WO2009025832A1

WO2009025832A1 - Apparatus for running tubulars

Info

Publication number: WO2009025832A1
Application number: PCT/US2008/009935
Authority: WO
Inventors: Richard Mcintosh
Original assignee: Individual
Current assignee: Individual
Priority date: 2007-08-22
Filing date: 2008-08-21
Publication date: 2009-02-26
Anticipated expiration: 2010-02-22

Abstract

A method and apparatus for running tubulars into a well bore for use with a top drive or power swivel comprising a make-up assembly with inner and outer mandrels one of which has an array of ramped surfaces while the other is a ball or roller cage with balls or rollers and apertures wherein relative movement of the mandrels urges the balls or rollers to protrude radially through the apertures to engage a tubular internally or externally. Also provided is an elevator assembly with elevator links and transfer elevators to position tubulars for engagement by the make-up assembly.

Description

APPARATUS FOR RUNNING TUBULARS

[0001] This application claims priority from U.S. Provisional Application Serial No. 60,965,697 ("the '697 application") filed August 22, 2007. The '697 application is incorporated here by reference.

BACKGROUND OF THE INVENTION

[0002] The present invention relates to a method and apparatus for facilitating the connection of tubulars used in the oil and gas exploration and extraction industries using a top drive. More specifically, the invention relates to an apparatus for running tubulars into a well bore. [0003] In the construction of oil or gas wells it is usually necessary to line the well bore with a string of steel pipes with threaded connectors commonly known as tubulars or tubing or generically as oil country tubular goods ("OCTG"). For purposes of this application, such steel pipes shall hereinafter be referred to as "tubular OCTG". Because of the length of the tubular OCTG required, individual sections of tubular OCTG are typically progressively added to the string as it is lowered into a well from a drilling rig or platform. The section to be added is restrained from falling into the well by some tubular engagement means, typically a spider or the like, and is lowered into the well to position the threaded pin of the tubular OCTG section adjacent to the threaded box of the tubular OCTG in the well bore. The sections are then joined by relative rotation of the sections until such time as the desired total length has been achieved. [0004] It is common practice to use a power tong to torque the connection to a predetermined torque in order to connect the sections of tubular OCTG. This traditional method and equipment types have been used extensively around the world for a period in excess of fifty years. While this method is in daily use it normally requires a large team of specialist personnel along with a plethora of equipment to successfully undertake this task. It is also a very dangerous task with personnel having to be located on a small platform suspended up to 50 feet above the rotary table and the power tong tethered to a steel cable under high loads.

[0005] hi more recent times, a top drive may be used; that is, a top driven rotational system used for drilling purposes. Where a top drive system is used to make the connection, the use of a slip type elevator to restrain the section of tubular OCTG to be added may be problematic, due to the configuration of the top drive apparatus on the drilling platform. It is therefore known to make use of an apparatus connected to the top drive, which can be inserted into the section of tubular OCTG to be added, and engaged therewith to hold the section in place. Such apparatus may comprise one or more toothed grapples, which may be hydraulically operated to engage an inner surface of the tubular. While this is an advancement over the traditional approach, as it requires substantially less equipment, it has serious drawbacks in the form of potential damage it can cause to the outer or inner surface of the tubular OCTG. These grapples also tend to be very sensitive to varying changes in tubular weight and diameters and therefore require a large resource of alternative sizes for each tubular OCTG size to be run.

[0006] Secondly as the grapples tend to bite aggressively into the tubular OCTG and take no account of alignment issues it is possible to load one side of the grapples while running the tubular OCTG into the well bore. The possibility of loading one side of the tubular OCTG can present serious consequences for the integrity of the tubular OCTG and its ability to withstand down-hole pressures in the borehole. This in turn may also result in premature failure of the grapples or impede their ability to act correctly on the tubular OCTG.

[0007] The intention of the present invention is to offer a much-improved method of running tubular OCTG into a borehole without the shortfalls in the tools available today.

