Abstract: An apparatus (100) for determining an azimuth of a drilling tool (304) during drilling of a borehole. The apparatus (100) comprises a rate sensor (102) configured to collect rate sensor data indicative of a component of a rate of rotation of the earth for determining the azimuth by gyrocompassing. The rate sensor (102) is further configured for communication with a surface unit (306). The apparatus (100) also comprises a drill pipe extension detector (104) configured to detect a process associated with extension of a drill pipe (312) connecting the drilling tool (304) to the surface unit (306). The rate sensor (102) is configured to transmit collected rate sensor data to the surface unit (306) based on the detected process associated with extension of the drill pipe (312).

Abstract: A system can be used to determine properties of a wellbore treatment fluid. The system can include a rotational system defining an axis of rotation and an aging cell. The aging cell can be positioned in the rotational system to rotate about the axis of rotation. The aging cell can include a housing, a sensor shaft, and a sensor. The housing can define an interior region of the aging cell to receive a wellbore treatment fluid. The sensor shaft can be at an angle from the axis of rotation and can be coupled to the interior region to transmit electronic signals about the wellbore treatment fluid. The sensor can be positioned on the sensor shaft to detect the electronic signals while the aging cell rotates about the axis of rotation, and the electronic signals can be used to determine the properties of the wellbore treatment fluid.

Abstract: Method(s) and apparatus according to which: a bottom-hole assembly (“BHA”) and a drilling rig together attempt to drill a wellbore segment along a planned trajectory while a test scenario is executed on the drilling rig by varying operating parameter(s) of the drilling rig in a predetermined manner during a predetermined time interval; performance characteristic(s) monitored by sensor(s) of the BHA during the predetermined time interval are then received; the predetermined manner in which the operating parameter(s) of the drilling rig were varied during the predetermined time interval is/are then compared to the received performance characteristic(s) monitored by the sensor(s) of the BHA during the predetermined time interval; and based on said comparison, the operating parameter(s) of a drilling rig (e.g., another drilling rig) are controlled while a BHA (e.g., another BHA) operably associated with the drilling rig attempts to drill a wellbore segment along a similar planned trajectory.

Abstract: Methods for treating a wellbore. An example method includes positioning a conduit in the wellbore. The conduit is a liner hanger or a tie-back liner. The conduit includes a conduit body and a reactive metal sealing element disposed on the conduit body. The reactive metal sealing element includes a reactive metal having a first volume. The method further includes contacting the reactive metal with a fluid that reacts with the reactive metal to produce a reaction product having a second volume greater than the first volume. The method further includes contacting a surface adjacent to the reactive metal sealing element with the reaction product.

Abstract: A downhole shunt tube isolation system includes an isolation sleeve housing defining an isolation sleeve chamber and an isolation sleeve moveable within the isolation sleeve chamber between an open position and a closed position. The isolation sleeve has a slurry pathway that fluidically couples a first slurry tube segment to a second slurry tube segment with the isolation sleeve in the open position and fluidically decouples the first slurry tube segment from the second slurry tube segment in the closed position. The downhole shunt tube isolation system further includes a fluid channel in communication with the isolation sleeve chamber. The channel is initially closed to hydraulically lock the isolation sleeve in the open position. Additionally, the downhole shunt tube isolation system includes an actuation mechanism configured to open the fluid channel to hydraulically unlock the isolation sleeve and a biasing member to bias the isolation sleeve to the closed position.

Abstract: A method for controlling a drilling trajectory of a wellbore includes receiving a target trajectory reference of a drill bit within a wellbore from a formation model. The method also includes receiving real-time formation evaluation measurements from at least one sensor positioned within the wellbore and computing a target trajectory set-point change based on the real-time formation evaluation measurements. Further, the method includes generating a target trajectory from the target trajectory reference and the target trajectory set-point change and steering the drill bit using the target trajectory.

