Patent Publication Number: US-8522885-B2

Title: System and methods for tubular expansion

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application is a divisional of U.S. patent application Ser. No. 11/962,290, filed Dec. 21, 2007, now U.S. Pat. No. 8,069,916, which claims benefit of U.S. Provisional Patent Application Ser. No. 60/883,254, filed Jan. 3, 2007, and each application is herein incorporated by reference in its entirety. 
    
    
     BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     Embodiments of the invention generally relate to tubing expansion. 
     2. Description of the Related Art 
     Methods and apparatus utilized in the oil and gas industry enable placing tubular strings in a borehole and then expanding the circumference of the strings in order increase a fluid path through the tubing and in some cases to line the walls of the borehole. Some of the advantages of expanding tubing in a borehole include relative ease and lower expense of handling smaller diameter tubing and ability to mitigate or eliminate formation of a restriction caused by the tubing thereby enabling techniques that may create a monobore well. Many examples of downhole expansion of tubing exist including patents, such as U.S. Pat. No. 6,457,532, owned by the assignee of the present invention. 
     However, prior expansion techniques may not be possible or desirable in some applications. Further, issues that present problems with some of these approaches may include ease of makeup at the drill rig floor and operation, ability to transmit torque across an expander tool, and capability to recover a stuck expander tool or insert the tool through restrictions smaller than an expansion diameter. Carrying the expander tool in with unexpanded tubing and fixing the tubing relative to the expander tool can create additional challenges for some applications. 
     Therefore, there exists a need for improved methods and apparatus for expanding tubing. 
     SUMMARY OF THE INVENTION 
     A system for expanding tubing in one embodiment includes an expander disposed on a work string and having a first extended configuration capable of expanding the tubing and a second collapsed configuration with a smaller outer diameter than the first extended configuration. The system further includes first and second tubing holding devices disposed on the work string and located respectively ahead of the expander and behind the expander. Additionally, a hydraulic operated jack couples to the expander to move the expander relative to the tubing holding devices. 
     For one embodiment, a method of expanding tubing includes securing an expansion tool to the tubing, wherein the expansion tool includes an expander, a jack, and first and second tubing holding devices. The method further includes actuating the expander of the expansion tool to a first extended configuration from a second collapsed configuration having a smaller outer diameter than the first extended configuration. Supplying fluid pressure to the jack coupled to the expander thereby moves the expander through the tubing which is held by at least one of the first and second tubing holding devices disposed respectively ahead of the expander and behind the expander. 
     A method of expanding tubing in one embodiment includes providing an assembly with an expansion tool, the tubing, and a boring tool, wherein the expansion tool includes an expander, a jack, and first and second tubing holding devices. The method further includes running the assembly in a borehole, forming a borehole extension with the boring tool, and disposing the tubing at least partially within the borehole extension. In addition, supplying fluid pressure to the jack coupled to the expander thereby expands the tubing as the expander moves through the tubing which is held by at least one of the first and second tubing holding devices disposed respectively ahead of the expander and behind the expander. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       So that the manner in which the above recited features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. 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. 
         FIGS. 1A to 1G  are a cross-section view of an expander tool in a deactivated configuration, according to embodiments of the invention. 
         FIG. 2  is a partial cross-section view of a portion of the expander tool after actuation of a collapsible swage held by a latch section shown enlarged in  FIG. 2A . 
         FIG. 3  is a partial cross-section and exploded view of a connection shown in  FIG. 1A  exemplary of component connections within the expander tool. 
         FIG. 4  is a schematic view of the expander tool disposed in tubing to be expanded and coupled to a work string. 
         FIG. 5  is a schematic view of the expander tool disposed in the tubing with the collapsible swage and first and second slips actuated such that the first slips grip the tubing. 
         FIG. 6  is a schematic view of the expander tool upon actuation of a hydraulic jack to stroke the swage through the tubing toward the first slips. 
