Patent Publication Number: US-8985225-B2

Title: Tubular engaging device and method

Description:
BACKGROUND 
     The present disclosure relates generally to the field of drilling and processing of wells, and, more particularly, to a tubular engaging device and method for using the tubular engaging device. 
     In conventional oil and gas operations, a well is typically drilled to a desired depth with a drill string, which includes drillpipe, drill collars and a bottom hole drilling assembly. The drill string may be turned by a rotary table and kelly assembly or by a top drive. A top drive typically includes a quill, which is a short length of pipe that couples with the upper end of the drill string, and one or more motors configured to turn the quill. The top drive is typically suspended from a traveling block above the rig floor so that it may be raised and lowered throughout drilling operations. 
     In conventional operations, to add a length of tubular (e.g., drillpipe or drill collar) to the drill string, an elevator is coupled with the tubular to facilitate hoisting the tubular from the rig floor. The tubular is aligned with the drill string and lowered onto the drill string. An iron roughneck at the rig floor may be used to rotate the tubular and attach the tubular to the drill string. However, it is now recognized that using an iron roughneck to add each new length of tubular to the drill string may be time consuming and expensive. Accordingly, it is now recognized that there exists a need for a device and method for connecting tubulars to drill strings without the use of an iron roughneck. 
     BRIEF DESCRIPTION 
     In accordance with one aspect of the present disclosure, a device for a top drive drilling system includes a sub having a first coupling end configured to mate with the top drive drilling system and a second coupling end configured to mate with a tubular. The device also includes a movable sleeve disposed around at least a portion of the sub. The movable sleeve is configured to be selectively disposed around the tubular by sliding axially along the sub. The device includes a plurality of engagement features extending inwardly from an inner circumference of the movable sleeve. When the movable sleeve is disposed around the tubular, the plurality of engagement features are configured to engage the tubular when the movable sleeve is rotated in a first direction and to not engage the tubular when the movable sleeve is rotated in a second direction. 
     In accordance with another aspect of the disclosure, a device for a top drive drilling system includes a movable sleeve configured to be disposed around at least a portion of a sub. The movable sleeve is configured to be selectively disposed around a tubular by sliding axially along the sub. The device also includes a plurality of engagement features extending inwardly from an inner circumference of the movable sleeve. When the movable sleeve is disposed around the tubular, the plurality of engagement features are configured to engage the tubular when the movable sleeve is rotated in a first direction and to not engage the tubular when the movable sleeve is rotated in a second direction. 
     Present embodiments also provide a method for coordinating tubulars in a top drive drilling system. In one embodiment, the method includes sliding a movable sleeve axially along a sub. The method also includes disposing a plurality of engagement features around a tubular. The plurality of engagement features extend inwardly from an inner circumference of the movable sleeve. The method includes rotating the plurality of engagement features around the tubular in a first direction. The method also includes engaging the plurality of engagement features with the tubular to cause the plurality of engagement features to apply a frictional force to the tubular. The frictional force is configured to cause the tubular to rotate in the first direction. 
    
    
     
       DRAWINGS 
       These and other features, aspects, and advantages of the present invention will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein: 
         FIG. 1  is a schematic representation of a well being drilled in accordance with present techniques; 
         FIG. 2  is a schematic cross-sectional view of an embodiment of a sub assembly coupled with a top drive drilling system for coordinating tubulars in accordance with present techniques; 
         FIG. 3  is a schematic cross-sectional view of the embodiment of the sub assembly of  FIG. 2  with a tubular coupled to the sub assembly in accordance with present techniques; 
         FIG. 4  is a schematic cross-sectional view of an embodiment of a sub assembly with an automated movable sleeve coupled with a top drive drilling system for coordinating tubulars in accordance with present techniques; 
         FIG. 5  is a schematic top view of an embodiment of an engagement assembly used to engage a tubular when rotated in a first direction in accordance with present techniques; 
         FIG. 6  is a schematic top view of an embodiment of an engagement assembly used to engage a tubular when rotated in a second direction in accordance with present techniques; 
         FIG. 7  is a schematic top view of an embodiment of an engagement feature in accordance with present techniques; 
         FIG. 8  is flow chart of an embodiment of a method for coordinating tubulars with a top drive drilling system in accordance with present techniques; and 
         FIG. 9  is a flow chart of another embodiment of a method for coordinating tubulars with a top drive drilling system in accordance with present techniques. 