Abstract: Systems and methods for controlling an orientation of a tool face for a drilling rig. Multiple methods are provided that use estimated tool face orientation along with measured parameters to determine inputs to the drilling rig such that, after activation, the tool face has a desired orientation.

Abstract: A mandrel in production tubing within a well has a side pocket with an inlet port for connection to an upper control line segment that extends upward alongside the production tubing. An outlet port is below the inlet port for connection to a lower control line segment extending below the pocket. A filter assembly is lowered through the production tubing into the pocket. A valve at a lower end of the pocket is movable from a closed position closing the outlet port to an open position opening the outlet port. A probe mounted to a lower end of the filter assembly engages and pushes the valve from the closed position to the open position while the filter assembly is being seated in the pocket.

Abstract: A system for providing support in a downhole motor, the system includes a stator housing including an end, a stator contour within the stator housing, a rotor including a rotor end and lobes configured to engage with the stator contour to eccentrically rotate the rotor, and a radial support extending from the stator contour toward the end of the stator housing, and positioned radially between the rotor end of the rotor and the stator housing to support the rotor and decrease an amount of eccentric rotation of the rotor.

Abstract: One illustrative diverter valve disclosed herein includes a body with a primary flow path therethrough, first and second fluid flow galleries, first and second fluid outlets, a first sliding sleeve element and a second sliding sleeve element. The first and second sliding sleeve elements, respectively, include first and second internal flow bores, respectively, wherein each of the first and second sliding sleeve elements are adapted to be moved from a first closed position to a second open position, and vice-versa. In the first and second positions, respectively, the first sliding sleeve element blocks or does not block, respectively, fluid flow between the first internal flow bore and the first fluid flow gallery. In the first and second positions, respectively, the second sliding sleeve element blocks or does not block, respectively, fluid flow between the second internal flow bore and the second fluid flow gallery.

Abstract: An illustrative modular manifold disclosed herein includes, among other things, a low-pressure manifold comprising a frac fluid outlet valve, wherein a fracturing fluid is adapted to be supplied from the low-pressure manifold via the frac fluid outlet valve to a suction side of a frac pump, and a high-pressure manifold comprising at least one frac fluid inlet valve, wherein the high-pressure manifold is adapted to receive, via the frac fluid inlet valve, a fracturing fluid discharged from the frac pump. In this example, the modular manifold also includes a support structure for mechanically supporting the low- and high-pressure manifolds and a plurality of height-adjustable support legs operatively coupled to the support structure.

Abstract: A controllable drilling head for a drill string for ground drilling with a drilling head tip and a locating pin that carries the drilling head tip, the drilling head tip having a bore slanted to the longitudinal axis and the locating pin being angled to the longitudinal axis, wherein the drilling head tip can rotate on the locating pin, the drilling head tip and the locating pin being arranged in a first angular position relative to one another for straight drilling, and the drilling head tip and the locating pin being arranged in a second angular position relative to one another for drilling that deviates from straight drilling.

Abstract: A method for drilling a subterranean wellbore includes rotating a drill string in the subterranean wellbore. The drill string includes a drill collar, a drill bit, and survey sensors (e.g., a triaxial accelerometer set and a triaxial magnetometer set) deployed therein. The triaxial accelerometer set and the triaxial magnetometer set make corresponding accelerometer and magnetometer measurements while drilling (rotating). These measurements are synchronized to obtain synchronized accelerometer and magnetometer measurements and then further processed to compute at least an inclination and an azimuth of the subterranean wellbore while drilling. The method may further optionally include changing a direction of drilling the subterranean wellbore in response to the computed inclination and azimuth.

