WO2011056163A1

WO2011056163A1 - Apparatus & method for running tubulars

Info

Publication number: WO2011056163A1
Application number: PCT/US2009/005962
Authority: WO
Inventors: Richard Mcintosh; Toby Scott Baudoin
Original assignee: 2M-Tek, Inc.
Priority date: 2009-11-04
Filing date: 2009-11-04
Publication date: 2011-05-12

Abstract

A method and apparatus for running tubular into a well bore for use with a top drive or power swivel comprising a make-up assembly with inner and outer members one of which has an array of ramped surfaces while the other is a outer or outer cage with slipper-gripper blocks and apertures wherein relative movement of the members urges the slipper-gripper block 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 tubular for engagement by the make-up assembly.

Description

APPARATUS & METHOD FOR RUNNING TUBULARS

[0001] This application is a continuation-in-part application to International Application No. PCT/US2008/00935, filed 21 August 2008.

BACKGROUND OF THE INVENTION

[0002] The present invention relates to an apparatus and method 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 and method for running tubulars into or out of a well bore.

[0003] In the construction of oil or gas wells it is usually necessary to drill and line the well bore with a string of steel pipes commonly known as tubulars, casing, 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 (tubular members) are typically progressively added to the string (tubular string) as it is lowered into or lifted out of a well from a drilling rig or platform. The section to be added or removed 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 the threaded box of the tubular OCTG in the well bore. The sections are then joined by relative rotation of the sections and the process repeated until such time as the desired total length has been achieved.

[0004] It is common practice to use a power tong to torque each 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 often having to be located on a small platform suspended up to 50 feet from the rotary table or drilling rig floor and the power tong tethered to a steel cable under high loads.

[0005] In more recent times, a top drive may be used; this is, a top drive rotational system used for drilling purposes. Where a top drive system is used to make up 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 interior of or around the exterior of a 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 or outer surface of the tubular OCTG. While this is an advancement over the traditional approach as it requires substantially less equipment, it does however have serious drawbacks in the form of potential damage it may 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] Thirdly, as the grapples tend to be suspended on the outside of the member for internal gripping tools with no means of constraint they can become a huge safety issue if the rotational drive is engaged whilst the probe is not inside the tubular OCTG. The centrifugal forces cause the grapples to separate from the tool member, causing them to become entangled in the steel framework of the rig and potentially becoming dangerous objects falling from the derrick structure.

[0008] Fourthly, traditional methods of tool design permits the slip assemblies, bodies or inserts to potentially friction bond or become adhered to each other under heavy load conditions. This factor is due to the static frictional forces increasing; thereby displacing the lubricants between the sliding member surfaces. If these slip assemblies, bodies or inserts become frictionally adhered, this can cause serious problems, especially in a well control situation. It can cause the tubular OCTG or the slip assemblies, bodies or inserts to require to be mechanically separated by means of a cutting torch or other means.

[0009] Lastly in more recent designs the grapple portion has been replaced by the adoption of ball and taper technology originally designed for anchor handling applications where a static or dynamic axial load is applied. However this method of restraining the OCTG tubular is ineffective in providing rotational torque capacity required for the make-up of said OCTG tubulars. This is due to the self energizing features of the current designs. These designs do not allow the operator the ability to hydraulically or pneumatically control or apply a predetermined load sufficient to produce required indentations prior to applying torque.

[0010] The intention of the present invention is to offer a much improved apparatus and method of running tubular OCTG into or out of a borehole vastly improving the safety, efficiency and torque capability without the shortfalls in the tools available today.

SUMMARY OF THE INVENTION

[0011] 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 or the outside. The system comprises a top drive, a tubular OCTG running assembly, elevator links, transfer elevators, tubular sealing element, and mud valve.

[0012] 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. This function is normally achieved using a manually operated single joint elevator, however the present invention has incorporated a hydraulic transfer elevator complete with safety interlock thereby reducing the need to manually position or function the transfer elevator making the operation much safer and more operationally efficient. 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.

[0013] According to a first aspect of the present invention, there is provided a tubular OCTG running assembly for running tubular OCTG into and/or out of the well bore, the assembly comprising a probe engageable within the tubular OCTG, wherein the probe comprises an inner member having an outer surface with a plurality of inclined ramps and an outer cage surrounding the inner member having a plurality of openings to captively constrain the balls or slipper- gripper blocks. The openings of the outer member are aligned with the inclined ramps of the inner member and are axially movable to cause the balls and or slipper-gripper blocks 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.

[0014] According to a second aspect of the present invention, there is provided a tubular OCTG running assembly for running tubular OCTG into and/or out of the well bore, the assembly comprising a housing assembly engageable with the external surface of the tubular OCTG, wherein the housing assembly comprises an outer member having an inner surface with a plurality of inclined ramps and an inner cage within the outer member having a plurality of openings to captively constrain the balls or slipper-gripper blocks. The openings of the inner member are aligned with the inclined ramps of the outer member and are axially movable to cause the balls and or slipper-gripper blocks to climb and descend the inclined ramps thus, respectively to protrude from and retract within said apertures and, when protruding, to bear upon the outer surface of the tubular OCTG to lock the probe and receiving tubular OCTG in engagement.

