Patent Publication Number: US-7591304-B2

Title: Pipe running tool having wireless telemetry

Description:
CROSS-REFERENCE TO RELATED APPLICATION(S) 
   This application is a continuation-in-part of U.S. patent application Ser. No. 11/040,453, filed on Jan. 20, 2005, issued as U.S. Pat. No. 7,096,977, which is a continuation of U.S. patent application Ser. No. 10/189,355, filed on Jul. 3, 2002, issued as U.S. Pat. No. 6,938,709, which is a continuation of U.S. patent application Ser. No. 09/518,122, filed Mar. 3, 2000, issued as U.S. Pat. No. 6,443,241, which claims priority under 35 U.S.C. §119(e) to U.S. Provisional Patent Application No. 60/122,915, filed on Mar. 5, 1999. 

   BACKGROUND OF THE INVENTION 
   1. Field of the Invention 
   This invention relates to well drilling operations and, more particularly, to a device for assisting in the assembly of pipe strings, such as casing strings, drill strings and the like; and/or to a device for measuring drilling parameters during a drilling operation. 
   2. Description of the Related Art 
   The drilling of oil wells involves assembling drill strings and casing strings, each of which comprises a plurality of elongated, heavy pipe segments extending downwardly from an oil drilling rig into a hole. The pipe string consists of a number of sections of pipe which are threadedly engaged together, with the lowest segment (i.e., the one extending the furthest into the hole) carrying a drill bit at its lower end. Typically, the casing string is provided around the drill string to line the well bore after drilling the hole and to ensure the integrity of the hole. The casing string also consists of a plurality of pipe segments which are threadedly coupled together and formed with internal diameters sized to receive the drill string and/or other pipe strings. 
   The conventional manner in which plural casing segments are coupled together to form a casing string is a labor-intensive method involving the use of a “stabber” and casing tongs. The stabber is manually controlled to insert a segment of casing into the upper end of the existing casing string, and the tongs are designed to engage and rotate the segment to threadedly connect it to the casing string. While such a method is effective, it is cumbersome and relatively inefficient because the procedure is done manually. In addition, the casing tongs require a casing crew to properly engage the segment of casing and to couple the segment to the casing string. Thus, such a method is relatively labor-intensive and therefore costly. Furthermore, using casing tongs requires the setting up of scaffolding or other like structures, and is therefore inefficient. 
   Accordingly, it will be apparent to those skilled in the art that there continues to be a need for a device for use in a drilling system which utilizes an existing top drive assembly to efficiently assemble pipe strings, and which positively engages a pipe segment to ensure proper coupling of the pipe segment to a pipe string. 
   Another problem associated with the drilling of oil wells includes the difficulties associated with accurately measuring drilling parameters in the oil and gas well system during a drilling operation, such as pipe string weight, torque, vibration, speed of rotation, angular position, number of revolutions, rate of penetration, and internal pressure. Current methods of measuring and observing such drilling parameters are generally indirect, meaning that they are measured at a point conveniently accessible but not necessarily located on the actual pipe sting. 
   For example, the pipe string weight is often indirectly measured by measuring the pull on a cable of a hoisting system, which raises and lowers the pipe string. This type of measurement is inaccurate due to frictional forces associated with the cable, the sheaves, and the measurement device attached to the cable. 
   The pipe string torque is difficult to measure since it is often difficult to measure the torque output of the torque driving system, which rotates or drives the pipe string. For example, typically, the pipe string is either rotated with a large mechanical drive called a rotary table or directly by a large motor called a top drive. The torque output of each of these drive systems cannot be easily measured and most often is either calculated from the current going to the drive motor when a top drive is used, or by measuring the tension of a drive chain which drives the rotary table when a rotary table is used. Both of these methods are very inaccurate and subject to outside influences that can cause the readings to be inconsistent, such as stray electrical currents through the drive motor when a top drive is used, or wear of the measured mechanical devices when a rotary table is used. 
   Another drilling parameter that is difficult to measure is vibration. Vibration of the pipe string is very damaging to its components especially to the drill bit at the end of the pipe string, which drills a well bore. 
   Various methods have been proposed to solve the above described problems with the measuring of drilling parameters during a drilling operation, including installing various instrumented pins onto components of the hoisting system or the top drive system. Other more direct approaches have been tried with limited success. For example, some have installed a load sensor at the top of the derrick for measuring pull of the hoisting system on the derrick. These are commonly referred to as crown block weight sensors. 
   Various other devices have been developed for directly measuring torque and vibration on the pipe string. For example, one such device for use with a rotary table includes a plate that attaches to the top of the rotary table between the table and a drive bushing, referred to as the kelly drive bushing. However, currently more and more oil and gas well drilling systems are using top drive drilling systems instead of rotary tables, rending this approach less desirable and possibly obsolete. 
   Others have tried to make special instrumented subs that screw directly into the pipe string. One such device is large and bulky and does not fit into existing top drive systems. These devices provide the accuracy desired in the measure of the drilling parameters, but compromise the drilling equipment due to their size and shape. In addition, these devices require redesign of the top drive system to accommodate them. 
   Accordingly, a need exists for an apparatus and method for accurately measuring drilling parameters during a drilling operation that does not require modification of the top drive assembly to which it attaches. The present invention addresses these needs and others. 
   SUMMARY OF THE INVENTION 
   In one embodiment, the present invention is a system for measuring desired drilling parameters of a pipe string during an oil and gas well drilling operation that includes a top drive assembly; a pipe running tool engageable with the pipe string and coupled to the top drive assembly to transmit translational and rotational forces from the top drive assembly to the pipe string; and one or more measurement devices mounted to the pipe running tool for measuring the desired drilling parameters of the pipe string during the oil and gas well drilling operation. 
   Other features and advantages of the present invention will become apparent from the following detailed description, taken in conjunction with the accompanying drawings which illustrate, by way of example, the features of the present invention. 

   
     DESCRIPTION OF THE DRAWINGS 
       FIG. 1  is an elevated side view of a drilling rig incorporating a pipe running tool according to one illustrative embodiment of the present invention; 
       FIG. 2  is a side view, in enlarged scale, of the pipe running tool of  FIG. 1 ; 
       FIG. 3  is a cross-sectional view taken along the line  3 - 3  of  FIG. 2 ; 
       FIG. 4  is a cross-sectional view taken along the line  4 - 4  of  FIG. 2 ; 
       FIG. 5A  is a cross-sectional view taken along the line  5 - 5  of  FIG. 2  and showing a spider\elevator in a disengaged position; 
       FIG. 5B  is a cross-sectional view similar to  FIG. 5A  and showing the spider\elevator in an engaged position; 
       FIG. 6  is a block diagram of components included in one illustrative embodiment of the invention; 
       FIG. 7  is a side view of another illustrative embodiment of the invention; 
       FIG. 8  is a cross-sectional view of a pipe running tool according to one embodiment of the invention, with a top drive assembly shown schematically 
       FIG. 9  is a perspective view of a slip cylinder for use in the pipe running tool of  FIG. 8 ; 
       FIG. 10  is a side view, shown partially in cross-section, of a pipe running tool according to another embodiment of the invention; 
       FIG. 11  is a side view, shown partially in cross-section, of a pipe running tool according to yet another embodiment of the invention; and 
       FIG. 12  is an enlarged view of a portion of  FIG. 8 . 
