Patent Publication Number: US-2011048741-A1

Title: Downhole telescoping tool with radially expandable members

Description:
BACKGROUND 
     This disclosure relates generally to hydrocarbon exploration and production, and in particular to forming well bore tubular strings and connections to facilitate hydrocarbon production or downhole fluid injection. 
     During hydrocarbon exploration and production, a well bore typically traverses a number of zones within a subterranean formation. A tubular system may be established in the well bore to create flow paths from the multiple producing zones to the surface of the well bore. Efficient production is highly dependent on the inner diameter of the tubular production system, with greater inner diameters producing more hydrocarbons or allowing inserted equipment with appropriate pressure ratings to be used in well completions. Existing apparatus and methods for producing hydrocarbons include a complex set of tubulars, connections, liner hangers, sand control devices, packers and other equipment which tend to constrict the inner diameter of the production system available for production. 
     The tubular system implemented during the treatment, completion and production of subterranean oil and gas wells may also include a packer set at a preselected location above a production zone. In the case of wells of substantial depth, and particularly wells where the downhole temperatures are substantially in excess of or below the surface temperatures, problems have been encountered due to excessive expansion or contraction of the elongated tubing string. For example, in the treatment or stimulation of the well, it is common to introduce fluids at surface ambient temperature into the tubing string. In some cases, the fluid is introduced as steam at elevated temperatures. When the major portions of the tubing string are at a much higher temperature initially, this inherently results in a cooling, and hence a substantial contraction of the tubing string, resulting in the production of a substantial tensile stress in the tubing string between its surface connection and the set packer. Similarly, in the production phase of such wells, the production fluid is normally at a temperature substantially in excess of the temperature of the majority of the tubing string, resulting in a substantial expansion of the tubing string and the production of a substantial compressive force on the tubing string. Additionally, changes in fluid pressure inside and outside the tubing string play a major role in the development of substantial tension or compressive forces in the tubing string. 
     In other systems, a tubing hanger assembly is disposed at a relatively elevated downhole position within the well to suspend the production tubing extending to the production zones from such tubing hanger. Intermediate the tubing hanger and the top of the well there is commonly provided one or more production tubing strings commonly referred to as a “space-out section” which extends to a well surface hanger which is utilized to suspend the tubing string weight intermediate the downhole hanger and the surface hanger. The tubing strings coupled to the hangers undergo similar expansion or contraction forces as described. 
     To address the described expansion or contraction of the downhole tubulars, an expansion joint is disposed in the tubing string. The expansion joint may be located between the bottom of the tubing string and the packer. The expansion joint may be located between the surface hanger and the downhole hanger, or in the space-out section. The expansion joint is an axially moveable or telescoping device or component designed to enable relative movement between two fixed assemblies in the event of thermal expansion or contraction. Expansion joints within the completion assembly prevent any movement or forces being transmitted to fixed components such as packers or tubing hangers. Such expansion joints may, for example, comprise an elongated seal bore receptacle attached to the packer or hanger within which there is sealingly telescopically mounted a mandrel connected at its upper end to the tubing string and relatively movable with respect to the seal bore of the receptacle in response to the changes in tension or compression in the tubing string. A telescoping joint disposed in a space-out section may be capable of expansion or contraction to absorb temperature produced variations in length of the space-out section or dimensional differences between the planned and actual location of the surface hanger with respect to the downhole hanger. Further, the telescoping joint may have rotational or torque transmitting capability so that rotation can be accomplished through the joint to the right or to the left in order to perform required operations on various pieces of apparatus carried by the tubing string. 