[0015] The probe or external latching assembly further comprises a hydraulic actuator having a sleeve that is in connectable engagement with the cage housing (member with the openings), and when activated, will cause the cage housing to travel axially relative to the movement of the member with the inclined ramps, thus providing a means of controlling the placement of the balls or slipper-gripper blocks relative to the inclined ramps, therein locking or unlocking the probe in place prior to applying a rotational force, lifting action or lowering action or both upon the tubular OCTG. The contact forces between the balls and or the slipper-gripper blocks and the surface of the tubular OCTG can be controlled such that the necessary indentations are produced on the tubular OCTG to provide for the required torque value.

[0016] The surface of the slipper gripper blocks can be hemispherical or can be of any other surface profile such as nodular, sinusoidal, waveform, etc. The surface finish or texture can either be smooth, coated with a grit type material, toothed such as conventional inserts (could possibly look like a carbide burr), or a combination of these. The hemisphere profiles could be shaped so that they extend beyond the cage housing more than the hemispheric diameter as is with current ball and taper technology which is extremely limited. They can extend out any desired distance allowing the tool to work for a larger range of sizes and or weights.

[0017] One major advantage of this method of engagement of the balls and or slipper-gripper blocks 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 or outer 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. Standard dies, grapples, inserts, etc. tend to scar the tubulars in longitudinal directions, placing stress concentration areas as well as crevices for corrosion to take place. The advantage of the balls and or slipper-gripper block engagement mechanism is that they produce smooth indentations which do not create areas of increased corrosion or stress concentrations. The areas of indentation are actually work hardened thus they are mechanically stronger than the remaining tubular material. Thus, this means of engagement enhances the mechanical properties of the tubular rather than degrading the mechanical properties.

[0018] According to a third aspect of the present invention, there is provided a remotely operated 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 tubular running 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 horizontal axis; providing a secondary means of positioning the transfer elevators to facilitate transfer of the tubular OCTG into the stabbing position for make-up.

[0019] The tubular running assembly may further be provided with a positive locking means to maintain the balls and or slipper-gripper blocks 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. [0020] In addition to gripping, rotating, anchoring, lifting and lower the tubular OCTG, another function of the tubular running 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 tubular running assembly of the present invention. In use, the tubular running 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 members of the tubular running assembly are equipped with a through bore to permit tubular fill- up and circulation to take place at any time.

[0021] There may also be provided a packer cup with a sealing element, preferably comprising an elastomeric 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 through the tubular OCTG assembly.

[0022] The present invention further comprises a wireless communication 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 may also stop the rotation of the make-up assembly of the present invention at a pre-determined torque point utilizing either a wireless communication safety system or a system of hydraulic or pneumatic control line umbilicals. The wireless communication safety control system can also be used in other applications to measure and control torque, applied loads such as string weight and/or have the ability to dump torque or applied load at a predetermined point. The wireless communication safety system may also be coupled conventionally using a series of cables should the use of wireless communication be restricted.

[0023] The safety control system is also able to set and unset the hydraulic actuator used to hydraulically manipulate the cage housing of the tubular engagement apparatus causing the balls and or slipper-gripper blocks to contact the tubular OCTG to facilitate handling and make-up or breakout of the tubular OCTG threaded connection. The safety 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 safety control system of the present invention monitor the open and close status of the transfer elevator, the status of the hydraulic actuator and thereby the position of the balls and or slipper-gripper blocks. The safety control system is design rated and or certified for use in a hazardous working environment. Communication with the processor of the safety control system can be accomplished through a wireless communications link.

[0024] The tubular running assembly may further comprise a lower member as a tapered guide shoe or a bull-nose centralizer with a tapered high density urethane, polymer coated, or composite 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 member to further protect the thread and sealing areas of the tubular OCTG to be coupled together. The lower member further comprises a valve to prevent mud discharge onto the drill floor when the mud pumps are disengaged and the apparatus is removed from the tubular OCTG. The lower member can also be fitted with singular or multiple two-way acting check valves to facilitate reverse circulation or a solid member if necessary.

[0025] It is an object of this invention to provide a tubular running 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 tubular engagement apparatus comprises a series of inner and outer members or housings, one of which has an array of ramped surfaces while the other comprises a series of apertures, with a plurality of balls and or slipper-gripper blocks captively located between the inner and outer members, wherein relative axial movement of the members or cage housing acts to urge the balls and or slipper-gripper blocks to protrude radially through the apertures in the cage housing thus engaging the tubular OCTG. It is further intended that the gripping principal may be used for internal or external gripping. It is further intended that the balls and or slipper-gripper blocks and their respective ramped surfaces may be disposed randomly about the tubular engagement apparatus or in longitudinally spaced rows where the balls and or slipper-gripper blocks of each row are offset laterally with respect to those of the next succeeding row.