   

   DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS 
   As shown in  FIGS. 1-12 , the present invention is directed to a pipe running tool for use in drilling systems and the like to threadingly connect pipe segments to pipe strings (as used hereinafter, the term pipe segment shall be understood to refer to casing segments and/or drill segments, while the term pipe string shall be understood to refer to casing strings and/or drill strings.) 
   The pipe running tool according to the present invention engages a pipe segment and is further coupled to an existing top drive assembly, such that a rotation of the top drive assembly imparts a torque on the pipe segment during a threading operation between the pipe segment and a pipe string. In one embodiment, the pipe running tool is also used to transmit a translational and rotational forces from the top drive assembly to a pipe string during a drilling operation. In this embodiment, the pipe running tool includes measurement devices for measuring drilling parameters during a drilling operation. 
   In the following detailed description, like reference numerals will be used to refer to like or corresponding elements in the different figures of the drawings. Referring now to  FIGS. 1 and 2 , there is shown a pipe running tool  10  depicting one illustrative embodiment of the present invention, which is designed for use in assembling pipe strings, such as drill strings, casing strings, and the like. As shown for example in  FIG. 2 , the pipe running tool  10  comprises, generally, a frame assembly  12 , a rotatable shaft  14 , and a pipe engagement assembly  16 , which is coupled to the rotatable shaft  14  for rotation therewith. The pipe engagement assembly  16  is designed for selective engagement of a pipe segment  11  (as shown for example in  FIGS. 1 ,  2 , and  5 A) to substantially prevent relative rotation between the pipe segment  11  and the pipe engagement assembly  16 . As shown for example in  FIG. 1 , the rotatable shaft  14  is designed for coupling with a top drive output shaft  28  from an existing top drive  24 , such that the top drive  24 , which is normally used to rotate a drill string to drill a well hole, may be used to assemble a pipe segment  11  to a pipe string  34 , as is described in greater detail below. 
   As show, for example, in  FIG. 1 , the pipe running tool  10  may be designed for use in a well drilling rig  18 . A suitable example of such a rig is disclosed in U.S. Pat. No. 4,765,401 to Boyadjieff, which is expressly incorporated herein by reference as if fully set forth herein. As shown in  FIG. 1 , the well drilling rig  18  includes a frame  20  and a pair of guide rails  22  along which a top drive assembly, generally designated  24 , may ride for vertical movement relative to the well drilling rig  18 . The top drive assembly  24  is preferably a conventional top drive used to rotate a drill string to drill a well hole, as is described in U.S. Pat. No. 4,605,077 to Boyadjieff, which is expressly incorporated herein by reference. The top drive assembly  24  includes a drive motor  26  and a top drive output shaft  28  extending downwardly from the drive motor  26 , with the drive motor  26  being operative to rotate the drive output shaft  28 , as is conventional in the art. The well drilling rig  18  defines a drill floor  30  having a central opening  32  through which pipe string  34 , such as a drill string and/or casing string, is extended downwardly into a well hole. 
   The rig  18  also includes a flush-mounted spider  36  that is configured to releasably engage the pipe string  34  and support the weight thereof as it extends downwardly from the spider  36  into the well hole. As is well known in the art, the spider  36  includes a generally cylindrical housing which defines a central passageway through which the pipe string  34  may pass. The spider  36  includes a plurality of slips which are located within the housing and are selectively displaceable between disengaged and engaged positions, with the slips being driven radially inwardly to the respective engaged position to tightly engage the pipe string  34  and thereby prevent relative movement or rotation of the pipe string  34  with respect to the spider housing. The slips are preferably driven between the disengaged and engaged positions by means of a hydraulic or pneumatic system, but may be driven by any other suitable means. 
   Referring primarily to  FIG. 2 , the pipe running tool  10  includes the frame assembly  12 , which comprises a pair of links  40  extending downwardly from a link adapter  42 . The link adapter  42  defines a central opening  44  through which the top drive output shaft  28  may pass. Mounted to the link adapter  42  on diametrically opposed sides of the central opening  44  are respective upwardly extending, tubular members  46  ( FIG. 1 ), which are spaced a predetermined distance apart to allow the top drive output shaft  28  to pass therebetween. The respective tubular members  46  connect at their upper ends to a rotating head  48 , which is connected to the top drive assembly  24  for movement therewith. The rotating head  48  defines a central opening (not shown) through which the top drive output shaft  28  may pass, and also includes a bearing (not shown) which engages the upper ends of the tubular members  46  and permits the tubular members  46  to rotate relative to the rotating head body, as is described in greater detail below. 
   The top drive output shaft  28  terminates at its lower end in an internally splined coupler  52  which is engaged to an upper end (not shown) of the rotatable shaft  14  of the pipe running tool  10 . In one embodiment, the upper end of the rotatable shaft  14  of the pipe running tool  10  is formed to complement the splined coupler  52  for rotation therewith. Thus, when the top drive output shaft  28  is rotated by the top drive motor  26 , the rotatable shaft  14  of the pipe running tool  10  is also rotated. It will be understood that any suitable interface may be used to securely engage the top drive output shaft  28  with the rotatable shaft  14  of the pipe running tool  10 . 
   In one illustrative embodiment, the rotatable shaft  14  of the pipe running tool  10  is connected to a conventional pipe handler, generally designated  56 , which may be engaged by a suitable torque wrench (not shown) to rotate rotatable shaft  14  and thereby make and break threaded connections that require very high torque, as is well known in the art. 
   In one embodiment, the rotatable shaft  14  of the pipe running tool is also formed with a lower splined segment  58 , which is slidably received in an elongated, splined bushing  60  which serves as an extension of the rotatable shaft  14  of the pipe running tool  10 . The rotatable shaft  14  and the bushing  60  are splined to provide for vertical movement of the rotatable shaft  14  relative to the bushing  60 , as is described in greater detail below. It will be understood that the splined interface causes the bushing  60  to rotate when the rotatable shaft  14  of the pipe running tool  10  rotates. 
   The pipe running tool  10  further includes the pipe engagement assembly  16 , which in one embodiment comprises a torque transfer sleeve  62  (as shown for example in  FIG. 2 ), which is securely connected to a lower end of the bushing  60  for rotation therewith. The torque transfer sleeve  62  is generally annular and includes a pair of upwardly projecting arms  64  on diametrically opposed sides of the sleeve  62 . The arms  64  are formed with respective horizontal through passageways (not shown) into which are mounted respective bearings (not shown) which serve to journal a rotatable axle  70  therein, as described in greater detail below. The torque transfer sleeve  62  connects at its lower end to a downwardly extending torque frame  72  in the form of a pair of tubular members  73 , which in turn is coupled to a spider\elevator  74  which rotates with the torque frame  72 . It will be apparent that the torque frame  72  may have any one of a variety of structures, such as a plurality of tubular members, a solid body, or any other suitable structure. 