     The principles of the present disclosure are directed to overcoming one or more of the limitations of the existing apparatus and processes for increasing fluid injection or hydrocarbon production during treatment, completion and production of subterranean wells. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       For a more detailed description of the embodiments of the present disclosure, reference will now be made to the accompanying drawings, wherein: 
         FIG. 1  is a schematic view of an expandable tubular string disposed in a borehole, the string including expandable tubular members coupled together by connections or joints; 
         FIG. 2A  is an enlarged, partial cross-section view of one of the tubular connections of  FIG. 1 , including the radial expansion and plastic deformation of a portion of the first tubular member; 
         FIG. 2B  shows the radial expansion and plastic deformation of the tubular members and connection of  FIG. 2A ; 
         FIG. 3  is a schematic representation of an operating environment for a basic exemplary completion or production apparatus; 
         FIG. 4  is a partial, cross-section view of an expandable tubular telescoping tool in accordance with the principles herein, showing the various components of the tool assembly in an axially contracted position; 
         FIG. 5  is a full cross-section view of the upper guide member of  FIG. 4 ; 
         FIG. 6  is the telescoping tool assembly of  FIG. 4  shown in an axially expanded position; 
         FIG. 7  is a partial, cross-section view of another embodiment of an expandable tubular telescoping tool in accordance with the principles herein, showing the various components of the tool assembly in an axially contracted position; 
         FIG. 8  is the telescoping tool assembly of  FIG. 7  shown in an axially expanded position; 
         FIG. 9  is a full cross-section view of the upper guide member of  FIGS. 7 and 8 ; 
         FIG. 10  is a side perspective view of the upper guide member of  FIGS. 7-9 ; 
         FIG. 11  is a side perspective view of the lower guide member of  FIGS. 7 and 8 ; 
         FIG. 12  is a radial section view of the telescoping tool assembly at section  12  of  FIG. 7 ; 
         FIG. 13  is a radial section view of the upper guide member at section  13  of  FIGS. 9 and 10 ; 
         FIG. 14  is a radial section view of the lower guide member at section  14  of  FIG. 11 ; 
         FIG. 15  is a radial section view of the telescoping tool assembly at section  15  of  FIG. 7 ; 
         FIG. 16  is a radial section view of the telescoping tool assembly at section  16  of  FIG. 7 ; and 
         FIG. 17  is a radial section view of the telescoping tool assembly at section  17  of  FIG. 7 . 
     
    
    
     DETAILED DESCRIPTION 
     In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present disclosure is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the invention, and is not intended to limit the invention to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce desired results. 
     Unless otherwise specified, any use of any form of the terms “connect”, “engage”, “couple”, “attach”, or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . ”. The terms “pipe,” “tubular member,” “casing” and the like as used herein shall include tubing and other generally cylindrical objects. In addition, in the discussion and claims that follow, it may be sometimes stated that certain components or elements are in fluid communication. By this it is meant that the components are constructed and interrelated such that a fluid could be communicated between them, as via a passageway, tube, or conduit. The various characteristics mentioned above, as well as other features and characteristics described in more detail below, will be readily apparent to those skilled in the art upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings. 
     Referring initially to  FIG. 1 , a string  14  of coupled tubular members is disposed in a well bore  10  drilled through the formation  12 , creating an annulus  13 . The string  14  comprises a series of connected tubular members, such as casing joints  15 ,  16 ,  17  and  18 , having a centerline or axis  19 . In some embodiments, the casing joints are secured by connections  15   a,    16   a  and  17   a  as indicated to form an elongate string that extends to the well surface. The casing string  14  is illustrated as being made up of individual casing joints of approximately 40 feet in length, for example, with a joint connection between the adjoining casing joints. In accordance with the principles of the present disclosure, the casing string  14  is to be radially expanded and plastically deformed into engagement with the surrounding well bore  10  using a forging device or expansion mandrel that passes internally through the casing string  14  and the connections  15   a,    16   a,  and  17   a.  In other embodiments, the well bore  10  is cased and the string  14  is expanded toward the casing. 
     Referring now to  FIG. 2A , the connection  15   a  of  FIG. 1  is shown enlarged and in partial cross-section about the axis  19 . The first tubular member  16  includes an internal connection surface  22  at an end portion  24 . In some embodiments, the internal surface  22  includes threads. An external connection surface  28  of an end portion  26  of the second tubular member  15  is coupled to the internal connection  12  of the end portion  14  of the first tubular member  10 . In some embodiments, the external surface  28  includes threads such that the surfaces  22 ,  28  are threadedly engaged. The first and second tubulars  16 ,  15  abut at locations  30 ,  32 . In an exemplary embodiment, the internally threaded connection  22  of the end portion  24  of the first tubular member  16  is a box connection, and the externally threaded connection  28  of the end portion  26  of the second tubular member  15  is a pin connection. 
     In an exemplary embodiment, as illustrated in  FIGS. 2A and 2B , the first and second tubular members  16 ,  15  may then be positioned within another structure  10  such as, for example, a wellbore, and radially expanded and plastically deformed, for example, by moving an expansion device or cone  34  through the interiors of the first and second tubular members. The movement of the expansion cone  34  through the interiors of the first and second tubular members  16 ,  15  may be from top to bottom or from bottom to top. As shown, the tubular members  15 ,  16  are radially expandable from a first unexpanded position to a final plastically deformed position. 
