Abstract: Inside blowout preventer release tool body having a one-piece planar upper section and a one-piece tubular lower section. In one embodiment, the upper section includes a pair of longitudinal members defining a central open region, the longitudinal members joined at one end having a formed lifting feature configured to accept a manipulator cable or chain. The lifting feature is positioned such that when the release tool body and an inside blowout preventer connected thereto are lifted by the rig hoist using cables, chains, and the like, they are easily moved over, aligned with, and connected with a working drillpipe while minimizing possibility of slipping off the cables or chains. The lower section includes a threaded end mating with a mating end of an inside blowout preventer, a central longitudinal bore to accept a release rod, and an upper end formed to accept the lower ends of the longitudinal members of the upper section.

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: A method of installing a wellbore junction assembly in a well can include connecting at least two tubular strings to one opposite end of a tubular string connector with similarly dimensioned oriented connections, whereby the tubular strings are interchangeably connectable to the connector by the oriented connections. A wellbore junction assembly can include at least two tubular strings and a tubular string connector having opposite ends. Each of the tubular strings may be secured to one opposite end of the connector by oriented connections, whereby each of the tubular strings has a fixed rotational orientation relative to the connector. A well system can include a tubular string connector, each of first and second tubular strings being secured to the connector, and a support which reduces bending of the second tubular string which results from deflection of the second tubular string from one wellbore section into another wellbore section.

Abstract: A method for pre-tensing sections of concentric tubulars in a wellbore. The method can include mechanically coupling an inside tubing pipe to an inside tubing string disposed in the wellbore. The method can also include mechanically coupling a second tubing to a second tubing string disposed in the wellbore. The method can further include suspending, by the first tubing, the first tubing, the first tubing string, the second tubing string, and the second tubing. The method can also include inserting, while suspending the first tubing, the first tubing string, the second tubing string, and the second tubing by the first tubing, a first slip into the first space between the first tubing and the second tubing. The method can further include inserting the first tubing, the first tubing string, the second tubing string, the second tubing, and the first slip further into the wellbore.

Abstract: A fill up tool includes a mandrel; a primary sealing member disposed around the mandrel; and a selectively operable secondary sealing member activated by rotation of the mandrel. In another embodiment, the selectively operable secondary sealing member is activated using hydraulic pressure.

Abstract: An automatic drilling system includes a top drive comprising a proximity sensor disposed in a housing thereof. A portion of the top drive is coupled to elevators through load transfer springs such that axial loading applied to the elevators results in relative movement between a link load collar and a load ring. A proximity sensor is mounted such that the relative movement results in a change in signal output thereof. A processor is in signal communication with the proximity sensor and is configured to operate a drive shaft motor. The processor is configured to disable rotation of the motor when the relative movement is indicative of axial loading on the elevators.

Abstract: A radio frequency (RF) applicator may be rotated during positioning within a wellbore in a subterranean formation. The wellbore may have at least one bend therein. The RF applicator may include a series of tubular conductors, and a respective bendable tubular dielectric coupler rotationally interlocking opposing ends of adjacent ones of the series of tubular conductors to define a tubular antenna. The RF applicator may include at least one RF feed conductor extending within the tubular antenna and connected to the series of tubular conductors.

Abstract: A stop collar for a tubular and method for installing a stop collar on a tubular. The stop collar includes a flexible member extending circumferentially around the tubular more than once. A tension force on the flexible member causes the flexible member to apply a radially-inward gripping force on the tubular. The stop collar may also include a shield disposed around at least a portion of the flexible member, to protect the flexible member in a downhole environment. The stop collar may also or instead include an adhesive disposed radially between the flexible member and the tubular.

Abstract: A system of couplings and method of use of the couplings to locate a downhole tool connected to coiled tubing, such as a bottom hole assembly, within a selected segment of a casing string. The selected segment of casing may be a ported collar or ported housing that permits the treatment and/or stimulation of the adjacent well formation. The system of couplings may be two, three, or four couplings spaced apart at predetermined lengths. The predetermined lengths may be shorter than typical lengths of casing segments. The distance between the first and second coupling may be substantially identical to the distance between the third and fourth coupling. The use of distances between the couplings that are shorter than the length of conventional casing segments may provide surface indicators as to the location of the bottom hole assembly with a higher confidence than relying on a traditional tally sheet.