[0026] It is a further object of this invention to provide a tubular running assembly for handling a tubular member, making up or breaking out of threaded connections between the tubular member and another tubular member or tubular string, and the handling of the tubular string into or out of a wellbore, comprising a tubular engagement apparatus connectable to the driveshaft of a top drive, power swivel, or the like, the tubular engagement apparatus having a ball and taper assembly and an actuator or a slipper-gripper block and taper assembly and an actuator; wherein the ball and taper assembly or the slipper-gripper block and taper assembly consist of inner and outer members, one member containing an array of tapered or ramped surfaces while the other member comprises a tube with a plurality of apertures which retain the balls or slipper-gripper block; wherein relative axial movement between the inner and outer members of the ball and taper assembly or the slipper-gripper block and taper assembly acts to urge the balls or the slipper gripper block up or down the tapers to radially protrude or retract the balls or slipper- gripper block through the apertures in the tube member, thus engaging or disengaging the tubular member; wherein the tubular engagement apparatus is energized and de-energized by powered mechanical means provided by the actuator, hydraulic, pneumatic, or the like, whereby the balls or slipper-gripper blocks are forced up or down the tapers of the drive member thereby causing the balls or slipper-gripper blocks to come into contact with or retract from the surface of the tubular member; and wherein rotation of the driveshaft of a top drive, power swivel, or the like produces a corresponding rotation in the tubular member or tubular string via engagement of the ball and taper assembly or slipper-gripper block and taper assembly, whereby there is minimal relative rotation between the tubular engagement assembly and the tubular member or tubular string.

[0027] The inventive tubular running 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 tubular running assembly of the present invention into and out of the tubular OCTG and thereby the well bore.

[0028] It is a further object of this invention that the tubular running assembly comprise a hydraulic actuator that when energized will cause the cage housing to travel axially relative to the movement of the member with the inclined ramps thus providing a means of controlling the placement of the balls and or slipper-gripper blocks relative to the member containing the ramped surfaces therein locking the probe in place prior to applying a rotational force, lifting or lowering action upon the tubular OCTG.

[0029] It is further intended that the tubular running assembly be provided with a through bore to allow the transmission of drilling fluids or mud for the purpose of filling or circulation of the tubular OCTG while running into the well bore and further comprise a lower packer cup on the lower member 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.

[0030] It is an object of this invention that the tubular running 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 outer or roller mechanism and use the rotational capability of the top drive to remotely couple the two tubular OCTG together.

[0031] It is a further object .of this invention that the elevator assembly comprise a set of links used to position the tubular OCTG from a mostly horizontal position to the vertical 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.

[0032] It is a further object of this invention that the hydraulic or pneumatic cylinders may 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.

[0033] It is a further object of this invention that the weight compensation control system can be a separate system installed above the tubular running assembly actuator and below the top drive 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.

[0034] 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; latching transfer elevator around tubular OCTG; moving a top drive with a tubular running 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 aforementioned 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; activate the hydraulic actuator into the release position producing relative movement of the members causing the balls and or slipper-gripper block to retract radially through apertures in the tube; lowering the tubular running assembly onto or into the tubular OCTG; activate the hydraulic actuator into the latch position producing relative movement of the members causing the balls and or slipper-gripper block to protrude radially through apertures in the tube; once the balls and or slipper-gripper blocks 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 mating 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 tubular running 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.

[0035] It is further intended that the surface of slipper-gripper blocks may be: smooth, smooth and hardened, coated with a grit type material, toothed such as conventional inserts and dies, toothed and grit coated, or a multitude or combination thereof. The slipper-gripper block surface may be of any shape or profile including: smooth, curved, flat, hemispherical, nodular, lumpy, sinusoidal, waveform, etc., and any combination thereof. The slipper-gripper block may contain one or more surface features such as nodules, etc. The hemispheres or other surface profiles on the slipper-gripper blocks can either be smooth, coated with a grit type material, can include some type of tooth profile such as conventional dies, or any combination thereof. The hemispherical profiles of the slipper-gripper blocks can be shaped so that they extend beyond the tube member more than is possible with current ball and taper technology. They can extend out any desired distance, thereby allowing the tool to work for a larger range of sizes and or weights. The slipper-gripper blocks can produce a higher concentration of ball type protrusions per given length as would conventional ball and taper technology by placing more than one ball protrusion per gripper block. The backing surface opposite side to the gripping surface of the slipper- gripper block as well as a matching profile on the member could be flat, curved, cylindrical, etc. The backing surfaces provide far more contact surface area between the slipper-gripper block backing surface and member tapered ramp than balls. The slipper-gripper blocks also provide more surface area on their edges for the application of torque than do balls. Again, balls create a point loading on the sides of the tapered slots on the member with the potential for indentation. The slipper-gripper blocks greatly reduce this potential for member damage. The backing surfaces of the slipper-gripper blocks and or the sliding mating surface of the member can be coated with a friction reduction material, plating or process such as Teflon, Xylan, plain bearing or self lubricating materials such as an acetal filled bronze, chrome plating, hard chrome plating, electroless nickel, etc. The slipper-gripper blocks are constrained within a housing, such that they cannot be removed without complete disassembly of the tool. This becomes important should the assembly be rotated in free space (such as above a rig floor in the derrick), the slipper-gripper blocks cannot become projectiles. The slipper-gripper block technology including the hemispherical or nodular surface features may also be used as inserts, dies or grapples for other tubular running or gripping tools such as tongs, spiders, elevators, safety clamps, fishing tools, sub surface tools, whipstocks or packer type assemblies etc.