     
    
    
     DETAILED DESCRIPTION 
     The present disclosure provides a novel coupling device for a top drive drilling system and a method that can be used in drilling operations. The presently disclosed techniques allow for tubulars to be coordinated (e.g., assembled, disassembled, etc.) using a top drive having the coupling device attached to the top drive. Further, the tubulars may be coordinated using power from the top drive without the use of an iron roughneck. The coupling device may include a movable sleeve disposed around a portion of a sub. During operation, the sub is coupled to the top drive (e.g., to the quill of the top drive) and the sub may interlock or otherwise engage the movable sleeve to translate motion from the top drive via the sub to the movable sleeve. Engagement features extend inwardly from the movable sleeve and may be engaged with a tubular by extending a portion of the movable sleeve over the tubular and rotating the movable sleeve (e.g., using the top drive to rotate the coupling device) and thereby rotating the engagement features around the tubular. When the engagement features are engaged with the tubular, the engagement features may provide sufficient torque to rotate the tubular to attach the tubular to a drill string or to detach the tubular from the drill string. 
     Turning now to the drawings,  FIG. 1  is a schematic of a drilling rig  10  in the process of drilling a well in accordance with present techniques. The drilling rig  10  includes an elevated rig floor  12  and a derrick  14  extending above the rig floor  12 . A supply reel  16  supplies drilling line  18  to a crown block  20  and traveling block  22  configured to hoist various types of drilling equipment above the rig floor  12 . The drilling line  18  is secured to a deadline tiedown anchor  24 , and a drawworks  26  regulates the amount of drilling line  18  in use and, consequently, the height of the traveling block  22  at a given moment. Below the rig floor  12 , a drill string  28  extends downward into a wellbore  30  and is held stationary with respect to the rig floor  12  using slips  32 . A portion of the drill string  28  extends above the rig floor  12 , forming a stump  34  to which another length of tubular  36  may be added. In certain embodiments, the tubular  36  may be coupled to a sub assembly  38  in accordance with present embodiments, and the sub assembly  38  may be coupled to a top drive drilling system  40 . In particular, the sub assembly  38  may be coupled to a quill  46  of the top drive drilling system  40 . The top drive drilling system  40 , hoisted by the traveling block  22 , positions the tubular  36  above the wellbore before coupling the tubular  36  with the drill string  28 . The top drive drilling system  40 , once coupled with the tubular  36 , may then lower the coupled tubular  36  toward the stump  34  and rotate the tubular  36  such that it connects with the stump  36  and becomes part of the drill string  28 . 
     In certain embodiments, the top drive drilling system  40  may include elevators for positioning the tubular  36  over the drill string  28  and coupling the tubular  36  with other features. For example, the elevators may be used to hoist the tubular  36  up a pipe ramp  48  and through a V-door  50  to a position over the drill string  28 . After the tubular  36  is positioned over the drill string  28 , the sub assembly  38  may be used to couple the tubular  36  to the drill string  28 . Further, the sub assembly  38  may be used to decouple the tubular  36  from the drill string  28  after it has previously been coupled to the drill string  28 . The sub assembly  38  may include engagement features that apply a torque to the tubular  36  when the sub assembly  38  is rotated in a first direction. The torque may be applied to the tubular  36  by the engagement features gripping the tubular  36  and causing a rotational force to be transferred from the top drive drilling system  40  to the tubular  36  when the sub assembly  38  is rotated in the first direction. When the sub assembly  38  is rotated in a second direction, the engagement features do not engage the tubular  36 . For example, the engagement features may slip, or no longer grip the tubular  36 . 
     To couple the tubular  36  to the drill string  28 , a sleeve of the sub assembly  38  may be lowered around the upper end of the tubular  36 . Thereafter, the sub assembly  38  is rotated in the first direction until the tubular  36  is coupled to the drill string  28 . As will be appreciated, while the sub assembly  38  is applying rotational force to the tubular  36 , the slips  32  are used to hold the drill string  28  in place and to keep the drill string  28  from rotating. After the tubular  36  is coupled to the drill string  28 , the sub assembly  38  is rotated in the second direction to disengage the engagement features from the tubular  36 . The sub assembly  38  may be raised off of the upper end of the tubular  36  after the tubular  36  is coupled to the drill string  28 . Thus, the tubular  36  may be added to the drill string  28  using power from the top drive drilling system  40  without using an iron roughneck. 