   The spider\elevator  74  is preferably powered by a hydraulic or pneumatic system, or alternatively by an electric drive motor or any other suitable powered system. As shown in  FIGS. 5A and 5B , the spider\elevator includes a housing  75  which defines a central passageway  76  through which the pipe segment  11  may pass. The spider\elevator  74  also includes a pair of hydraulic or pneumatic cylinders  77  with displaceable piston rods  78 , which are connected through suitable pivotable linkages  79  to respective slips  80 . The linkages  79  are pivotally connected to both the top ends of the piston rods  78  and the top ends of the slips  80 . The slips  80  include generally planar front gripping surfaces  82 , and specially contoured rear surfaces  84  which are designed with such a contour to cause the slips  80  to travel between respective radially outwardly disposed, disengaged positions, and radially inwardly disposed, engaged positions. The rear surfaces of the slips  80  travel along respective downwardly and radially inwardly projecting guiding members  86  which are complementarily contoured and securely connected to the spider body. The guiding members  86  cooperate with the cylinders  77  and linkages  79  to cam the slips  80  radially inwardly and force the slips  80  into the respective engaged positions. Thus, the cylinders  77  (or other actuating means) may be empowered to drive the piston rods  78  downwardly, causing the corresponding linkages  79  to be driven downwardly and therefore force the slips  80  downwardly. The surfaces of the guiding members  86  are angled to force the slips  80  radially inwardly as they are driven downwardly to sandwich the pipe segment  11  between them, with the guiding members  86  maintaining the slips  80  in tight engagement with the pipe segment  11 . 
   To disengage the pipe segment  11  from the slips  80 , the cylinders  77  are operated in reverse to drive the piston rods  78  upwardly, which draws the linkages  79  upwardly and retracts the respective slips  80  back to their disengaged positions to release the pipe segment  11 . The guiding members  86  are preferably formed with respective notches  81  which receive respective projecting portions  83  of the slips  80  to lock the slips  80  in the disengaged position ( FIG. 5A ). 
   The spider\elevator  74  further includes a pair of diametrically opposed, outwardly projecting ears  88  formed with downwardly facing recesses  90  sized to receive correspondingly formed, cylindrical members  92  at a bottom end of the respective links  40 , and thereby securely connect the lower ends of the links  40  to the spider\elevator  74 . The ears  88  may be connected to an annular sleeve  93  which is received over the spider housing  75 . Alternatively, the ears may be integrally formed with the spider housing. 
   In one illustrative embodiment, the pipe running tool  10  includes a load compensator, generally designated  94 . In one embodiment, the load compensator  94  is in the form of a pair of hydraulic, double rodded cylinders  96 , each of which includes a pair of piston rods  98  that are selectively extendable from, and retractable into, the cylinders  96 . Upper ends of the rods  98  connect to a compensator clamp  100 , which in turn is connected to the rotatable shaft  14  of the pipe running tool  10 , while lower ends of the rods  98  extend downwardly and connect to a pair of ears  102  which are securely mounted to the bushing  60 . The hydraulic cylinders  96  may be actuated to draw the bushing  60  upwardly relative to the rotatable shaft  14  of the pipe running tool  10  by applying a pressure to the cylinders  96  which causes the upper ends of the piston rods  98  to retract into the respective cylinder bodies  96 , with the splined interface between the bushing  60  and the lower splined section  58  of the rotatable shaft  14  allowing the bushing  60  to be displaced vertically relative to the rotatable shaft  14 . In that manner, the pipe segment  11  carried by the spider\elevator  74  may be raised vertically to relieve a portion or all of the load applied by the threads of the pipe segment  11  to the threads of the pipe string  34 , as is described in greater detail below. 
   As is shown in  FIG. 2 , the lower ends of the rods  98  are at least partially retracted, resulting in the majority of the load from the pipe running tool  10  being assumed by the top drive output shaft  28 . In addition, when a load above a pre-selected maximum is applied to the pipe segment  11 , the cylinders  96  will automatically retract the load to prevent the entire load from being applied to the threads of the pipe string  11 . 
   In one embodiment, the pipe running tool  10  still further includes a hoist mechanism, generally designated  104 , for hoisting a pipe segment  11  upwardly into the spider\elevator  74 . In the embodiment of  FIG. 2 , the hoist mechanism  104  is disposed off-axis and includes a pair of pulleys  106  carried by the axle  70 , the axle  70  being journaled into the bearings in respective through passageways formed in the arms  64 . The hoist mechanism  104  also includes a gear drive, generally designated  108 , that may be selectively driven by a hydraulic motor  111  or other suitable drive system to rotate the axle  70  and thus the pulleys  106 . The hoist may also include a brake  115  to prevent rotation of the axle  70  and therefore of the pulleys  106  and lock them in place, as well as a torque hub  116 . Therefore, a pair of chains, cables, or other suitable, flexible means may be run over the respective pulleys  106 , extended through a chain well  113 , and engaged to the pipe segment  11 . The axle  70  is then rotated by a suitable drive system to hoist the pipe segment  11  vertically and up into position with the upper end of the pipe segment  11  extending into the spider\elevator  74 . 
   In one embodiment, as shown in  FIG. 1 , the pipe running tool  10  further includes an annular collar  109  which is received over the links  40  and which maintains the links  40  locked to the ears  88  of the spider\elevator  74  and prevents the links  40  from twisting and/or winding. 
   In use, a work crew may manipulate the pipe running tool  10  until the upper end of the tool  10  is aligned with the lower end of the top drive output shaft  28 . The pipe running tool  10  is then raised vertically until the splined coupler  52  at the lower end of the top drive output shaft  28  is engaged to the upper end of the rotatable shaft  14  of the pipe running tool  10  and the links  40  of the pipe running tool  10  are engaged with the ears  88  of the spider\elevator  74 . The work crew may then run a pair of chains or cables over the respective pulleys  106  of the hoist mechanism  104 , connect the chains or cables to a pipe segment  11 , engage a suitable drive system to the gear  108 , and actuate the drive system to rotate the pulleys  106  and thereby hoist the pipe segment  11  upwardly until the upper end of the pipe segment  11  extends through the lower end of the spider\elevator  74 . The spider\elevator  74  is then actuated, with the hydraulic cylinders  77  and guiding members  86  cooperating to forcibly drive the respective slips  80  into the engaged positions ( FIG. 5B ) to positively engage the pipe segment  11 . The slips  80  are preferably advanced to a sufficient extent to prevent relative rotation between the pipe segment  11  and the spider\elevator  74 , such that rotation of the spider\elevator  74  translates into a corresponding rotation of the pipe segment  11 , allowing for a threaded engagement of the pipe segment  11  to the pipe string  34 . 
