Patent Document

BACKGROUND OF THE INVENTION  
         [0001]    1. Field of the Invention  
           [0002]    The present invention generally relates to an apparatus and methods for wellbore completion. More particularly, the invention relates to an apparatus and methods for allowing rotational movement of downhole tools. More particularly yet, the invention provides a hydraulically activated swivel.  
           [0003]    2. Description of the Related Art  
           [0004]    In the drilling of oil and gas wells, a wellbore is formed using a drill bit that is urged downwardly at a lower end of a drill string. After drilling a predetermined depth, the drill string and bit are removed, and the wellbore is lined with a string of steel pipe called casing. The casing provides support to the wellbore and facilitates the isolation of certain areas of the wellbore adjacent hydrocarbon bearing formations. The casing typically extends down the wellbore from the surface of the well to a designated depth. An annular area is thus defined between the outside of the casing and the earth formation. This annular area is filled with cement to permanently set the casing in the wellbore and to facilitate the isolation of production zones and fluids at different depths within the wellbore.  
           [0005]    It is common to employ more than one string of casing in a wellbore. In this respect, a first string of casing is set in the wellbore when the well is drilled to a first designated depth. The well is then drilled to a second designated depth, and a second string of casing, or liner, is run into the well to a depth, whereby the upper portion of the second liner is overlapping the lower portion of the first string of casing. The second liner string is then fixed or hung in the wellbore, usually by some mechanical slip mechanism well-known in the art, and cemented. This process is typically repeated with additional casing strings until the well has been drilled to total depth.  
           [0006]    A recent trend in well completion has been the advent of expandable tubular technology. It has been discovered that both slotted and solid tubulars can be expanded in situ so as to enlarge their inner diameter. This, in turn, enlarges the path through which both fluid and downhole tools may travel. Also, expansion technology enables a smaller tubular to be run into a larger tubular, and then expanded so that a portion of the smaller tubular is in contact with the larger tubular therearound. Tubulars are expanded by the use of a cone-shaped mandrel or by an expander tool with expandable, fluid actuated members disposed on a body and run into the wellbore on a tubular string. During expansion of a tubular, the tubular walls are expanded past their elastic limit. Examples of expandable tubular devices include slotted screen, joints, packers, and liners. The use of expandable tubulars as hangers and packers allows for greater fluid bypass when running in the hole, because the conventional slip mechanism and sealing mechanism are eliminated.  
           [0007]    Generally, a liner is a string of casing that does not extend to the top of the wellbore, but instead is anchored or suspended from inside the bottom of the previous tubular string. Multiple uses for expandable liners are being discovered. For example, an intermediate liner can be hung off of a string of surface casing by expanding an upper portion of the intermediate liner into frictional contact with the lower portion of surface casing therearound. This allows for the hanging of a string of liner without the need for a separate slip assembly as described above. Additional applications for the expansion of downhole liners exist. These include the use of an expandable sand screen, employment of an expandable seat for seating a diverter tool, and the use of an expandable seat for setting a packer.  
           [0008]    An expandable liner is typically run into the wellbore with a running assembly disposed at an end of a drill string. Typically, a conventional swivel is connected directly to the running tool and the expander tool to interact with the running assembly during the expansion operation. The running assembly includes an expander tool and a running tool. Generally, the expander tool is disposed at the bottom end of the drill string and the running tool is located below the expander tool. The conventional swivel attaches to the running assembly between the expander and the running tool, thereby allowing the expander tool to rotate while the running tool remains stationary. Additionally, the running tool is mechanically attached to the liner through a mechanical holding device.  
           [0009]    After the expandable liner is lowered to a predetermined point near the end of an existing casing string, the upper portion of the liner is ready to be expanded into contact with the casing. To activate the expander tool, a hydraulic isolation device, like a ball, is circulated down into a seat in the expander tool. Thereafter, fluid is pumped from the surface of the wellbore down the drill string into the expander tool. When the fluid pressure builds up to a predetermined level, the expander tool is activated, thereby starting the expansion operation. During the expansion operation, the conventional swivel on the expandable liner allows the expander tool to rotate while the liner and the running tool remain stationary.  
