Abstract: A method for designing, monitoring, and updating a trajectory of a wellbore at a wellsite. The method includes receiving a plurality of inputs related to the trajectory for the wellbore. The inputs may include a starting point of the trajectory. A zone may be defined within a subsurface beneath the wellsite as safe. The method further includes defining a first set of control points within the zone of the subsurface, and generating a proposed path of the trajectory by connecting the starting point of the trajectory to a plurality of trajectory targets via the first set of control points. The method also includes validating that the proposed path of the trajectory is within the zone of the subsurface.

Abstract: A method for drilling includes rotating a BHA in a wellbore. Triaxial accelerometer and triaxial magnetometer measurements are made while rotating the BHA using corresponding triaxial accelerometer and triaxial magnetometer sets that are deployed in a roll-stabilized housing. Magnetic dip angles are computed from the accelerometer and magnetometer measurements using an inclination independent model. The computed dip angles are compared with a reference magnetic dip angle and a magnetometer bias is selected that minimizes a difference between the computed magnetic dip angles and the reference magnetic dip angle.

Abstract: Techniques for controlling a trajectory of a mud motor directional drill. A system receives one or more inputs pertaining to constraints for a wellbore in a mud motor drilling operation. The system constructs, as a function of the one or more inputs, a discretized well depth horizon. One or more binary slide and rotate commands for controlling a directional drill within the wellbore is generated based on an analysis of the discretized well depth horizon. The system controls the directional drill according to the one or more binary slide and rotate commands.

Abstract: A wellhead landing, locking and sealing detection system may receive an acoustic signal from at least one acoustic sensor located on an outer surface of a wellhead. A wellhead landing, locking and sealing detection system may process the acoustic signal resulting in a processed acoustic signal. Processing the acoustic signal may include normalizing the acoustic signal, smoothing the acoustic signal, and differentiating a background signal from the acoustic signal. A wellhead landing, locking and sealing detection system may select a portion of the processed acoustic signal. A wellhead landing, locking and sealing detection system may identify a reflection characterization, frequency or profile from the portion. A wellhead landing, locking and sealing detection system may, based on the reflection characterization, frequency or profile, identifying a landing, locking and sealing configuration of the equipment with the wellhead.

Abstract: A method may include drilling a portion of a borehole with a bottomhole assembly (BHA) including the downhole tool in an automated drilling routine. A method may include receiving, at a control unit of the BHA, a disengagement downlink communication having a disengagement magnitude and disengagement duration. A method may include, based at least partially on the disengagement downlink communication, disengaging the automated drilling routine.

Abstract: Methods may include obtaining a preprocessed observed geophysical dataset based on an observed geophysical dataset of the subterranean region of interest and forming a training dataset composed of a geophysical training models and corresponding simulated geophysical training datasets. The methods may further include iteratively determining a simulated geophysical dataset from a current geophysical model, determining a data loss function between the preprocessed observed geophysical dataset and the simulated geophysical dataset, and training a machine learning (ML) network, using the training dataset, to predict a predicted geophysical model. The methods may still further include determining a model loss function between the current and predicted geophysical models and updating the current geophysical model based on an inversion using the data loss and model loss functions.

Abstract: This invention relates to a mechanical hydraulic torque converter for horizontal well drilling, and belongs to the technical field of oil and gas drilling tools. The hydraulic torque converter includes a driving shaft, an upper-shell, a driving shaft positioning shell, a TC bearing assembly, a universal shaft shell, a universal shaft assembly, a stator shell, a hollow rotor, a middle-shell, a torque separation assembly, a lower connector, and a confluence assembly. The universal shaft assembly is mounted in the universal shaft outer shell, and two ends of the universal shaft assembly are respectively connected with the driving shaft and the hollow rotor. One end of the confluence assembly is connected with the torque separation assembly, and the other end of the confluence assembly is communicated with an outlet of the lower connector. The tool is jointly driven by the rotating speed of upper drill string and drilling fluid displacement.