         FIG. 7  is a schematic view of the expander tool after resetting the jack and reactivating the slips such that the second slips grip the tubing in order to expand more or all of the tubing via this cycling of the tool. 
         FIG. 8  is a schematic view of an assembly with an optional drillbit/underreamer coupled to an expander device similar to the tool shown in  FIGS. 1A to 1G  with the first slips replaced with a liner stop holding down a surrounding tubing to be expanded. 
         FIG. 9  is a schematic view of another expander device also similar to the tool shown in  FIGS. 1A to 1G  but incorporating a latching mechanism to couple the device to tubing to be expanded instead of a threaded relationship. 
         FIGS. 10 and 11  illustrate an alternative swage for the expander tool, according to embodiments of the invention. 
     
    
    
     DETAILED DESCRIPTION 
     Embodiments of the invention generally relate to methods and assemblies suitable for expanding tubing in a borehole of a hydrocarbon well. According to some embodiments, an expander device includes a collapsible swage formed of collets, at least one slip arrangement and a hydraulic jack to stroke the swage through tubing to be expanded. The tubing may be any type of tubular member or pipe such as casing, liner, screen or open-hole clad. As an example of an application that may utilize embodiments of the invention, U.S. Provisional Patent Application No. 60/829,374, which is herein incorporated by reference, illustrates procedures where an open-hole clad is expanded in-situ in order to form a monobore well. 
       FIGS. 1A to 1G  illustrate a cross-section view of an expander tool  400  (illustrated in its entirety schematically in  FIG. 4 ) in a deactivated configuration. The expander tool  400  includes a pickup sub  102  and a first slip assembly  104  both shown in  FIG. 1A , a tell tail assembly  106  shown in  FIG. 1B , one or more jacks  108  shown in  FIGS. 1B through 1E , an externally threaded, tool-to-unexpanded tubing, coupler sub  110  shown in  FIG. 1F , and a collapsible expander or swage  112  and a second slip assembly  114  shown in  FIG. 1G . These and other components of the expander tool  400  enable easy reconfiguration or replacement of one or more module components such as described further herein. For example, the pickup sub  102  may be interchanged to switch from one drill pipe or work string thread to another depending on a work string  404  (shown in  FIG. 4 ) employed to convey the tool  400  into a borehole. 
     Coupling of the pickup sub  102  to the first slip assembly  104  may utilize a connection arrangement, identified by area  3  and shown in an exploded view in  FIG. 3 , exemplary of similar recurring connections within the expander tool  400 , as visible throughout  FIGS. 1A to 1G . This connection arrangement facilitates building of the tool  400  without requiring making of connections to a torque that enables holding both tensile and rotational loads in operation. Further, the connection permits torque transmission across the tool  400  in either rotational direction, which may be possible with the work string  404  that is wrenched together during makeup of the work string  404 . 
     Referring to  FIG. 3 , a nut  300  surrounding the pickup sub  102  includes external threads  301  that mate with internal threads  302  of a slip mandrel  116  of the slip assembly  104 . Engagement between the threads  301 ,  302  takes tensile loads between the pickup sub  102  and the slip mandrel  116  by trapping a split ring  304  disposed in a groove  305  around the pickup sub  102  against a shoulder  306  along an inside of the slip mandrel  116 . Castellated dogs  307  on an outer surface of the pickup sub  102  engage mating castellated dogs  308  around the inside of the slip mandrel  116 . Rotational torque across the pickup sub  102  and the slip mandrel  116  received by the dogs  307 ,  308  thereby prevents imparting rotation to the threads  301 ,  302 . 