     It should be noted that the illustration of  FIG. 1  is intentionally simplified to focus on the sub assembly  38  coupled to the top drive drilling system  40 , which is described in detail below. Many other components and tools may be employed during the various periods of formation and preparation of the well. Similarly, as will be appreciated by those skilled in the art, the orientation and environment of the well may vary widely depending upon the location and situation of the formations of interest. For example, rather than a generally vertical bore, the well, in practice, may include one or more deviations, including angled and horizontal runs. Similarly, while shown as a surface (land-based) operation, the well may be formed in water of various depths, in which case the topside equipment may include an anchored or floating platform. 
       FIG. 2  is a schematic cross-sectional view of an embodiment of the sub assembly  38  coupled with the top drive drilling system  40  for coordinating tubulars. The sub assembly  38  includes a sub  56  having a first coupling end  58  and a second coupling end  60 . In certain embodiments, the first coupling end  58  may include threads to couple the first coupling end  58  to a threaded coupling end  62  of the quill  46 . In other embodiments, the sub  56  may be configured to be coupled to the quill  46 , or another part of the top drive drilling system  40 , in another manner (e.g., using a clamp, bolt, etc). The second coupling end  60  may also include threads to couple the second coupling end  60  to a threaded coupling end  64  of the tubular  36  when such a coupling is desired (e.g., to transfer fluids). Again, as will be appreciated, in other embodiments, the sub  56  may be configured to be coupled to the tubular  36  in another manner. As illustrated, the coupling end  64  of the tubular  36  may be part of a tool joint  66 . 
     The sub assembly  38  also includes a movable sleeve  68  disposed around a portion of the sub  56 . The movable sleeve  68  includes one or more splines  70  that slidably engage one or more grooves in the sub  56 . The splines  70  allow the movable sleeve  68  to move axially along the sub  56  and allow for transfer of motion from the sub  56  to the movable sleeve  68 . For example, the movable sleeve  68  may use the splines  70  to slide between the first coupling end  58  and the second coupling end  60 . As such, the movable sleeve  68  may be selectively disposed around the tool joint  66  of the tubular  36  and a portion of the sub  56 , simply around the sub  56 , or any of various different devices. In certain embodiments, the movable sleeve  68  may be positioned manually, while in other embodiments the movable sleeve  68  may be positioned using automation features that will be described in more detail below in relation to  FIG. 4 . As will be appreciated, the sub  56  and/or the movable sleeve  68  may include a braking portion, locking device, or another mechanism to hold the movable sleeve  68  at a desired position. 
     In the illustrated embodiment, a first sealing device  72  (e.g., o-ring, gasket, etc) is disposed between the sub  56  and the movable sleeve  68 . As illustrated, the first sealing device  72  may be disposed between the second coupling end  60  of the sub  56  and the movable sleeve  68 . In certain embodiments, the first sealing device  72  may disposed in a circumferential groove  73  in the movable sleeve  68  to hold the first sealing device  72  in place. In other embodiments, the first sealing device  72  may be disposed in a groove in the coupling end  60  to hold the first sealing device  72  in place. A second sealing device  74  (e.g., o-ring, gasket, etc) is disposed within a lower portion of the movable sleeve  68  and is used to provide a seal between the movable sleeve  68  and the tubular  36  when the movable sleeve  68  is disposed around the tubular  36 . As such, the first sealing device  72  and the second sealing device  74  may be used together to provide a pressure seal (e.g., for pumping mud through the sub  56  and into the tubular  36 ). 
     The movable sleeve  68  includes an engagement assembly  76  with engagement features  78  (e.g., sprag elements, cam-like features, or gripping elements) extending inwardly from an inner circumference  80  of the movable sleeve  68 . When the movable sleeve  68  is disposed around the tubular  36 , the engagement features  78  of the engagement assembly  76  are arranged to engage the tubular  36  (e.g., grip the tubular  36 ) when rotated in a first direction and to not engage the tubular  36  (e.g., slip over the surface of the tubular  36 ), or to disengage the tubular  36  (e.g., no longer grip the tubular  36  if previously gripped), when rotated in a second direction. For example, the engagement features  78  may apply a frictional rotation force or torque to the tubular  36  when the engagement assembly  76  is rotated in the first direction to grip the tubular  36 . When the engagement assembly  76  is rotated in the second direction, the engagement features  78  may slip, or no longer grip the tubular  36 . When frictional force is applied, the applied frictional force may be used to rotate the tubular  36 , such as for connecting the tubular  36  to the drill string  28  or disconnecting the tubular  36  from the drill string  28 . As will be appreciated, the engagement assembly  76  may be rotated by rotating the sub assembly  38 . Further, the top drive drilling assembly  40  may be used to rotate the sub assembly  38 . In certain embodiments, the engagement assembly  76 , the engagement features  78 , or a subset of the engagement features  78  may be reversible so that the engagement features  78  engage the tubular  36  when rotated in the second direction and do not engage the tubular  36  when rotated in the first direction. 
