Abstract: A top drive for well operations having a gearbox, a traction motor connected to the gearbox so that a motor shaft of the traction motor extends into the gearbox, a quill extending into the gearbox, a gear train positioned within the gearbox and mechanically connected between the traction motor shaft and the quill, and a connector positioned in the gear train, wherein in a coupled configuration the connector communicates torque through the gear train, and wherein in a decoupled configuration the connector does not communicate torque through the gear train. A method for operating a top drive by applying a first torque to a quill with two traction motors, disconnecting one of the traction motors from the quill, and applying a second torque less than the first torque to the quill with the non-disconnected traction motor.

Abstract: A mobile robot is disclosed herein. The mobile robot may include a frame, a propulsion module, a navigation module designed to navigate the mobile robot along a target pathway, and a computational module. The mobile robot may obtain a composition reading of the drilling fluid and a pressure reading of the drilling fluid. The robot may determine, using the computational module, an additive to add to a drilling fluid reservoir based on the composition reading and the pressure reading. The mobile robot may then retrieve the additive from an inventory and deposit the additive into the drilling fluid reservoir.

Abstract: A leak detection tool is positioned in in a tubing string that is disposed in a wellbore. The leak detection tool is attached to a downhole end of a line and includes a cup. An outside diameter of the cup is substantially the same as an inside diameter of the tubing string. An uphole end of the line is attached to a spool disposed proximate to an uphole end of the wellbore. The leak detection tool is propelled through the tubing string in a downhole direction by pumping a fluid down the tubing string such that a fluid pressure uphole of the cup is greater than a fluid pressure downhole of the cup. A flow of fluid from an interior of the tubing string uphole of the cup to an exterior of the tubing string through a leak in a wall of the tubing string is detected as the cup passes the leak. A depth of the leak is determined based on a length of the line from the spool to the leak detection tool when the flow of fluid from uphole of the cup through the leak is first detected.

Abstract: A system with multiple spinners in a spinner assembly, each spinner comprising a drive shaft, a sleeve with arcuate segments surrounding the drive shaft, a first cap that receives a first end of the sleeve and a second cap that receives a second end of the sleeve, which secures the sleeve to the drive shaft. A system with two spinner subassemblies in a spinner assembly, and with a coupling assembly that moves the subassemblies a same distance in opposite directions relative to a center axis of the spinner assembly. A method can include securing multiple arcuate segments of the sleeve to a drive shaft of the spinner by inserting a first end of the sleeve into a first recess of a first cap and inserting a second end of the sleeve into a second recess of a second cap.

Abstract: An expansion system is capable of expanding a tubular that has no shoe or plug. The tubular is expanded by a cone coupled to a mandrel, which is energized by a jack actuator to effect a plurality of strokes. The jack actuator is supported by a support member. The jack actuator releasably engages and locks to an operational pipe at predetermined length intervals corresponding to the length of each actuator stroke. The actuator jack is reset and moved to a new locking location between strokes. The operational pipe holds the expandable tubular in place during expansion. After expansion, the cone, mandrel, actuator jack, and operational pipe are free of the expandable tubular and can be pulled out of the wellbore. The expansion system can be used for applications of patches having a small size in wellbores where milling debris may be detrimental.

Abstract: The present disclosure generally relates to a method for making up a tubular joint. The method includes rotating a first tubular relative to a second tubular to engage the first and second tubulars while measuring a torque between the first and second tubulars, calculating a set point of a relative rotational speed between the first and second tubulars using the measured torque, and using the calculated set point with a closed-loop controller to control the relative rotational speed between the first and second tubulars.

Abstract: A rollable display comprises a flexible display panel; at least one BRC member having one end coupled with an edge of the flexible display panel; a roller assembly having a roller coupled with another end of the BRC member and a motor for rotating the roller, the roller assembly being ascended while rolling the BRC member onto the roller when the motor is rotated in a first direction, and being descending while unrolling the BRC member from the roller when the motor is rotated in a second direction opposite to the first direction; and a panel guide part connected to the roller assembly and moved along with the roller assembly; wherein the flexible display panel is rolled onto the panel guide part when the roller assembly and the panel guide part ascend, and is unrolled from the panel guide part when the roller assembly and the panel guide part descend.

Abstract: Methods and systems for connecting threaded tubulars are presented. One example method generally includes monitoring relative rotation between a backup tong and a tubular clamped in the backup tong to determine slippage of the backup tong.

