Formation breakdown pressure near wellbores

1 . A computer-implemented method, comprising:

receiving input parameters for computing a breakdown pressure for a wellbore in a formation, the input parameters comprising an inclination angle of the wellbore from a vertical axis, and an azimuth angle of the wellbore relative to a maximum horizontal stress direction, at a particular depth;

determining, during hydraulic fracturing operations, a pore pressure for the wellbore based on a time duration, an injection fluid compressibility, and a poroelastic parameter;

determining a poroelastic stress for the wellbore using a poroelastic stress equation and based on the pore pressure determined for the wellbore, an empirical parameter, a pore pressure, the poroelastic parameter, a tensile strength of rock, and a Poisson ratio;

determining, during the hydraulic fracturing operations, a breakdown pressure upper bound for the wellbore based on a minimum horizontal stress and a maximum horizontal stress for the wellbore, an overburden vertical stress for the wellbore, the inclination angle of the wellbore, the azimuth angle of the wellbore, and a wellbore circumferential angle;

applying, during the hydraulic fracturing operations, a stress correction on the breakdown pressure upper bound for the wellbore based on whether the wellbore is an open hole wellbore or a cemented liner wellbore, to generate a stress-corrected upper bound breakdown pressure for the wellbore;

determining, during the hydraulic fracturing operations, the breakdown pressure for the wellbore based on the stress-corrected upper bound breakdown pressure for the wellbore, the poroelastic stress for the wellbore, and the pore pressure for the wellbore;

determining, based at least on the breakdown pressure, a horsepower level for creating a fracture geometry used in the hydraulic fracturing operations;

determining a successful placement of stimulation materials for the hydraulic fracturing operations;

determining, based at least on the breakdown pressure, a pressure rating of tubulars required for fracturing treatment; and

completing the hydraulic fracturing operations using the horsepower level, the successful placement of the stimulation materials, and one or more tubulars having the pressure rating of the tubulars required for the fracturing treatment.

2 . The computer-implemented method of claim 1 , wherein determining the pore pressure for the wellbore comprises:

determining the pore pressure for the wellbore using a Stehfest method equation that is a function of the time duration, a distance from the wellbore in a radial direction, the injection fluid compressibility, and the poroelastic parameter.

3 . The computer-implemented method of claim 2 , wherein the Stehfest method equation further comprises a modified Bessel function of a second kind of order 0.

4 . The computer-implemented method of claim 1 , wherein determining the poroelastic stress is further based on a Composite Simpson's Rule for numerical integration.

5 . The computer-implemented method of claim 1 , wherein the input parameters further comprise an initial wellbore pressure, a rock permeability, a rock porosity, the injection fluid compressibility, an injection fluid viscosity, the Poisson ratio, a wellbore radius, and a distance from the wellbore in a radial direction, at the particular depth.

6 . The computer-implemented method of claim 5 , wherein an initial value for the distance from the wellbore in the radial direction is two and a half the wellbore radius.

7 . The computer-implemented method of claim 1 , wherein the wellbore is one of: (i) a deviated wellbore, or (ii) a vertical wellbore.

8 . The computer-implemented method of claim 1 , wherein an initial value for the time duration is a time at which the formation is expected to break after a slurry injection.

9 . The computer-implemented method of claim 1 , wherein an initial value for the time duration is 1000 seconds.

10 . The computer-implemented method of claim 1 , wherein the wellbore is either open hole or cement lined.

11 . A system comprising:

one or more processors configured to perform operations comprising:

receiving input parameters for computing a breakdown pressure for a wellbore in a formation, the input parameters comprising an inclination angle of the wellbore from a vertical axis, and an azimuth angle of the wellbore relative to a maximum horizontal stress direction, at a particular depth;

determining, during hydraulic fracturing operations, a pore pressure for the wellbore based on a time duration, an injection fluid compressibility, and a poroelastic parameter;

determining a poroelastic stress for the wellbore using a poroelastic stress equation and based on the pore pressure determined for the wellbore, an empirical parameter, a pore pressure, the poroelastic parameter, a tensile strength of rock, and a Poisson ratio;

