Embodiments of the invention generally relate to tools and methods for hanging and/or expanding liner strings. In one embodiment, a method of hanging a liner assembly from a previously installed tubular in a wellbore includes running the liner assembly and a setting tool into the wellbore using a run-in string. The setting tool includes an isolation valve and the liner assembly includes a liner hanger and a liner string. The method further includes sending an instruction signal from the surface to the isolation valve, wherein the isolation valve closes in response to the instruction signal and isolates a setting pressure in the setting tool from the liner string; and increasing fluid pressure in the setting tool, thereby setting the liner hanger.

BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     Embodiments of the present invention generally relate to tools and methods for hanging and/or expanding liner strings. 
     2. Description of the Related Art 
     In wellbore construction and completion operations, a wellbore is initially formed to access hydrocarbon-bearing formations (i.e., crude oil and/or natural gas) by the use of drilling. Drilling is accomplished by utilizing a drill bit that is mounted on the end of a drill support member, commonly known as a drill string. To drill within the wellbore to a predetermined depth, the drill string is often rotated by a top drive or rotary table on a surface platform or rig, or by a downhole motor mounted towards the lower end of the drill string. After drilling to a predetermined depth, the drill string and drill bit are removed and a section of casing is lowered into the wellbore. An annulus is thus formed between the string of casing and the formation. The casing string is temporarily hung from the surface of the well. A cementing operation is then conducted in order to fill the annular area with cement. The casing string is cemented into the wellbore by circulating cement into the annulus defined between the outer wall of the casing and the borehole. The combination of cement and casing strengthens the wellbore and facilitates the isolation of certain areas of the formation behind the casing for the production of hydrocarbons. 
     It is common to employ more than one string of casing or liner in a wellbore. In this respect, the wellbore is drilled to a first designated depth with a drill bit on a drill string. The drill string is removed. A first string of casing is then run into the wellbore and set in the drilled out portion of the wellbore, and cement is circulated into the annulus behind the casing string. Next, the wellbore is drilled to a second designated depth, and a second string of casing or liner, is run into the drilled out portion of the wellbore. If the second string is a liner, the liner string is set at a depth such that the upper portion of the second liner string overlaps the lower portion of the first string of casing. The second liner string is then fixed, or “hung” off of the existing casing using a liner hanger to fix the new string of liner in the wellbore. The second liner string is then cemented. A tie-back casing string may then be landed in a polished bore receptacle (PBR) of the second liner string so that the bore diameter is constant through the liner to the surface. This process is typically repeated with additional liner strings until the well has been drilled to total depth. As more casing or liner strings are set in the wellbore, the casing or liner strings become progressively smaller in diameter in order to fit within the previous casing string. In this manner, wells are typically formed with two or more strings of casing and/or liner of an ever-decreasing diameter. 
     The process of hanging a liner off of a string of surface casing or other upper casing string involves the use of a liner hanger. The liner hanger is typically run into the wellbore above the liner string itself. The liner hanger is actuated once the liner is positioned at the appropriate depth within the wellbore. The liner hanger is typically set through actuation of slips which ride outwardly on cones in order to frictionally engage the surrounding string of casing. The liner hanger operates to suspend the liner from the casing string. However, it does not provide a fluid seal between the liner and the casing. Accordingly, a packer may be set to provide a fluid seal between the liner and the casing. 
     During the wellbore completion process, the packer is typically run into the wellbore above the liner hanger. A threaded connection typically connects the bottom of the packer to the top of the liner hanger. Known packers employ a mechanical or hydraulic force in order to expand a packing element outwardly from the body of the packer into the annular region defined between the packer and the surrounding casing string. In addition, a cone is driven behind a tapered slip to force the slip into the surrounding casing wall and to prevent packer movement. Numerous arrangements have been derived in order to accomplish these results. 
     The cementing process typically involves the use of liner wipers and drill-pipe plugs. A liner wiper is typically located inside the top of a liner, and is lowered into the wellbore with the liner at the bottom of a working string. The liner wiper plug typically defines an elongated elastomeric body used to separate fluids pumped into a wellbore. The wiper has radial wipers to contact and wipe the inside of the liner as the wiper travels down the liner. The liner wiper has a cylindrical bore through it to allow passage of fluids. 
     After a sufficient volume of cement has been placed into the wellbore, the plug is deployed. Using a displacement fluid, such as drilling mud, the plug is pumped into the working string. As the plug travels downhole, it seats against the liner wiper, closing off the internal bore through the liner wiper. Hydraulic pressure above the plug forces the plug and the wiper to dislodge from the bottom of the working string and to be pumped down the liner together. This forces the circulating fluid or cement that is ahead of the wiper plug and dart to travel down the liner and out into the liner annulus. 
     SUMMARY OF THE INVENTION 
     Embodiments of the present invention generally relate to tools and methods for hanging and/or expanding liner strings. In one embodiment, a method of hanging a liner assembly from a previously installed tubular in a wellbore includes: running the liner assembly and a setting tool into the wellbore using a run-in string. The setting tool includes an isolation valve and the liner assembly includes a liner hanger and a liner string. The method further includes sending an instruction signal from the surface to the isolation valve. The isolation valve closes in response to the instruction signal and isolates a setting pressure in the setting tool from the liner string. The method further includes increasing fluid pressure in the setting tool, thereby setting the liner hanger. 
     In another embodiment, a setting tool for hanging a liner assembly from a previously installed tubular in a wellbore, includes a tubular mandrel having a bore therethrough and a port formed through a wall thereof; a piston in fluid communication with the port and operable to set a liner hanger of the liner assembly; a latch operable to couple the liner assembly to the mandrel; a seal configured to isolate an annulus between the liner assembly and the setting tool; and an isolation valve. The isolation valve is operable to receive an instruction signal from the surface and close in response to receiving the instruction signal. 
     In another embodiment, a method of hanging a liner assembly from a previously installed tubular in a wellbore includes running the liner assembly and a setting tool into the wellbore using a run-in string. The setting tool includes a piston and an electric actuator and the liner assembly includes a liner hanger and a liner string. The method further includes sending an instruction signal from a surface to the electric actuator. The actuator supplies fluid pressure to the piston in response to the instruction signal, thereby setting the liner hanger. 
     In another embodiment, a setting tool for hanging a liner assembly from a previously installed tubular in a wellbore, includes: a tubular mandrel having a bore therethrough; a piston coupled to the mandrel and operable to set a liner hanger of the liner assembly; a latch operable to couple the liner assembly to the mandrel; a seal configured to isolate an annulus between the liner assembly and the setting tool and; an electric actuator. The actuator is operable to receive an instruction signal from a surface and supply fluid pressure to the piston. 
     In another embodiment, a method of expanding a liner in a wellbore, includes running the liner assembly and an expander assembly into the wellbore using a run-in string. The expander assembly includes an electric actuator and a two-position expander. The method further includes sending an instruction signal from a surface to the actuator; forming a launcher in the liner for the expander; shifting the two-position expander from a contracted position to an expanded position in the launcher by the actuator in response to the signal; and expanding the liner. 
    