SUMMARY OF THE INVENTION

[0008] An apparatus has been invented for handling tubular OCTG. The apparatus is connectable to a top drive and can be used to grip the tubular OCTG from the inside. The system comprises a top drive, a tubular OCTG make-up assembly, elevator links and transfer elevators. [0009] The operator can remotely manipulate the elevator links to extend or retract the transfer elevators to pick up and position a tubular OCTG above the tubular OCTG already secured in the rotary table on the drill floor. The operator can then engage a probe and activate a hydraulic or pneumatic actuator causing a gripper assembly to grip the tubular OCTG, and then use the rotational capability of the top drive to remotely couple the two joints of tubular OCTG together. [0010] According to a first aspect of the present invention, there is provided a make-up assembly for running tubular OCTG into and/or out of the well bore, the make-up assembly comprising a probe engageable within the tubular OCTG, wherein the probe comprises an inner mandrel having an outer surface, a plurality of inclined ramps, a ball cage surrounding the mandrel and having a plurality of balls or rollers captively located in apertures in the ball cage and aligned with the inclined ramps of the mandrel, being relatively movable to cause the balls or rollers to climb and descend the inclined ramps thus, respectively to protrude from and retract within said apertures and, when protruding, to bear upon the inner surface of the tubular OCTG to lock the probe and receiving tubular OCTG in engagement.

[0011] The probe further comprises an upper hydraulic actuator having an inner sliding sleeve that, when activated, will cause the ball cage to travel relative to the movement of the inner mandrel, thus providing a means of controlling the placement of the balls or rollers relative to the ball cage, therein locking the probe in place prior to applying a rotational force, lifting action or lowering action upon the tubular OCTG.

[0012] The make-up assembly can include further means for moving the balls or rollers radially with respect to the inner mandrel.

[0013] One major advantage of this method of engagement of the balls or rollers against the tubular OCTG is that this method provides for maximum displacement of load without causing damage to the inner surface of the tubular OCTG. Damage to or scarring of the inner face of the tubular OCTG can cause premature failure of the tubular OCTG resulting in the requirement to undertake expensive remediation work on the well bore.

[0014] According to a second aspect of the present invention, there is provided an elevator assembly for facilitating the transfer of a tubular OCTG from the V-door of a drilling rig to the vertical position and thereby allowing the tubular OCTG to be stabbed into a similar tubular OCTG located in the slip assembly located in or on the drill floor for the running or pulling of tubular OCTG into and/or out of the well bore. The elevator assembly comprises a set of telescoping transfer elevator links attached to the make-up assembly of the present invention connected to the top drive system or drilling hook on a non-top-drive fitted rig, whereby the telescoping transfer elevator links can be extended to facilitate engagement of the tubular OCTG at the V-door and then retracted to bring the tubular OCTG into a position to be raised to a position ready for stabbing of the tubular OCTG into a similar tubular OCTG located in the slip assembly located in or on the drill floor. The elevator assembly may also have an elevator link tilt assembly comprising two or more hydraulic actuators, wherein the link tilt assembly is coupled to the telescoping transfer elevator links such that the extension or retraction of the hydraulic actuators can pivot the telescoping transfer elevator links about a point located on a vertical axis; providing a secondary means of positioning the transfer elevators to facilitate transfer of the tubular OCTG into the stabbing position for make-up. [0015] The make-up assembly may further be provided with positive locking means to maintain the balls or rollers in engagement with a tubular OCTG should the make-up assembly otherwise fail. The positive locking means may be provided in conjunction with axially angled faces, and/or in conjunction with circumferentially angled faces. The positive locking means may comprise, for example, a spring or hydraulic safety interlock system.