BRIEF DESCRIPTION OF THE DRAWINGS

[0036] 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:

[0037] Figure 1 shows an elevation view of a tubular engagement apparatus in accordance with one embodiment of the present invention with a plurality of balls and or slipper-gripper blocks and their respective apertures mounted in circumferential and longitudinal rows thereon. [0038] Figure 2 shows an elevation view of a tubular engagement apparatus in accordance with a second embodiment of the present invention with a plurality of balls and or slipper-gnpper blocks and their respective apertures mounted randomly thereon.

[0039] Figure 3 shows an elevation view of a tubular engagement apparatus in accordance with a third embodiment of the present invention with a plurality of balls and or slipper-gnpper blocks and their respective apertures mounted diagonally thereon.

[0040] Figure 4 shows an elevation view of a tubular engagement apparatus in accordance with a fourth embodiment of the present invention with a plurality of balls and or slipper-gnpper blocks and their respective apertures mounted in circumferential rows whereby every other row is staggered thereon.

[0041] Figure 5 shows a sectional view through the member of the tubular running assembly in Figure 1, showing the longitudinal alignment of the balls and or slipper-gnpper blocks of adjacent rows.

[0042] Figure 6 shows a sectional view through the member of the tubular running assembly in Figure 2, 3, and 4 showing further longitudinal alignment of the balls and or slipper-gripper blocks of adjacent rows, which leaves no continuous longitudinal spaces between the columns of balls and or slipper-gripper blocks, as in the case of figure 1 & 5.

[0043] Figure 7 shows the tapered guide shoe of the lower member of the tubular running assembly which may be urethane coated, nylon drift material, or some form of composite to protect the tubular OCTG threads during stab-in operations.

[0044] Figure 8 shows an axial sectional view of a tubular engagement apparatus according to the invention displaying the outer or ramp profile used to energize the balls and or slipper- gripper blocks against the inner wall of a tubular OCTG.

[0045] Figure 9 shows an axial view of a tubular running assembly in accordance with one embodiment of the present invention shown in Figure 1 installed inside a tubular joint OCTG.

[0046] 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. [0047] Figure 11 shows an elevation view of the tubular running 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.

[0048] Figure 12 shows a pictorial view of a top drive assembly defining how the tubular running 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.

[0049] Figure 13 shows an elevation view of a tubular running 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.

[0050] Figure 14 shows a sectioned elevation view of the ball and or slipper-gripper block and taper assembly for gripping the internal surface of a tubular OCTG.

[0051] Figure 15 shows a sectioned elevation view of the ball and or slipper-gripper block and taper assembly for gripping the external surface of a tubular OCTG.

[0052] Figure 16 is a top view of one embodiment of a slipper-gripper block showing a single hemispherical surface profile.

[0053] Figure 17 is a front view of the slipper-gripper block of Figure 16 showing the inclined surface on the bottom side as well as the cylindrical portion at the base of the hemispherical profile used to protrude the hemispherical surface further out from the cage housing.

[0054] Figure 18 is an end view of the slipper-gripper block of Figure 16 .

[0055] Figure 19 is a bottom view of the

slipper-gripper block of Figure 16.

[0056] Figure 20 is a top view of a second embodiment of a slipper-gripper block showing a double hemispherical surface profile.

[0057] Figure 21 is a front view of the slipper gripper block of Figure 20 showing the inclined surface on the bottom side.

[0058] Figure 22 is an end view of the slipper-gripper block of Figure 20.

[0059] Figure 23 is a bottom view of the slipper-gripper block of Figure 20. DETAILED DESCRIPTION OF THE INVENTION

[0060] In Figures 1 to 4 is shown a tubular engagement apparatus comprising a probe that can be inserted into a tubular OCTG 10 as shown in Figures 8 and 9, 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.

[0061] The tubular engagement apparatus comprises an inner tubular member 7 shown in Figures 5, 6 and 8 having a plurality of ramped surfaces 8 shown in Figure 8 spaced apart thereon, a second elongate outer cage member 3 superimposed with respect to the ramped surfaces 8 of the inner member 7, a plurality of balls and or slipper-gripper blocks 9 captively retained within apertures 4 of the cage 3 so as to reside respectively on the ramped surfaces 8 of the inner member 7. Energizing a hydraulic or pneumatic actuator 2 will cause relative movement of the outer cage 3 to cause the balls and or slipper-gripper blocks 9 to ascend or descend the ramped surface 8 of the inner member 7 thereby protruding partially from the apertures 4 contained in various styles about or around the outer cage 3, causing the rolling or sliding 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 member 7 has a through bore 20 shown in Figure 8 formed through its long axis for the purpose of allowing conveyance of drilling fluids or mud.