determining, during the hydraulic fracturing operations, a breakdown pressure upper bound for the wellbore based on a minimum horizontal stress and a maximum horizontal stress for the wellbore, an overburden vertical stress for the wellbore, the inclination angle of the wellbore, the azimuth angle of the wellbore, and a wellbore circumferential angle;

applying, during the hydraulic fracturing operations, a stress correction on the breakdown pressure upper bound for the wellbore based on whether the wellbore is an open hole wellbore or a cemented liner wellbore, to generate a stress-corrected upper bound breakdown pressure for the wellbore;

determining, during the hydraulic fracturing operations, the breakdown pressure for the wellbore based on the stress-corrected upper bound breakdown pressure for the wellbore, the poroelastic stress for the wellbore, and the pore pressure for the wellbore;

determining, based at least on the breakdown pressure, a horsepower level for creating a fracture geometry used in the hydraulic fracturing operations;

determining a successful placement of stimulation materials for the hydraulic fracturing operations;

determining, based at least on the breakdown pressure, a pressure rating of tubulars required for fracturing treatment; and

completing the hydraulic fracturing operations using the horsepower level, the successful placement of the stimulation materials, and one or more tubulars having the pressure rating of the tubulars required for the fracturing treatment.

12 . The system of claim 11 , wherein determining the pore pressure for the wellbore comprises:

determining the pore pressure for the wellbore using a Stehfest method equation that is a function of the time duration, a distance from the wellbore in a radial direction, the injection fluid compressibility, and the poroelastic parameter.

13 . The system of claim 12 , wherein the Stehfest method equation further comprises a modified Bessel function of a second kind of order 0.

14 . The system of claim 11 , wherein determining the poroelastic stress is further based on a Composite Simpson's Rule for numerical integration.

15 . The system of claim 11 , wherein the input parameters further comprise an initial wellbore pressure, a rock permeability, a rock porosity, the injection fluid compressibility, an injection fluid viscosity, the Poisson ratio, a wellbore radius, and a distance from the wellbore in a radial direction, at the particular depth.

16 . A non-transitory computer storage medium encoded with instructions that, when executed by one or more computers, cause the one or more computers to perform operations comprising:

receiving input parameters for computing a breakdown pressure for a wellbore in a formation, the input parameters comprising an inclination angle of the wellbore from a vertical axis, and an azimuth angle of the wellbore relative to a maximum horizontal stress direction, at a particular depth;

determining, during hydraulic fracturing operations, a pore pressure for the wellbore based on a time duration, an injection fluid compressibility, and a poroelastic parameter;

determining a poroelastic stress for the wellbore using a poroelastic stress equation and based on the pore pressure determined for the wellbore, an empirical parameter, a pore pressure, the poroelastic parameter, a tensile strength of rock, and a Poisson ratio;

determining, during the hydraulic fracturing operations, a breakdown pressure upper bound for the wellbore based on a minimum horizontal stress and a maximum horizontal stress for the wellbore, an overburden vertical stress for the wellbore, the inclination angle of the wellbore, the azimuth angle of the wellbore, and a wellbore circumferential angle;

applying, during the hydraulic fracturing operations, a stress correction on the breakdown pressure upper bound for the wellbore based on whether the wellbore is an open hole wellbore or a cemented liner wellbore, to generate a stress-corrected upper bound breakdown pressure for the wellbore;

determining, during the hydraulic fracturing operations, the breakdown pressure for the wellbore based on the stress-corrected upper bound breakdown pressure for the wellbore, the poroelastic stress for the wellbore, and the pore pressure for the wellbore;

determining, based at least on the breakdown pressure, a horsepower level for creating a fracture geometry used in the hydraulic fracturing operations;

determining a successful placement of stimulation materials for the hydraulic fracturing operations;

determining, based at least on the breakdown pressure, a pressure rating of tubulars required for fracturing treatment; and

completing the hydraulic fracturing operations using the horsepower level, the successful placement of the stimulation materials, and one or more tubulars having the pressure rating of the tubulars required for the fracturing treatment.

17 . The non-transitory computer storage medium of claim 16 , wherein determining the pore pressure for the wellbore comprises:

determining the pore pressure for the wellbore using a Stehfest method equation that is a function of the time duration, a distance from the wellbore in a radial direction, the injection fluid compressibility, and the poroelastic parameter.