     In the embodiments just described, and throughout the disclosure herein, the wellbore or borehole described may be uncased or cased. The expandable tubulars may be radially expanded and plastically deformed toward the uncased borehole, or toward a casing already in place in the borehole. 
     Referring to  FIG. 3 , a schematic representation of an operating environment for a basic exemplary completion or production apparatus  100  is shown. The apparatus  100  is an exemplary embodiment, and various other embodiments of the apparatus  100  consistent with the teachings herein are included. As depicted, a drilling rig  110  is positioned on the earth&#39;s surface  105  and extends over and around a well bore  120  that penetrates a subterranean formation F for the purpose of recovering hydrocarbons. The well bore  120  may be drilled into the subterranean formation F using conventional (or future) drilling techniques. The well bore  120  may extend substantially vertically away from the surface  105  over a vertical portion  122 , or may deviate at any angle from the surface  105  over a lateral well bore portion  124 . In some instances, all or portions of the well bore  120  may be vertical, deviated, horizontal, and/or curved. 
     At least a portion of the vertical well bore  122  may be lined with casing  125  that may be cemented  127  into position against the formation F in a conventional manner. A lower portion  128  of the well bore  122  may also be lined with cemented casing  125 . In some instances, the operating environment for the apparatus  100  includes a substantially uncased, open hole well bore  120 . The well bore may also include the uncased, open hole lateral well bore portion  124 . The lateral well  124  may include various hydrocarbon producing zones  80 ,  82 ,  84 ,  86 ,  88 ,  90 . The drilling rig  110  includes a derrick  112  with a rig floor  114  through which a tubing or work string  118  extends downwardly from the drilling rig  110  into the well bore  120 . The tubing string  118  suspends a representative downhole production apparatus  100  to a predetermined depth within the well bore  120  to perform a specific operation, such as perforating a casing, expanding a fluid path therethrough, fracturing the formation F, producing the formation F, or other completion or production operation. The tubing string  118  may also be known as the entire conveyance above and coupled to the apparatus  100 . The drilling rig  110  is conventional and therefore includes a motor driven winch and other associated equipment for extending the tubing string  118  into the well bore  120  to position the apparatus  100  at the desired depth. 
     While the exemplary operating environment depicted in  FIG. 3  refers to a stationary drilling rig  110  for lowering and setting the apparatus  100  within a land-based well bore  120 , one of ordinary skill in the art will readily appreciate that mobile workover rigs, well servicing units, such as coiled tubing units, and the like, could also be used to lower the apparatus  100  into the well bore  120 . It should be understood that the apparatus  100  may also be used in other operational environments, such as within an offshore well bore. 
     The production apparatus  100 , disposed partially in cased hole  122  and substantially in open hole  124 , includes an upper end having a liner hanger  132 , a lower end  136 , and a tubing section  134  extending therebetween. The lower end  136  may include devices  138 ,  140  such as a guide shoe, a float shoe or a float collar of a type known in the art, and other tubing conveyed devices  142 ,  144 . The borehole  124  and the tubing section  134  define an annulus  146  therebetween. The tubing section  134  includes an interior  148  that defines a flow passage  150  therethrough. The tubing section  134  may include an inner string  152  with a lower end  154  that extends into a polished bore receptacle  144 . The inner string  152  may be used to carry out preliminary operations, such as perforating or jetting. Alternatively, the tubing section  134  does not include the inner string  152  such that the flow passage  150  is the main flowbore through the apparatus  100 . A plurality of devices  158  are connected in the tubing section  134  and provide operational interaction with the various hydrocarbon producing zones  180 ,  182 ,  184 ,  186 ,  188 . The completion or production devices  158  may include seals, packers, subs, screens, blast joints and other devices used in completion or production strings. 
     Referring to  FIG. 4 , an assembly  200  for axial expansion and contraction of a tubular string is shown. As will be shown and described herein, tubular members of the assembly  200  are configured for relative axial movement while coupled to allow for expansion and contraction of the overall tubular string. Thus, the assembly  200  may also be referred to as an axial expansion tool or telescoping tool. In some embodiments, one or more of the tubular members in the telescoping tool is radially expandable, as will be described more fully herein. In certain embodiments, the tubular members are radially expandable to a plastically deformed position. 