     With reference to  FIGS. 1A and 4 , the first slip assembly  104  includes a plurality of first wedges  118  with teeth  120  that may be oriented in one direction toward the swage  112 . This orientation provides unidirectional gripping of a surrounding tubing  402  (shown in  FIG. 4 ) to be expanded. To actuate the first slip assembly  104 , fluid pressure supplied by the work string  404  to inside of the tool  400  passes through first slip port  122  in the slip mandrel  116  and acts on first slip piston  124  to move the first wedges  118  up a ramped portion of the slip mandrel  116 . An actuated outer gripping diameter of the first slip assembly  104  corresponds to an inside diameter of the tubing  402  prior to expansion such that the teeth  120  engage the inside surface of the tubing  402 . In operation, the tubing  402  may slide past the first slip assembly  104  toward the swage  112  to accommodate shrinkage of the tubing  402  during expansion, but is restrained by the first slip assembly  104  against moving with the swage  112 . In the absence of actuating fluid pressure in the tool  400 , first slip spring  126  returns the first slip assembly  104  to a deactivated position, as shown. 
     In some embodiments, a tell tail assembly may be included. For example, referring to  FIG. 1B , the tell tail assembly  106  includes a sliding sleeve  128  acted on by a closing spring  130  and defining a pressure relief port  132  that is misaligned with a pressure relief passage  134  to inside of the tool  400  when the sliding sleeve  128  is normally biased by the spring  130 . Upon full stroke of the jacks  108  during operation of the tool  400 , a head member  142  of the jacks  108  contacts the sleeve  128  and pushes the sleeve  128  against the bias of the spring  130  to align the pressure relief port  132  of the sliding sleeve  128  with the pressure relief passage  134  to inside of the tool  400 . This subsequent relief in pressure signals to an operator that the jacks  108  have completed a full stroke in order for the operator to reset the jacks  108  and commence expansion. 
     The tool  400 , as illustrated, includes release features described further herein that enable the operator to collapse the swage  112 , e.g., in an emergency or stuck situation, thereby permitting withdrawal of the swage  112  through, for example, unexpanded portions of the tubing  402 . These features may require applying overpressure to the tool  400  while the pressure relief port  132  of the sliding sleeve  128  and the pressure relief passage  134  are aligned. Therefore, a tell tail closing sleeve  136  disposed inside the tell tail assembly  106  operates to enable blocking the pressure relief passage  134  to the inside of the tool  400 . A shear pin  140  maintains the closing sleeve  136  above the pressure relief passage  134  until a collapse ball is dropped onto a closing sleeve seat  138  of the closing sleeve  136  such that fluid pressure above the ball shears the pin  140  and forces the sleeve  136  to move to a position that blocks the pressure relief passage  134 . Additional fluid pressure above the ball forces the ball through the seat  138  to enable pressurizing further sections of the tool  400 . 
     The jacks  108  create relative movement between an inner string  158  and an outer housing  160 . This relative movement strokes the swage  112  that is coupled for movement with the outer housing  160  through the tubing  402  since one or both of the slip assemblies  104 ,  114  fix the inner string  158  with respect to the tubing  402 . A first jack input port  144  supplies fluid to one of the jacks  108  and creates at least part of a driving fluid pressure that urges the head member  142  of the outer housing  160  toward the tell tail assembly  106 . 
     The jacks  108  may include multiple jacks (three shown) connected in series to increase operating force provided by the jacks  108  that stroke the swage  112  through the tubing  402 . For some embodiments, one full stroke of the jacks  108  translates the swage  112  twelve feet, for example, such that the jacks  108  that are longitudinally connected must occupy a sufficient length of the tool  400  to produce this translation. While the jacks  108  thereby generate sufficient force and still have a diameter that remains smaller than the diameter of the borehole, connecting the jacks  108  in series may make the tool  400  too long for feasible transport and handling as one piece requiring final assembly at the well. 
     Therefore,  FIG. 1C  illustrates a first spear coupling arrangement  146  suitable for connecting the jacks  108  together at the rig floor using, for example, C-plates rather than a false rotary. For some embodiments, the spear coupling arrangement  146  may be connected downhole and/or be hydraulically operated. The first spear coupling arrangement  146  locks together longitudinal lengths of the inner string  158  of the jacks  108  and the outer housing  160  of the jacks  108  due to the engagements created by inner and outer collets  148 ,  150 , respectively. 