           [0010]    After the liner has been expanded against the casing, the running tool is disengaged from the liner, thereby transferring the weight of the liner string to the casing. Generally, the running tool includes a primary release system that is activated by pressuring up beyond the pressure reached for expansion. Thereafter, the fluid pressure is increased to a predetermined level to deactivate the running tool, thereby releasing the running tool from the liner. The running tool typically includes a secondary or back-up release for disengaging the liner from running tool if the primary release system fails to operate properly. In the event of a hydraulic failure, the back-up release permits the running tool to release the liner by a mechanical means. Typically, the back-up release involves left-hand rotation of the running tool by the drill string. As the drill string rotates to the left, the rotational force causes a mechanism within the running tool mechanically disconnect the running tool from the liner. After the running tool is disengaged from the liner, the running assembly is removed from the wellbore while the expanded liner remains downhole.  
           [0011]    Several problems may occur using a conventional swivel and the running assembly to expand a liner downhole. One problem particularly associated with running the liner into the wellbore is the likelihood of encountering a downhole obstruction. In this event, the liner including the expander tool, conventional swivel, and running tool may need to be rotated in one direction, thereby allowing the liner to be “drilled” into the wellbore to overcome the obstruction. However, the conventional swivel does not permit the running assembly to act as one rotationally locked unit. Another problem is associated with the removal of the running tool from the liner after the expansion operation. When the running tool primary release mechanism fails to operate properly, it may be necessary to rotate the running tool to the left to mechanically disconnect the running tool from the liner. However, the conventional swivel does not have the functionality to release the running tool by rotating the swivel in a single direction.  
           [0012]    A need therefore exists for an apparatus for expanding a liner without swivel that allows the running assembly to selectively act as one rotationally locked unit. There is a further need for an apparatus having the capability to support the entire weight of a string of liner while providing rotational freedom between an expanding tool and running tool. There is yet a further need for an apparatus to rotate the running tool to the left to mechanically disconnect the running tool from the liner in the event of a failure of primary release system due to a hydraulic malfunction.  
         SUMMARY OF THE INVENTION  
         [0013]    The present invention generally relates to an apparatus for use in a wellbore. The apparatus comprises a top body, a bottom body, and a sleeve mechanically connected to the top and bottom bodies. The sleeve movable between a first position to a second position, whereby in the first position, the top and bottom bodies rotate as one unit and in the second position, the top body rotates independent of the bottom body in a first direction and with the bottom body in a second direction.  
           [0014]    A hydraulically activated swivel for use in a well is also provided. The hydraulically activated swivel consists of an upper tubular and a lower tubular. The lower tubular is connected to a bottom connection by a lower spline assembly. The hydraulically activated swivel further includes a sleeve member connected to the upper tubular. The sleeve member movable from a first location to a second location. In the first location, the lower spline assembly is fully engaged, thereby permitting the upper and lower tubular to rotate as one unit. While in the second location, the lower spline assembly is disengaged, thereby allowing the upper tubular to rotate independent of the lower tubular in a first direction and with the lower tubular in a second direction.  
           [0015]    A method is further provided for completing a wellbore. The method comprises running an assembly and a liner disposed on a drill string into the wellbore. The assembly includes an expander tool, a hydraulically actuated swivel, and a running tool mechanically connected to the liner. The method includes rotating the assembly and the liner as one rotationally locked unit and then placing the assembly and liner at a predetermined location near the end of an existing casing in the wellbore. The method also includes activating the hydraulically activated swivel by dropping a hydraulic isolation device from the surface of the wellbore. The method further includes activating the expander tool, expanding the liner into the existing casing, deactivating the expander, and then removing the drill string and running assembly from the wellbore. 
       
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0016]    So that the manner in which the above recited features and advantages of the present invention are attained and can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof which are illustrated in the appended drawings.  
         [0017]    It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.  
         [0018]    [0018]FIGS. 1A and 1B illustrates a cross-sectional view of one embodiment of a hydraulically activated swivel in accordance with the present invention.  
         [0019]    [0019]FIGS. 2A and 2B are a cross-sectional view of the swivel after the sleeve is shifted axially downward to a second position.  
         [0020]    [0020]FIG. 3 is an enlarged cross-sectional view of one embodiment of the swivel as illustrated on FIG. 2B.  
         [0021]    [0021]FIGS. 4A and 4B is a cross-sectional view illustrating the hydraulically activated swivel in compression. 