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 tubular joint elevator includes a ringed portion configured to lift a tubular joint. The elevator includes an elevating mechanism disposed adjacent to the ringed portion, and configured to elevate the tubular joint. In some embodiments, the elevator includes first, second, and third doors. The elevator includes a first locking member, and the first door includes a first locking recess. The first locking member is axially displaceable between an advanced position and a retracted position such that it is either received in or separated from the first locking recess. The third door includes a locking pin, and the first door comprises a locking hole. The third door is longitudinally displaceable between a first position and a second position such that the locking pin is either separated from, or received in, the locking hole. Methods of using the same are also included.

Abstract: A method of drilling and fracturing a well includes installing a drilling/frac adapter on a lower wellhead housing. The drilling/frac adapter has a higher internal pressure rating than the lower wellhead housing. The operator drills through the drilling/frac adapter to a desired depth, then runs and cements a casing string in the well. A lower packoff is installed in an annulus between the casing hanger and the lower wellhead housing and an upper packoff is set in an annulus between the drilling/frac adapter and the casing hanger. Frac fluid is pumped through the frac tree into the casing string at a higher pressure than the pressure rating of the lower housing but less than the pressure rating of the drilling/frac adapter. Then, the upper packoff and the drilling/frac adapter are removed from the lower housing and installing an upper wellhead housing on the lower wellhead housing.

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 example double shoulder threaded tool joint connection includes a pin with external threads formed between a pin external shoulder and a pin nose. The tool joint also includes a box with internal threads formed between a box face and a box internal shoulder. The box internal shoulder may have a different pitch that the pin external shoulder. The internal threads and the external threads may be arranged and designed for connection with each other so that the box and the pin are connected with a common center-line and with a primary seal formed by the pin external shoulder forced against the box face and a secondary seal formed between the pin nose forced against the box internal shoulder.

Abstract: A shoulder elevator having a gated pipe opening, is disclosed. The elevator has a ringed body having unclosed sector creating an opening for receiving a pipe within the body ring. Pivotally mounted gates positioned on opposite sides of the unclosed, sector of the ringed body, move in unison to an open and partially close the unclosed sector of the ringed body around the pipe in response to pipe contact with rearward end of the gates. A lever is provided to manually pivot the gates to an open and closed position around a pipe. Lifting lugs or ears are provided to attach the elevator to the lifting links of a hoist.

Abstract: A system and method for monitoring and controlling a snubbing unit having traveling slips and stationary slips are provided. Position sensors are associated with the slips for detecting opened and closed positions of the slips. Load sensors are associated with the slips for detecting load status of the slips. A control system receives input signals from the sensors, and confirms that either the traveling slips or the stationary slips are loaded before releasing or allowing the release the opposing set of slips, when transferring the pipe string load from the one set of slips to the other set of slips.

Abstract: Threaded couplings and methods for use in drilling with casing can include first and second male members having exterior threads engaged with interior threads of a female member. Exterior shoulders of the male members can abut interior shoulders of the female member to facilitate placement of the male members such that pin noses thereof are positioned at the center of the female member, where abutment between the pin noses of the male members can form a seal. The shoulders can be provided with negative angles to prevent disengagement. Tapered surfaces can be provided on the male members, to contact tapered surfaces on the female member to form metal-to-metal seals for enhancing the integrity of the connection, a straight thread configuration can be used to maximize the thickness of the coupling, and bearing journals or guides can be used to facilitate engagement of the threads and retention of the engagement.

Abstract: A centralizer, method, and centralizer assembly. For example, the centralizer assembly includes a first stop collar fixed in place on a tubular, and a first end collar that is sized to slide axially over the first stop collar. The centralizer assembly also includes a first retainer coupled with the first end collar. The first retainer prevents the first stop collar from sliding past the first stop collar in at least one axial direction. The assembly also includes a plurality of ribs coupled with the first end collar and configured to engage a surrounding tubular in which the tubular is disposed.

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 apparatus comprises a first number of splines located near a first end of a first joint section and a second number of splines located near a second end of a second joint section. The first number of splines extends in an axial direction of the first joint section and spans a circumferential surface of the first joint section. Each of the first number of splines has a base, a tip, and a pair of flanks that extends from the base to the tip and forms an acute angle. Each of the first number of splines are configured to be received between adjacent pairs of splines in the second number of splines as the first end of the first joint section and the second end of the second joint section are joined.