     During stabbing of two sections of the jacks  108  together, a subsequent connecting inner portion  162  of the jacks  108  contacts the inner collets  148  and moves the inner collets  148  to an unsupported state against normal bias to a supported position. In addition, a subsequent connecting outer portion  164  of the jacks  108  contacts the outer collets  150  and moves the outer collets  150  to an unsupported state against normal bias to a supported position. The inner and outer collets  148 ,  150  then click into position and return back to respective supported positions, thereby securing the two sections of the jacks  108  together. A keyed engagement  166  enables transmission of torque through the inner string  158  at the first spear coupling arrangement  146 . 
     The outer collets  150  may couple to an externally threaded placement holding sub  152  to facilitate moving the outer collets  150  relative to the inner collets  148 . A segmented and internally threaded ring  154  mates by threaded engagement with the holding sub  152 , while a cover  156  holds the threaded ring  154  together around the holding sub  152 . Rotation of the threaded ring  154  relative to the holding sub  152  translates the holding sub  152  and hence the outer collets  150  axially. In a retracted position of the holding sub  152 , the inner collets  148  may lock first during assembly followed by locking of the outer collets  150  upon extending the holding sub  152  to an extended position, as shown. This sequential locking feature therefore facilitates makeup and disassembly of the jacks  108  in a sealed manner. 
     Referring to  FIG. 1D , a first exhaust port  168  of the jacks  108  functions to relieve pressure to outside of the tool  400  so as to not oppose the movement in response to fluid pressure supplied through the first jack input port  144 . Second and third jack input ports  170 ,  172  supply fluid to additional ones of the jacks  108  to boost the force that moves the outer housing  160  relative to the inner string  158 . Second and third exhaust ports  174 ,  176  (shown in  FIG. 1F ) disposed on opposite operational piston sides relative to the second and third jack input ports  170 ,  172 , respectively, ensure that this movement occurs unopposed. 
     With reference to  FIG. 1E , a second spear coupling arrangement  178  may connect further sections of the jacks  108  together. The first and second spear coupling arrangements  146 ,  178  may be identical such that there may not be any differences between  FIGS. 1C and 1E  for some embodiments. However, an alternative configuration exemplarily depicted by way of the second spear coupling arrangement  178  shows an externally circular grooved placement holding sub  182  instead of the externally threaded placement holding sub  152  in the first spear coupling arrangement  146 . While both placement holding subs  152 ,  182  are movable for the same purpose between extended and retracted positions, axial movement of the grooved placement holding sub  182  occurs by manual axial manipulation, which may be facilitated by engagement of the grooved placement holding sub  182  with a C-plate. To maintain the grooved placement holding sub  182  in either the extended or retracted position, threaded pins engage axially spaced sets of circular grooves  184  corresponding to each position. In operation, the operator backs the pins  180  out to a lock-ring stop (not visible) and then positions the grooved placement holding sub  182  in either the extended position or retracted position prior to advancing the pins  180  back into corresponding ones of the grooves  184  to hold the grooved placement holding sub  182  axially. The second spear coupling arrangement  178  otherwise operates and functions like the first spear coupling arrangement  146  described herein. 
     Referring to  FIG. 1F , the externally threaded, tool-to-unexpanded tubing, coupler sub  110  couples to the outer housing  160  to move relative to the inner string  158  upon actuation of the jacks  108 . For some embodiments, the coupler sub  110  may be omitted, such as when the tubing  402  is already disposed in the borehole prior to lowering the tool  400 . Further, the coupler sub  110  may employ, in some embodiments, various other types of connections than threads. Threaded engagement between the coupler sub  110  and an end of the tubing  402  supports the tool  400  within the tubing  402  during makeup of the tubing  402  and/or suspends the tubing  402  around the tool  402  while deploying the work string  404  into the borehole. A relative hard material with respect to the tubing  402  may form the coupler sub  110  such that the coupler sub  110  expands/deforms the tubing  402  at the threaded engagement to release the tubing  402  from the coupler sub  110  upon initiating the expansion process with the jacks  108  after gripping the tubing  402  with the first slip assembly  104 . 
