An in-situ stress measurement method is provided. The method includes measuring a length of a maximum diameter at which an amount of distortion relative to a diameter of a standard circle of a measurement cross section of a boring core is largest and a length of a minimum diameter at which the amount of distortion relative to the diameter of the standard circle is smallest based on a shape of the measurement cross section of the boring core; measuring a length of a diameter in a vertical direction and a length of a diameter in a horizontal direction of the measurement cross section of a side-wall core acquired by hollowing ground in a well in an excavation direction thereof, based on a shape of the measurement cross section of the side-wall core; and calculating a maximum horizontal stress and a minimum horizontal stress by first and second equations.

A coring tool includes a coring bit to cut and detach a core sample from a subsurface formation formed in a borehole. The coring tool includes a pressure vessel that includes a core chamber to store the core sample at a pressure and a piston positioned adjacent to the core chamber. The pressure vessel includes a chamber adjacent to the piston and a gas reservoir to store a gas that expands as the gas is moved to a surface of the borehole. The pressure vessel includes a valve coupled to an inlet of the chamber and an outlet of the gas reservoir, wherein the gas is to flow into the chamber when the valve is open to move the piston to cause an increase in the pressure of the core chamber.

A coring tool includes a coring bit to cut and detach a core sample from a subsurface formation formed in a borehole. The coring tool includes a pressure vessel that includes a core chamber to store the core sample at a pressure and a piston positioned adjacent to the core chamber. The pressure vessel includes a chamber adjacent to the piston and a gas reservoir to store a gas that expands as the gas is moved to a surface of the borehole. The pressure vessel includes a valve coupled to an inlet of the chamber and an outlet of the gas reservoir, wherein the gas is to flow into the chamber when the valve is open to move the piston to cause an increase in the pressure of the core chamber.

A system for generating artificial permeability during the completion phase may include sensors that capture real-time data pertaining to a reservoir parameter, a formation parameter, or a tool condition parameter. The system may also include a drilling tool arranged in a wellbore to drill, using side drill bits, paths into a formation zone based on a drilling program. The system may also include an access module to access the real-time data captured by the sensors inside the well. The system may also include one or more processors configured to arrange the drilling tool in the wellbore, in proximity to the formation zone. The one or more processors may also be configured to cause an operation of the drilling tool based on the drilling program, update the drilling program based on the real-time sensor data, and cause an adjustment of the drilling of the paths based on the updated drilling program.

A system for generating artificial permeability during the completion phase may include sensors that capture real-time data pertaining to a reservoir parameter, a formation parameter, or a tool condition parameter. The system may also include a drilling tool arranged in a wellbore to drill, using side drill bits, paths into a formation zone based on a drilling program. The system may also include an access module to access the real-time data captured by the sensors inside the well. The system may also include one or more processors configured to arrange the drilling tool in the wellbore, in proximity to the formation zone. The one or more processors may also be configured to cause an operation of the drilling tool based on the drilling program, update the drilling program based on the real-time sensor data, and cause an adjustment of the drilling of the paths based on the updated drilling program.

A method for predicting a total minimum horizontal stress (σ.sub.h) and a total maximum horizontal stress (σ.sub.H) for an anisotropic formation may comprise: measuring Young's moduli parallel ±15° and perpendicular ±15° to a transverse isotropy plane of a horizontal core sample from the anisotropic subterranean formation; measuring Poisson's ratios parallel ±15° and perpendicular ±15° to the transverse isotropy plane of the horizontal core sample; inputting the measured Young's moduli and Poisson's ratios of the horizontal core sample into a 1-dimensional mechanical earth model (1-D MEM); and calculating, using the 1-D MEM, a predicted total minimum horizontal stress (σ.sub.h) and a predicted total maximum horizontal stress (σ.sub.H).

A method for predicting a total minimum horizontal stress (σ.sub.h) and a total maximum horizontal stress (σ.sub.H) for an anisotropic formation may comprise: measuring Young's moduli parallel ±15° and perpendicular ±15° to a transverse isotropy plane of a horizontal core sample from the anisotropic subterranean formation; measuring Poisson's ratios parallel ±15° and perpendicular ±15° to the transverse isotropy plane of the horizontal core sample; inputting the measured Young's moduli and Poisson's ratios of the horizontal core sample into a 1-dimensional mechanical earth model (1-D MEM); and calculating, using the 1-D MEM, a predicted total minimum horizontal stress (σ.sub.h) and a predicted total maximum horizontal stress (σ.sub.H).

An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators.

An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators.

A downhole tool comprising, a coring module for obtaining at least one rotary core sample from a formation, a core storage module for storing the at least one rotary core sample and connected to the coring module, and a motor module for moving the at least one rotary core sample from the coring module to the core storage module and wherein the motor module is connected to the coring module. Additionally, the downhole tool may comprise a first, second, and third sensing modules configured to take measurements of the core sample.