Abstract: A down hole well tool for installing a casing or liner in a well bore includes a tool unit and an expansion module for expansion of the casing or liner. The expansion module has at least two sets of rolling means arranged along an axial direction of the expansion module, and each set of rolling means is provided at an outer circumference of the expansion module. The diameter of the rolling means decreases at least between the two sets along the expansion module, providing the expansion module with a decreasing diameter in an axial down hole direction of the well bore.

Abstract: A method for running a tubular string in wellbore operations according to one or more aspects of the present disclosure includes providing a tubular running tool comprising gripping assembly rotationally connected to a carrier, the gripping assembly comprising a body and slips; connecting the carrier to a quill of a top drive of a drilling rig; positioning an end of a tubular for gripping with the slips; actuating the slips into gripping engagement with the tubular; and rotating the tubular with the slips in gripping engagement therewith.

Abstract: Systems, apparatus, and methods for longitudinally moving or running a tubular, with the system including an elevator suspended from a rig. The elevator includes a body defining a bore to receive a tubular and wedges defining channels therebetween, with the wedges being configured to engage the tubular. The system may also include a spider including a body defining a bore to receive the tubular and wedges defining channels therebetween. The wedges of the spider may be configured to engage the tubular, and the wedges of the elevator may be configured to slide axially at least partially in the channels of the spider. The wedges of the spider may be configured to slide axially at least partially in the channels of the elevator.

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 method of servicing an electric submersible pump in a well with a positive wellhead pressure includes providing production tubing in the well casing, a coil tubing string within the production tubing having an electric submersible pump at a downhole end of the coil tubing string, and a pump-receiving housing above the injection port of the wellhead. With the injection port sealed and the pump-receiving housing opened, the electric submersible pump may be inserted or removed from the pump-receiving housing. With the pump-receiving housing closed and the injection port opened, the electric submersible pump may be moved to or from the production tubing in the well.

Abstract: An expandable translating joint comprises a first expandable tubular member having a lower end with a recessed inner wall portion and a second expandable tubular member having an upper end with a recessed outer wall portion. The second expandable tubular member is partially disposed within the first expandable tubular member such that the recessed inner wall portion at least partially surrounds the recessed outer wall portion. A retainer is coupled to the recessed inner wall portion of the first expandable tubular member and disposed within the recessed outer wall portion of the lower second expandable tubular member. An expansion cone is operable to move axially through and radially expand the first and second expandable tubulars. The first expandable tubular can translate relative to the second tubular member both before and after expansion.

Abstract: A threaded tubular connection includes a first body terminated by an external abutment, and linked to a male threading prolonged by a terminal portion forming an internal abutment surface at its axial end, such that the connection includes a second body defining a bearing surface for the external abutment at one free end, and including an initial portion on its internal surface connecting the bearing surface to a female threading, made up onto the male threading, and terminating in an internal shoulder facing the internal abutment, such that the linking profile between one of the following: the external abutment, the internal abutment, the bearing surface, and/or the internal shoulder, has a profile with a variable diameter in cross section, over a length of the body which is less than the terminal portion or initial portion.

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 method of running a first tubular within a second tubular includes running the first tubular into the second tubular past at least one lateral extending from the second tubular, running a diverting tool at the first tubular with the running of the first tubular, withdrawing the first tubular from the second tubular until an end of the first tubular is beyond a junction between the at least one lateral and the second tubular and, running the first tubular into the at least one lateral.

Abstract: There is disclosed a tool for centering a casing or liner In a borehole. The tool Includes a tubular section Inserted In the casing/liner. A number of pressure cylinders (4) are mounted in the tubular section along the circumference. The pressure cylinders may be expanded by pressure from the Inside of the tubular section. In use, the casing/liner with the tubular section is run into the borehole with the pressure cylinders retracted. Thereafter, the pressure Inside the casing/liner Is Increased pressing the pressure cylinders out and centering the casing/liner.

Abstract: An attachment apparatus for attaching to a tubular. The apparatus may include a flexible member extending circumferentially around the tubular more than once. A tension force on the flexible member may cause the flexible member to apply a first radially-inward gripping force on the tubular. An annular sleeve may be positioned radially-outward from the flexible member. The sleeve may apply a second radially-inward gripping force on the flexible member and the tubular.