Abstract: Certain aspects of the present disclosure provide techniques for downlink control information (DCI). A method that may be performed by a cooperative user equipment (UE) includes receiving configuration information for receiving control information associated with a target UE, receiving, based on the configuration information, the control information associated with the target UE, and forwarding the received control information to the target UE.

Abstract: A well drilling device for undersea in-situ exploitation of a natural gas hydrate is provided. The well drilling device includes a well drilling module, wherein the well drilling module includes a frame, a portal framed lead rail and a manipulator are mounted in the frame, a lower hydraulic tong is mounted at the bottom of the frame, an upper hydraulic tong is arranged coaxially above the lower hydraulic tong, and a coaxial space between the upper hydraulic tong and the lower hydraulic tong is a drilling column placement position; the upper hydraulic tong is mounted in a top drive, and the top drive is assembled in the portal framed lead rail to move vertically in a vertical direction of the portal framed lead rail; and a pipe rack is arranged in a rotation range of the manipulator, and is configured to store and place a drilling column.

Abstract: Systems and methods presented herein facilitate automation of coiled tubing drilling (CTD) operations. For example, a computer-implemented method includes performing a drilling operation via a CTD system; detecting data relating to one or more operating parameters of the drilling operation via one or more sensors of the CTD system during the drilling operation; and automatically adjusting at least one adjustable operating parameter of the drilling operation based on the detected data during the drilling operation.

Abstract: A pitch data processing system of a horizontal directional drilling system can include a sonde, an offset and range calibration unit, a pitch speed limiter, and a low pass filter. The sonde can include an accelerometer configured to measure and output a raw pitch signal. The offset and range calibration unit can receive and process the raw pitch signal and output a calibrated pitch signal. The pitch speed limiter can receive the calibrated pitch signal. The pitch speed limiter is configured to set upper and lower pitch change speed limits. The pitch speed limiter can yield a speed-change limited pitch signal. The low pass filter can receive the speed-change limited pitch signal and attenuate the received speed-change limited pitch signal above a selected cutoff frequency of the low pass filter, the low pass filter configured to output an adjusted pitch signal.

Abstract: An orienting interface for alignment of a profile feature with a window of a tubular for installation at a junction of a multilateral well. The interface includes the coupling of an orienting device that accommodates the profile with an anchoring segment of the tubular. This coupling takes place with fasteners through selectively aligned openings in each of the device and the segment. More specifically, the openings in the anchoring segment differ in number from that of the orienting device so as to prevent a tailored resolution for alignment between the profile and the window.

Abstract: A system may obtain azimuth and inclination measurements from a downhole tool in a downhole environment. A system may obtain a downhole ROP and downhole DLS from a downhole control unit. A system may determine a corrected DLS demand based at least partially on a ratio of downhole ROP and surface ROP. A system may transmit a DLS demand setting to the downhole tool based at least partially on the corrected DLS demand and the downhole ROP. A system may drill at least a portion of a borehole with the downhole tool based at least partially on the corrected DLS demand.

Abstract: Methods, devices and systems are disclosed for magnetically ranging while drilling with a coiled tubing unit or drill pipe by way of a an electrically conducive but environmentally electrically insulated wire installed through a coiled tubing spool or drill pipe complete with electrically insulative subs in the coiled tubing bottom hole assembly or drill pipe. The method and systems allow for the injection of excitation current into the formation by way of selectively electrifying various drill stem components, thereby facilitating current collection on a target tubular which radially emanates a magnetic field about the target well tubular(s). The method and devices allow for the construction of complex downhole current injection configurations which allow for modification of the bottom hole assembly to maximize target well signal generation in the presence of adverse environmental conditions.

