pore volume in the subsurface formation based on the fracture porosity model and a rock bulk volume associated with the subsurface formation; and
estimating oil gas reserves in the subsurface formation based on the fracture pore volume.
2. The method of claim 1 , further comprising:
fracturing the core plug sample by tensile axial load following the standard ASTM D3967-08.
3. The method of claim 2 , further comprising deriving fracture porosity by subtracting the matrix porosity from the total porosity.
4. The method of claim 3 , wherein the step of analyzing borehole image logs further comprises:
determining fracture intensity based on a calibration of the borehole image log and aperture calculation.
5. The method of claim 3 , wherein the step of developing the geomechanical model and one or more fracture drivers further comprises:
determining a rock brittleness property of the core plug sample;
performing a paleo-stress analysis on the core plug sample;
developing a stress regime model; and
performing a critical stress analysis on the core plug sample.
6. The method of claim 1 , wherein the core plug sample is extracted from a subsurface formation comprising at least one of shale, limestone, and sandstone.
7. The method of claim 1 , wherein the plurality of fracture features comprise natural fracture type, dip angle, dip azimuth, and intensity along of a wellbore.
8. The method of claim 1 , further comprising:
determining the geomechanical model by applying geomechanics numerical simulation using finite and boundary elements geomechanics simulation methods.
9. The method of claim 1 , wherein the plurality of discrete fracture network realizations comprise a well-test analysis, an optimization algorithm, a mechanical earth model, discrete fracture network, critical stress analysis, determining fluid flow paths, and scaling up for fractures.
10. The method of claim 1 , wherein the plurality of discrete fracture network realizations are performed based on the plurality of fracture features for the fractured core plug sample, the fracture porosity for the fractured core plug sample, and the fracture permeability sensitivity to stress for the fractured core plug sample.
11. The method of claim 1 , wherein the plurality of discrete fracture network realizations are optimized to reduce a difference between a predicted flow capacity and a measured flow capacity.
12. The method of claim 11 , wherein:
the measured flow capacity comprises a flow capacity from a pressure transient analysis (KHPTA), and
the predicted flow capacity comprises a total flow capacity which is a sum of a flow capacity associated with fractures (Fractures KHFract-simulate), a flow capacity associated with High Permeability Streak (High Permeability Streak KHHPS), and a flow capacity associated with matrix (Matrix KHFacim).