     Aspects shown related to the swage  112  and actuation of the swage  112  extend across  FIGS. 1F and 1G  and include a swage piston  188  coupled to swage collets  190 , which ride up and are propped up by extended collets support surface  191 . In operation, a swage input port  186  directs pressurized fluid inside the inner string  158  to the swage piston  188  coupled to the swage  112 . The pressurized fluid overcomes urging of an expander tool spring  192  maintaining the swage collets  190  in a retracted position. A swage shroud  193  may cover at least part of the swage collets  190  while in the retracted position and aid in holding the swage collets  190  in a radial inward direction. 
     The end of the tool shown in  FIG. 1G  further includes the second slip assembly  114  and a tool bore closing element such as a ball seat  194  for sealing off the interior of the inner string  158  once an actuation ball (not shown) is dropped and landed in the seat  194 . The second slip assembly  114  includes a plurality of second wedges  195  urged toward a deactivated position in the absence of an actuating fluid pressure supplied through the second slip port  196 . An actuated outer gripping diameter of the second slip assembly  114  corresponds to an inside diameter of the tubing  402  after expansion such that the second wedges  195  grip the inside surface of the tubing  402  at locations along the tubing  402  where the swage  112  has already been stroked through the tubing  402 . 
     In operation, the ball seat  190  receives the actuation ball having a smaller diameter than the closing sleeve seat  138  such that the actuation ball passes straight through the tell tail closing sleeve  136 . Closing off flow through the tool  400  enables fluid flowing through the work string  404  to pressurize the tool  400  including the first slip port  122 , the jack ports  144 ,  170 ,  172 , the swage input port  186 , and the second slip port  196 . The slip assemblies  104 ,  114  activate with the swage  112  prior to the jacks  108  initiating relative movement between the inner string  158  and the outer housing  160  due to jacking delay shear pin  197  that temporarily prevents this relative movement until an identified fluid pressure is reached above the pressure required to extend the swage  112 . 
       FIG. 2  shows a portion of the expander tool  400  after actuation of the collapsible swage  112 . During actuation, fluid pressure forces the piston  188  to move against the bias of the expander tool spring  192  thereby positioning the collets  190  against the extended collets support surface  191 . A latching configuration may retain the swage  112  in the extended position with the spring  192  compressed even after relieving fluid pressure applied to the piston  188 . For some embodiments, a snap ring  200  (see the enlarged view in  FIG. 2A ) disposed around an outside of the piston  188  and an inward protruding shear pinned ring  202  temporarily pinned at a fixed position along a traveling path of the piston  188  define this latching configuration. A sloped leading edge of the snap ring  200  enables the snap ring  200  to pass across the shear pinned ring  202  during actuation of the swage  112  while a retaining back edge of the snap ring  200  engages the shear pinned ring  202  and prevents the spring  192  from urging the piston  188  back. 
     As illustrated in  FIGS. 1G and 2 , the release features for the swage  112  provide the ability to release the swage  112  from the extended position thereby causing the spring  192  to act on the piston  188  and pull back in the collets  190 , such as depicted in  FIG. 1G . While the swage  112  may collapse to have an outer diameter smaller than an inner diameter of the tubing  402  prior to expansion of the tubing  402 , the outer diameter of the swage  112  when collapsed may, for some embodiments, remain larger than the inner diameter of the tubing  402  prior to expansion of the tubing  402 . Applying an identified overpressure to the tool  400  provides sufficient force via the piston  188  and the collets  190  coupled to the piston  188  to cause an outward facing shoulder of the piston  188  to bears on the shear pinned ring  202  until broken free or released to permit movement of the ring  202  with the piston  188 . As a result of the shear pinned ring  202  being released and making the snap ring  200  thus unfixed, the spring  192  may function to retract the swage  112  once pressure is relieved from the tool  400 . 