Abstract: Embodiments of the present disclosure relate to an apparatus, a system, and a method for detecting and indicating the position of an actuator of wellsite equipment. The apparatus comprises a housing, the housing comprising a first housing portion operatively coupleable to the actuator and a second housing portion configured to receive at least one sensor therewithin. The at least one sensor provides an output signal indicative of the position of the actuator. The position of the actuator is indicative of a valve position.

Abstract: An apparatus and method for electromagnetic heating of a hydrocarbon formation. The method involves providing a producer well, which defines a longitudinal axis, between at least a first and second transmission line conductor. At a reference location along the length of the longitudinal axis, the first and second transmission line conductors are laterally spaced from the producer well by a first and second reference distance, respectively. At a second location, the first and second transmission line conductors are laterally spaced from the producer well by a third and fourth distance, respectively. At least one of the third and fourth distances are greater than the first and second reference distances, respectively. Excitation of the transmission line conductors generates an electromagnetic field having a reference shape and a reference position at the reference location and at least one of a more elongated shape and a different position at the second location.

Abstract: An apparatus and method are used in conjunction with a system for performing horizontal directional drilling, the system including a drill string extending from a drill rig to a boring tool such that the boring tool is steerable based on a roll orientation. The system also includes an arrangement for generating steering commands for guiding the boring tool to a target position. Responsive at least in part to the steering commands, a display is configured to selectively indicate each of a rotate command, a push command and a spin command. A steering indicator is described which indicates a current roll orientation of the boring tool. A 3-D grid can be animated and centered on either a steering or target indicator. Rounding of a steering command ratio can limit the display of target roll orientations to only those that a given boring tool transmitter is capable of sensing and indicating.

Abstract: The disclosed embodiments include systems and methods to perform automated drilling for both surface and downhole control. The method includes receiving a curvature reference set point, and calculating a curvature error with respect to the curvature reference set point. The method also includes providing the curvature error to a linear matrix inequalities based robust linear quadratic regulator controller. The method further includes determining one or more steering commands based on an output of the linear matrix inequalities based robust linear quadratic regulator controller. The method further includes providing the one or more steering commands to be implemented by a drilling tool during a drilling operation.

Abstract: A downhole signal generation system may include a main housing, a spring, and a valve plug configured to move along a central bore of the main housing between an open position and a closed position to selectively block fluid flow through the main housing. The downhole signal generation system may further include a ball housing insert with a ball slot and a ball release collar disposed about the ball housing insert. The downhole signal generation system may also include a latching feature configured to secure the valve plug to the ball housing insert with the ball release collar in a holding position, and to release the valve plug in response to the ball release collar moving to the release position. Moreover, the spring may be configured to drive the valve plug from the open position to the closed position in response to the latching feature releasing the valve plug.

Abstract: A system for tracking an underground object. An above-ground tracking device has an antenna array located at a terminal end. The antenna array can determine a location of the underground object based upon the direction and magnitude of a magnetic field emanating from that object. The tracking device is registrable with a rover such that the antenna array may be moved by the rover in response to the magnetic field. A processor onboard the tracking device may communicate commands to the rover to either maintain its position relative to the underground object, or move to a location where the magnetic field can be measured.

Abstract: A system can be provided that can include a measurement tool that can be coupled to a conveyance mechanism for positioning the measurement tool downhole in a wellbore. The wellbore can be encased by a tubular. The system can further include a vibration-inducing device that can cause the tubular to vibrate. Additionally, the system can include an interferometer coupled to the measurement tool for detecting the vibration in the tubular. The system can further generate data useable to determine at least one status of the tubular and at least one status of a cement layer. The cement layer can be positioned between the tubular and a subterranean formation surrounding the wellbore.