     
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT  
       [0022]    This invention comprises of a hydraulically activated swivel  100  useful in a running assembly to expand an expandable liner downhole. Generally, the expandable liner is a tubular or tailpipe that is anchored or suspended at the bottom of the previous tubular string. Typically, the expandable liner is anchored or suspended by expanding an upper portion of the expandable liner into frictional contact with a lower portion of the tubular string. The expandable liner may be constructed and arranged to apply to various downhole applications.  
         [0023]    In one application, the expandable liner may be constructed to include an integral packer arrangement to seal and hang the expandable liner from the previous tubular string. In the integral packing arrangement, the body of the expandable liner is modified by machining grooves into the surface. Thereafter, the grooves are typically filled with a pliable material, such as an elastomer, forming a packer, thereby increasing the sealing capability of the expandable liner to the previous tubular string. The integral packer arrangement also includes hardened inserts disposed between the grooves, such as carbide buttons, for gripping the surrounding tubular string upon contact. The gripping mechanism increases the capacity of the expandable liner to support its weight and to serve as a hanger. The expandable liner may also include a non-integral packer arrangement where the packer and the hanger are formed on different portions of expandable liner.  
         [0024]    Additional applications for expandable liners include the use of an expandable sand screen, employment of an expandable seat for seating a diverter tool, and the use of an expandable seat for setting a packer. Therefore, the invention is not limited to expanding a tubular string, but is equally applicable to various downhole applications. Thus, throughout this disclosure, the term “liner” shall refer to various downhole applications.  
         [0025]    [0025]FIGS. 1A and 1B illustrate a cross-sectional view of one embodiment of the hydraulically activated swivel  100  in accordance with the present invention. The swivel  100  is generally disposed between an expander tool  90  and a running tool  80 . The swivel  100  may be attached to the expander tool  90  using a top connection  105 , while a bottom connection  260  may be used to connect running tool  80  to a lower end of the swivel  100 . As illustrated, FIGS. 1A and 1B show the swivel  100  in the run-in position. In this position, the swivel  100  acts a one complete unit. In other words, the expander tool  90 , the swivel  100  and the running tool  80  are rotationally locked with respect to one another, thereby allowing the rotation of the liner (not shown) by the drill string (not shown).  
         [0026]    As shown in FIG. 1A, an upper mandrel  110  of the swivel  100  is connected to the top connection  105  using a thread, and is torsionally locked by at least one upper torque pin  115 . The upper mandrel  110  is tubular body that contains an upper mandrel passageway  112  to direct fluid through the swivel  100 . An upper spline assembly  120  connects the upper mandrel  110  to a housing  125 . As used herein, a spline assembly means a mechanical torque connection between a first and second member. Typically, the first member includes a plurality of keys and the second member includes a plurality of keyways. When rotational torque is applied to the first member, the keys act on the keyways to transmit the torque to the second member. Additionally, the spline assembly may be disengaged by axial movement of one member relative to the other member, thereby permitting rotational freedom of each member. In this respect, a rotational force applied to the upper mandrel  110  will be transmitted through the engaged upper spline assembly  120 , thereby causing the housing  125  to rotate.  
         [0027]    In the embodiment shown on FIG. 1A, biasing members  130  are disposed at the lower end of the upper mandrel  110  to function as a shock absorber between the upper mandrel  110  and a lower mandrel  135 . During operation of the swivel  100 , the biasing members  130  permit the upper mandrel  110  to axially move a predetermined distance. The predetermined distance is illustrated on FIG. 1A as gap  134 . In the preferred embodiment, the biasing members  130  are Bellville washers. However, other forms of biasing members  130  may be employed such as elasterometric material, springs or combinations thereof, so long as they permit substantial axial movement of the upper mandrel  110 .  
         [0028]    As illustrated in FIGS. 1A and 1B, the lower mandrel  135  is tubular body having a lower mandrel passageway  132  through the center of the mandrel  135 . In this respect, the lower mandrel passageway  132  is fluidly connected to the upper mandrel passageway  112 , thereby forming a fluid conduit through the length of this swivel  100 . The lower mandrel  135  further includes an aperture  205  in a wall thereof in fluid communication with the lower mandrel passageway  132 .  