[0016] In addition to gripping, rotating, lifting and lowering the tubular OCTG, another function of the make-up assembly is to transmit the circulation of drilling fluid or mud through the tubular OCTG. In order to pump drilling fluids or mud, a seal must be established between the tubular OCTG and the make-up assembly of the present invention, hi use, the make-up assembly will be connected to a top drive via a threaded connection at its upper end, or to a non-top-drive rig via a pup joint latched into an elevator. Both systems have available a means of connecting to a circulating system that will permit the tubular being handled to be filled or circulated at any time during the running operation. In preferred embodiments, the mandrel of the make-up assembly is equipped with a through bore to permit tubular fill-up and circulation to take place at any time. [0017] There may also be provided a packer cup with a sealing element, preferably comprising an elastomer element or layer over a steel body. The sealing element of the packer cup is self energized to establish an initial seal and further energized by the pressure inside the tubular OCTG, which forces the sealing element against the walls of the tubular OCTG, thereby forming a seal to allow mud or drilling fluid to be pumped though the tubular OCTG assembly. [0018] The present invention further comprises a control system that is able to manipulate the telescoping transfer elevator links, link tilts, and other elements of all aspects of the present invention. The control system of the present invention is able to open and close the transfer elevators, retract and extend the telescoping transfer elevator links, the secondary link tilt, control and measure the application of torque and turns and stop the rotation of the make-up assembly of the present invention at a pre-determined torque point utilizing either a wireless communication system or a system of hydraulic or pneumatic control line umbilical. The wireless communication system can also be used in other applications to measure and control torque, applied loads and or have the ability to dump torque or applied load at a predetermined point. The system may also be coupled conventionally using a series of cables should the use of wireless communication be restricted. [0019] The control system is also able to set and unset the hydraulic actuator used to hydraulically manipulate the outer cage of the make-up assembly causing the balls or rollers to contact the tubular OCTG to facilitate make-up or breakout of the tubular OCTG threaded connection. The control system is also able to monitor feedback loops that include sensors or monitors on the elements of the present invention. For example, sensors of the control system of the present invention monitor the open and close status of the transfer elevators, the status of the hydraulic actuator and thereby the position of the balls or rollers. The control system is designed or rated for use in a hazardous working environment. Communication with the processor of the control system is accomplished through a wireless communications link.

[0020] The make-up assembly may further comprise a lower mandrel as a tapered guide shoe or a bull-nose centralizer with a tapered high density urethane or polymer coated section sized to suit the tubular OCTG being run, to facilitate easy stabbing of the apparatus into the tubular OCTG, attached to the bottom of the inner mandrel to further protect the thread and sealing areas of the tubular OCTG to be coupled together. The lower mandrel further comprises an inner sleeve assembly fitted with a two-way acting valve to prevent mud discharge onto the drill floor when the apparatus is removed from the tubular OCTG.

[0021] It is an object of this invention to provide a make-up assembly for connection to a top drive for running individual or multiple tubular OCTG into and/or out of a well bore, and allowing the operator to make-up or breakout a tubular OCTG, wherein the make-up assembly comprises a series of inner and outer mandrels one of which has an array of ramped surfaces while the other comprises a ball or roller cage with a plurality of balls and or rollers, wherein relative movement of the mandrels and balls or rollers acts to urge the balls and or rollers to protrude radially through the apertures in the roller cage thus engaging the tubular OCTG internally. It is further intended that the same principal used for internal gripping may also be modified to suit external gripping applications. It is further intended that the balls or rollers and their respective ramped surfaces may be disposed randomly about the make-up assembly or in longitudinally spaced rows where the balls or rollers of each row are offset laterally with respect to those of the next succeeding row.

[0022] The inventive make-up assembly may also be connected to a power swivel suspended under a traditional Kelly in the event that the drilling rig does not have a top drive installed and or on a hydraulic work-over rig or snubbing unit. In the latter application the power swivel may be installed into a hydraulic or pneumatically controlled frame to lift and lower the power swivel and make-up assembly of the present invention into and out of the tubular OCTG and thereby the well bore.

[0023] It is a further object of this invention that the make-up assembly comprise an upper hydraulic actuator having an inner sliding sleeve that when energized will cause the cage to travel relative to the movement of the inner sliding sleeve, thus providing a means of controlling the placement of the balls and rollers relative to the inner mandrel therein locking the probe in place prior to applying a rotational force, lifting or lowering action upon the tubular OCTG. [0024] It is further intended that the make-up assembly be provided with a through bore to allow the transmission of drilling fluids or mud for the purposes of filling or circulation of the tubular OCTG while running into the well bore and further comprise a lower packer cup on the lower mandrel section of the make-up assembly which is self energizing by pressure inside the tubular OCTG thereby forming a seal to allow drilling fluid or mud to be pumped into the tubular OCTG and/ or well bore.

[0025] It is an object of this invention that the make-up assembly further comprise an elevator assembly with elevator links and transfer elevators which can be remotely manipulated to extend or retract the transfer elevators to pick up and position a tubular OCTG above the tubular OCTG already secured in the rotary table on the drill floor wherein the operator can then engage the make-up assembly to energize the ball or roller mechanism and use the rotational capability of the top drive to remotely couple the two tubular OCTG together.