     In  FIG. 4 , the telescoping tool assembly  200  is shown in an axially contracted position. An upper half of the telescoping tool assembly  200  is shown in cross-section, including an outer housing  220 , an internal upper guide member  210  and a lower guide and seal assembly  230 . The outer housing  220  is a tubular member including an upper end  222  and a lower end  224 . The internal upper guide member  210  is a tubular member including an upper end  212  and a lower end  214 . As shown in  FIG. 5 , an inner surface  215  of the upper guide  210  includes one or more slots  216  extending from an intermediate portion of the upper guide  210  to the end  214 . In some embodiments, the slots  216  are milled. In some embodiments, an axial length  218  of the slots  216  is approximately 6 feet to 10 feet, though this range is exemplary only and other lengths are contemplated. 
     Still referring to  FIG. 4 , the lower guide  230  is a tubular member including an upper end  232  and a lower end  234 . The upper end  232  includes outer slots  236  and ribs or splines  237  for slidably mating with the slots  216 , creating the telescoping arrangement between the upper guide  210  and the lower guide  230  wherein these members reciprocate relative to each other. In some embodiments, the slots  236  are milled resulting in the splines  237 . In some embodiments, the axial length of the slots  236  and splines  237  is similar to the length  218  such that a stroke  238  is created between the mating splines  237  and slots  216 . The mating splines  237  and slots  216 ,  236  may also be referred to as anti-rotation splines. The splines and slots are an interlocking mechanism for axial movement and anti-rotation. In other embodiments, the positions of the splines  237  and the slots  216  are reversed, wherein the splines  237  are disposed on the upper guide  210  and instead extend into the slots  216  disposed on the lower guide  230 . In some embodiments, other interlocking mechanisms are used between the telescoping and reciprocal upper guide  210  and lower guide  230  for axial movement and simultaneous prevention of relative rotation between these two members. While rotation between the two tubular members  210 ,  230  in the tool  200  is prevented, it should be understood that the overall tool  200  may be rotated as part of the larger tubular string into which the tool  200  is coupled. Thus, rotating or torquing through the tool  200  is possible via the anti-rotation mechanism that prevents relative rotation inside the tool  200 . 
     The slidably coupled and reciprocating guide members  210 ,  230  are disposed inside the outer housing  220 . Disposed between the guide members  210 ,  230  and the outer housing  220  is a sleeve or layer  270 . A portion of the sleeve  270  is disposed between the guide members  210 ,  230  over the length of the interlocked splines and slots. Another portion of the sleeve  270  is disposed between the lower guide  230  and the outer housing  220 . One or more sealing members or bands  239  may be disposed between the lower guide  230  and the outer housing  220 . 
     In some embodiments, the sleeve  270  is a layer of non-metal material disposed between the metal tubulars  210 ,  230  and metal tubular  220  to prevent metal to metal contact between these tubulars. For example, the sleeve  270  comprises a layer of high strength, high modulus material. In exemplary embodiments, the sleeve  270  comprises a polyurethane material. In still other embodiments, the sleeve  270  is a layer of a spray on material, a bonded on (to one tubular or the other) material, a wrapped on material, or a combination thereof. In some embodiments, the sleeve  270  is a nano material. In some embodiments, the sleeve  270  is a composite material. The sleeve  270  is a lubricous, or becomes a lubricous, material that provides lubricity between the metal tubular members. The sleeve  270  is a non-cladding material, wherein bonding or other permanent attachment between the metal tubular members is prevented. As will be further described herein, the lubricous material  270  allows relative axial movement of the guide members  210 ,  230  and the outer housing  220  of the telescoping tool assembly  200 , both before and after radial expansion and plastic deformation of the tool assembly. In some embodiments, the sleeve  270  also radially expands to transfer radial expansion loads between the tubular member  210 ,  230 , and between the tubular members  220 ,  230 , and act as a seal. 
     In some embodiments, the upper end  222  of the outer housing  220  is attached to the upper end  212  of the upper guide member  210 , such as via a hanger connection, a threaded connection or a weld. In some embodiments, the connection between the outer housing  220  and the upper guide  210  is permanent. The upper end  222  of the outer housing  220  includes a connector coupled with a connector end  242  of a tubular member  240 . The connectors may be threaded to form a threaded connection  225 . In some embodiments, the tubular member  240  is a non expandable oilfield casing or tubing string with a premium connection. In some embodiments, the tubular member  240  is expandable. In some embodiments, the outer housing  220  is an expandable member with a premium connection to form the connection  225 . 