     The overpressure may further subsequently shift an overpressure sleeve  199  that provides the ball seat  194 . Drain opening shear pins  185  hold the overpressure sleeve  199  blocking an overpressure drain  198  during normal operation of the tool  400 . After the overpressure causes retraction of the swage  112 , the shear pins  185  fail permitting the overpressure sleeve  199  to move and open the overpressure drain  198  such that a wet string does not have to be pulled out of the well since fluid exits from the tool  400  and the work string  404  through the overpressure drain  198 . 
     A relatively larger redundant ball seat  189 , disposed above the overpressure drain  198  may be utilized should the overpressure sleeve  199  shift prior to retraction of the swage  112 . The redundant ball seat  189  therefore enables an even greater overpressure to be applied for causing hydraulic based retraction of the swage  112  as described heretofore. A third redundant option for retracting the swage  112 , if stuck, involves mechanical pulling of the tool  400  using forces (e.g., 90,700 kilograms) exceeding those required for expanding the tubing  402 . This pulling of the inner string  158  while the swage  112  is stuck causes the swage release shear pins  187  to fail and hence loading beyond holding capacity of the shear pinned ring  202  resulting in release of the piston  188 , as occurs with the hydraulic based retraction options. The spring  192  may then function to retract the swage  112 . 
       FIG. 4  illustrates the expander tool  400  disposed in the tubing  402  to be expanded and coupled to the work string  404 . The externally threaded, tool-to-unexpanded tubing, coupler sub  110  of the tool  400  supports the tubing  402  around the tool  400  by mating threaded engagement at the end of the tubing  402 . The run-in configuration as shown in  FIG. 4  includes the slips  104 ,  114 , the swage  112 , and the jacks  108  all as initially assembled prior to pressurizing the tool  400 . 
       FIG. 5  shows the expander tool  400  disposed in the tubing  402  with the collapsible swage  112  and first and second slip assemblies  104 ,  114  actuated such that the first slip assembly  104  grips the tubing  402 . As described herein, dropping the actuation ball and supplying fluid through the work string  404  may achieve pressurization of the tool  400  for this actuation. The second slip assembly  114 , while actuated, may fail to grip or extend into engaging contact with any surrounding surfaces, such as an open borehole wall. 
       FIG. 6  illustrates the expander tool  400  upon actuation of the jacks  108  to stroke the swage  112  through the tubing  402  toward the first slip assembly  104 . The coupler sub  110  of the tool  400  disengages from the tubing  402  at the beginning of the initial stroke of the jacks  108  by, for example, initiating expansion of the tubing  402  at least at the engagement of the tubing  402  with the coupler sub  110 . The swage  112  may expand a circumference of the tubing  402  as the swage  112  passes through the tubing  402 . At the end of the stroke of the jacks  108 , the operator releases pressure in the tool  400  to deactivate the first slips  104 , which may be locked out from reactivation in some embodiments. The swage  112  stays positioned in the tubing  402  where expansion stopped since the swage  112  remains latched in the extended position even without the tool  400  being pressurized. Next, the operator pulls on the work string  404  to reset the jacks  108  and position the second set of slips  114  in the tubing  402 . 
     As shown in  FIG. 7 , pressurization of the tool  400  activates the second slip assembly  114  to grip the tubing  402  at a location that the swage  112  previously expanded. The pressurization also operates the jacks  108  to move the swage  112  through the tubing  402 . Cycling of the tool  400  by resetting the jacks  108  after every pressurization of the tool  400  to reset the second slip assembly  114  and stroke the jacks  108  enables expanding more or all of the tubing  402 . 
       FIG. 8  illustrates an assembly  800  with an optional drillbit/underreamer  801  coupled to an expander device  840  similar to the tool  400  shown in  FIGS. 1A to 1G . Any embodiment described herein may incorporate earth removal members such as the drillbit/underreamer  801  to permit one trip drilling/underreaming and locating and expanding tubing. While not shown, such drilling assemblies may further include, for example, a mud motor, a logging while drilling (LWD) device, a measurement-while-drilling (MWD) device, and/or a rotary steerable system. Furthermore, the drilling assemblies may be deployed on conveyance members such as drill pipe or coiled tubing. Ability to transmit torque across the tool  800  facilitates these one trip operations. 