[0062] The inner member 7 may be of circular cross section having the outer cage 3 concentrically disposed around it.

[0063] The inner member 7 and the cage 3 may be arranged for longitudinal movement one with respect to the other.

[0064] The inner member 7 and the outer cage 3 may be splined to one another thereby allowing longitudinal relative movement but disallowing rotational movement there between.

[0065] The cage may be an outer cage 3 having an array of apertures 4, through which the respective balls and or slipper-gripper blocks 9 may partially protrude.

[0066] 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 23. [0067] Figure 1 shows the tubular running assembly with a series of longitudinally displaced rows of apertures 4, a lower packer cup 5, and a guide shoe 6 to facilitate stabbing of the tubular running assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner member 7. The size and quantity of the balls and or slipper- gripper blocks 9 can be increased or decreased to suit varying applications and or types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0068] Figure 2 shows the tubular running assembly with a series of randomly displaced rows of apertures 4, a lower packer cup 5, and a guide shoe 6 to facilitate stabbing of the tubular running assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner member 7. The size and quantity of the balls and or slipper-gripper blocks 9 can be increased or decreased to suit varying applications and or types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0069] Figure 3 shows the tubular running assembly with a series of diagonally displaced rows of apertures 4, a lower packer cup 5, and a guide shoe 6 to facilitate stabbing of the tubular running assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner member 7. The size and quantity of the balls and or slipper- gripper blocks 9 can be increased or decreased to suit varying applications and or types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0070] Figure 4 shows the tubular running assembly with a series of staggered displaced rows of apertures 4, a lower packer cup 5, and a guide shoe 6 to facilitate stabbing of the tubular running assembly into a tubular OCTG 10 and a hydraulic or pneumatic actuator 2 for energizing the cage 3 in respect to the inner member 7. The size and quantity of the balls and or slipper-gripper blocks 9 can be increased or decreased to suit varying applications and or types of tubular OCTG or total string weight or length of the connected tubular OCTG 10 when installed in the well bore.

[0071] Figure 5 shows a sectional view through the member of the tubular running assembly in Figure 1, showing the longitudinal alignment of the balls and or slipper-gripper blocks 9 of adjacent rows. [0072] Figure 6 shows a sectional view through the member of the tubular running assembly in Figure 2, 3, and 4 showing further longitudinal alignment of the balls and or slipper-gripper blocks of adjacent rows, which leaves no continuous longitudinal spaces between the columns of balls and or slipper-gripper blocks 9, as in the case of figure 1 & 5. This non-uniform arrangement of the slipper-gripper blocks 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.

[0073] Figure 7 shows the tapered guide shoe 6 of the lower member of the tubular running assembly which may be urethane coated, nylon drift material, or some form of composite to protect the tubular OCTG threads and facilitate stabbing.

[0074] Figure 8 shows a detailed close-up view of the ramped surfaces 8 of the inner member 7 that the balls and or slipper-gripper blocks 9 ascend and descend. The view also shows the aperture 4 through which the balls and or slipper-gripper blocks 9 can partially protrude through and engage the inner surface of the tubular OCTG 10.

[0075] Figure 9 shows an embodiment of the present invention installed inside a tubular OCTG 10 prior to the balls and or slipper-gripper blocks 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 makeup assembly to the top drive or hook assembly does not engage the tubular OCTG 10.

[0076] 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 shows the mounting point 15 for the link tilt mounted on the outside of the link main body 16. The figure also shows the attachment points 11 to facilitate mounting the main link bodies 16 onto the hydraulic actuator 2. Also shown is the lower link extendable portion 18 of the link assembly with the elevator attachment point 19 near its end.

[0077] Figure 1 1 shows a vertical view of the tubular running 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 outer cage 3, the slipper-gripper blocks apertures 4, packer cup 5, lower guide shoe 6, link lower body 18, transfer elevator attachment points 19, and the transfer elevator 27.

[0078] 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.

[0079] Figure 13 shows a sectional view of tubular running assembly installed into a frame 23 installed onto a base plate 21 with telescoping members 24 allowing the tubular running assembly to be raised and lowered. In this arrangement the tubular running assembly would be typically 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 utilizing a power swivel or rotary drive assembly 22. The frame 23 is variable in height and contains multistage hydraulic or pneumatic cylinders 28 to raise and lower the apparatus as well as track forwards and backwards relative to the tubular OCTG. Member 25 is an attachment member to the powered rotational device.

[0080] Figure 14 is a sectioned view illustrating the relationship and orientation of the balls and or slipper-gripper blocks 9, the inner member 7, cage housing 3, internal bore 20, inclined ramps 8, and tapered nose cone 6 for an internal gripping tubular engagement apparatus.