   The top drive assembly  24  is then lowered relative to the rig frame  20  by means of a top hoist  25  to drive the threaded lower end of the pipe segment  11  into contact with the threaded upper end of the pipe string  34  ( FIG. 1 ). As shown in  FIG. 1 , the pipe string  34  is securely held in place by means of the flush-mounted spider  36  or any other suitable structure for securing the string  34  in place, as is well known to those skilled in the art. Once the threads of the pipe segment  11  are properly mated with the threads of the pipe string  34 , the top drive motor  26  is actuated to rotate the top drive output shaft  28 , which in turn rotates the rotatable shaft  14  of the pipe running tool  10  and the spider\elevator  74 . This in turn causes the coupled pipe segment  11  to rotate to threadingly engage the pipe string  34 . 
   In one embodiment, the pipe segment  11  is intentionally lowered until the lower end of the pipe segment  11  rests on top of the pipe string  34 . The load compensator  94  is then actuated to drive the bushing  60  upwardly relative to the rotatable shaft  14  of the pipe running tool  10  via the splined interface between the bushing  60  and the rotatable shaft  14 . The upward movement of the bushing  60  causes the spider\elevator  74  and therefore the coupled pipe segment  11  to be raised, thereby reducing the load that the threads of the pipe segment  11  apply to the threads of the pipe string  34 . In this manner, the load on the threads can be controlled by actuating the load compensator  94 . 
   Once the pipe segment  11  is threadedly coupled to the pipe string  34 , the top drive assembly  24  is raised vertically to lift the entire pipe string  34 , which causes the flush-mounted spider  36  to disengage the pipe string  34 . The top drive assembly  24  is then lowered to advance the pipe string  34  downwardly into the well hole until the upper end of the top pipe segment  11  is close to the drill floor  30 , with the entire load of the pipe string  11  being carried by the links  40  while the torque was supplied through shafts. The flush-mounted spider  36  is then actuated to engage the pipe string  11  and suspend it therefrom. The spider\elevator  74  is then controlled in reverse to retract the slips  80  back to the respective disengaged positions ( FIG. 5A ) to release the pipe string  11 . The top drive assembly  24  is then raised to lift the pipe running tool  10  up to a starting position (such as that shown in  FIG. 1 ) and the process may be repeated with an additional pipe segment  11 . 
   Referring to  FIG. 6 , there is shown a block diagram of components included in one illustrative embodiment of the pipe running tool  10 . In this embodiment, the tool includes a conventional load cell  110  or other suitable load-measuring device mounted on the pipe running tool  10  in such a manner that it is in communication with the rotatable shaft  14  of the pipe running tool  10  to determine the load applied to the lower end of the pipe segment  11 . The load cell  110  is operative to generate a signal representing the load sensed, which in one illustrative embodiment is transmitted to a processor  112 . The processor  112  is programmed with a predetermined threshold load value, and compares the signal from the load cell  110  with the predetermined threshold load value. If the load exceeds the predetermined threshold value, the processor  112  activates the load compensator  94  to draw the pipe running tool  10  upwardly a selected amount to relieve at least a portion of the load on the threads of the pipe segment  11 . Once the load is at or below the predetermined threshold value, the processor  112  controls the top drive assembly  24  to rotate the pipe segment  11  and thereby threadedly engage the pipe segment  11  to the pipe string  34 . While the top drive assembly  24  is actuated, the processor  112  continues to monitor the signals from the load cell  110  to ensure that the load on the pipe segment  11  does not exceed the predetermined threshold value. 
   Alternatively, the load on the pipe segment  11  may be controlled manually, with the load cell  110  indicating the load on the pipe segment  11  via a suitable gauge or other display, with a work person controlling the load compensator  94  and top drive assembly  24  accordingly. 
   Referring to  FIG. 7 , there is shown another preferred embodiment of the pipe running tool  200  of the present invention. The pipe running tool includes a hoisting mechanism  202  which is substantially the same as the hoisting mechanism  104  described above. A rotatable shaft  204  is provided that is connected at its lower end to a conventional mud-filling device  206  which, as is known in the art, is used to fill a pipe segment  11 , for example, a casing segment, with mud during the assembly process. In one illustrative embodiment, the mud-filling device is a device manufactured by Davies-Lynch Inc. of Texas. 
   The hoisting mechanism  202  supports a pair of chains  208  which engage a slip-type single joint elevator  210  at the lower end of the pipe running tool  200 . As is known in the art, the single joint elevator is operative to releasably engage a pipe segment  11 , with the hoisting mechanism  202  being operative to raise the single joint elevator and the pipe segment  11  upwardly and into the spider\elevator  74 . 
   The tool  200  includes links  40  which define the cylindrical lower ends  92  which are received in generally J-shaped cut-outs  212  formed in diametrically opposite sides of the spider\elevator  74 . 
   From the foregoing, it will be apparent that the pipe running tool  10  efficiently utilizes an existing top drive assembly  24  to assemble a pipe string  11 , for example, a casing or drill string, and does not rely on cumbersome casing tongs and other conventional devices. The pipe running tool  10  incorporates the spider\elevator  74 , which not only carries pipe segments  11 , but also imparts rotation to them to threadedly engage the pipe segments  11  to an existing pipe string  34 . Thus, the pipe running tool  10  provides a device which grips and torques the pipe segment  11 , and which also is capable of supporting the entire load of the pipe string  34  as it is lowered down into the well hole. 
     FIG. 8  shows a pipe running tool  10 B according to another embodiment of the invention. In this embodiment, an upper end of the a pipe running tool  10 B includes a top drive extension shaft  118  having internal threads  120  which threadably engage external threads  122  on the output shaft  28  of the top drive assembly  24 . As such, a rotation of the output shaft  28  of the top drive assembly  24  is directly transferred to the top drive extension shaft  118  of the pipe running tool  10 B. Note that in another embodiment, the top drive extension shaft  118  may be externally threaded and the output shaft  28  of the top drive assembly  24  may be internally threaded. 
   Attached to a lower end of the top drive extension shaft  118  is a lift cylinder  124 , which is disposed within a lift cylinder housing  126 . The lift cylinder housing  126 , in turn, is attached, such as by a threaded connection, to a stinger body  128 . The stinger body  128  includes a slip cone section  130 , which slidably receives a plurality of slips  132 , such that when the stinger body  128  is placed within a pipe segment  11 , the slips  132  may be slid along the slip cone section  130  between engaged and disengaged positions with respect to an internal diameter  134  of the pipe segment  11 . The slips  132  are may driven between the engaged and disengaged positions by means of a hydraulic, pneumatic, or electrical system, among other suitable means. 