     The lower end  234  of the lower guide member  230  includes a connector coupled with a connector end  252  of a tubular member  250 . The connectors may be threaded to form a threaded connection  235 . In some embodiments, the tubular member  250  is a non expandable oilfield casing or tubing string with a premium connection. In some embodiments, the tubular member  250  is expandable. In some embodiments, the lower guide member  230  is an expandable member with a premium connection to form the connection  235 . In some embodiments, the upper guide member is expandable. A shear connection  260 , such as a shear ring or shear pin, extends through the outer housing end  224  and the lower guide end  234  to secure the assembly  200  in the contracted or closed position shown in  FIG. 4 . The contracted position may be maintained by the shear connection  260  while the assembly  200  is being lowered into its operating position such that the assembly  200  does not expand or open before it is in place. 
     In  FIG. 4 , the expansion tool  200  is shown in the contracted or closed position. When tensile and/or compressive forces are created in one or both of the tubing strings  240 ,  250  due to thermal or pressure effects therein, the expansion tool is configured to axially expand or open as shown in  FIG. 6 . Upon application of the axial forces from the tubing strings  240 ,  250 , the shear connection  260  is sheared to release the lower assembly, comprising the lower guide member  230  coupled to the tubular member  250 , from the upper assembly, comprising the upper guide member  210  coupled to the outer housing  220  which is coupled to the tubular member  240 . The lower assembly is then allowed to move axially relative to the upper assembly, as shown in  FIG. 6  and represented by the strokes  238 ,  258 . More particularly, the lower guide  230  moves axially relative to the upper guide  210 , with the interlocking splines  237  and slots  216 ,  236  sliding axially against each other while preventing relative rotation. The non-metal sleeve or layer  270  prevents metal to metal contact between the interlocking and sliding splines and slots while also providing one or more of load transfer, sealing and lubricity. Axial forces applied in the opposite direction will force the assembly  200  back toward the contracted position of  FIG. 4 . Movement between the contracted and expanded positions of the assembly  200  will absorb the axial forces that may be detrimental to fixed components of the well completion system, such as packers, tubing hangers or tubing anchors. 
     In some embodiments, the shear connection  260  is placed at variable axial positions from that shown. Further, in some embodiments, the original sheared run-in position of the assembly  200  can be any of various positions between the contracted position of  FIG. 4  and the expanded position of  FIG. 6 . The pinned, run-in position may be closed, open, or partially open. 
     Referring next to  FIG. 7  another embodiment is shown including a telescoping tool assembly  300  with radially expandable members. An upper assembly includes an upper guide member  310  coupled to an outer housing  320  which is coupled to an upper tubular string  340 . A lower assembly includes a lower guide member  330  coupled to a lower tubular string  350 . The two assemblies are sheared connected at  360 . In some embodiments, the shear connection  360  is located at other axial positions along the assembly  300 , to provide various closed, open, or partially open run-in positions. Sealing members  339  are coupled between the lower guide  330  and the outer housing  320 . A non-metal sleeve or layer  370  includes axial lengths disposed between the lower guide  330  and the outer housing  320 , and between the lower guide  330  and the upper guide  310  at an interlocking and sliding anti-rotation mechanism  390 . As shown in  FIG. 8 , axial forces in the tubing strings  340 ,  350  will cause the connection  360  to shear and the upper and lower assemblies to move axially relative to each other by sliding of the lower guide splines, as shown in  FIG. 11 , in the upper guide slots  316 , as shown in  FIG. 9 . In some embodiments, the splines and slots are located on opposite members, and other interlocking arrangements are used to allow reciprocating translation of the upper and lower guides while preventing rotation. Such an arrangement allows rotation and torque to be transferred through the tool  300 . 
     Referring to  FIGS. 10 and 11 , an end  314  of the upper guide member  310  ( FIG. 10 ) is configured to received an end  332  of the lower guide member  330  ( FIG. 11 ). The lower guide member  330  include alternating splines  337  and slots  336 . The splines  337  mates with slots  316  milled into the inner surface  315  of the upper guide member  310 . A sealing band  339  is provided on the lower guide  330  for sealing with the upper guide  310 . A non-metal sleeve or layer  370  is provided on the lower guide  330  to each contact with and transfer loads between the lower guide  330  and the upper guide  310  and outer housing  320 . 