     The method of one trip drilling/underreaming and locating and expanding tubing may involve rotating and axially moving a work string  804  to advance the drillbit/underreamer  801  through a formation, such as below a previously cased portion of a well. The drillbit/underreamer  801  may form separate tools or one integrated component that drills identified diameter boreholes. For example, drilling may form a borehole of a first diameter. Underreaming of the borehole may create a section with a second diameter larger than the first diameter and in which a surrounding tubing  802  is to be expanded to have, for example, an inner diameter substantially matching the first diameter of the borehole. Positioning of the tubing  802  at the section with the second diameter and then expanding the tubing  802  based on the description herein may occur after the drilling and/or underreaming. Previously incorporated U.S. Provisional Patent Application No. 60/829,374, describes such methods that enable forming a monobore well. 
     Instead of the first slip assembly  104  shown in  FIG. 4 , a liner stop  805  holds down the tubing  802  to be expanded during an initial stroke of a swage  812  through the tubing  802 . Like the drillbit/underreamer  801  that may be utilized with any embodiment described, the liner stop  805  may replace the first slips of any embodiment herein whenever practical depending on the length of the tubing  802 . A filler pipe  803  spans from an end of the device  840  to an end of the tubing  802  opposite the swage  812 . The liner stop  805  couples between the work string  804  and the filler pipe  803 . 
     For some embodiments, an internally threaded interference ring  807  of the liner stop  805  threads around an externally threaded locking sub  809  of the liner stop  805 . In operation, the interference ring  807  is rotated with respect to the locking sub  809  to translate the interference ring  807  into abutting contact with the end of the tubing  802  once the device  840  is coupled to the tubing  802 . Pins  811  inserted through walls of the interference ring  807  and into corresponding external longitudinal slots  813  along the locking sub  809  may prevent further relative rotation between the interference ring  807  and the locking sub  809  and maintain the interference ring  807  in contact with the tubing  802  at least until expansion initiates at which time the tubing  802  is prevented from moving away from or with the swage  812  but may shrink and move away from the interference ring  807 . Otherwise, and after the first stroke, the device  840  may operate and function like the tool  400  described herein. 
       FIG. 9  shows another expander device  940  also similar to the tool  400  shown in  FIGS. 1A to 1G  but incorporating a latching mechanism  910  to couple the device to tubing  902  to be expanded instead of a threaded relationship. The latching mechanism  910  permits the device  940  to be run through the tubing  902  while the tubing  902  is disposed in the borehole, e.g., while suspended from the well surface, and latched into the tubing  902 . Once latched into the tubing  902 , the tubing  902  may be released from being suspended and run-in the borehole with the device  940  to an identified location using the work string  904 . For some embodiments, the latching mechanism  910  includes dogs  911  that are frangible upon actuation of the device  940  as described herein. The dogs  911  may retract in some embodiments upon actuation of a first slip assembly  903  and swage  912 . Patent application publication U.S. 2004/0216892 A1, which is herein incorporated by reference, discloses an exemplary suitable latch for use as the latching mechanism  910 . 
     As exemplarily depicted in the illustrations and their orientation, expanding of the tubing progresses from a bottom of the tubing to its top. However, tubing expansion according to the invention may take place either bottom-up or top-down depending on application and configuration of the tool. In addition, a solid expander (e.g., a fixed diameter cone) or any compliant or collapsible swage may replace segmented, collet-type swages identified in the preceding description and shown by way of example in the figures. 
     In one embodiment, the swage piston  188 , for example and with reference to  FIG. 1F , may operatively couple to a two-position expander  512  that is shown in  FIG. 10  prior to radially extending cone segments  525 ,  575 . As such, the two-position expander  512  illustrates another type of the swage  112  for use in the expander tool  400  depicted in  FIG. 4 . U.S. Pat. No. 7,121,351, which is incorporated herein in its entirety, describes the two-position expander  512  and its operation. 