Abstract: Disclosed is a directional well trajectory control method based on drill pipe drive, the method including the following steps: parameters down-transmission, determining the offset vector, closed loop control of eccentric ring rotation angle, and well parameter closed-loop control; this method can achieve three-dimensional well trajectory control without frequent trips during drilling operations, and has a high penetration rate, good wellbore cleaning effect, well trajectory control accuracy, high flexibility, low tripping times, high borehole quality, high safety, etc., which is suitable for the development of special process wells such as medium-deep wells, ultra-deep wells, ultra-thin oil layer horizontal wells and unconventional oil and gas wells in China's complex oil and gas reservoirs. This method can also achieve precise control of well trajectory, and overcome the shortcomings of existing control methods that cannot achieve closed-loop control and cannot remove interference signals.

Abstract: One illustrative valve disclosed herein includes a body, a first flow bore in the body that includes a fluid flow gallery, a first fluid flow port and a second fluid flow port, wherein the fluid flow gallery is in fluid communication with the first and second fluid flow ports. In this example, the valve also includes a second flow bore in the body and at least one sliding sleeve positioned in the body, wherein the at least one sliding sleeve is adapted to be moved from a first closed position to a second open position, and vice-versa, wherein, in the first closed position, fluid communication between the first flow bore and the second flow bore is blocked and wherein, in the second open position, fluid communication between the first flow bore and the second flow bore is established.

Abstract: A system for disassembling a drill assembly including a drill bit and one or more columns interlinked with each other. The system includes a first clamping mechanism adapted to engage one of the drill bit or a first column, and a second clamping mechanism adapted to engage a second column disposed successively to the drill bit or the first column. The second clamping mechanism is turned relative to the first clamping mechanism to at least partially delink the second column from the first column or the drill bit. The system further includes a first actuator adapted to move one of the first clamping mechanism or the second clamping mechanism relative to the other to define a gap therebetween to reveal an interface between the second column and the drill bit or the first column for delinking the second column relative to the drill bit or the first column.

Abstract: Disclosed herein is a device and method for correlating core sample zones with an actual subterranean depth. The disclosed device has a pair of independent distance measuring devices operably in communication with a core sample apparatus where a first distance measuring device measures the length of a core sample entering a core sampling tube and a second distance measuring device measures a drive depth of the core sampling tube entering into the ground. A processing unit is provided for correlating the two distances so as to allow a determination as to the actual depth below ground from where a given zone of the core sample is extracted.

Abstract: A shut-off system and control method for a rotary steerable tool that includes a body having an inner chamber, a piston gallery extending between the inner chamber and a piston port, and an exhaust gallery extending between the inner chamber and an exhaust port. A spool in the inner chamber is movable into a plurality of positions to direct and control the flow of drilling fluid to energize pistons of the rotary steerable tool. The spool includes a spool shaft. A first passage extends through the spool shaft and receives drilling fluid via a spool inlet port in the shaft from a drilling fluid inlet port of the rotary steerable tool. A shut off valve is controlled to rotate on the spool shaft to open and shut the spool inlet port to drilling fluid flow.

Abstract: Examples described herein provide a computer-implemented method that includes modeling at least one torque and drag parameter for an upstream well construction operation. The method further includes acquiring at least one measured torque and drag parameter during performing the upstream well construction operation. The method further includes interpolating friction factors at different sampling times for the at least one measured torque and drag parameter. The method further includes transposing the friction factors at the different sampling times for the at least one measured torque and drag parameter to a time-based series. The method further includes performing a corrective action responsive to determining that one or more of the friction factors at a particular point in time is indicative of the one or more of the friction factors deviating from an expected value.

Abstract: A machine includes a boom coupled to a movable carrier and at least one boom actuator adapted to actuate the boom. At least one boom sensor is configured to generate signals indicative of a spatial orientation of the boom. A drilling work device is coupled at a distal portion of the boom. First and second actuators are adapted to actuate the drilling work device. At least one drilling work device sensor is configured to generate signals indicative of a spatial orientation of the drilling work device. A controller receives signals indicative of the spatial orientation of the boom, receives signals indicative of the spatial orientation of the drilling work device, and actuates at least one of the at least one boom actuator and the first and second actuators through predetermined sequential steps to automatically position the machine in a shipping configuration.