[0026] It is a further object of this invention that the elevator assembly comprise a set of links used to position the tubular OCTG from the vertical position to the horizontal position wherein said links each contain a single and/ or multi stage hydraulic or pneumatic cylinder contained within the body of the links or mounted externally allowing the operator to extend the links into the correct position to accept the tubular OCTG in the transfer & lifting elevators. [0027] It is a further object of this invention that the hydraulic or pneumatic cylinders be coupled to a weight compensation control system whereby the activation of the weight compensation system will provide for the tubular OCTG to be lowered in a controlled fashion into the tubular OCTG already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular OCTG zero weight in gravity and protect the threads of the tubular OCTG during stabbing operations, for make-up or breakout operations. [0028] It is a further object of the invention to provide a method of running tubular OCTG into and/or out of a well bore, comprising the steps of: locating a tubular OCTG and extending links and transfer elevators around the tubular OCTG; moving a top drive assembly in an upward movement causing the captured or retained tubular OCTG into a vertical position above a tubular OCTG already secured in the rotary table on the drill floor; activation of the weight compensation system to lower the tubular OCTG in a controlled fashion into the afore mentioned tubular OCTG already secured in the rotary table; engage the threads of the upper tubular OCTG in the threads of the tubular OCTG already secured in the rotary table on the drill floor; lowering the top drive with attached make-up assembly entering the tubular OCTG; once inside the tubular OCTG, activate the hydraulic actuator to cause relative movement of the mandrels causing balls and or rollers to partially protrude radially through apertures in a roller cage thus engaging the tubular OCTG; once the balls or rollers are engaged on the inner or outer wall of the tubular OCTG rotate the top drive mechanism to cause the upper tubular OCTG threads to engage correctly with the opposing threads of the tubular OCTG already secured in the rotary table on the drill floor and thereby connecting both tubular OCTG into one continuous member; lifting the tubular OCTG members in an upward direction by the make-up assembly connected to the top drive while unsetting the slip mechanism of the retaining device in the rotary table to allow the joined tubular OCTG to be lowered into the well bore. By reversing the process the tubular OCTG members can be removed from a well bore if desired

BRIEF DESCRIPTION OF THE DRAWINGS

[0029] These and other aspects of the present invention will now be described by way of example only and with reference to the accompanying drawings, in which: [0030] Figure 1 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention with a plurality of balls and or rollers and their respective apertures radially mounted thereon.

[0031] Figure 2 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention with a plurality of balls and or rollers and their respective apertures randomly mounted thereon.

[0032] Figure 3 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention with a plurality of balls and or rollers and their respective apertures diagonally mounted thereon. [0033] Figure 4 shows an axial sectional view of a make-up assembly in accordance with one embodiment of the present invention showing the relationship between the inner mandrel, cage, thru bore, balls and rollers thereon.

[0034] Figure 5 shows a sectional view through the mandrel of the make-up assembly in Figure

1, showing the longitudinal alignment of the balls or rollers of adjacent rows.

[0035] Figure 6 shows a sectional view through the mandrel of the make-up assembly in Figure 2

& 3, showing further longitudinal alignment of the balls or rollers of adjacent rows, which leaves no continuous longitudinal spaces between the columns of balls or rollers, as is the case in figure

1 & 5.

[0036] Figure 7 shows the tapered guide shoe - lower mandrel of the make-up assembly which may be urethane coated or of nylon drift material to protect the tubular OCTG threads during stab-in operations.

[0037] Figure 8 shows an axial sectional view of a make-up assembly according to the invention displaying the ball or ramp profile, used to energize the balls or rollers against the inner wall of the tubular OCTG.

[0038] Figure 9 shows an axial view of a make-up assembly in accordance with one embodiment of the present invention shown in Figure 1 with a plurality of balls and or rollers radially mounted thereon installed inside a tubular joint OCTG.

[0039] Figure 10 shows a sectional view through the elevator links of the elevator assembly in accordance with one embodiment of the present invention showing the multi-stage hydraulic ram installed inside the link along with the adjustment holes used to further extend the length of the links for varying rig applications.