     Generally, the two-position expander  512  comprises a first assembly  500  and a second assembly  550 . The first assembly  500  includes a first end plate  505  and the plurality of cone segments  525 . The first end plate  505  is a substantially round member with a plurality of “T”-shaped grooves  515  formed therein. Each groove  515  matches a “T”-shaped profile  530  formed at an end of each cone segment  525 . It should be understood, however, that the groove  515  and the profile  530  are not limited to the “T”-shaped arrangement illustrated in  FIG. 10  but may be formed in any shape without departing from principles of the present invention. 
     Each cone segment  525  has an outer surface that includes a first taper  540  adjacent to the shaped profile  530 . As shown, the first taper  540  has a gradual slope to form the leading shaped profile of the two-position expander  512 . Each cone segment  525  further includes a second taper  535  adjacent to the first taper  540 . The second taper  535  has a relatively steep slope to form the trailing profile of the two-position expander  512 . The inner surface of each cone segment  525  preferably has a substantially semi-circular shape to allow the cone segment  525  to slide along an outer surface of a tubular member  591  (e.g., similar to the support surface  191  visible in  FIG. 1G ). Furthermore, a track portion  520  is formed on each cone segment  525 . The track portion  520  is used with a mating track portion  570  formed on each cone segment  575  to align and interconnect the cone segments  525 ,  575 . In this embodiment, the track portion  520  and mating track portion  570  arrangement is similar to a tongue and groove arrangement. However, any track arrangement may be employed without departing from principles of the present invention. 
     Similar to the first assembly  500 , the second assembly  550  of the two-position expander  512  includes a second end plate  555  and the plurality of cone segments  575 . The end plate  555  is preferably a substantially round member with a plurality of “T”-shaped grooves  565  formed therein. Each groove  565  matches a “T”-shaped profile  580  formed at an end of each cone segment  575 . 
     Each cone segment  575  has an outer surface that includes a first taper  590  adjacent to the shaped profile  580 . As shown, the first taper  590  has a relatively steep slope to form the trailing shaped profile of the two-position expander  512 . Each cone segment  575  further includes a second taper  585  adjacent to the first taper  590 . The second taper  585  has a relatively gradual slope to form the leading profile of the two-position expander  512 . The inner surface of each cone segment  575  preferably has a substantially semi-circular shape to allow the cone segment  575  to slide along an outer surface of the tubular member  591 . 
       FIG. 11  is an enlarged view of the two-position expander  512  after radially extending the cone segments  525 ,  575 . The first assembly  500  and the second assembly  550  are urged linearly toward each other along the tubular member  591 . As the first assembly  500  and the second assembly  550  approach each other, the cone segments  525 ,  575  are urged radially outward. More specifically, as the cone segments  525 ,  575  travel linearly along the track portion  520  and mating track portion  570 , a front end  595  of each cone segment  575  wedges the cone segments  525  apart, thereby causing the shaped profile  530  to travel radially outward along the shaped groove  515  of the first end plate  505 . Simultaneously, a front end  545  of each cone segment  525  wedges the cone segments  575  apart, thereby causing the shaped profile  580  to travel radially outward along the shaped groove  565  of the second end plate  555 . The radial and linear movement of the cone segments  525 ,  575  continue until each front end  545 ,  595  contacts a stop surface  510 ,  560  on each end plate  505 ,  555  respectively. In this manner, the two-position expander  512  is moved from the first position having a first diameter to the second position having a second diameter that is larger than the first diameter. 
     Although the expander  512  illustrated in  FIGS. 10 and 11  is a two-position expander, the expander  512  may be a multi-position expander having any number of positions without departing from principles of the present invention. For instance, the cone segments  525 ,  575  could move along the track portion  520  and mating track portion  570  from the first position having a first diameter to the second position having a second diameter and subsequently to a third position having a third diameter that is larger than the first and second diameters. 
     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.