A method of evaluating a stress state of a wellbore isolation barrier with an evaluation application receiving a data set, obtained from wellbore sensors, from a remote data source by one or more communication methods. The data set comprises periodic wellbore data indicative of the stress state of the wellbore isolation barrier. The evaluation application may determine a modeled stress state of the wellbore isolation barrier by evaluating a data set consisting of the received data. The evaluation application may generate an alert if the model stress state exceeds a user threshold.

A method of determining maximum stress in a well drilled in a reservoir, primarily a hydrocarbon reservoir, where there is at least one zone. Collapse regions are produced while drilling a well because the material of the wall of the well exceeds its maximum allowable stress, the material fractures and falls off, leaving a cavity. The caliper of the damaged zone is measured by devices that extend radially until coming into contact with the physical wall of the well. The disclosed method determines the maximum allowable stress based on the caliper measurements and other variables which are determinable.

Provided herein are systems and methods for hydraulic fracturing in earth. Systems may comprise a first well comprising sensors configured to collect sensor data at the first well. The calibration data may comprise sensor data, hydraulic fracture treatment conditions of the first well, geological data from an area containing the first well, or production date of oil or gas from the first well. The calibration data may be analyzed with the aid of one or more processors to generate an integrated 3-D model of hydraulic fracturing and fluid flow in the wellbore and reservoir of the first well. The system may further comprise a second well configured to operate according to simulation data generated from the integrated 3-D model of the first well and hydraulic fracture treatment conditions received from a user device. The user device may be configured to communicate with a server comprising the one or more processors.

A method for enhancing wellbore integrity and/or for sealing a wellbore by sealing formation or micro-annulus fractures in a wellbore. Such sealing can be at least partially accomplished by the use of timed expansion of an expandable sealant material that is placed a wellbore. The expansion of the expandable sealant material causes the cement surface or formation surface to be compressed, thereby creating a tight seal and/or eliminating annulus cracking, fracture, and/or gas channels in the wellbore. A degradable polymer can be used when restoration of the wellbore formation is desired.

The present invention discloses a sensing-acquisition-wireless transmission integrated microseismic monitoring system, comprising a sensing unit, wherein the system further comprises an acquisition-wireless transmission unit. The acquisition-wireless transmission unit comprises a flameproof enclosure, an acquisition instrument, a battery, a wireless transmitter and a transmitting antenna. A push nut is arranged at an open end of the flameproof enclosure. A support stage is sheathed on an outer wall of the flameproof enclosure. A connection ring is movably sheathed on the open end of the flameproof enclosure. The push nut is connected to the connection ring. Multiple inner wing elastic plates are circumferentially arranged on the connection ring. The inner wing elastic plates are connected to corresponding expandable plate outer wings, respectively. The present invention further discloses a sensing-acquisition-wireless transmission integrated microseismic monitoring method.

A tool assembly and method are for performing formation stress testing in an openhole section of a borehole, wherein the openhole section of the borehole is to be provided with, or already have been provided with, a perforation tunnel generated by a series of electrically induced focused acoustic shock waves. The tool assembly has at least two borehole isolation means arranged with an axial distance therebetween for forming an isolated section at the openhole section of the borehole; a pump device for altering a pressure within the isolated section; a pressure sensor for measuring a pressure within the isolated section; a control unit for controlling a testing sequence; an acoustic shock wave device for generating the series of acoustic shock waves to excavate the perforation tunnel; and an acoustic shock wave sub for actuating the acoustic shock wave device.

An auto-collapsible pore pressure probe device, including a support system, a penetration system and a measurement system. The support system includes a first support frame, a second support frame, a separation mechanism, a ring clamp, a fixing nut, a fixing bolt, support legs, slots, a support base, and a third support frame. The penetration system includes a rod storage wheel, a motor, a tightening mechanism, a penetration drive motor, a gear, a fixing bracket, a fixing bolt, and a friction wheel. The measurement system includes a pore pressure probe, a control cabinet, a CPTU probe, a pore pressure sensor, a probe connector, an external thread, an internal thread, a fastening strip, a connecting bolt, a connector, a data transmission and power supply cable, a displacement sensor, and a deck unit. An operating method of the pore pressure probe device is also provided.

A method for optimizing borehole drilling by a drill string having a drill bit at a rotated and axially urged to drill formations includes measuring a parameter related to at least axial and torsional motion of a drill string propagating as elastic waves at a selected position along the drill string. An axial force exerted by the drill bit and torque applied to the drill bit are determined from the measurements related to at least axial and torsional motion. A confined compressive strength of the formations is determined from the measurements related to at least axial and torsional motion. At least one of the determined axial force and the determined torque is adjusted such that a mechanical specific energy applied to the formation is closest in value to the confined compressive strength.

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 subsurface representation that includes geometry and material properties of subsurface geological formations may be generated. To compute the initial (pre-production) state of stress, gravitational forces and tectonic forces may be applied to the subsurface representation. These loads may result in stress and displacement fields within the subsurface representation. The stress field may be calibrated against available measurements. At this point, the subsurface representation may be reinitialized by resetting the displacements within the subsurface representation while maintaining the stress field.