[0081] Figure 15 is a sectioned view illustrating the relationship and orientation of the balls and or slipper-gripper blocks 9, the inner member 7, cage housing 3, internal bore 20, and inclined ramps 8 for an external gripping tubular engagement apparatus.

[0082] Figure 16 is a top view of one embodiment of a slipper-gripper block 40 showing a single hemispherical surface profile 34 and retention shoulder 39 which retains slipper-gripper block within cage housing whereby only hemispherical portion 34 is allowed to protrude through apertures..

[0083] Figure 17 is a front view of the slipper-gripper block 40 showing the inclined surface 36 on the bottom side 38 as well as the cylindrical portion 35 at the base of the hemispherical profile used to protrude the hemispherical surface further out from the cage housing. Figure also shows the flat torque shoulders 37.

[0084] Figure 18 is an end view of one embodiment of a slipper-gripper block 40.

[0085] Figure 19 is a bottom view of one embodiment of a slipper-gripper block 40. [0086] Figure 20 is a top view of a second embodiment of a slipper-gripper block 41 showing a double hemispherical surface profile 34 as well as retention shoulder 39.

[0087] Figure 21 is a front view of a slipper-gripper block 41 showing the inclined surface 36 on the bottom side 38 as well as the flat torque shoulders 37.

[0088] Figure 22 is an end view of the slipper-gripper block 41.

[0089] Figure 23 is a bottom view of the slipper-gripper block 41.

[0090] 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 can be covered by the claims appended hereto.

[0091] 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

CLAIMS We claim:

1. A tubular running assembly for handling a tubular member, making up or breaking out of threaded connections between the tubular member and another tubular member or tubular string, and the handling of the tubular string into or out of a wellbore, comprising: a tubular engagement apparatus connectable to the driveshaft of a top drive, power swivel,or the like, the tubular engagement apparatus having a ball and taper assembly and an actuator; wherein the ball and taper assembly consist of inner and outer members, one member containing an array of tapered or ramped surfaces while the other member comprises a tube with a plurality of apertures which retain the balls; wherein relative axial movement between the inner and outer members of the ball and taper assembly acts to urge the balls up or down the tapers to radially protrude or retract the balls through the apertures in the tube member, thus engaging or disengaging the tubular member; wherein the tubular engagement apparatus is energized and de-energized by powered mechanical means provided by the actuator, hydraulic, pneumatic, or the like, whereby the balls are forced up or down the tapers of the drive member thereby causing the balls to come into contact with or retract from the surface of the tubular member; and wherein rotation of the driveshaft of a top drive, power swivel, or the like produces a corresponding rotation in the tubular member or tubular string via engagement of the ball and taper assembly, whereby there is minimal relative rotation between the tubular engagement assembly and the tubular member or tubular string.

2. The apparatus of claim 1 , wherein the ball and taper assembly can be energized to an engaged and or released position via the actuator.

3. The apparatus of claim 1, wherein upon energizing the ball and taper assembly to the engaged position, the applied contact force between the balls and tubular member can be predetermined and controlled.

4. The apparatus of claim 3, wherein the applied contact force between the balls and the tubular member is sufficient to impart desired torque from the driving member to the tubular member with minimal relative movement there between.

5. The apparatus of claim 3, wherein the applied contact force between the balls and the tubular member is sufficient to create indentations into the surface of the tubular member necessary to impart desired torque from the driving member to the tubular member with minimal relative movement there between.

6. The assembly of claim 1, further comprising a hydraulic actuator that when energized will produce relative axial movement between the inner and outer members of the ball and taper assembly, providing a means of controlling the placement of the balls relative to the tapers therein locking the tubular engagement apparatus in place prior to applying a rotational force, lifting or lowering action, or both upon the tubular member or tubular string.

7. The apparatus of claim 1 further comprising a set of matingly engaged surfaces on the inner and outer members such as splines or otherwise to allow relative axial movement while disallowing rotational movement between the inner and outer members.

8. The assembly of claim 1 further comprising an elevator assembly with a transfer elevator and telescoping elevator links which can be remotely manipulated to extend or retract the transfer elevators to pick up and position a tubular member above the tubular member or tubular string already secured in the rotary table on the drill floor wherein the operator can then energize the tubular engagement apparatus and use the rotational capability of the top drive to remotely couple the two tubular members.

9. The assembly of claim 8 further comprising a set of telescoping elevator links used to position the tubular member from a mostly horizontal position to the vertical 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 or retract the links into the correct position to accept the tubular member in the transfer elevators.

10. The assembly of claim 9 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 member to be lowered in a controlled fashion into the tubular member already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular member zero weight in gravity to protect the threads of the tubular member during stabbing operations, for make-up or breakout operations.

11. The assembly of claim 1 wherein a weight compensation control system can be utilized and installed as a separate system affixed above the tubular running assembly actuator and below the top drive whereby the activation of the weight compensation system will provide for the tubular member to be lowered in a controlled fashion into the tubular member already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular member zero weight in gravity to protect the threads of the tubular member during stabbing operations, for make-up or breakout operations.