         [0029]    Load members  140  are disposed between the lower mandrel  135  and the housing  125 . The load members  140  permit rotational movement of the housing  125  relative to the lower mandrel  135 . Additionally, the load members  140  are capable of supporting the entire weight of the liner during the expansion operation by the expander tool  90 . In the preferred embodiment, the load members  140  are a plurality of stacked thrust bearings  215 . However, other forms of load members  140  may be employed, so long as they are capable of supporting the weight of the liner and allow rotational movement between the housing  125  and the lower mandrel  135 . Each thrust bearing  145  comprises at least one wire carrier  165 , a lower member  160 , a ball  155 , an upper member  150  and a shoulder member  145 . The wire carrier  165  connects the housing  125  to the lower member  160 . The lower member  160  is rotationally connected to the upper member  150  through the ball  155 . The upper member  150  is connected to the lower mandrel  135  through the shoulder member  145 . In this manner, the housing  125  is rotationally connected to the lower mandrel  135 .  
         [0030]    [0030]FIG. 1B shows a seal spacer  170  and a seal adapter  185  disposed at the lower end of the load members  140 . The upper end of the seal adapter  185  is secured to the housing  125  by a locking pin  175  while the lower end is supported by a lockring  195  disposed around the lower mandrel  135 . Further, a first seal member  270 , such as an o-ring, is disposed at the lower end of the seal adapter  185 , thereby allowing the seal adapter  185  to provide a sealing means between the lower mandrel  135  and the shiftable sleeve  225 .  
         [0031]    [0031]FIG. 1B further depicts a shiftable sleeve  225  in a first position. The sleeve  225  is movable between the first and a second position using hydraulic force. As illustrated, the sleeve  225  is partially disposed between the housing  125 , the lower mandrel  135  and the bottom connection  260 . At least one shearable connection  180  connects the sleeve  225  to the housing  125 . In one embodiment, the shearable connection  180  is a shear pin. However, other forms of shearable connections may be employed, so long as they are capable of failing at a predetermined force, thereby allowing the sleeve  225  to move axially downward relative to the housing  125 . In addition to the shearable connection  180 , a middle spline assembly  190  also mechanically connects the sleeve  225  to the housing  125 . In FIG. 1B, the middle spline assembly  190  is fully engaged, thereby capable of transmitting the full rotational force from the housing  125  to the sleeve  225 . Further, a first sleeve shoulder  275  is formed on the inner portion of the sleeve  225 . The first sleeve shoulder  275  is located near the aperture  205  in the lower mandrel  135  and later provides a hydraulic area to shift the sleeve  225  axially downward. A second sleeve shoulder  220  is also formed at the lower portion of the sleeve  225 . The second sleeve shoulder  220  is used as a stop to limit the downward axial movement of the sleeve  225 . A second sealing member  210 , such as an o-ring, is disposed between the sleeve  225  and the lower mandrel  135 . In this respect, both the first and second sealing members  210 ,  270  act as a fluid tight seal as the sleeve  225  is hydraulically urged downward.  
         [0032]    As further shown on FIG. 1B, the lower end of the sleeve  225  is mechanically connected to the bottom connection  260  by a lower spline assembly  240 . While the sleeve  225  is in the first position, the lower spline assembly  240  is capable of transmitting the rotational force from the sleeve  225  to the bottom connection  260 . Below the lower spline assembly  240 , a spline assembly relief  245  is formed to house a portion of the lower spline assembly  240  after the sleeve  225  has shifted to the second position. Also illustrated in FIG. 1B, a spring clip  265  is disposed on the outer portion of the sleeve  225 . The spring clip  265  is used to mate with at least one relief groove  250  formed on an outer portion of the bottom connection  260  after the sleeve  225  is moved to the second position.  
         [0033]    [0033]FIG. 1B further depicts the bottom connection  260  at the lower end of the swivel  100 . The primary function of the bottom connection  260  is to act as a connection means between the swivel  100  and the running tool  80 . The bottom connection  260  is secured to the lower mandrel  135  by a thread, and is torsionally locked by at least one lower torque pin  255 . An upper portion of the bottom connection  260  is partially disposed between the sleeve  225  and the lower mandrel  135 . As shown, a plurality of washers  280  are disposed on an upper end of the bottom connection  260  to reduce friction between the bottom connection  260  and the sleeve  225  after the sleeve  225  is moved to the second position.  