Abstract: A sucker rod tong assembly for fastening together sucker rods to a rod coupling, where the assembly can include a two-stage mechanical drive mechanism. The first stage can connect an upper sucker rod to a lower sucker rod via a rod coupling. The first stage can be limited in mechanical ability to tighten the connection to a pre-set shoulder torque value. The second stage can then be hydraulically and mechanically sequenced, using a linear gear drive mechanism, to rotate a main tong pinion gear that can further rotate the sucker rod connection through a fixed circumferential displacement to a mechanical stop.

Abstract: A spinner roller set adapted for use in an apparatus used to connect and disconnect threaded drilling tubulars includes a first and a second modular spinner roller that mounts independent drive and spacer discs on a central shaft. The setup is arranged so that the spinner rollers when in use can engage a small diameter tubular using the same setup as that for engaging a much larger diameter tubular. When a drive disc is in need of replacement, the worn drive disc can be removed from the central shaft and replaced with a new drive disc. The other drive discs and spacers can be reused.

Abstract: A top drive for a drilling rig includes a top drive housing, a threaded element used in a drilling operation, the threaded element having a grooved surface, and a back-up wrench with a toothed surface which engages with the grooved surface of the threaded element. The back-up wrench is suspended from the top drive housing. The back-up wrench is movable in relation to the top drive housing so as to selectively engage the threaded element.

Abstract: A positioning arrangement, a rod handling device, a drill rig and a method for positioning a drill rod are provided. The positioning arrangement comprises a positioning organ, arranged to position a drill rod with a length axis, and a displacement arrangement with a first portion and a second portion, the first portion being connected to the positioning organ and the second portion being connectable to a base part. The displacement arrangement is arranged to displace the positioning organ from a first position to a second position via a translational displacement, such that a length axis of a drill rod positioned by the positioning organ will be substantially aligned with the drill hole axis in the second position.

Abstract: Embodiments of the present disclosure are directed toward a choke valve system including a choke valve body and a plurality of choke trims. The plurality of choke trims comprises a plug and cage choke trim, an external sleeve choke trim, and a drilling choke trim, wherein the drilling choke trim is configured to enable a fluid flow rate greater than the plug and cage choke trim and the external sleeve choke trim, and wherein each of the plurality of choke trims is configured to be mutually exclusively secured within the choke valve body.

Abstract: A lower stabilizing arm for stabilizing tubulars for stabbing to the threaded connections of a drill string on drilling rigs. The lower stabilizing arm comprises a bracket and an upper arm having an upper end and a lower end. An upper pair of axially opposed rotary actuators connects the upper end of the upper arm to the bracket. A lower arm is provided having an upper end and a lower end. A central rotary actuator is connected between the lower end of the upper arm and the upper end of the lower arm. A roller bracket is provided having a pair of v-shaped rollers mounted on the roller bracket. A lower pair of axially opposed rotary actuators connects the second end of the lower arm to the roller bracket.

Abstract: Present embodiments are directed to a gripping device configured to couple with a pipe element. A housing of the gripping device is configured to extend over and at least partially around a distal end of the pipe element. Torsional clamp devices are configured to engage an outer circumferential surface of the pipe element with frictional engagement features that extend radially inward from the housing. A sealing mechanism is configured to shift a pipe seal relative to the housing and into engagement with the distal end of the pipe element and to facilitate fluid flow through the gripping device into the pipe element.

Abstract: A die holder device includes a die holder that has an axial centre line and is adapted to receive a clamp die. The die holder is included in a clamp arm or slide block. The die holder is restricted from axial movement by at least a first complete or partial conical surface and possibly by a second complete or partial conical surface that directly or indirectly bears against the clamp arm or the slide block.

Abstract: An instrumented shell for sensing drilling parameters of a drilling assembly positionable at a wellsite. The drilling assembly includes a top drive assembly and a downhole tool. The instrumented shell includes a shell body, instruments and an interconnector. The shell body is positionable about the top drive assembly, and has pockets extending therein and a cover positionable about the shell body. The instruments include sensors, and are removably disposable in the pocket and sealable therein with the at least one cover. The interconnector includes a top drive connector removably connectable to the top drive assembly and a shell connector removably connectable to the shell body with a cable therebetween to pass signals therebetween whereby drilling parameters of the downhole tool may be directly collected.