Abstract: An apparatus for use in a wellbore includes a drill string section, a drive shaft disposed in the drill string section, a bearing assembly connected to the drive shaft, and an alignment assembly connecting the bearing assembly to the drill string section. The alignment assembly has a first alignment member and a second alignment member slidingly engaging one another to allow at least a portion of the bearing assembly to tilt relative to the drill string section. A related method includes the steps of positioning a drive shaft in a drill string section; connecting a bearing assembly to the drive shaft using the alignment assembly, the alignment assembly having a first alignment member and a second alignment member; and allowing at least a portion of the bearing assembly to tilt relative to the drill string section using the alignment assembly by having the first alignment member and the second alignment member slidingly engage one another.

Abstract: Systems, methods, and apparatus including a downhole membrane potentiometer that may be used in well systems. The downhole membrane potentiometer may include a first circuit film having a resistance trace, a second circuit film having a collector trace, and an insulator spacer coupled between the first circuit film and the second circuit film. The insulator spacer may include one or more pressure vent holes in a first side of the insulator spacer and one or more pressure vent holes in a second side of the insulator spacer to minimize a differential pressure between the inside and outside of the downhole membrane potentiometer.

Abstract: A system can include a tubular string with a drilling bottom hole assembly connected at a distal end of a coiled tubing including a communication line permitting communication between surface instrumentation and the drilling bottom hole assembly, and the drilling bottom hole assembly including an orienter and ranging equipment. The tubular string is positioned in an intercept wellbore which intersects a target wellbore downhole of an obstruction that prevents access to the target wellbore downhole of the obstruction. A method can include drilling an intercept wellbore outward from an original wellbore, after an obstruction is introduced between the original wellbore and a target wellbore, and intersecting the target wellbore with the intercept wellbore, so that fluid communication is provided between the intercept and target wellbores.

Abstract: A pressure pulse generator and an RSS may change the pressure of a fluid flow through a BHA. If the dogleg at the BHA is less than a target dogleg, then the pressure pulse generator goes into pass-through mode to increase the pressure at the RSS and thereby increase a pad force of the RSS steering pads, increasing the severity of the dogleg. If a downhole tool is stuck, then the pressure pulse generator and the RSS are simultaneously actuated to unstick the downhole tool. The RSS is used to generate and transmit pressure pulses to a downhole tool.

Abstract: Disclosed herein are an apparatus, system, and method directed for an autonomous wellbore cleaner. In one embodiment, an apparatus for cleaning a wellbore, the apparatus comprising: an autonomous robot, wherein the robot is self-propelled; a power source for the robot; a motor for propelling the robot axially within the wellbore; at least one cleaning tool positioned on the robot; at least one sensor to detect an initiate-cleaning attribute downhole in the wellbore; and a processor to direct the robot to initiate a cleaning operation in response to the initiate-cleaning attribute exceeding a threshold.

Abstract: Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling, which automatically adjusts at least one parameter during the directional drilling to automatically control the direction of drilling when drilling a kickoff that transitions a wellbore from a vertical section to a curve or tangent section. In embodiments, the closed-loop control can be configured to automatically adjust a steering ratio (SR) parameter that controls time that a steering tool will spend in holding a desired magnetic toolface.

Abstract: The present disclosure generally relates to a downhole mechanical services tool, and more particularly to a hydraulic power system which makes power available to rotary tools for actuating a variety of accessories of cutting, milling, brushing and polishing. For example, a downhole well tool hydraulic power system may include a rotary module configured to rotate relative to a body of the downhole well tool hydraulic power system. The downhole well tool hydraulic power system may also include a hydraulic pump module configured to pressurize a compensated hydraulic fluid for delivery to the rotary module. The downhole well tool hydraulic power system may further include a compensator configured to deliver the compensated hydraulic fluid to the hydraulic pump module. In addition, the downhole well tool hydraulic power system may include a pressure barrier between the hydraulic pump module and the rotary module.

