Method to determine poromechanical properties of fluid-saturated rock
Systems and methods are disclosed. The method includes obtaining well data for a fluid-saturated rock and obtaining a poroelastodynamic relationship linking a deformation of the fluid-saturated rock to a poromechanical property of the fluid-saturated rock. The method further includes determining the poromechanical property of the fluid-saturated rock by applying a vector operator to the poroelastodynamic relationship. The method still further includes determining a value of the poromechanical property by substituting the well data into the vector-operated poroelastodynamic relationship.
1 . A method comprising:
obtaining well data for a fluid-saturated rock;
obtaining a poroelastodynamic relationship linking a deformation of the fluid-saturated rock to a poromechanical property of the fluid-saturated rock;
determining the poromechanical property of the fluid-saturated rock by applying a vector operator to the poroelastodynamic relationship;
determining a value of the poromechanical property by substituting the well data into the vector-operated poroelastodynamic relationship; and
determining a hydraulic fracturing process using the value of the poromechanical property; and
fracturing the fluid-saturated rock within a subterranean region of interest based on the hydraulic fracturing process.
2 . The method of claim 1 , further comprising:
determining a well trajectory plan using the value of the poromechanical property.
3 . The method of claim 1 , wherein the well data comprises a sonic log.
4 . The method of claim 1 , wherein the fluid-saturated rock comprises sandstone.
5 . The method of claim 1 , wherein the fluid-saturated rock comprises hydrocarbons.
6 . The method of claim 1 , wherein the deformation comprises a change in length.
7 . The method of claim 1 , wherein the poromechanical property comprises Biot's modulus.
8 . The method of claim 1 , wherein the vector operator comprises curl.
9 . The method of claim 1 , wherein the poroelastodynamic relationship is governed by Biot's theory of linear poroelastodynamics.
10 . The method of claim 1 , wherein determining the poromechanical property further comprises:
neglecting a first term within the vector-operated poroelastodynamic relationship; and
assuming a second term within the vector-operated poroelastodynamic relationship.
11 . The method of claim 1 , wherein the vector-operated poroelastodynamic relationship links a wave phase velocity to the poromechanical property of the fluid-saturated rock.
12 . A system comprising:
a well logging system to obtain well data for a fluid-saturated rock;
a computer processor configured to:
receive the well data;
receive a poroelastodynamic relationship linking a deformation of the fluid-saturated rock to a poromechanical property of the fluid-saturated rock;
determine the poromechanical property of the fluid-saturated rock by applying a vector operator to the poroelastodynamic relationship;
determine a value of the poromechanical property by substituting the well data into the vector-operated poroelastodynamic relationship; and
determine a hydraulic fracturing process using the value of the poromechanical property; and
a hydraulic fracturing system configured to fracture the fluid-saturated rock within a subterranean region of interest based on the hydraulic fracturing process.
13 . The system of claim 12 , further comprising a seismic interpretation workstation to determine a well trajectory plan using the value of the poromechanical property.
14 . The system of claim 12 , wherein the well logging system comprises a sonic logging system.
15 . The system of claim 12 , wherein the well logging system comprises a gamma ray logging system.
16 . The system of claim 12 , wherein the well logging system comprises a density logging system.