Abstract: A top drive mechanism for a drill rod for cutting of delayed coking units in the petroleum refining industry includes a gooseneck connector, a washpipe assembly, an output shaft, and a power mechanism for driving the output shaft to rotate. The output shaft has an integral structure formed by a shaft body and a flange; a step I is disposed on an outer circumferential surface of the output shaft; a support ring is disposed on an end face of the step I; the output shaft mates with the support ring through a key I; a lock nut fixes the support ring onto the end face of the step I; a lower portion of the support ring is provided with a self-aligning thrust roller bearing. The structure has high stability such that the service life of the top drive device is extended and installation and disassembly are easy and fast.

Abstract: A casing running tool is connected to a top drive with a clutch that operates with set down weight against a spring resistive force. Setting down weight with rotation in a first direction raises an actuation member that pushes the slips out radially. The weight of the string then keeps the slips in position so that the string can be picked up and the rig floor slips removed followed by lowering the string while circulating and rotating. With slips set inside the joint and the string hanging free, rotating the top drive rotates the string as the string is lowered. With slips again supporting the string on the rig floor the top drive can be rotated in an opposed direction with weight set down to back off the slips and to remove it from the top joint.

Abstract: A pipe drive system includes a gripping device configured to couple with a pipe element. A housing of the gripping device is configured to extend over and at least partially around a distal end of the pipe element. Torsional clamp devices are configured to engage an outer circumferential surface of the pipe element with frictional engagement features that extend radially inward from the housing. A sealing mechanism is configured to shift a pipe seal relative to the housing and into engagement with the distal end of the pipe element and to facilitate fluid flow through the gripping device into the pipe element.

Abstract: A drill rig 10 has a drill tower 12, rotation head 14 and drill table 16. The rotation head 14 is supported on and linearly traversable along drill tower 12. A drill rig traverse system 20 provides pull back and pull down force to the rotation head 14 enabling the rotation head 14 to traverse along drill tower 12 and controlling contact force between a drill bit and toe of a hole being drilled. The system 20 is formed as a combination of a hydraulic ram traverse system 22 providing both pull back and pull down force; and a winch pull back system 24 providing pull back only. Both hydraulic ram traverse system 22 and winch pull back system 24 can traverse the rotation head for the full length of the tower 12 when simultaneously applying pull back to the rotation head 14.

Abstract: A system includes a top drive system equipped with a mounted winch configured to draw tubular or well equipment into alignment with a quill of the top drive system. The winch comprises a spool and a flexible line that extends from the spool and through channels in the top drive system, exiting through the quill. An attachment feature at the distal end of the flexible line couples the flexible line with the tubular or drilling equipment. Once this coupling has been established, the winch may rotate such that the flexible line retracts through the quill of the top drive system, drawing the tubular or well equipment into alignment with the quill.

Abstract: A hydrocarbon drilling tubulars storage and handling system, said system comprising: —first and second rotary storage racks, each rotary storage rack being rotatable about a vertical axis and having storage slots for storage of multiple tubulars in each rotary storage rack in vertical orientation, the first and second rotary storage rack each including a drive to rotate the storage rack about its vertical axis, —a tubulars racking device positioned between the first and second rotary storage racks, said racking device including a rotary structure that is rotatable about a vertical axis and a drive to rotate the rotary column structure about said vertical axis, the rotary structure supporting at a first side thereof a first tubular racker assembly and at a second side thereof a second tubular racker assembly, each tubular racker assembly including one or more one gripping members adapted to grip a tubular.

Abstract: A device for handling drill string components in respect of a drill rig. A gripper is configured to grip a first drill string component to be threaded on to or off from a second drill string component being partly drilled into a rock formation. A support is configured to fasten the device onto the drill rig. A handling unit is movably connected to the support. The handling unit includes the gripper and is movable between a drill string position and a loading position. The handling unit includes an auxiliary engagement unit configured to engage the second drill string component in the drill string position and an angle variation unit configured to vary an angle of the gripper and thereby the gripped first drill string component in order to allow the alignment in the drill string position. Also a method and a drill rig.

Abstract: A wellhead assembly includes a wellhead housing having a bore and a locking profile including a gallery slot, and an annular notch. An inner wellhead assembly is selectively landed in the bore of the wellhead housing, the inner wellhead assembly having a lock ring with a lock ring profile that engages the locking profile. The engaging surface is a sloped downward facing surface at an axially upper end of the gallery slot. The annular notch has a notch engaging profile with a downward facing notch upper shoulder and an upward facing notch lower shoulder. The locking profile includes an inlay, the inlay being located on the notch upper shoulder and the engaging surface.