[0040] Figure 11 shows a side view of the make-up assembly and elevator assembly in accordance with one embodiment of the present invention showing how it would be rigged up for connection to a top-drive assembly.

[0041] Figure 12 shows a pictorial view of a top drive assembly defining how the make-up assembly and elevator assembly of the present invention may be installed too. It should be noted that manufacturers of top drive systems are many and each may have their own technical differences in configuration of moving parts. However it is generally found that they are all capable of executing the same tasks of providing a means for connection to a drilling string or cross-over sub; providing a means for rotation in both forward and reverse directions and the ability to apply torque in varying degrees of power.

[0042] Figure 13 shows a side view of a make-up assembly in accordance with one embodiment of the present invention showing how it would be rigged up to a power swivel and hydraulic or pneumatically controlled torque frame.

DETAILED DESCRIPTION OF THE INVENTION

[0043] hi Figures 1 to 4 is shown a make-up assembly comprising a probe that can be inserted into a tubular OCTG 10 as shown in Figures 9 and 10, for the purpose of making up or breaking out a threaded connection on a tubular OCTG 10 such as tubular OCTG used in the construction of a well bore, in accordance with an embodiment of the present invention. [0044] The make-up assembly comprises an inner tubular mandrel 7 having a plurality of ramped surfaces 8 spaced apart thereon, a second elongate member 3 superimposed with respect to the ramped surfaces 8 of the inner mandrel 7, a plurality of rolling members 9 captively retained within apertures 9 of the cage 3 so as to reside respectively on the ramped surfaces 8 of the inner mandrel 7. Energizing a hydraulic or pneumatic actuator 2 will cause relative movement of the cage 3 to cause the rolling members 9 to descend the ramped surface 8 of the inner mandrel 7 thereby protruding partially from the apertures 4 contained in various styles about or around the cage 3, causing the rolling members 9 to contact the tubular OCTG 10 and thereafter a rotational movement can be applied by the top drive engaging the threaded portion of the tubular OCTG 10 to connect it to its respective partner located in the rotary table. In addition the inner mandrel 7 has a through bore 20 formed through its long axis for the purpose of allowing conveyance of drilling fluids or mud.

[0045] The inner mandrel 7 may be of circular cross section having the cage 3 concentrically disposed around it.

[0046] The inner mandrel 7 and the cage 3 may be arranged for longitudinal movement one with respect to the other.

[0047] The cage 3 may be a ball 9 or roller cage having an array of apertures 4, through which the respective balls or rollers 9 may partially protrude.

[0048] An embodiment of the present invention will now be described, by way of example only with reference to the accompanying drawings numbered as figure 1 through to 14. [0049] Figure 1 shows the make-up assembly with a series of longitudinally displaced rows of apertures 4, a lower packer cup 5, a guide shoe 6 to facilitate stabbing of the make-up assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner mandrel 7. The size and quantity of the balls or rollers 9 can be increased or decreased to suit varying applications, types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0050] Figure 2 shows the make-up assembly with a series of diagonally displaced rows of apertures 4, a lower packer cup 5, a guide shoe 6 to facilitate stabbing of the make-up assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner mandrel 7. The size and quantity of the balls or rollers 9 can be increased or decreased to suit varying applications, types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0051] Figure 3 shows the make-up assembly with a series of randomly displaced rows of apertures 4, a lower packer cup 5, a guide shoe 6 to facilitate stabbing of the make-up assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner mandrel 7. The size and quantity of the balls or rollers 9 can be increased or decreased to suit varying applications, types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0052] Figure 4 shows a cross sectional view of the make-up assembly showing the inner mandrel 7 with the thru bore 20, the ramped surfaces 8 for the ball or rollers 9 to ascend and or descend and the lower guide shoe 6.

[0053] Figure 5 shows a schematic representation of an end view of the make-up assembly showing the inner mandrel 7, cage 3 and the ball or roller 9 showing the longitudinal alignment of the ball or rollers 9 in adjacent rows.

[0054] Figure 6 shows a schematic representation of an end view of the make-up assembly as detailed in figures 2 & 3 showing the inner mandrel 7, the cage 3 and the ball or roller 9 showing that either diagonal or random placement of the ball or roller 9 leaves no continuous longitudinal spaces between the columns of balls or rollers 9 as is the case in figure 1. This non-uniform arrangement of the balls or rollers 9 results in a more uniform grip being induced into the inner wall of the tubular OCTG 10 once the make-up assembly is energized. [0055] Figure 7 shows the arrangement of the tapered guide shoe 6 used to facilitate stabbing the make-up assembly into a tubular OCTG 10.