Abstract: A pipe-handling system includes at least two pipe-handling units arranged in a vertically displaceable manner along respective guide tracks of, respectively, first and second portions of a tower. The pipe-handling unit is provided with lower and upper rotary units spaced apart vertically on a chassis. Each of the rotary units is provided with a rotatable tong and a hanging-off device. A method is for inserting and withdrawing a pipe string in/from a borehole by the use of the pipe-handling system.

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.

Abstract: An elevator to manipulate a tubular segment includes an elevator body with a bore formed therethrough having an axis therein, the elevator body including a plurality of openings extending from an outer surface of the elevator body to the bore of the elevator body, and a base member coupled to a bottom surface of the elevator body, the base member having a guide portion that directs the tubular segment into the bore of the elevator body. The elevator also includes a plurality of slip assemblies disposed inside the plurality of openings and coupled to the elevator body, each of the plurality of slip assemblies including an actuator body coupled to the elevator body, a slip, the slip including an engagement surface disposed orthogonal to the axis of the bore of the elevator body that engages the tubular segment.

Abstract: A wireline connector device (10) for use in wireline intervention operations comprises a housing (18) connected to a first wireline conduit (L), a piston sleeve (46) located within the housing, and a collet device (60) configured to receive and retain a second wireline conduit, the collet device having a plurality of collet fingers (58) arranged within the piston sleeve, which is movable within the housing to open and close the collet fingers. Optionally a restrictor (57) can be configured to control the movement of the piston sleeve, and can be adjustable to lock the piston sleeve in the second position when the collet fingers are closed around the second wireline conduit. Typically at least one indicator rod (55) projects from the housing, and the piston sleeve engages indictor rod in the second position.

Abstract: A system and method for splicing a non-spoolable tool anywhere along a coiled tubing string. A removable tubing section may be connected along a coiled tubing string by two spoolable connectors. The coiled tubing string may be unspooled from a reel until the removable tubing section and connectors are positioned within a work window. The removable tubing section may be disconnected from the tubing string through the work window and a tool may be connected to the coiled tubing string via the two connectors. The tool may then be positioned within a wellbore by insertion of the coiled tubing string. The tool may aid in the insertion of the coiled tubing string into the wellbore. A portion of the wellhead may be disconnected and raised to expose the connectors to permit the removal of the removable tubing section and the connection of a non-spoolable tool.

Abstract: A system for aligning and connecting components including a support structure and a measuring apparatus coupled to the support structure. The measuring apparatus is arranged to spatially analyze a first tubular component with respect to a second tubular component for determining an adjustment vector therebetween. An alignment apparatus is coupled to the support structure and in data communication with the measuring apparatus. The alignment apparatus includes a plurality of actuators operatively arranged in parallel for moving at least one of the first or second tubular components relative to the other for coaxially arranging the first and second tubular components in accordance with the adjustment vector. A connection apparatus is coupled to the support structure and operatively arranged for connecting the first and second tubular components together.

Abstract: In one aspect, a system includes a tool, a hanger connected to the tool, and a plurality of tubulars connected to the hanger and adapted to be positioned within a wellbore. The tool, hanger, and tubulars are rotatable in response to at least the application of torsion to the tool, and without transferring torque to the connection between the tool and the hanger. In another aspect, a method includes positioning a tubular string within a wellbore, connecting a hanger to the tubular string, and applying torsion to the tubular string to rotate the tubular string. To apply torsion to rotate, a tool is connected to the hanger, and torsion is applied to the tool without transferring torque to the connection between the tool and the hanger. In another aspect, there is provided an apparatus for rotating a tubular string in a preexisting structure, such as a wellbore.

Abstract: A contoured boss for conforming to an outer surface of a tubular member for deployment within a subterranean formation, the contoured boss comprising a valve receiving body having a contoured outer surface that extends radially outward from an outer surface of the tubular member; and passage for receiving a valve, the passage extending through the valve receiving body. A method for facilitating stimulation treatments in completions and a method of centering a tubular member having an outer surface within a borehole are also provided.

Abstract: An expandable device comprising a plurality of expandable cells. The cells may be bistable cells or other types of cells that are expanded from a contracted position towards an expanded position. Additionally, the cells may be combined with locking mechanisms to hold the structure in an expanded position.