Abstract: A slip design has segments that move relatively axially before moving in tandem up a ramp for radial extension. Due to the fact of the relative movement the segments interlock due to their geometric configuration or their surface treatment such that at the conclusion of such relative movement the load carrying thickness is effectively increased. The extended position minimizes radial extension of the slips for a smaller tool drift dimension while still allowing the needed radial extension and actually extending the radial reach of the slip assembly. The segment can have triangular or trapezoidal tapered interfaces that provide bearing areas between slip segments and adjacent spacer segment. Alternatively, the slips segments can have opposing wickers so that after riding up an underlying support member can interact with that member for load transfer. The supporting members can also be secured to an underlying mandrel for further load transfer.

Abstract: A wellhead assembly includes a tubular wellhead housing having a bore and an annular gallery slot. The annular gallery slot is defined by an enlarged inner diameter of the bore. A tubular hanger is selectively landed in the bore of the wellhead housing, defining an annular cavity between the bore and an outer diameter of the tubular hanger. The tubular hanger is supported by the wellhead housing with a hanger support located in the annular cavity. A flow-by passage is in fluid communication with the annular cavity at locations above and below the hanger support. The flow-by passage intersects with the gallery slot and intersects an outer radial surface of the tubular hanger.

Abstract: A wellhead assembly including a tubing hanger adapted to be connected to a tubing string and landed in a wellhead, and defining a tubing annulus between the tubing string and casing in a well. The wellhead assembly also includes a tubing annulus upper access bore extending downward from an upper end of the tubing hanger, and a tubing annulus lower access bore extending upward from a lower end of the tubing hanger and misaligned with the upper access bore, the lower access bore adapted to communicated with the tubing annulus. A communication cavity connects the upper and lower access bores within the tubing hanger. A remotely actuated valve is in the communication cavity for selectively opening and closing communication between the lower access bore and the upper access bore.

Abstract: A stabilizer to suppress unwanted pivotal movement in pipe handling equipment suspended from bails. The stabilizer can contain either or both adjustable contacting members and non-adjustable contacting members which are rigidly connected to a portion of the pipe handling equipment. The adjustable contacting members contact the bails on one or both sides of the bail(s) to suppress motion of the elevator relative to the bail.

Abstract: A casing running tool is provided having a central mandrel with spiral wedge grooves, an outer cage having generally horizontal slots corresponding to the spiral wedge grooves, and grabber balls disposed between the spiral wedge grooves and the horizontal slots. Each of the spiral wedge grooves has a deeper end and a shallower end, between which the respective grabber balls roll. When a grabber ball is disposed in the shallower end of the respective spiral wedge groove, the grabber ball exerts a radial force against an inner wall of a casing or liner being supported. In addition, the running tool facilitates the application of torque from the running tool to the casing or liner being supported.

Abstract: An automated roughneck may include a backup tong and a makeup tong. The makeup tong and backup tong may be selectively movable relative to one another. The makeup tong and backup tong may include spinner and gripper assemblies respectively adapted to make up and break out threaded connections. The automated roughneck may be configurable to be removable from the drill string in a lateral direction.

Abstract: A device is taught for gripping casing joints comprising one or more first cylinders and one or more second cylinders actuated by a singular hydraulic system. A second device is taught comprising a gripping system, said gripping system comprising one or more slips cammed against one or more inclined recesses when the gripping system is rotated to maintain gripping engagement of the casing. A third device is taught comprising a gripping system, said gripping system comprising one or more slips received into one or more inclined recesses. A fourth device is taught comprising one or more dies supported on one or more said slips by means of mating load transfer profiles. A fifth device is taught comprising a tubular guide means. A sixth device is taught comprising an integral fluid compensator chamber. A seventh device is taught comprising a hydraulic swivel comprising one or more sealing means having predictable seal fluid leak rates.

Abstract: Present embodiments are directed to a device for a top drive drilling system. The device includes a movable sleeve configured to be disposed around at least a portion of a sub. The movable sleeve is configured to be selectively disposed around a tubular by sliding axially along the sub. The device also includes a plurality of engagement features extending inwardly from an inner circumference of the movable sleeve. When the movable sleeve is disposed around the tubular, the plurality of engagement features are configured to engage the tubular when the movable sleeve is rotated in a first direction and to not engage the tubular when the movable sleeve is rotated in a second direction.

Abstract: Embodiments disclosed herein relate to methods and apparatus to inhibit rotation within a drilling rig. The apparatus may include a first member connected to a first component of the drilling rig, and a second member connected to the first member and connected to a second component of the drilling rig, the second component configured to move vertically with respect to the first component. The first member is configured to move vertically with respect to the second member and the first member and the second member substantially inhibit rotation between each other. The apparatus may include a rotational adjustment system, in which the rotational adjustment system is used to connect with one of the components of the drilling rig.