   In one embodiment, a lower end of the top drive extension shaft  118  is externally splined allowing for a vertical movement, but not a rotationally movement, of the extension shaft  118  with respect to an internally splined ring  136 , within which the splined lower end of the top drive extension shaft  118  is received. The splined ring  136  is further non-rotatably attached to the lift cylinder housing  126 . As such, a rotation of the top drive assembly  24  is transmitted from the output shaft  28  of the top drive assembly  24  to the top drive extension shaft  118 , which transmits the rotation to the splined ring  136  through the splined connection of the extension shaft  118  and the splined ring  136 . The splined ring  136 , in turn, transmits the rotation to the lift cylinder housing  126 , which transmits the rotation to the stinger body  128 , such that when the slips  132  of the stinger body  128  are engaged with a pipe segment  11 , the rotation or torque of the top drive assembly  24  is transmitted to the pipe segment  11 , allowing for a threaded engagement of the pipe segment  11  with a pipe string  34 . 
   In one embodiment, the pipe running tool  10 B includes a slip cylinder housing  138  attached, such as by a threaded connection, to an upper portion of the stinger body  128 . Disposed within the slip cylinder housing  138  is a slip cylinder  140 . In one embodiment, the pipe running tool  10 B includes one slip cylinder  140 , which is connected to each of the plurality of slips  132 , such that vertical movements of the slip cylinder  140  cause each of the plurality of slips  132  to move between the engaged and disengaged positions with respect to the pipe segment  11 . 
   Vertical movements of the slip cylinder  140  may be accomplished by use of a compressed air or a hydraulic fluid acting of the slip cylinder  140  within the slip cylinder housing  138 . Alternatively, vertical movements of the slip cylinder  140  may be controlled electronically. In one embodiment, a lower end of the slip cylinder  140  is connected to a plurality of slips  132 , such that vertical movements of the slip cylinder  140  cause each of the plurality of slips  132  to slide along the slip cone section  130  of the stinger body  128 . 
   As shown, an outer surface of the slip cone section  130  of the stinger body  128  is tapered. For example, in this embodiment the slip cone section  130  is tapered radially outwardly in the downward direction and each of the plurality of slips  132  include an inner surface that is correspondingly tapered radially outwardly in the downward direction. In one embodiment, the slip cone section  130  includes a first tapered section  142  and a second tapered section  146  separated by a radially inward step  144 ; and each of the plurality of slips  132  includes a includes a first tapered section  148  and a second tapered section  152  separated by a radially inward step  150 . The inward steps  144  and  150  of the slip cone section  130  and the slips  132 , respectively, allow each of the plurality of slips  132  to have a desirable length in the vertical direction without creating an undesirably small cross sectional area at the smallest portion of the slip cone section  130 . An elongated length of the slips  132  is desirable as it increases the contact area between the outer surface of the slips  132  and the internal diameter of the pipe segment  11 . 
   In one embodiment, when the slip cylinder  140  is disposed in a powered down position, the slips  132  are slid down the slip cone section  130  of the stinger body  128  and radially outwardly into an engaged position with the internal diameter  134  of the pipe segment  11 ; and when the slip cylinder  140  is disposed in an upward position, the slips  132  are slid up the slip cone section  130  of the stinger body  128  and radially inwardly to a disengaged position with the internal diameter  134  of the pipe segment  11 . 
   In one embodiment, each of the slips  132  includes a generally planar front gripping surface  154 , which includes a gripping means, such as teeth, for engaging the internal diameter  134  of the pipe segment  11 . In one embodiment, the slip cylinder  140  is provided with a powered down force actuating the slip cylinder  140  into the powered down position with sufficient force to enable a transfer of torque from the top drive assembly  24  to the pipe segment  11  through the slips  132 . 
     FIG. 9  shows one embodiment of a slip cylinder  140  for use with the pipe running tool  10 B of  FIG. 8 . As shown, the slip cylinder  140  includes a head  156  and a shaft  158 , wherein the shaft  158  includes a plurality of feet  160  each for attaching to a notch  162  in a corresponding one of the plurality of slips  132  (see also  FIG. 8 .) A slot  164  may extend between each of the plurality of feet  160  of the slip cylinder  140  to add flexibility to the feet  160  to facilitate attachment of the feet  160  to the corresponding slips  132 . The head  156  of the slip cylinder  140  may also include a circumferential groove  166  for receiving a sealing element, such as an o-ring, to seal the hydraulic fluid or compressed gas above and below the slip cylinder head  156 . In various embodiments the plurality of slips  132  may include three, four, six or any appropriate number of slips  132 . 
   As shown in  FIG. 8 , attached to the slip cylinder housing  138  is a pipe segment detector  168 . In one embodiment, upon detection by the pipe detector  168  of a pipe segment being placed adjacent to the pipe detector  168 , the pipe detector  168  activates the slip cylinder  140  to the powered down position, moving the slips  132  into engagement with the pipe segment  11 , allowing the pipe segment  11  to be translated and/or rotated by the top drive assembly  24 . 
   As is also shown in  FIG. 8 , a lower end of the stinger body  128  includes a stabbing cone  170 , which is tapered radially outwardly in the upward direction. This taper facilitates insertion of the stinger body  128  into the pipe segment  11 . Adjacent to the stabbing cone  170  is a circumferential groove  172 , which receives an inflatable packer  174 . In one embodiment, there are two operational options for the packer  174 . For example, the packer  174  can be used in either a deflated or an inflated state during a pipe/casing run. When filling up the casing/pipe string with mud/drilling fluid, it is advantageous to have the packer  174  in the deflated state in order to enable a vent of air out of the casing. This is called the fill-up mode. When mud needs to be circulated through the whole casing string at high pressure and high flow, it is advantageous to have the packer  174  in the inflated state to seal off the internal volume of the casing. This is called the circulation mode. 
   In one embodiment, an outer diameter of the inflatable packer  174  in the deflated state is larger that the largest cross-sectional area of the cone  170 . This helps channel any drilling fluid which flows toward the cone  170  to an underside of the inflatable packer  174 , such that during the circulation mode, the pressure on the underside of the inflatable packer  174  causes the packer  174  to inflate and form a seal against the internal diameter of the pipe segment  11 . This seal prevents drilling fluid from contacting the slips  132  and/or the slip cone section  130  of the stinger body  128 , which could lessen the grip of the slips  132  on the internal diameter  134  of the pipe segment  11 . 
   In an embodiment where the a pipe running tool includes an external gripper, such as that shown in  FIG. 2 , a packer may be disposed above the slips. By controlling how far the pipe is pushed up through the slips prior to setting these slips, it is controlled whether the packer is inserted in the casing (circulation mode) or still above the casing (fill-up mode) when the slips are set. For this reason, such a pipe running tool may include a pipe position sensor which is capable of detecting  2  independent pipe positions. 