Abstract: A method of forming a tubular conduit in a borehole, wherein the borehole is closed by means of a pressure barrier capable of sustaining a borehole pressure and having at least one pressure sealable inlet, comprises: introducing a substantially flat, elongate flexible member into the borehole; and forming the flexible member into a tubular form to define the conduit inside the borehole below the pressure barrier. An apparatus for forming a tubular conduit in a borehole closed by a pressure barrier capable of sustaining a borehole pressure and having at least one pressure sealable inlet, comprises: a supply of a substantially flat, elongate flexible member; a feed system for introducing the member into the borehole; and a former below the pressure barrier for forming the flat member into a substantially tubular conduit in the borehole.

Abstract: An expanded non-bonded mesh well screen. A method of manufacturing a well screen includes the steps of: expanding at least a portion of a screen jacket; and then securing the screen jacket onto a base pipe. A well screen system includes a base pipe and an at least partially expanded screen jacket surrounding the base pipe. The screen jacket is expanded prior to being positioned on the base pipe.

Abstract: A tubular member handling apparatus including a tubular member running tool, an elevator, first actuators each extending between the running tool and the elevator, and second actuators each extending between the running tool and a corresponding first actuator. The running tool includes a slotted member having a plurality of elongated slots, a recessed member slidably coupled to the slotted member and having a plurality of recesses, and a plurality of rolling members each retained between one of the recesses and one of the slots. Each rolling member partially extends through an adjacent slot when located in a shallow end of a corresponding recess, and retracts to within an outer perimeter of the slotted member when located in a deep end of the corresponding recess.

Abstract: A noninvasive method for the affixing of a transmission in a downhole housing wherein the housing is deformed, creating an oval cross section, and inserting the transmission into the housing with the greatest cross section of the transmission being positioned along the major axis of the oval created and, thereafter, releasing pressure to cause said housing to return to its normal circular cross section.

Abstract: Just above an oil wellbore, an example circumferential displacement tool grips a threaded coupling in performing a circumferential displacement method of properly tightening the coupling to an upper sucker rod and/or to a lower one. In some examples, upper and lower joints of the coupling are tightened sequentially and independently to ensure proper circumferential displacement at each joint. In some examples, during disassembly of a string of rods being withdrawn from the wellbore, the tool can unscrew the coupling selectively from either the upper rod or the lower one. In some examples, a controller monitors the tightening or unscrewing of a joint and derives a joint signature based on a series of torque and rotation readings sampled during the make or break operations. The controller, in some examples, identifies a defective joint by comparing the joint signature to a predetermined reference.

Abstract: A wet connection system suitable for use in hydrocarbon wells preferably comprises one or more elongate, small diameter conduits (50) which extend down the wellbore (2) and terminate adjacent a locating structure (11) on the production tubing (10). Equipment (70) deployed at the locating structure is connected to one or more self supporting conductors (30) which extend down the conduits from the wellhead (5). Preferably the conductors are retractable and the conduits are sealingly connected to the equipment, allowing the equipment and conductors to be deployed and recovered independently of each other and to be flushed with dielectric oil (99) pumped down the conduits after re-connection.

Abstract: A component for a drill stem including a tubular body with at least one first end zone and a second end zone. The component includes a sheath for passage of a cable extending inside the tubular body between the first end and the second end zone and at least one liner which lines at least a portion of the inside of the tubular body in the first end zone. At least a first end portion of the sheath includes a first threading. The liner supports a second threading. The first and second threading are screwed together.

Abstract: A system for manipulating a tubular about a drilling rig is provided. The system includes a swivel body rotatably coupled with a becket. The becket is configured to couple with a traveling block of the drilling rig. The system also includes an engagement feature rotatably coupled with the swivel body. The engagement feature is configured to be actuated to engage the tubular. In addition, the system includes a tilt mechanism configured to be actuated to transition the swivel body and the engagement feature between a tilted orientation and an upright orientation relative to the becket.

Abstract: A clamping system for making and breaking threaded connections between a first component and a second component includes a first clamp assembly and a second clamp assembly. The first clamp assembly includes a first clamp member and a second clamp member disposed about an opening in the first clamp assembly. The second clamp assembly includes a third clamp member and a fourth clamp member disposed about an opening in the second clamp assembly. The opening in the second clamp assembly being coaxially aligned with the opening in the first clamp assembly. The first clamp member and the second clamp member are configured to engage the first component. The third clamp member and the fourth clamp member are configured to engage the second component. The first clamp member and the second clamp member are configured to rotate the first component relative to the second component.