[0056] Figure 8 shows a detailed close-up view of the ramped surfaces 8 of the inner mandrel 7 that the balls or rollers 9 ascend and descend. The view also shows the apertures 4 through which the balls or rollers 9 can partially protrude through and engage the inner surface of the tubular OCTG 10.

[0057] Figure 9 shows an embodiment of the present invention installed inside a tubular OCTG 10 prior to the balls or rollers 9 being energized. It can be clearly seen that the hydraulic or pneumatic actuator 2 or the drill pipe crossover joint 1 which connects the make-up assembly to the top drive or hook assembly does not engage the tubular OCTG 10.

[0058] Figure 10 shows a sectional cross view of the main elevator link body 16 showing the inner hydraulic or pneumatic multi- stage cylinder 14 used to extend or retract the lower link body 18 in relation to the corresponding link body 16. It also displays the adjustable mounting points 13 contained in the link body 16 such that the total length of the link body 16 may be set prior to extension or retraction. This will allow for a greater flexibility of total length, which will compensate for the variable distances between well centers and V-doors on drilling rigs. The figure also show the mounting point 15 for the link tilt mounted on the outside of the link main body 16. There are mounted on the upper section of the main link body 16 attachment points 11 to facilitate mounting the main link bodies 16 onto the hydraulic actuator 2. In order to provide a secondary means of retention the mounting points 11 include two threaded holes 12 for bolting a link retaining plate 27 and the transfer elevator attachment points 19.

[0059] Figure 11 shows a vertical view of the make-up assembly and elevator assembly detailing one configuration for attachment to a top drive assembly via the drill pipe crossover 1, the hydraulic actuator 2, the cage 3, the ball or roller apertures 4, packer cup 5, lower guide shoe 6, link lower body 18, attachment points 11, retaining plate 27 and the transfer elevator attachment points 19.

[0060] Figure 12 shows a pictorial view of a top drive assembly defining how the make-up assembly and elevator assembly of the present invention may be installed too. In this depiction, a top drive 30 on a frame 29 rides on a track 33, being raised or lowered by a block 32. A typical toothed grapple apparatus 31 is shown attached to the top drive 30. [0061] Figure 13 shows a sectional view of make-up assembly installed into a frame 23 installed onto a base plate 21 with telescoping members 24 allowing the make-up assembly to be raised and lowered. In this arrangement the make-up assembly would be typically be installed onto a wellhead assembly where no rig, derrick or top drive assembly was present. It could also be installed on a hydraulic work-over unit or snubbing unit. The frame 24 is variable in height and contains multi-stage hydraulic or pneumatic cylinders 28 to raise and lower the apparatus. [0062] It will be apparent that many other changes may be made to the illustrative embodiments, while falling within the scope of the invention and it is intended that all such changes be covered by the claims appended hereto.

[0063] Although the disclosed embodiments have been described in detail, it should be understood that various changes, substitutions and alterations can be made to the embodiments without departing from their spirit and scope. Other technical advantages of the present invention will be readily apparent to one skilled in the art from the following figures, drawings, descriptions and claims.

Claims

CLAIMSI claim:

1. A make-up assembly for connection to a top drive for running individual or multiple tubular OCTG with threaded connectors into and/or out of a well bore, wherein the make-up assembly comprises a series of inner and outer mandrels one of which has an array of ramped surfaces while the other compromises a ball or roller cage with a plurality of balls and or rollers, wherein relative movement of the mandrels and balls or rollers acts to urge the balls and or rollers to protrude radially through apertures in the roller cage thus engaging the tubular OCTG internally or externally.

2. The make-up assembly of claim 1, further comprising an upper hydraulic actuator having an inner sliding sleeve that when energized will cause the cage to travel relative to the movement of the inner sliding sleeve thus providing a means of controlling the placement of the balls and rollers relative to the inner mandrel therein locking the probe in place prior to applying a rotational force, lifting or lowering action upon the tubular OCTG.