   Referring now to an upper portion of the pipe running tool  10 B, attached to an upper portion of the splined ring  136  is a compensator housing  176 . Disposed above the compensator housing  176  is a spring package  177 . A load compensator  178  is disposed within the compensator housing  176  and is attached at its upper end to the top drive extension shaft  118  by a connector or “keeper”  180 . The load compensator  178  is vertically movable within the compensator housing  176 . With the load compensator  178  attached to the top drive extension shaft  118  in a non-vertically movable manner, and with the extension shaft  118  connected to the stinger body  128  via a splined connection, a vertical movement of the load compensator  178  causes a relative vertical movement between the top drive extension shaft  118  and the stinger body  128 , and hence a relative vertical movement between the top drive assembly  24  and the pipe segment  11  when the stinger body  128  is engaged with a pipe segment  11 . 
   Relative vertical movement between the pipe segment  11  and the top drive assembly  24  serves several functions. For example, in one embodiment, when the pipe segment  11  is threaded into the pipe sting  34 , the pipe string  34  is held vertically and rotationally motionless by action of the flush-mounted spider  36 . Thus, as the pipe segment  11  is threaded into the pipe string  34 , the pipe segment  11  is moved downwardly. By allowing relative vertical movement between the top drive assembly  24  and the pipe segment  11 , the top drive assembly  24  does not need to be moved vertically during a threading operation between the pipe segment  11  and the pipe sting  34 . Also, allowing relative vertical movement between the top drive assembly  24  and the pipe segment  11  allows the load that threads of the pipe segment  11  apply to the threads of the pipe string  34  to be controlled or compensated. 
   As with the slip cylinder  140 , vertical movements of the load compensator  178  may be accomplished by use of a compressed air or a hydraulic fluid acting of the load compensator  178 , or by electronic control, among other appropriate means. In one embodiment, the load compensator  178  is an air cushioned compensator. In this embodiment, air is inserted into the compensator housing  176  via a hose  182  and acts downwardly on the load compensator  178  at a predetermined force. This moves the pipe segment  11  upwardly by a predetermined amount and lessens the load on the threads of the pipe segment  11  by a predetermined amount, thus controlling the load on the threads of the pipe segment  11  by a predetermined amount. 
   Alternatively, a load cell (not shown) may be used to measure the load on the threads of the pipe segment  11 . A processor (not shown) may be provided with a predetermined threshold load and programmed to activate the load compensator  178  to lessen the load on the threads of the pipe segment  11  when the load cell detects a load that exceeds the predetermined threshold value of the processor, similar to that described above with respect to  FIG. 6 . 
   As shown in  FIG. 8 , the lift cylinder housing  126  includes a load shoulder  184 . Since the lift cylinder  124  is designed to be vertically moveable with the load compensator  178 , during a threading operation between the pipe segment  11  and the pipe string  34 , the lift cylinder  124  is designed to be free from the load shoulder  184 , allowing the load compensator  178  to control the load on the threads of the pipe segment  11 , and allowing for movement of the pipe segment  11  relative to the top drive assembly  24 . However, when it is desired to lift the pipe segment  11  and/or the pipe string  34 , the lift cylinder  124  is moved vertically upward by the top drive assembly  24  into contact with the load shoulder  184 . The weight of the pipe running tool  10 B and any pipes held thereby is then supported by the interaction of the lift cylinder  124  and the load shoulder  184 . As such, the pipe running tool  10 B is able to transfer both torque and hoist loads to the pipe segment  11 . 
   As shown in  FIG. 8 , the top drive extended shaft  118  includes a drilling fluid passageway  186  which leads to a drilling fluid valve  188  in the lift cylinder  124 . The drilling fluid passageway  186  in the extended shaft  118  and the drilling fluid valve  188  in the lift cylinder  124  allow drilling fluid to flow internally past the splined connection of the spline ring  136  and the splined section of the extension shaft  118 , and therefore does not interfere with or “gumm up” this splined connection. The lift cylinder  124  also includes a circumferential groove  192  for receiving a sealing element, such as an o-ring, to provide a seal preventing drilling fluid from flowing upwardly therepast, thus further protecting the splined connection. Below the drilling fluid valve  188  in the lift cylinder  124 , the drilling fluid is directed through a drilling fluid passageway  190  in the stinger body  128 , through the internal diameters of the pipe segment  11  and the pipe sting  34  and down the well bore. In one embodiment, the pipe segment  11  is a casing segment having a diameter of at least fourteen inches. 
   As can be seen from the illustration of  FIG. 8  and the above description related thereto, in this embodiment a primary load path is provided wherein the primary load of the pipe running tool  10 B and any pipe segments  11  and/or pipe strings  34  is supported by, i.e. hangs directly from the threads  122  on the output shaft  28  of the top drive assembly  24 . This allows the pipe running tool  10 B to be a more streamlined and compact tool. 
     FIG. 10  shows a pipe running tool  10 C having an external gripping pipe engagement assembly  16 C for gripping the external diameter of a pipe segment  11 C, and a load compensator  178 C. The external gripping pipe engagement assembly  16 C of  FIG. 10  includes substantially the same elements and functions as described above with respect to the pipe engagement assembly  16  of  FIGS. 2-5B  and therefore will not be described herein to avoid duplicity, except where explicitly stated below. 
   The embodiment of  FIG. 10  shows a top drive assembly  24 C having an output shaft  122 C connected to a top drive extension shaft  118 C on the pipe running tool  10 C. A lower end of the top drive extension shaft  118 C is externally splined allowing for a vertical movement, but not a rotationally movement, of the extension shaft  118 C with respect to an internally splined ring  136 C, within which the splined lower end of the top drive extension shaft  118 C is received. 
   The load compensator  178 C is connected to the top drive extension shaft  118 C by a keeper  180 C. The load compensator  178  is disposed within and is vertically moveable with respect to a load compensator housing  176 . The load compensator housing  176  is connected to the splined ring  136 C, which is further connected to an upper portion of the pipe engagement assembly  16 C. Disposed above the load compensator housing  176 C is a spring package  177 C. 
   With the load compensator  178 C attached to the top drive extension shaft  118 C in a non-vertically movable manner, and with the extension shaft  118 C connected to the pipe engagement assembly  16 C via a splined connection (i.e., the splined ring  136 C), a vertical movement of the load compensator  178 C causes a relative vertical movement between the top drive extension shaft  118 C and the pipe engagement assembly  16 C, and hence a relative vertical movement between the top drive assembly  24 C and the pipe segment  11 C when the pipe engagement assembly  16 C is engaged with a pipe segment  11 C. 
   Vertical movements of the load compensator  178 C may be accomplished by use of a compressed air or a hydraulic fluid acting of the load compensator  178 C, or by electronic control, among other appropriate means. In one embodiment, the load compensator  178 C is an air cushioned compensator. In this embodiment, air is inserted into the compensator housing  176 C via a hose and acts downwardly on the load compensator  178 C at a predetermined force. This moves the pipe segment  11 C upwardly by a predetermined amount and lessens the load on the threads of the pipe segment  11 C by a predetermined amount, thus controlling the load on the threads of the pipe segment  11 C by a predetermined amount. 