12. The assembly of claim 1 wherein the tubular running assembly is connectable to a top drive to apply clockwise or counterclockwise torque allowing the operator to makeup or breakout a tubular member.

13. The assembly of claim 1 further comprising a lower member with a tapered high density urethane, polymer coated, or composite section sized to suit the tubular member being run, to facilitate easy stabbing of the apparatus into the tubular member.

14. The assembly of claim 1 wherein the lower member further comprises a valve to prevent mud discharge onto the drill floor when the apparatus is removed from the tubular member.

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

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

17. The assembly of claim 1 further comprising a control system to manipulate the actuator, 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 tubular engagement assembly.

18. The assembly of claim 17 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.

19. The apparatus of claim 1 wherein the tapered ramps are at an angle between 6 degrees and 20 degrees relative to the central axis.

20. The apparatus of claim 1 wherein the tapered ramps are at an angle between 9 degrees and 12 degrees relative to the central axis.

21. 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; latching transfer elevator around tubular OCTG; moving a top drive with a tubular running 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 aforementioned 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; activate a hydraulic actuator into the release position producing relative movement of the members causing balls to retract radially through apertures in a tube; lowering the tubular running assembly onto or into the tubular OCTG; activate the hydraulic actuator into the latch position producing relative movement of the members causing the balls to protrude radially through apertures in the tube; once the balls 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 mating 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 tubular running 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.

22. A tubular running assembly for handling a tubular member, making up or breaking out of threaded connections between the tubular member and another tubular member or tubular string, and the handling of the tubular string into or out of a wellbore, comprising: a tubular engagement apparatus connectable to the driveshaft of a top drive, power swivel, or the like, the tubular engagement apparatus having a slipper-gripper block and taper assembly and an actuator; wherein the slipper-gripper block and taper assembly consist of inner and outer members, one member containing an array of tapered or ramped surfaces while the other member comprises a tube with a plurality of apertures which retain the slipper- gripper block; wherein relative axial movement between the inner and outer members of the slipper- gripper block and taper assembly acts to urge the slipper gripper block up or down the tapers to radially protrude or retract the slipper-gripper block through the apertures in the tube member, thus engaging or disengaging the tubular member; wherein the tubular engagement apparatus is energized and de-energized by powered mechanical means provided by the actuator, hydraulic, pneumatic, or the like, whereby the slipper gripper block are forced up or down the tapers of the drive member thereby causing the slipper-gripper block to come into contact with or retract from the surface of the tubular member; and wherein rotation of the driveshaft of a top drive, power swivel, or the like produces a corresponding rotation in the tubular member or tubular string via engagement of the slipper gripper block and taper assembly, whereby there is minimal relative rotation between the tubular engagement assembly and the tubular member or tubular string.

23. The apparatus of claim 22, wherein the slipper-gripper block and taper assembly can be energized to an engaged and or released position via the actuator.

24. The apparatus of claim 22, wherein upon energizing the slipper-gripper block and taper assembly to the engaged position, the applied contact force between the balls and tubular member can be predetermined and controlled.

25. The apparatus of claim 24, wherein the applied contact force between the slipper- gripper block and the tubular member is sufficient to impart desired torque from the driving member to the tubular member with minimal relative movement there between.

26. The apparatus of claim 24, wherein the applied contact force between the slipper- gripper block and the tubular member is sufficient to create indentations into the surface of the tubular member necessary to impart desired torque from the driving member to the tubular member with minimal relative movement there between.

27. The assembly of claim 22, further comprising a hydraulic actuator that when energized will produce relative axial movement between the inner and outer members of the slipper-gripper block and taper assembly, providing a means of controlling the placement of the slipper-gripper block relative to the tapers therein locking the tubular engagement apparatus in place prior to applying a rotational force, lifting or lowering action, or both upon the tubular member or tubular string.

28. The apparatus of claim 22 further comprising a set of matingly engaged surfaces on the inner and outer members such as splines or otherwise to allow relative axial movement while disallowing rotational movement between the inner and outer members.

29. The assembly of claim 22 further comprising an elevator assembly with a transfer elevator and telescoping elevator links which can be remotely manipulated to extend or retract the transfer elevators to pick up and position a tubular member above the tubular member or tubular string already secured in the rotary table on the drill floor wherein the operator can then energize the tubular engagement apparatus and use the rotational capability of the top drive to remotely couple the two tubular members.

30. The assembly of claim 29 further comprising a set of telescoping elevator links used to position the tubular member from a mostly horizontal position to the vertical 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 or retract the links into the correct position to accept the tubular member in the transfer elevators.

31. The assembly of claim 30 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 member to be lowered in a controlled fashion into the tubular member already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular member zero weight in gravity to protect the threads of the tubular member during stabbing operations, for make-up or breakout operations.

32. The assembly of claim 22 wherein a weight compensation control system can be utilized and installed as a separate system affixed above the tubular running assembly actuator and below the top drive whereby the activation of the weight compensation system will provide for the tubular member to be lowered in a controlled fashion into the tubular member already secured in the rotary table on the drill floor and utilizing the weight compensation system will effectively give the tubular member zero weight in gravity to protect the threads of the tubular member during stabbing operations, for make-up or breakout operations.