3. The make-up assembly of claim 1 further comprising an elevator assembly with telescoping elevator links and transfer elevators which can be remotely manipulated to extend or retract the transfer elevators to pick up and position a tubular OCTG above the tubular OCTG already secured in a rotary table on a drill floor wherein an operator can then engage the make-up assembly to energize the ball or roller mechanism and use the rotational capability of the top drive to remotely couple the two tubular OCTG.

4. The make-up assembly of claim 3 further comprising a set of telescoping elevator links used to position the tubular OCTG from the vertical position to the horizontal position wherein said links each contain a single and/ or multi stage hydraulic or pneumatic cylinder contained within the body of the links or mounted externally allowing the operator to extend the links into the correct position to accept the tubular OCTG in the transfer elevators.

5. The make-up assembly of claim 1 wherein the make-up assembly is connectable to a top drive to apply torque to the inner mandrel thereby allowing the operator to make-up or breakout a tubular OCTG.

6. The make-up assembly of claim 4 wherein the hydraulic or pneumatic cylinders are coupled to a weight compensation control system whereby the activation of the weight compensation system will provide for the tubular OCTG to be lowered in a controlled fashion into the tubular OCTG already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular OCTG zero weight in gravity and protect the threaded connectors of the tubular OCTG during stabbing operations, for make-up or breakout operations.

7. The make-up assembly of claim 1 further comprising a lower mandrel with a tapered high density urethane or polymer coated section sized to suit the tubular OCTG being run, to facilitate easy stabbing of the apparatus into the tubular OCTG.

8. The make-up assembly of claim 7 wherein the lower mandrel further comprises an inner sleeve assembly fitted with a two-way acting valve to prevent mud discharge onto the drill floor when the apparatus is removed from the tubular OCTG.

9. The make-up assembly of claim 1 wherein the balls or rollers and their respective ramped surfaces may be disposed randomly about the make-up assembly or in longitudinally spaced rows where the balls or rollers of each row are offset laterally with respect to those of the next succeeding row.

10. The make-up assembly of claim 1 further comprising a through bore to allow the transmission of drilling fluids or mud for the purposes of filling or circulation of the tubular OCTG while running into the well bore, a lower packer cup on the lower mandrel section of the make-up assembly wherein said lower packer cup is self energizing by pressure inside the tubular OCTG thereby forming a seal to allow the drilling fluid or mud to be pumped into the tubular OCTG and/ or well bore.

11. The make-up assembly of claim 4 further comprising a control system to manipulate the telescoping transfer elevator links, link tilts, to open and close the transfer elevators, retract and extend the telescoping transfer elevator links, the secondary link tilt, control and measure the application of torque and turns and stop the rotation of the make-up assembly.

12. The make-up assembly of claim 11 wherein the control system further comprises a wireless communication system with a back-up series of cables used to record, measure and control the application of torque, applied turns and control a dump valve that is energized upon reaching a pre-determined torque point.

13. A method of running tubular OCTG with threaded connectors into and/or out of a well bore, comprising the steps of: locating a tubular OCTG and extending links and transfer elevators around the tubular OCTG; moving a top drive assembly in an upward movement causing the captured or retained tubular OCTG into a vertical position above a tubular OCTG already secured in a rotary table on a drill floor; activation of a weight compensation system to lower the tubular OCTG in a controlled fashion into the afore mentioned tubular OCTG already secured in the rotary table; engage the threads of the upper tubular OCTG in the threads of the tubular OCTG already secured in the rotary table on the drill floor; lowering a top drive with attached make-up assembly entering the tubular OCTG; once inside the tubular OCTG, activate a hydraulic actuator to cause relative movement of the mandrels causing balls and or rollers to partially protrude radially through apertures in a roller cage thus engaging the tubular OCTG; once the balls or rollers are engaged on the inner or outer wall of the tubular OCTG rotate the top drive mechanism to cause the upper tubular OCTG threads to engage correctly with the opposing threads of the tubular OCTG already secured in the rotary table on the drill floor and thereby connecting both tubular OCTG into one continuous member; lifting the tubular OCTG members in an upward direction by the make-up assembly connected to the top drive while unsetting a slip mechanism of a retaining device in the rotary table to allow the joined tubular OCTG to be lowered into the well bore.