   Alternatively, a load cell (not shown) may be used to measure the load on the threads of the pipe segment  11 C. A processor (not shown) may be provided with a predetermined threshold load and programmed to activate the load compensator  178 C to lessen the load on the threads of the pipe segment  11 C when the load cell detects a load that exceeds the predetermined threshold value of the processor, similar to that described above with respect to  FIG. 6 . 
   The pipe running tool according to one embodiment of the invention, may be equipped with the hoisting mechanism  202  and chains  208  to move a single joint elevator  210  that is disposed below the pipe running tool as described above with respect to  FIG. 7 . Alternatively, a set of wire ropes/slings may be attached to a bottom portion of the pipe running tool for the same purpose, such as is shown in  FIG. 10 . 
   As is also shown in  FIG. 10 , the pipe running tool  10 C includes the frame assembly  12 C, which comprises a pair of links  40 C extending downwardly from a link adapter  42 C. The links  40 C are connected to and supported at their lower ends by a hoist ring  71 C. The hoist ring  71 C is slidably connected to a torque frame  72 C. From the position depicted in  FIG. 10 , a top surface of the hoist rig  71 C contacts an external load shoulder on the torque frame  72 C. As such, the hoist ring  71 C performs a similar function as the lift cylinder  192  described above with respect to  FIG. 8 . When the compensator  178 C is disposed at an intermediate stroke position, such as a mid-stroke position, the top surface of the hoist ring  71 C is displaced downwards from the position shown in  FIG. 10 , free form the external load shoulder of the torque frame  72 C, thus allowing the compensator  178 C to compensate. 
   In one embodiment, when an entire pipe string is to be lifted, the compensator  178 C bottoms out and the external load shoulder of the torque frame  72 C rests on the top surface of the hoist ring  71 C. In one embodiment, the link adapter  42 C, the links  40 C and the hoist ring  71 C are axially fixed to the output shaft  122 C of the top drive assembly  24 C. As such, when the external load shoulder on the torque frame  72 C rests on the hoist ring  71 C, the compensator  178 C cannot axially move and as such cannot compensate. Therefore, in one embodiment, during the make-up of a pipe segment to a pipe string, the compensator  178 C lifts the torque frame  72 C and the top drive extension shaft  118 C on the pipe running tool  10 C upwardly until the compensator  178 C is at an intermediate position, such as a mid-stroke position. During this movement, the torque frame  72 C is axially free from the hoist ring  71 C. Although not shown, the pipe engagement assembly  16  of  FIGS. 2-5B  may be attached to its links  40  in the manner as shown in  FIG. 10 . 
     FIG. 11  shows a pipe running tool  10 D having an external gripping pipe engagement assembly  16 D for gripping the external diameter of a pipe segment  11 D, however, the pipe running tool of  FIG. 11  does not include the links  40  and  40 C as shown in the embodiments  FIGS. 2 and 10 , respectively. In stead, the pipe running tool  10 D of  FIG. 11  includes a primary load path, described below, wherein the primary load of the pipe running tool  10 D and any pipe segments  11 D and/or pipe strings is supported by, i.e. hangs directly from the threads on the output shaft  28 D of the top drive assembly  24 D. This allows the pipe running tool  10 D to be a more streamlined and compact tool. 
   The external gripping pipe engagement assembly  16 D of  FIG. 11  includes substantially the same elements and functions as described above with respect to the pipe engagement assembly  16  of  FIGS. 2-5B  and therefore will not be described herein to avoid duplicity, except where explicitly stated below. 
   The embodiment of  FIG. 11  shows a top drive assembly  24 D having an output shaft  122 D connected to a top drive extension shaft  118 D on the pipe running tool  10 D. A lower end of the top drive extension shaft  118 D is externally splined allowing for a vertical movement, but not a rotationally movement, of the extension shaft  118 D with respect to an internally splined ring  136 D, within which the splined lower end of the top drive extension shaft  118 D is received. 
   A load compensator  178 D is connected to the top drive extension shaft  118 D by a keeper  180 D. The load compensator  178 D is disposed within and is vertically moveable with respect to a load compensator housing  176 D, as described above with respect to the load compensators of  FIGS. 8 and 10 . The load compensator housing  176 D is connected to the splined ring  136 D, which is further connected to an upper portion of a lift cylinder housing  126 D. 
   Attached to a lower end of the extension shaft  118 D is a lift cylinder  124 D. When the top drive assembly  24 D is lifted upwards, the lift cylinder  124 D abuts a shoulder  184 D of the lift cylinder housing  126 D to carry the weight of the pipe engagement assembly  16 D and any pipe segments  11 D and/or pipe strings held by the pipe engagement assembly  16 D. A lower end of the lift cylinder housing  126 D is connected to an upper end of the pipe engagement assembly  16 D by a connector  199 D. 
   Connected to a lower end of the lift cylinder  124 D is a fill-up and circulation tool  201 D (a FAC tool  201 D), which sealingly engages an internal diameter of the pipe segment  11 D. The FAC tool  210 D allows a drilling fluid to flow through internal passageways in the extension shaft  118 D, the lift cylinder  124 D and the FAC tool  210 D and into the internal diameter of the pipe segment  11 D. 
   In one embodiment, the pipe running tool is also used to transmit a translational and rotational forces from the top drive assembly to a pipe string during a drilling operation. During a drilling operation, it is desirable to measure and present to a drilling operator the force on the drill bit, attached at the lower end of the pipe string, and the torque and speed being imparted to the drill bit along with other drilling parameters, such as drill string vibration and/or internal pressure. These readings are used by the drilling operator to optimize the drilling operation. In addition, other systems such as automatic devices for keeping the weight on the bit constant require signals representative of the torque, speed, and weight of the pipe string, as well as the drilling fluid pressure. 
   As shown in  FIG. 8  and enlarged in  FIG. 12 , in one embodiment the pipe running tool  10 B includes one or more measurement devices  121  for measuring drilling parameters during a drilling operation, such as pipe string weight, torque, vibration, speed of rotation, angular position, number of revolutions, rate of penetration and/or internal pressure. Placing measurement devices  121  directly on the pipe running tool  10 B provides a direct approach for measuring the desired drilling parameters of the pipe string  34 , since the pipe running tool  10 B is subjected to loads imparted on the pipe string  34  and hence on the drill bit. As such, the pipe running tool  10 B receives the actual torque and translation imparted by the top drive assembly  24  on the pipe string  34 , as well as the actual tension in the pipe string  34 , and the same speed of rotation, angular position, and number of revolutions as the pipe string  34 . 