Abstract: A multi-component tubular coupling is provided for wellhead assemblies. In one embodiment, the multi-component tubular coupling may include a first tubular member, a landing ring, and a second tubular member. The second tubular member may include internal threads, lock screws, or any combination thereof to couple to a wellhead component. In another embodiment, the multi-component tubular coupling may only include the first tubular member and the landing ring. In such an embodiment, a wellhead component may be secured to the coupling via lock screws.

Abstract: A device is taught for positioning drill pipe make up or break out equipment on a rig floor. The device comprises a forward arm connectable at a first end to the drill pipe make up or break out equipment, an upper rearward arm and a lower rearward arm, pivotably connectable between the forward arm and a column, said lower rearward arm further being axially movable along said column. The device further comprises means for maintaining the upper rearward arm in parallel relationship with the lower rearward arm and means for axially moving said lower rearward arm. Axial movement of said lower rearward arm acts to extend or retract said forward arm, while maintaining a constant axial position of the make up or break out equipment.

Abstract: A rotational driver for driving a connector through adjacent tubulars is provided. The adjacent tubulars are positionable in a wellbore of a wellsite for passing fluid therethrough. The rotational driver includes a gearbox housing positionable about the connector, a socket carried by the gearbox housing to receivingly engage the connector, and a plurality of gears driven by at least one motor. The gears are operatively connectable to the socket to transfer torque from the motor thereto, and have interlocking teeth defining a plurality of contacts therebetween whereby load on the gears is distributable therebetween.

Abstract: An apparatus includes a first housing portion comprising a first adjustable gripping system moveable between an engaged position that grips a cylindrical outer surface of a first tubular structure having a first diameter and a disengaged position that permits relative movement of the first housing portion and the first tubular structure. The apparatus also includes a second housing portion fixed relative to the first housing portion so that rotation of the first housing portion results in rotation of the second housing portion. The second housing portion includes a second gripping system to securely grip a cylindrical outer surface of a second tubular structure that is threadably attached to the first tubular structure and has a second diameter different than the first diameter. Methods of breaking tubing hanger connections are also disclosed.

Abstract: The present disclosure provides a drilling and tripping equipment package and control scheme and methods using two or more systems that operate simultaneously and continuously in a synchronized manner such that the feeding of tubulars into or out of a well bore is achieved with continuous or near continuous movement, without the need for periodic interruptions. The drilling and tripping equipment package and control scheme is also able to rotate the tubulars in the well bore with continuous speed and torque sufficient for both drilling and back-reaming operations. The drilling and tripping equipment package and control scheme is additionally able to circulate drilling fluid into the internal bore of the tubulars with sufficient pressure and flow to facilitate both drilling and back-reaming operations, with minimal interruption to circulation.

Abstract: A well tool adapted to be connected with and disconnected from a well tubing using a power tong device having a pair of tongs, a gripping span between the pair of tongs, and a maximum clearance diameter for an object passing through the tongs. The well tool includes a tubular mandrel. The tubular mandrel has a maximum mandrel diameter which is no greater than the maximum clearance diameter. The tubular mandrel includes a first mandrel connector which is adapted for connecting the tubular mandrel with a first well tubing in order to provide a first connection. The tubular mandrel is configured so that when the power tong device grips a tong gripping surface on the tubular mandrel and the first well tubing in order to connect the tubular mandrel and the first well tubing, the first connection is located within the gripping span.

Abstract: Rotating wellhead hanger assemblies are provided. In one embodiment, a wellhead hanger assembly includes a casing hanger and a casing hanger running tool coupled to the casing hanger. An exterior surface of the casing hanger includes a recess and the casing hanger running tool includes a dog that extends inward from the casing hanger running tool into the recess of the exterior surface of the casing hanger. Engagement of the dog with the recess of the casing hanger facilitates synchronous rotation of the casing hanger and its running tool. Additional systems, devices, and methods are also disclosed.

Abstract: A spider and method for supporting a tubular within a well bore. Radial dogs, controlled by cylinders that extend and retract simultaneously, are operable to support the tubular by the lower lip of a box connector. When a tubular connector is set down upon the dogs so as to depress one or more triggers located thereon, an interlock in a control system is actuated to prevent movement of the dogs. However, even while the spider is thus loaded, the dogs may nevertheless be retracted via an emergency override mechanism thereby allowing the tubular to be dropped into the wellbore. When the tubular has been lifted off of the triggers, the interlock is deactivated, and the dogs of the spider can be operated once again. The triggers may actuate sensor valves located within the dogs, which in turn actuates an interlock valve isolating the flow path of the cylinders.

