The disclosed embodiments include a method, apparatus, and computer program product configured to performing automated downhole wellbore trajectory control for correcting between an actual wellbore trajectory path and a planned wellbore trajectory path. For example, in one embodiment, a PID controller is configured to obtain real-time data gathered during the drilling operation, determine whether the actual wellbore trajectory path deviates from the planned wellbore trajectory path, and automatically initiate the downhole wellbore trajectory control to change the actual wellbore trajectory path to a modified correction path that is determined using a minimum incremental wellbore energy method.

A resistivity measuring tool used in a drillstring having a drill bit on a distal end for drilling a wellbore in a formation includes a tool body having a longitudinal axis, a transmitting antenna, and a receiving antenna. The receiving antenna includes an antenna body having a longer axis disposed longitudinally in the tool body, and a wire coil having a central axis disposed around the antenna body, wherein the wire coil central axis is substantially perpendicular to the longer axis of the antenna body, and wherein the wire coil is configured to generate a magnetic moment orthogonal to the tool body longitudinal axis. The transmitting antenna is configured to transmit electromagnetic energy into the formation and induce a voltage signal related to a parameter of the formation in the receiving antenna.

A method for drilling a subterranean wellbore includes deploying a drill string in the wellbore, the drill string including a drill bit and a steerable drilling motor. The drill string is automatically rotated at the surface back and forth between first and second opposing rotational directions, rotating in the first direction until a first torque limit is exceeded and rotating in the second direction until a second torque limit is exceeded. A toolface of the steerable drilling motor and a differential pressure across the steerable drilling motor are measured while automatically rotating the drill string. A surface processor processes the measured toolface and differential pressure in combination with a target toolface and a target differential pressure to compute new first and second torque limits. The automatic rotating is repeated using the new first and second torque limits.

An example system for a well includes a tubing string including spoolable, flexible, coiled tubing to transport fluids within the well; a packer associated with the tubing string to provide an annular seal to a section of a wellbore of the well; a power generator associated with the tubing string to generate power for the system based on fluid flow within the well; a wireless communication device associated with the tubing string to exchange information with one or more components of the system; one or more sensors associated with the tubing string to sense one or more environmental conditions in the well; one or more processing devices associated with the tubing string to generate at least some of the information based on the one or more environmental conditions; and one or more inflow control valves to control a rate of fluid flow into the system.

Methods, computing systems, and computer-readable media for interpreting drilling dynamics data are described herein. The method can include receiving drilling dynamics data simulated by a processor or collected by a sensor positioned in a drilling tool. The method can further include extracting a feature map from the drilling dynamics data, and determining that a feature zone from the feature map corresponds to a predetermined dynamic state. The feature zone can be determined using a neural network trained to associate feature zones with dynamic states. Additionally, the method can include selecting a drilling parameter for a drill string based on the feature zone.

A method for assessing reliability of an electronic component under downhole vibration conditions include designing a set of vibration test conditions and conduct failure analysis. The vibration test conditions include the natural vibration frequency, the overstress limit of the test vehicle, and the step stress profile for testing the test vehicle. The failure analysis of the failed electronic component includes the step of measuring an electrical resistance of the failed electronic component without a vibration load. When the electrical resistance of the failed electronic component remains large, the failed electronic component is cross-sectioned. Finally, the cross-sectioned electronic component is examined to identify a failure mode.

Systems and methods for fracturing operations include initiating pumping of a fracturing fluid into a target well according to one or more fracturing operation parameters, the target well extending through a subterranean formation. Subsequent to initiating pumping of the fracturing fluid into the target well, a response of a monitor well extending through the subterranean formation is detected, the monitor well including a sealed monitoring portion. The sealed monitoring portion is substantially filled with a liquid such that the response results from interactions between the sealed monitoring portion and a fracture extending from the target well. The method further includes modifying at least one of the one or more fracturing operation parameters in response to detecting the response of the monitor well.

A directional drilling system includes a rotary steerable tool. The rotary steerable tool includes an extendable member configured to extend outwardly from the rotary steerable tool upon actuation, and a geolocation electronics device configured to track a position of the rotary steerable tool and the extendable member and control actuation of the extendable member. The geolocation electronics device and extendable member are configured to rotate with the rotary steerable tool.

A control method for using a core drilling system is disclosed. In an embodiment the method includes detecting a predetermined drilling situation on the basis of the attainment of a predetermined threshold value for at least one predetermined corresponding drilling parameter and ending the core drilling operation by selecting a reverse-travel mode for removing the drilling tool from the borehole if the advancing device does not reach a predetermined threshold value for a predetermined corresponding distance value in a direction and the core drilling machine does not reach a predetermined threshold value for at least one predetermined corresponding drilling parameter or continuing the core drilling operation by selecting a predetermined operating mode if the advancing device reaches a predetermined threshold value for a predetermined corresponding distance value in a direction and the core drilling machine reaches a predetermined threshold value for at least one predetermined corresponding drilling parameter.

A while drilling mud loss treatment method includes providing a drilling tool main body with a through bore connected to an above arranged wired drill pipe string with a communication line to a topsides monitoring and control system, the drilling tool main body connected to a below arranged one or more drill collar sections with a lower of said drill collar sections connected to a drill bit, and drilling in a well. The main body is provided with an annular tank with a swellable sealant and the annular tank has a valve to an outlet to the through bore. A control system in the main body receives MWD sensor signals from an MWD sensor system and controls the valve having a valve actuator. The control system is, during drilling, running a monitoring and control algorithm using the signals as input for detecting an undesired mud loss state during drilling, and, if a mud loss state is detected, to command said valve actuator to open said valve upon detecting an undesired mud loss state, so as for ejecting said swellable sealant to said through bore.