Abstract: A downhole drilling tool, forming part of a subterranean drilling system, may include at least one plate secured to an exterior of an elongate body. Electronics may be disposed between the plate and the body to be protected by the plate while still readily accessible. A dynamic element may be radially extendable from the plate to engage an inner wall of a borehole being drilled. If this radially-extendable element becomes worn or damaged from this engagement, the plate may be replaced. More expensive components of the drilling tool may be contained within the elongate body, rather than the plate, thus reducing replacement frequency. Additionally, plates including unique features may be employed at different times without altering the underlying elongate body.

Abstract: An earth auger includes a transmission assembly arranged on a connecting base, a motor assembly connected with the transmission assembly and driving the transmission assembly to rotate, a controller arranged at a first side of the transmission assembly and connected with the motor assembly, a control knob and a plurality of indicator lights arranged on a housing, and a gyroscope sensor. The controller controls a rotation of the motor assembly through an on-off of a circuit. Angular velocities and angular acceleration critical values of different gears are set through the control knob. The indicator lights are used to display a current gear, and the gyroscope sensor is arranged on a second side of the transmission assembly. The gyroscope sensor obtains angular velocity information and angular acceleration information, and feedbacks a monitored signal to the controller. When the monitored signal exceeds a preset critical value, the controller stops the motor.

Abstract: A torque determination system for use in connection with a pumping system includes a first shaft sensor assembly that produces a first shaft revolution completion signal and a second shaft sensor assembly that produces a second shaft revolution completion signal. The torque determination system includes a processor unit configured to determine the torque produced by the motor based on a shaft twist angle calculated by comparing the first shaft revolution completion signal and the second shaft revolution completion signal.

Abstract: A method for mining narrow vein deposit of ore, the narrow vein deposit having a hanging wall and a foot wall, the method comprising: drilling a pilot hole into the narrow vein deposit along a path substantially centrally between the hanging wall and the foot wall to a depth within the vein; following the pilot hole with a larger diameter drilling assembly to fragment the ore into drill cuttings; circulating the drill cuttings to a wellhead; and collecting the drill cuttings for processing to recover the ore therefrom.

Abstract: A method of drilling a wellbore to a target includes measuring attitudes at two adjacent survey stations along a wellbore using a downhole surveying tool. An actual change in wellbore position over a survey leg linking the two survey stations is determined. Corrections are applied to the measured attitude at one or both of the survey stations such that a modeled well path joining the survey stations reflects the determined actual change in wellbore positon between the two survey stations.

Abstract: A knock-off plug for a mill, including a body having a fluid pathway therein and configured for connection to a fluid conduit, a tortuous pathway fluidically associated with the fluid pathway, the plug configured to jettison the tortuous pathway upon knock off. A mill, including a knock off plug having a tortuous pathway therein. A method for beginning a casing exit, including running a mill, a knock-off plug, a diverter and an anchor as an assembly to depth in a borehole, passing a pressure signal through the knock-off plug to the anchor, the plug having a tortuous pathway therein, setting the anchor, knocking the knock-off plug off the mill and removing tortuous pathway. A wellbore system, including a borehole in a subsurface formation, a string in the borehole, and a knock-off plug, disposed within or as a part of the string.

Abstract: A method of quantifying tortuosity of a wellbore includes receiving survey data for the wellbore indicating an azimuth and an inclination for the wellbore at one or more measurement depths of the wellbore. The method further includes receiving wellbore diameter data for the wellbore indicating the diameter of the wellbore at one or more measurement depths of the wellbore. The method further includes, based on the survey data and the wellbore data and for each measurement depth, selecting a reference diameter and determining a tortuosity length corresponding to a maximum length that a straight tubular having the reference diameter can extend from the measurement depth and down through the wellbore without bending.

Abstract: Disclosed are devices and methods for creating a bore in bone. The devices and methods described involve driving a rotating bit in an axial direction such that both rotation and linear movement are controlled and measurable. The instrument is useful for a surgeon to control and simultaneously measure the travel of the tool into the bone and prevent injury to surrounding structures.