         [0034]    [0034]FIGS. 1A and 1B illustrate the swivel  100  in the run-in position. In this position, the swivel  100  acts as one complete unit. In other words, the expander tool  90 , the swivel  100  and the running tool  80  are rotationally locked with respect to one another, thereby allowing the rotation of the liner by the drill string. In this respect, a rotational force applied from the drill string to the expander tool  90  may be transmitted to the top connection  105 . In turn, the top connection  105  transmits the rotational force through the upper torque pin  115  to the upper mandrel  110 . The upper mandrel  110  transmits the rotational force through the upper spline assembly  120  to the housing  125 . The housing  125  transmits the rotational force through the middle spline assembly  190  to the sleeve  225 . The sleeve  225  transmits the rotational force through the lower spline assembly  240  to the bottom connection  260 . The bottom connection  260  transmits the rotational force to the running tool  80  that is holding the liner. In this manner, the swivel  100  acts as a conduit for rotational force from the drill string to the liner.  
         [0035]    [0035]FIGS. 2A and 2B are a cross-sectional view of the swivel  100  after the sleeve  225  is shifted axially to the second position. The axial movement of the sleeve  225  may be accomplished using a hydraulic isolation device (not shown), such as a ball or a dart, that is circulated down into a seat (not shown) below the running tool  80 . Dropping the ball onto the seat allows fluid pressure to build up in the running tool  80  and the lower mandrel passageway  132  until the fluid level reaches aperture  205 . At that point, pressurized fluid enters aperture  205  creating hydraulic force that acts against the first sleeve shoulder  275  of the sleeve  225 . At a predetermined hydraulic force, the shearable connection  180  fails and the sleeve  225  is urged axially downward toward the second position. The sleeve  225  reaches the second position when the second sleeve shoulder  220  contacts the plurality of washers  280  disposed on the bottom connection  260 . The movement of the sleeve  225  from the first to the second position also disengages the spline assembly  245 , thereby removing the mechanical connection between the sleeve  225  and the bottom connection  260 . Thereafter, the upper portion that includes connection  105 , upper mandrel  110 , housing  125 , and sleeve  225 , is rotationally separate from the lower portion that includes mandrel  135  and connection  260 . In other words, the swivel  100  is capable of exclusively rotating the upper portion in a first direction while allowing the bottom portion to remain stationary.  
         [0036]    On the other hand, the swivel  100  may rotate as a rotationally locked unit in a second direction. The movement of the sleeve  225  to the second position aligns the spring clip  265  on the sleeve  225  with the relief groove  250  formed on an outer portion of the bottom connection  260 . The spring clip  265  is constructed and arranged to mate with the relief groove  250  when the upper portion of the swivel  100  rotates in the second direction. In this respect, the spring clip  265  acts upon the relief groove  250  causing the lower portion to rotate with the upper portion of the swivel  100 . Conversely, the spring clip  265  will not mate with the relief groove  250  when the upper portion of the swivel  100  rotates in the first direction, thereby allowing the upper portion to rotate freely in respect to the lower portion. In this manner, the spring clip  265  and the relief groove  250  act as a clutch system allowing the rotation of the upper and lower portion as a rotationally locked unit in the second direction while permitting the upper portion to rotate free of the lower portion in the first direction.  
         [0037]    [0037]FIG. 3 is an enlarged cross-sectional view of the swivel  100  as illustrated in FIG. 2B. In this view, the sleeve  225  is in the second position in contact with the plurality of washers  280 . Further, the middle spline assembly  190  is partially engaged, thereby permitting transfer of rotational force between the housing  125  and the sleeve  225 . However, the lower spline assembly  240  is completely disengaged. The portion of the spline assembly  240  attached to the bottom connection  260  did not move while the portion of spline assembly  240  attached to the sleeve  225  moved axially downward into the spline assembly relief  245 . Therefore, the lower portion of the swivel  100  is no longer mechanically connected to the upper portion through the spline assembly  240 . As further illustrated, the spring clip  265  is in line with the clip groove  250 . While the swivel  100  in the preferred embodiment uses the sleeve  225  and spline assemblies  120 ,  190 ,  240  to connect the upper and lower mandrel  110 ,  135 , it would be understood by one skilled in the art that a variety of different methods may be employed, which allow the swivel  100  to function in the manner described in previous paragraphs.  