     As illustrated in  FIG. 2 , the engagement features  78  engage the tubular  36  when the coupling end  64  of the tubular  36  is not coupled to the second coupling end  60  of the sub  56 . However, as previously discussed, the coupling end  64  of the tubular  36  may be coupled to the second coupling end  60  of the sub  56 , as illustrated in  FIG. 3 . In such a configuration, the engagement features  78  may not engage the tubular  36 . For example, in the illustrated embodiment, the engagement features  78  are located beyond the tool joint  66  and are not of sufficient length to engage the tubular  36 . Further, with the tubular  36  coupled to the sub  56 , the top drive drilling system  40  may be used for standard drilling operations such as for pumping pressurized mud into the tubular  36 , raising or lowering the tubular  36 , raising or lowering the drill string  28 , rotation of the tubular  36  or drill string  38 , or for any other suitable purpose. 
       FIG. 4  is a schematic cross-sectional view of an embodiment of the sub assembly  38  with a automated movable sleeve  68  coupled with the top drive drilling system  40  for coordinating tubulars. The movable sleeve  68  may include one or more splines  70  as previously described. The splines  70  are configured to slidably engage one or more axial grooves  82  in the sub  56 . The arrangement of the splines  70  and the grooves  82  allows the movable sleeve  68  to move axially  84  along the sub assembly  38  while facilitating translation of rotational force. Although the splines  70  and grooves  82  are presented as extending in the axial direction  84 , in certain embodiments, the splines  70  and grooves  82  may extend in a different direction, such as a circumferential direction  85 . For example, the movable sleeve  68  may be selectively disposed around a portion of the sub  56  using a thread-like coupling that couples the movable sleeve  68  to the sub  56 . In such a configuration, the movable sleeve  68  may be rotated around the sub  56  to change the position of the movable sleeve  68 . Further, the movable sleeve  68  and/or the sub  56  may include a locking feature to hold the movable sleeve  68  in a fixed position relative to the sub  56 . 
     As illustrated, the sub assembly  38  may include a motor  86  to axially slide the movable sleeve  68 . Further, a controller  88  may be electrically and/or communicatively coupled to the motor  86 . Thus, the controller  88  may send control signals and/or power signals to the motor  86  to cause the motor  86  to slide the movable sleeve  68 . By using the motor  86  the movable sleeve  68  may slide to a number of positions without an operator manually positioning the movable sleeve  68 . As will be appreciated, in certain embodiments, an actuator or other device may be used instead of the motor  86  to slide the movable sleeve  68 . 
       FIG. 5  is a schematic top view of an embodiment of the engagement assembly  76  having engagement elements  78  used to engage the tubular  36  when rotated in a first direction  96 . The engagement elements  78  are arranged circumferentially around the engagement assembly  76  to enable engagement of the engagement assembly  76  with the exterior of the tubular  36 . Although the engagement elements  78  are illustrated as being generally straight, the engagement elements  78  may be curved, hooked, crescent shaped, or any other suitable shape. Specifically, the engagement elements  78  may be shaped to facilitate frictional engagement of the tubular  36  when turned in the first direction  96  and slippage when turned in a second direction  98  (i.e., opposite the first direction  96 ). Further, the engagement elements  78  may be constructed using steel, or any other suitable material such as a polymeric composition, metal, metal alloy, and so forth. The engagement elements  78  are arranged so that when the engagement assembly  76  is rotated in the first direction  96 , the engagement elements  78  will engage a tubular  36  disposed within the engagement assembly  76 . For example, when the engagement elements  78  rotate, the surface of the engagement elements  78  contacts the surface of the tubular  36 . The engagement elements  78  then grip, or press inwardly against, the tubular  36  and apply torque to the tubular  36 . As the engagement assembly  76  is further rotated in the first direction  96 , the engagement elements  78  apply sufficient torque to cause the tubular  36  to rotate in the first direction  96 . 