Abstract: A downhole mud motor includes a driveshaft rotatably disposed in a driveshaft housing, a bearing mandrel coupled to the driveshaft, wherein the bend adjustment assembly includes a first configuration that provides a first deflection angle between the driveshaft housing and the bearing mandrel, wherein the bend adjustment assembly includes a second configuration that provides a second deflection angle between the driveshaft housing and the bearing mandrel, and a locking assembly including a locked configuration configured to lock the bend adjustment assembly into one of the first configuration and the second configuration until the downhole mud motor has at least one of reached a predefined depth in the wellbore, and a mud weight has reached a predefined mud weight threshold at a given depth, in response to which the locking assembly is configured to actuate from the locked configuration to an unlocked configuration.

Abstract: A method that includes an electronic application identifying an ending of a first drilling segment and a simultaneous beginning of a second drilling segment; identifying a data set of the first drilling segment; automatically creating, in response to the identification of the first drilling segment ending, a new row in a database table that stores a data set for each drilling segment, with the new row storing the variable values of the first drilling segment; creating a multi-dimensional data matrix based on the values in the database table; and extracting, from multi-dimensional data matrix, an optimum value of a variable for an upcoming drilling segment. The method may also include determining that a trajectory or location of a rotary steering system is outside of a tolerance window; and the step of extracting the optimum value of the variable is in response to this determination.

Abstract: A rotary cone rock bit having a forward end and a rearward end, includes a bit body having a plurality of legs extending therefrom. Each of the legs have an outer surface that includes a leading surface, a center panel surface, and a trailing surface and at least one nozzle. A roller cone is rotatably supported on each of the legs. The rotary cone bit further includes at least identification tag for storing product identification information and/or drilling operation information. The at least one identification tag is positioned on the trailing surface of at least one of the legs.

Abstract: A system and a method include a control unit configured to receive one or more force signals from one or more force sensors coupled to one or both of a tool or an end effector. The one or more force signals are indicative of one or more forces exerted in relation to the tool or the end effector as the tool operates on a first component and a second component. The control unit is further configured to detect a difference in the one or more forces as an operative portion of the tool passes through a gap between the first component and the second component. The control unit is further configured to determine a distance of the gap based on the difference in the one or more forces.

Abstract: A device for transporting a sensor assembly down a bore of a known diameter comprises a pair of wheels offset in a radial direction by a first radial distance from a longitudinal axis of the sensor assembly and at least one eccentric weight. The first radial distance and a lateral distance between the wheels and a diameter of the wheels configures the device so that, in use, a longitudinal axis of the sensor assembly is substantially coincident with a longitudinal axis of the bore when the wheels are in contact with a wall of the bore.

Abstract: A downhole sensor apparatus including a structure and an electronics package. The structure and the electronics package configured to be inserted into a recess in an earth-boring tool on a drill string. The downhole sensor apparatus may include a cradle extending away from a first surface of the structure. The cradle is configured to at least partially receive a battery therein. The downhole sensor apparatus includes a cap configured to engage with the earth-boring tool and secure the structure within the recess. The downhole sensor apparatus also may include a ring disposed between the structure and the cap. The ring is configured to transfer a force from the cap to the structure, forcing a second surface of the structure against a bottom surface of the recess. An earth-boring tool comprising a recess in the earth-boring tool configured to receive a downhole sensor apparatus. A method securing a downhole sensor apparatus to an earth-boring tool.

Abstract: Disclosed are devices and methods for creating a bore in bone. The devices and methods described involve driving a rotating bit in an axial direction such that both rotation and linear movement are controlled and measurable. The instrument is useful for a surgeon to control and simultaneously measure the travel of the tool into the bone and prevent injury to surrounding structures.