Abstract: There is provided a system and method for installing a wellhead component in a single trip. Generally, a wellhead component may be run into a wellhead using a running tool. The running tool may then be retrieved from the wellhead and replaced with a locking tool, which is also run into the wellhead. Additional tools may be used to over-pull the wellhead component and to cementing the wellhead component in place. The process of retrieving and running tools into the wellhead is both time-consuming and costly. Accordingly, the disclosed embodiments include a one-trip tool configured to run a wellhead component into a wellhead, engage an internal coupling to lock the wellhead component in place, over-pull the wellhead component to ensure the internal coupling was properly engaged, and cement the wellhead component in place within the wellhead.

Abstract: A compensation and fill up assembly comprises a slip assembly for engaging a tubular and a compensation assembly for supporting a weight of the tubular when engaged by the slip assembly. The compensation and fill up assembly further comprises a fluid swivel and a fill up tool coupled to the fluid swivel by a fluid shaft. The fill up tool is insertable into and rotatable with the tubular using the fluid swivel.

Abstract: An apparatus for supporting tubular goods and wellbore tools that can be used to perform down-hole operations in oil and gas wells. The support apparatus has a minimal footprint and requires minimal surface area. The support apparatus can be used to jack and remove casing and other pipe, as well as other rig-less downhole well operations.

Abstract: A well screen assembly has a base pipe and one or more screen sections attached to the outer surface of the base pipe. The assembly also has one or more shunt tubes attached to the base pipe via top and bottom rings. The shunt tubes can be attached to the screen sections via B-rings and may be transport tubes or packing tubes. Connections are used for securing a jumper tube to adjoining shunt tubes of adjoining screen sections of the wellscreen assembly, which may be used in open or cased holes. At a well site, the joints of the wellscreens have timed threads so that the various shunt tubes can be aligned with one another along the assembly as the joints are made up. The connections of the present disclosure allow operators to install a jumper tubes between shunt tubes at the joint without needing to tighten fasteners or assembly components.

Abstract: An improved fluid conduit union and method for hammerless attachment apparatus for hammerless coupling the ends of abutting fluid conduits, such as pipe, hoses, or attachment fitting conduits, comprising a ring-shaped conduit receptacle assembly threadedly engaged and fixed on a female fitting at one conduit end and a cylindrical ring-shaped locking assembly positioned around a male fitting at the other conduit end. The ring-shaped locking assembly has a lock ring positionable by a rotatable locking ring nut threadedly engaging the ring-shaped conduit receptacle. Rotation of the locking ring nut translates the lock ring against the male fitting and firmly seats the male fitting at one conduit end to the female fitting at the other conduit end where they are locked in place, all without rotation of either fluid conduit.

Abstract: A device and a method for handling rod-shaped elements on drilling gear are disclosed. The device for handling rod-shaped elements on drilling gear includes a drill rod magazine on which the rod components are deposited between a center of a drill hole and a center of a drilling mast, an elevator with a guide that lifts the drill rods above a drill hole, and a drive for displacing the elevator, a gripper attached to the elevator for picking up the rod component from the drill rod magazine, and a plurality of monitors. The plurality of monitors automatically monitor the movement of the rod-shaped components amongst the magazine, the elevator, and the gripper.

Abstract: A gripping tool includes a gripping element and at least one gripping surface formed on the gripping element. The at least one gripping surface includes a plurality of teeth extending from the gripping element an outer layer. A method to surface process a gripping surface of a gripping tool includes providing the gripping surface in an environment comprising a source of additive material and heating the gripping surface at a temperature and a time to diffuse the additive material a depth into the gripping surface to form a diffusion layer.

Abstract: An automated tubular handling system adapted to make-up or break-out tubulars that includes a rotary drive adapted to operatively grip a tubular to be connected to or disconnected from a tubular string, a controller adapted to receive and process data indicative of a rotation, torque, and minimum time value associated with a make-up or a break-out of the tubular string, and a user interface adapted to convey the received data, the predetermined values, or both, of the tubular make-up or break-out to an operator. The controller compares the rotation, torque, and minimum time values to acceptable predetermined values to determine when the make-up or the break-out is complete. Automated methods are also disclosed.