     Conversely, the engagement assembly  76  may be rotated in the second direction  98 . When the engagement assembly  76  is rotated in the second direction  98 , the engagement elements  78  may slide around the tubular  36  without applying a sufficient frictional force to rotate the tubular  36 . Further, if the engagement elements  78  were previously engaged with the tubular  36 , rotating the engagement assembly  76  in the second direction  98  may disengage the engagement elements  78  from the tubular  36 . 
     As illustrated, the engagement elements  78  may be coupled to the engagement assembly  76  using hinges  100 . The hinges  100  provide a rotational axis for the engagement elements  78 . As will be appreciated, the hinges  100  may be formed to limit the range of movement of the engagement elements  78  in a particular direction, which may assist with engagement based on rotational direction. In certain embodiments, the engagement elements  78  may include geometric characteristics (e.g., generally straight, curved, etc.) and coupling features (e.g., hinges) that enable them to be reversed. For example, the engagement elements  78  may be reversed as shown in  FIG. 6 . 
       FIG. 6  is a schematic top view of an embodiment of the engagement assembly  76  used to engage the tubular  36  when rotated in the second direction  98  and to not engage the tubular  36 , or to disengage with the tubular  36 , when rotated in the first direction  96 . As may be appreciated, the engagement assembly  76  and/or the engagement elements  78  may be reversed using a variety of methods. For example, in certain embodiments, the engagement assembly  76  may be removed from the movable sleeve  68 , turned over, and reinserted into the movable sleeve  68 . In other embodiments, the engagement elements  78  may be moved between the position illustrated in  FIG. 5  and the position illustrated in  FIG. 6 . Further, in some embodiments, each engagement element  78  may be removed from the engagement assembly  76 , reversed (e.g., by turning or flipping over), and reinserted into the engagement assembly  76 . In such configurations, the hinges  100  may be removed while reconfiguring the engagement elements  78 . It should be noted, that while the engagement assembly  76  and/or the engagement elements  78  may be reversible, certain embodiments may use two separate engagement assemblies  76  (e.g., one engagement assembly  76  as illustrated in  FIG. 5  for providing torque in the first direction  96 , and another engagement assembly  76  as illustrated in  FIG. 6  for providing torque in the second direction  98 ). 
       FIG. 7  is a schematic top view of an embodiment of the engagement feature  78  having a generally crescent shape. The engagement feature  78  includes a body portion  104  with an engagement end  105 . The engagement end  105  is the portion of the engagement feature  78  that generally engages the tubular  36 . The engagement end  105  may include teeth or wickers  106  that facilitate frictional engagement of the engagement feature  78  with the tubular  36  (e.g., to grip the tubular  36 ). The engagement feature  78  may also include an attachment end  107  used to attach the engagement feature  78  to the engagement assembly  76 . The attachment end  107  includes an opening  108  where a hinge or mounting pin may be inserted during assembly to attach the engagement feature  78  to the engagement assembly  76 . 
       FIG. 8  is flow chart of an embodiment of a method  110  for coordinating tubulars with the top drive drilling system  40 . As will be appreciated, the sub assembly  38  may be used for tripping tubulars  36  (e.g., drillpipe, drill collar, etc.) in or out of the wellbore  30 , reaming in or out of the wellbore  30 , or for other drilling operations. Each of these operations may be performed without using an iron roughneck. As such, the sub assembly  38  may perform tripping more efficiently than systems using an iron roughneck. 
     During a tripping out sequence using the sub assembly  38 , the drill string  28  and the tubular  36  are positioned at a proper elevation, at block  112 . For example, the elevator of the top drive drilling system  40  may close around the stump  34  of the drill string  28 . The slips  32  are released to allow the drill string  28  to be moved. The elevator pulls the drill string  28  to the proper elevation and the slips  32  are applied to hold the drill string  28  in place. At block  114 , the top drive drilling system  40  is lowered to set the slips  32  and the movable sleeve  68  of the sub assembly  38  is lowered to position the engagement assembly  76  around the tool joint  66  of the uppermost tubular  36 . Then, at block  116 , the top drive drilling system  40  is rotated to cause the engagement assembly  76  of the movable sleeve  68  to engage the tubular  36 . In certain embodiments, the top drive drilling system  40  will rotate in a reverse, counter-clockwise, or second direction  98  to engage the engagement assembly  76  with the tubular  36 . As will be appreciated, the engagement features  78  may be arranged as illustrated in  FIG. 6  to engage the tubular  36  in the second direction  98 . The top drive drilling system  40  is rotated until a bottom tool joint of the tubular  36  is disconnected from the drill string  28 . In some embodiments, the top drive drilling system  40  will rotate in a forward, clockwise, or first direction  96  to disengage the engagement assembly  76  from the tubular  36 . Next, at block  118 , the top drive drilling system  40  is raised to remove the movable sleeve  68  from surrounding the tool joint  66  of the tubular  36 . In certain embodiments, the movable sleeve  68  is moved from surrounding the tool joint  66  using the motor  86 . The elevator then moves the tubular  36  so that it can be racked. To continue the tripping out sequence, blocks  112  through  118  may be repeated. 