   In addition, the pipe running tool  10 B is subjected to the vibration imparted on the pipe string  34 , and since drilling fluid passes through the fluid passageways  186  and  190  in the pipe running tool  10 B and the internal diameter of the pipe string  34 , the pipe running tool  10 B develops the same internal pressure as that in the pipe string  34 . Therefore by measuring the torque, weight, vibration, speed of rotation, angular position, number of revolutions, rate of penetration and internal pressure of the pipe running tool  10 B, the torque, weight, vibration, speed of rotation, angular position, number of revolutions, rate of penetration, and internal pressure of the pipe string  34  can be determined. Therefore, the pipe running tool  10 B of the present invention allows for direct accurate measurements of desired drilling parameters of the pipe string  34  without the need for modification of the top drive assembly  24 . 
   As shown in  FIG. 12 , in one embodiment, the extension shaft  118  of the pipe running tool  10 B includes one or more measurement devices  121  for measuring drilling parameters during a drilling operation. In the embodiment of  FIG. 12 , an upper portion of extension shaft  118  includes a recessed notch or circumferential groove  123 . As shown, disposed within the circumferential groove  123  is another or a second circumferential groove  125 . Mounted within the second circumferential groove  125  are one or more measurement devices  121  (schematically represented) for measuring the drilling parameters of the pipe string  34  during a drilling operation, and an electronics package  127  (schematically represented) for recording the drilling parameters and transmitting signals to the drill floor  30  so that the drilling operator may observe the drilling parameters during a drilling operation. 
   The measurement devices  121  may include one or more, or any combination of one or more drilling parameter measuring devices, including but not limited to proximity switches, strain gauges, gyros, encoders, accelerometers, pressure transducers, tachmoeters, and magnetic pick up switches for measuring drilling parameters including but not limited to torque, weight, vibration, speed of rotation, angular position, number of revolutions, rate of penetration and internal pressure. For example, strain gauges may be used for measuring the pipe string  34  weight and torque, an accelerometer may be used for measuring the vibration of the pipe string  34 , and a pressure transducer may be used for measuring the internal pressure of the pipe string  34 . 
   In one embodiment, the measurement devices  121  include strain gauges for measuring the stress at the surface of the second circumferential groove  125  in the extension shaft  118  of the pipe running tool  10 B, mounted in directions to measure the torsional stress or torque, and the axial stress or tension on the extension shaft  118  of the pipe running tool  10 B. These strain gauges are calibrated to measure the actual torque and tension on the pipe string  34 . For example, in one embodiment, the measurement devices  121  include a strain gauge, such as a load cell, mounted on an inner surface of the second circumferential groove  125 . Since the inner surface of the second circumferential groove  125  is formed to a smaller diameter than the outside diameter of the extension shaft  118  of the pipe running tool  10 B, the strain on this inner surface of the second circumferential groove  125  is magnified and therefore easier to detect. In addition, the corners  129  of the second circumferential groove  125  may be radiused, rather than square, in order to reduce localized strains at the corners  129 . This also serves to concentrate the strain on the inner surface of the second circumferential groove  125 , facilitating the detection of the strain. 
   In one embodiment, the measurement devices  121  include a further strain gauge calibrated to measure the vibration of the pipe running tool  10 B, and hence the vibration of the pipe string  34 . Alternatively, the measurement devices  121  may include an accelerometer calibrated to measure the vibration of the pipe running tool  10 B, and hence the vibration of the pipe string  34 . 
   In another embodiment, the measurement devices  121  include another further strain gauge calibrated to measure the internal pressure of the pipe running tool  10 B, and hence the internal pressure of the pipe string  34 . Alternatively, the measurement devices  121  may include a pressure transducer calibrated to measure the internal pressure of the pipe running tool  10 B, and hence the internal pressure of the pipe string  34 . In another such case, the measurement devices  121  include a device, such as a pressure transducer, placed in fluid communication with the fluid passageway  186  and/or  190  of the pipe running tool  10 B. 
   In yet another embodiment, the measurement devices  121  include a tachometer calibrated to measure the speed of rotation of the pipe running tool  10 B, and hence the speed of rotation of the pipe string  34 . Alternatively, the measurement devices  121  may include a further accelerometer calibrated to measure the speed of rotation of the pipe running tool  10 B, and hence the speed of rotation of the pipe string  34 . 
   The electronics package  127  may include electronic strain gauge amplifiers, signal conditioners, and a wireless signal transmitter connected to a patch antenna  131  (schematically represented) located on an outer surface or outer diameter of the extension shaft  118  of the pipe running tool  10 B. The electronics package  127  records the measured drilling parameters of the pipe string  34 , such as torque, weight, speed, angular position, number of revolutions, rate of penetration, vibration and/or internal pressure, and transmits signals representative of these parameters via wireless telemetry to a receiver  133  (schematically represented in  FIG. 8 ) located on the drill floor  30 . The receiver  133 , in turn, passes the signals to an instrument or computer  135  (schematically represented in  FIG. 8 ) viewable by the drilling operator so that the drilling parameters of the pipe string  34  may be observed during a drilling operation. In one embodiment, the receiver  133  and computer  135  form a portion of a pipe running tool control system. In addition, or alternatively, the electronics package  127  may communicate through wireless telemetry to transfer data between the pipe running tool  10 B and the top drive assembly  24  during a drilling operation. 
   The power for the electronics package  127  may be obtained in any one of a variety of ways. For example, in one embodiment, the electronics package  127  includes replaceable batteries removably disposed therein. In another embodiment, power is transmitted to the electronics package  127  from a stationary power antenna located around the outside of the pipe running tool  10 B to a receiving antenna located on the pipe running tool  10 B. In a still further embodiment, power is provided to the electronics package  127  through a standard slip ring. 
   As shown in  FIG. 12 , a thin walled sleeve  137  is received within the first circumferential groove  123  of the extension shaft  118  of the pipe running tool  10 B to close off the first circumferential groove  123  where the measurement devices  121  and the electronics package  127  are mounted. The sleeve  137  serves to protect the measurement devices  121  and the electronics package  127  from damage and exposure to the external environment and/or elements. In one embodiment, the sleeve  137  is threadably connected to a threaded portion of the first circumferential groove  123 . Sealing elements  139 , such as O-rings, may also be disposed between the first circumferential groove  123  and the sleeve  137  at a position above and below the first circumferential groove  123  to further protect the measurement devices  121  and the electronics package  127 . 
   Although the measurement devices  121  and the electronics package  127  have been described as being mounted on the extension shaft  118  of the pipe running tool  10 B, in other embodiments, the measurement devices  121  and the electronics package  127  may be mounted at other locations on the pipe running tool. In addition, although the measurement devices  121  and the electronics package  127  have been described as being mounted on an internally gripping pipe running tool, such as that shown in  FIG. 8 , in other embodiments, the measurement devices  121  and the electronics package  127  may be mounted on an externally gripping pipe running tool, such as any of the embodiments as shown and described with respect to  FIGS. 2 ,  10  and  11 . 
   While several forms of the present invention have been illustrated and described, it will be apparent to those of ordinary skill in the art that various modifications and improvements can be made without departing from the spirit and scope of the invention. Accordingly, it is not intended that the invention be limited, except as by the appended claims.