         [0038]    [0038]FIGS. 4A and 4B are a cross-sectional view illustrating the hydraulically activated swivel  100  in compression. The swivel  100  may need to compress during the expansion operation of the liner to permit the running tool  80  to operate properly. This present invention includes a function that allows the swivel  100  to compress a predetermined distance, thereby protecting components in the running tool  80  from impact loading during operation. In other words, the lower mandrel  135  and the bottom connection  260  move axially upward closing off the gap  134 , thereby compressing the biasing members  130  between the lower mandrel  135  and the upper mandrel  110 . In this manner, the swivel  100  permits the running tool  80  to function properly.  
         [0039]    In operation, the liner (not shown), expander tool  90 , swivel  100  and the running tool  80  are run-in the wellbore on a drill string (not shown). The swivel  100  is in the run-in position as illustrated in FIGS. 1A and 1B. If any obstruction is encountered during the run-in operation, the liner is “drilled” into the wellbore by applying a rotational force from the drill string to the liner through the expander tool  90 , swivel  100  and running tool  80 . In this respect, the swivel  100  acts as a complete unit as discussed in FIGS. 1A and 1B.  
         [0040]    The liner is run-in to a predetermined point near the end of an existing casing string (not shown). Subsequently, fluid is pumped from the surface of the wellbore down the drill string through the expander tool  90  and the upper and lower mandrel passageways  112 ,  132  to the running tool  80 . Thereafter, a hydraulic isolation device (not shown) is circulated down into a seat (not shown) below the running tool  80 . The fluid pressure builds up in the running tool  80  and the lower mandrel passageway  132  until the fluid level reaches aperture  205 . As pressurized fluid enters aperture  205 , a hydraulic force is created acting against the first sleeve shoulder  275  on the sleeve  225 . At a predetermined hydraulic force, the shearable connection  180  fails and the sleeve  225  is urged axially downward toward the second position, thereby contacting the plurality of washers  280  disposed on the bottom connection  260 .  
         [0041]    The movement of the sleeve  225  from the first to the second position disengages spline assembly  240 , thereby removing the mechanical connection between the sleeve  225  and the bottom connection  260 . Thereafter, the upper portion that includes connection  105 , upper mandrel  110 , housing  125 , and sleeve  225  is rotationally separate from the lower portion that includes mandrel  135  and connection  260 . In other words, the swivel  100  is capable of exclusively rotating the upper portion in a first direction while allowing the bottom portion to remain stationary. Subsequently, the expander tool  90  is activated and the expansion operation begins. A rotational force by the drill string in the first direction causes the expander tool  90  and the upper portion of the swivel  100  to rotate while the lower portion and the running tool  80  remain stationary. During the expansion operation, the load members  140  carry the entire weight of the liner and permit a rotational connection between the housing  125  and the lower mandrel  135 .  
         [0042]    Additionally, the movement of the sleeve  225  to the second position aligns the spring clip  265  on the sleeve  225  with the relief groove  250  formed on an outer portion of the bottom connection  260 . The spring clip  265  is constructed and arranged to mate and act upon the relief groove  250  when the upper portion of the swivel  100  rotates in the second direction but not in the first direction. In this manner, the spring clip  265  and the relief groove  250  act-as a clutch system allowing the rotation of the upper and lower portion as a rotationally locked unit in the second direction while permitting the upper portion to rotate free of the lower portion in the first direction.  
         [0043]    After the expansion operation is complete, the running tool  80  is deactivated, thereby allowing the liner to hang exclusively from the casing string. The running tool  80  is released from the liner through hydraulic means. In the event of a hydraulic failure, the running tool  80  may be released by mechanical means by rotating the swivel  100  in the second direction. In this respect, a rotational force from the drill string is transmitted in the second direction through the expander tool  90  to the top connection  105  of the swivel  100 . The top connection  105  transmits the rotational force through the upper torque pin  115  to the upper mandrel  110 . The upper mandrel  110  transmits the rotational force through the upper spline assembly  120  to the housing  125 . The housing  125  transmits the rotational force through the middle spline assembly  190  to the sleeve  225 . The sleeve  225  transmits the rotational force to the bottom connection  260  by allowing the spring clip  265  to contact and act against the clip groove  250 , thereby causing the bottom connection  260  to rotate in the second direction. The bottom connection  260  transmits the rotational force in the second direction to the running tool  80 , thereby releasing the running tool from the liner.  
         [0044]    While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.

Technology Category: 0