     A tripping in sequence also uses the sub assembly  38  and may be performed in a similar manner to the tripping out sequence. Specifically, the drill string  28  is positioned at a proper elevation, at block  112 . For example, the elevator of the top drive drilling system  40  opens from being around the stump  34  of the drill string  28 . The top drive drilling system  40  is raised up to an elevation where the tubular  36  may be thrown in. The elevator closes around the tubular  36  and positions the tubular  36  within the stump  34  (e.g., stabs the tubular  36  into the stump  34 ). At block  114 , the top drive drilling system  40  is lowered causing the movable sleeve  68  of the sub assembly  38  to position the engagement assembly  76  around the tool joint  66  of the tubular  36 . Then, at block  116 , the top drive drilling system  40  is rotated to cause the engagement assembly  76  of the movable sleeve  68  to engage the tubular  36 . In certain embodiments, the top drive drilling system  40  will rotate in the forward, clockwise, or first direction  96  to engage the engagement assembly  76  with the tubular  36 . As will be appreciated, the engagement features  78  may be arranged as illustrated in  FIG. 5  to engage the tubular  36  in the first direction  96 . The top drive drilling system  40  is rotated until a bottom tool joint of the tubular  36  is connected to the drill string  28  at an appropriate torque. In some embodiments, the top drive drilling system  40  will rotate in the reverse, counter-clockwise, or second direction  98  to disengage the engagement assembly  76  from the tubular  36 . Next, at block  118 , the top drive drilling system  40  is raised to remove the movable sleeve  68  from surrounding the tool joint  66  of the tubular  36 . Again, in certain embodiments, the movable sleeve  68  is moved from surrounding the tool joint  66  using the motor  86 . The elevators catch the tubular  36  and raise the drill string  28 . Further, the slips  32  are removed, the drill string  28  is lowered to the appropriate elevation for the stump  34 , and the slips  32  are applied. To continue the tripping in sequence, blocks  112  through  118  may be repeated. 
     In one embodiment, during operation of the top drive drilling system  40  with the sub assembly  38  attached, the movable sleeve  68  may be raised so that the engagement assembly  76  will not surround the tool joint  66  of the tubular  36 . The top drive drilling system  40  is rotated in the forward, or first direction  96 , then lowered onto the tool joint  66 . This causes the second coupling end  60  of the sub  56  to engage with the coupling end  64  of the tubular  36 . After the connection between the sub  56  and the tubular  36  is made up, drilling operations may be performed. Thus, using the sub assembly  38 , tripping in, tripping out, and drilling operations may be performed, without the use of an iron roughneck. 
       FIG. 9  is a flow chart of another embodiment of a method  124  for coordinating tubulars with the top drive drilling system  40 . At block  126 , the movable sleeve  68  may slide axially  84  along the sub  56 . Then, at block  128 , the engagement features  78  may be disposed around the tubular  36 . The engagement features  78  extend inwardly from the inner circumference  78  of the movable sleeve  68 . Next, at block  130 , the engagement features  78  are rotated around the tubular  36  in the first direction  96 . At block  132 , the plurality of engagement features  78  engage with the tubular  36  to cause the engagement features  78  to apply a frictional force to the tubular  36 . The frictional force causes the tubular  36  to rotate in the first direction  96 . In certain embodiments, the engagement features  78  may be disengaged from the tubular  36  to cause the engagement features  78  to discontinue applying the frictional force to the tubular  36  (e.g., such as by rotating the engagement features  78  in the second direction  98 ). Further, in some embodiments, the movable sleeve  68  may slide axially  84  along the sub  56  to move the engagement features  78  from being disposed around the tubular  36  (e.g., to move the movable sleeve  68  to not be disposed around the tubular  36 ). 
     While only certain features of the invention have been illustrated and described herein, many modifications and changes will occur to those skilled in the art. It is, therefore, to be understood that the appended claims are intended to cover all such modifications and changes as fall within the true spirit of the invention.