     Referring now to  FIG. 12 , a radial cross-section is shown of the assembly  300  of  FIG. 7 . The inner, lower guide member  330  is surrounded by the upper guide member  310 . Disposed between the interlocking splines and slots, as previously described, is the layer  370 . The radial cross-section of the upper guide member  310  of  FIGS. 9 and 10 , as shown in  FIG. 13 , illustrates the slots  316  in the inner surface  315 . The radial cross-section of the lower guide member  330  of  FIG. 11 , as shown in  FIG. 14 , illustrates the splines  337  separated by the reduced diameter outer surfaces  336 .  FIGS. 15-17  are additional radial cross-sections of the assembly  300  of  FIG. 7 . In  FIG. 15 , the lower guide member  330  is surrounded by the upper guide member  310 , with the intervening layer  370  disposed therebetween at the spline/slot arrangements. The outer housing  320  surrounds and contains the upper guide member  310 . In  FIG. 16 , a different portion of the layer  370  is shown disposed between the inner guide member  330  and the outer housing  320 . In  FIG. 17 , the outer housing  320  is shown surrounding and containing the upper part of the guide member  310 . As previously noted, the upper end of the outer housing  320  may be attached to the upper end of the upper guide member  310  via a hanger connection, a threaded connection or a weld. 
     In the expansion tool assemblies  200 ,  300 , an expansion device may be coupled thereto. An expansion device, such as the expansion cone  34 , may be coupled to the assemblies  200 ,  300  or to the tubing strings  240 ,  250 ,  340 ,  350 . Other expansion devices are known and contemplated herein. Before activation of the expansion device, the telescoping tools may be sheared from their run-in positions (any one of open, closed, or partially open) and the tubular guide members may be reciprocated relative to the other guide member and the outer housing to accommodate axial loads in the tubing strings. In further embodiments, upon application of a hydraulic or mechanical driving force, the expansion device is moved or displaced through the assemblies  200 ,  300  to radially expand and plastically deform portions thereof. As described herein, certain components and connections of the assemblies  200 ,  300  may be expandable while others are not. These components may be radially expandable to a plastically deformed position. The tubing strings  240 ,  250 ,  340 ,  350  may be expandable or non-expandable. In some embodiments, the assemblies  200 ,  300  include seals or other members bonded or attached to the outer surfaces such that the radially expanded assemblies  200 ,  300  engage the seals with an existing exterior structure and provide an anchor hanger. If all or some of the tubing strings  240 ,  250 ,  340 ,  350  are expanded, the assemblies  200 ,  300  may be expanded independently of the tubing strings or concurrently with the tubing strings. Different combinations of expandable and non-expandable components and connections may be used to produce desired results. 
     Thus, in the pre-expanded position, the assemblies  200 ,  300  can support axial tension and compression loads in the tubular strings. Further, when all or portions of the telescoping tool assemblies  200 ,  300  are radially expanded, the assemblies can continue to accommodate axial tension and compression loads in the tubular strings by allowing the moveable guide member to telescope or reciprocate relative to the other guide member and the outer housing. The radially expanded and plastically deformed tool assemblies  200 ,  300  retain their axial expansion or telescoping functionality. The layers  270 ,  370  are provided to facilitate the retained telescoping functionality. The layers  270 ,  370  provide lubricity between the moveable joint components, such as between the moveable guide member and the other guide member and outer housing. The layers  270 ,  370  comprise non-cladding materials such that the moveable guide members are not bonded upon radial expansion. The layers  270 ,  370  transfer loads between the assembly components, such as radial expansion loads from the inner tubular members to the outer tubular members. The layers  270 ,  370  provide sealing characteristics after radial expansion. The layers  270 ,  370  help maintain component and tool shape after radial expansion. The tools  200 ,  300  are re-shaped by radial expansion, and the layers  270 ,  370  provide a medium for retaining geometric shape after expansion while also maintaining functionality and operability of the relatively axially moveable members. 
     The assemblies  200 ,  300 , whether radially expanded or not, by being axially moveable limit or remove axial load constraints within the tubular or casing string they are coupled to, such as the strings  240 ,  250 ,  340 ,  350 . The assemblies  200 ,  300  also support pressures in both the pre- and post-expanded positions. 
     In all embodiments, radial expansion and plastic deformation of at least portions of the assemblies  200 ,  300  increases the effective flow area of the system to enable higher injection or production rates, and decreases restrictions, particularly at the liner hanger, for the passage of work strings and tools. Upon radial expansion, the assemblies  200 ,  300  are still capable of accommodating axial expansion or contraction loads in the tubular strings via the relatively moveable guide members. Further, the sleeves or layers  270 ,  370  transfer the radial expansion loads from the inner tubular members to the outer tubular members, in addition to providing sealing and lubricating characteristics. 
     While the disclosure is susceptible to various modifications and alternative forms, specific embodiments thereof are shown by way of example in the drawings and description. It should be understood, however, that the drawings and detailed description thereto are not intended to limit the disclosure to the particular form disclosed, but on the contrary, the intention is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the present disclosure.