33. The assembly of claim 22 wherein the tubular running assembly is connectable to a top drive to apply clockwise or counterclockwise torque allowing the operator to make-up or breakout a tubular member.

34. The assembly of claim 22 further comprising a lower member with a tapered high density urethane, polymer coated, or composite section sized to suit the tubular member being run, to facilitate easy stabbing of the apparatus into the tubular member.

35. The assembly of claim 22 wherein the lower member further comprises a valve to prevent mud discharge onto the drill floor when the apparatus is removed from the tubular member.

36. The assembly of claim 22 wherein the slipper-gripper block and their respective ramped surfaces may be disposed randomly about the tubular engagement apparatus or in longitudinally spaced rows where the slipper-gripper block of each row are offset laterally with respect to those in the next succeeding row.

37. The assembly of claim 22 further comprising a through bore to allow the transmission of drilling fluids or mud for the purposes of filling and or circulation of the tubular member while running into the well bore, a lower packer cup on the lower member section of the tubular running assembly wherein said lower packer cup is self energizing by pressure inside the tubular member thereby forming a seal to allow the drilling fluid or mud to be pumped into the tubular member and/or well bore.

38. The assembly of claim 22 further comprising a control system to manipulate the actuator, 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 tubular engagement assembly.

39. The assembly of claim 38 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.

40. The apparatus of claim 22 wherein the tapered ramps are at an angle between 6 degrees and 20 degrees relative to the central axis.

41. The apparatus of claim 22 wherein the tapered ramps are at an angle between 9 degrees and 12 degrees relative to the central axis.

42. 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; latching transfer elevator around tubular OCTG; moving a top drive with a tubular running 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 a weight compensation system to lower the tubular OCTG in a controlled fashion into the aforementioned 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; activate a hydraulic actuator into the release position producing relative movement of the members causing slipper-gripper block to retract radially through apertures in a tube; lowering the tubular running assembly onto or into the tubular OCTG; activate the hydraulic actuator into the latch position producing relative movement of the members causing the slipper-gripper block to protrude radially through apertures in the tube; once the slipper gripper block 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 mating 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 tubular running assembly connected to the top drive while upsetting 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.

43. The apparatus of claim 22 wherein the surface of slipper-gripper blocks may be: smooth, smooth and hardened, coated with a grit type material, toothed such as conventional inserts and dies, toothed and grit coated, or a multitude or combination thereof.

44. The apparatus of claim 22 wherein the slipper-gripper block surface may be of any shape or profile including: smooth, curved, flat, hemispherical, nodular, lumpy, sinusoidal, waveform, etc., and any combination thereof.

45. The apparatus of claim 22 wherein the slipper-gripper block may contain one or more surface features such as nodules, etc.

46. The apparatus of claim 22 wherein the hemispheres or other surface profiles on the slipper-gripper blocks can either be smooth, coated with a grit type material, can include some type of tooth profile such as conventional dies, or any combination thereof.

47. The apparatus of claim 22 wherein the hemispherical profiles of the slipper-gripper blocks can be shaped so that they extend beyond the tube member more than is possible with current ball and taper technology. They can extend out any desired distance, thereby allowing the tool to work for a larger range of sizes and or weights.

48. The apparatus of claim 22 wherein the slipper-gripper blocks can produce a higher concentration of ball type protrusions per given length as would conventional ball and taper technology by placing more than one ball protrusion per gripper block.

49. The apparatus of claim 22 wherein the backing surface opposite side to the gripping surface of the slipper-gripper block as well as a matching profile on the member could be flat, curved, cylindrical, etc.

50. The apparatus of claim 22 wherein these backing surfaces provide far more contact surface area between the slipper-gripper block backing surface and member tapered ramp than balls.

51. The apparatus of claim 22 wherein the slipper-gripper block also provide more surface area on their edges for the application of torque than do balls. Again, balls create a point loading on the sides of the tapered slots on the member with the potential for indentation. The slipper-gripper block greatly reduces this potential for member damage.

52. The apparatus of claim 22 wherein the backing surfaces of the slipper-gripper block and or the sliding mating surface of the member can be coated with a friction reduction material, plating or process such as Teflon, Xylan, plain bearing or self lubricating materials such as an acetal filled bronze, chrome plating, hard chrome plating, electroless nickel, etc.

53. The apparatus of claim 22 wherein the slipper-gripper block are constrained within a housing, such that they cannot be removed without complete disassembly of the tool. This becomes important should the assembly be rotated in free space (such as above a rig floor in the derrick), the slipper-gripper block cannot become a projectile.

54. The apparatus of claim 22 wherein the slipper-gripper block technology including the hemispherical or nodular surface features may also be used as inserts, dies or grapples for other tubular running or gripping tools such as tongs, spiders, elevators, safety clamps, fishing tools, sub surface tools, whipstocks or packer type assemblies etc.