Abstract: A system and method can be used for implementing self-adapting digital twins. The system may include operations for estimate a state matrix characterizing behavior of a hydrocarbon recovery process implemented by a hydrocarbon recovery tool. Observed values of one or more sensors for at least one process parameter may be obtained from sensors deployed throughout the drilling environment. These sensors may be physical sensors acquiring information about physical changes within the drilling environment; and processes monitoring output of system functions and/or other processes. A data assimilation tool may be applied to the estimated state matrix and the observed values to produce an updated state matrix. The updated state matrix may be used as the previous state matrix in a subsequent time step, thus implementing a self-adapting digital twin model.

Abstract: A planning tool plans movement of a boring tool for an underground drilling operation. The planning tool includes one or more wheels for rolling on a surface of the ground along a path responsive to movement by an operator to characterize the surface contour and to generate guidance for the boring tool to reach a target position. Planning can additionally be based on waypoints. The planning tool can be rolled unidirectionally or bidirectionally to characterize the surface contour. Bidirectional movement cancels accelerometer fixed bias. Path stitching is used to plan around obstacles. The planning tool can facilitate tracker placement. The planning tool can collect noise information for frequency selection purposes. A described technique maximizes linear drilling in an underground plan. Compensation and/or warnings are provided for unsteady, fast and slow movement of the planning tool while measuring the surface contour.

Abstract: A connection system for a lid in a beacon housing. The lid is connected to the housing at a tab at a first end, after a lip of the lid is placed under a shelf at its second end. The tab has a cross-bore for receiving a connection pin through both the cross-bore and corresponding holes in the housing which form a continuous passage. The lid is placed under tension to reduce relative vibration between the lid and the housing. A set screw is placed within the tab to place a force on the connection pin. Further set screws are distributed about the lid and place the lid in tension relative to the housing. The lid can be removed by reducing the tension provided by the set screws, removing the connection pin, and adjusting the lid such that it is no longer under the shelf of the housing.

Abstract: Embodiments directed to an apparatus and system of monitoring an instrument with a working tool engaged thereby. In one aspect, an embodiment including a working tool with a machine readable indicium indicative of a working tool attribute. The working tool may be receivable by an instrument such that a corresponding machine readable indicia reader receives an identifier of the working tool. Various attributes and conditions in relation to the instrument and working tool received thereby may be identified to facilitate the provisioning of a response to prompt various corrective actions. In this regard, a controller may provide an output in response to a received identifier of a working tool and an identified instrument operating condition.

Abstract: A drilling system may have a drilling rig with a drill string including a BHA with a drill bit. The method may include determining a current BHA location and a future BHA location based on the current BHA location and a current trajectory of the BHA and comparing the future BHA location to a target drilling path. When the future BHA location is a predetermined distance from the target drilling path, then a plurality of geometric convergence paths may be generated, each providing a convergence solution from the current BHA location toward the target drilling path. The method may include determining (i) a distance to drill, (ii) an overall curvature, and (iii) a time required for drilling, of each of the geometric convergence paths and selecting a geometric convergence path responsive to the above. The wellbore may be drilled in accordance with the selected one of the plurality of geometric convergence paths.

Abstract: A system includes a first rotary steerable tool configured to control a first drilling bit to drill a first well having a first well path. The first rotary steerable tool includes a first direction and inclination component that includes a first set of sensors configured to detect a static magnetic field and a signal source configured to generate a source signal. The system also includes a second rotary steerable tool configured to control a second drilling bit to simultaneously drill a second well having a second well path that tracks the first well path. The second rotary steerable tool includes a second direction and inclination component that includes a second set of sensors configured to detect the source signal.

Abstract: A method of controlling a pumping sequence of a fracturing fleet at a wellsite. A managing application executing on a computer in the control van can retrieve the pumping sequence from a local or remote storage computer. The managing application can establish an electronic communication link to receive sensor data from a plurality of fracturing units. The managing application can control the plurality of fracturing units with a stage script with multiple sequential instructions for a pumping stage of a pumping sequence while receiving one or more periodic data sets from the plurality of fracturing units wherein the data sets are indicative of the current state of the pumping stage of the pumping sequence.