    
     
       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 and 1B  are cross-sections of a setting tool, a liner assembly, and a wiper assembly, according to one embodiment of the present invention. 
         FIG. 2  is a cross-section of an isolation valve of the setting tool.  FIG. 2A  illustrates a coupling between a piston and retaining rod of the isolation valve.  FIG. 2B  illustrates a flapper of the isolation valve. 
         FIGS. 3A-D  illustrate installation of the liner assembly. 
         FIG. 4  is a cross-section of an isolation valve, according to another embodiment of the present invention.  FIGS. 4A-C  illustrate operation of the isolation valve.  FIG. 4D  illustrates an alternative embodiment of the isolation valve. 
         FIG. 5  is a cross-section of an isolation valve, according to another embodiment of the present invention. 
         FIG. 6  is a cross-section of an isolation valve, according to another embodiment of the present invention.  FIG. 6A  illustrates an electronics package of the isolation valve.  FIG. 6B  illustrates surface equipment for generating pressure pulses for the electronics package.  FIG. 6C  illustrates the computer/PLC of the surface equipment. 
         FIG. 7  is a cross-section of a portion of a setting tool and a liner assembly, according to another embodiment of the present invention.  FIG. 7A  is an enlarged view of a piston actuator of the setting tool.  FIGS. 7B and 7C  illustrate an expander assembly of the setting tool according to an embodiment of the invention. 
         FIG. 8A  illustrates a radio-frequency identification (RFID) electronics package, according to another embodiment of the present invention.  FIG. 8B  illustrates an active RFID tag.  FIG. 8C  illustrates a passive RFID tag. 
         FIG. 9A  is a sectional view of an expandable liner system disposed in a wellbore proximate a lower end of a string of casing, according to another embodiment of the present invention.  FIG. 9B  is a sectional view illustrating the reforming or unfolding of a corrugated liner to form a launcher of the expandable liner system.  FIG. 9C  is a sectional view of the expansion system after positioning a two-position expander in the launcher.  FIG. 9D  is a sectional view of the expandable liner system illustrating the expansion of the corrugated liner section.  FIG. 9E  is a sectional view of the expandable liner system illustrating the expansion of the upper liner section.  FIG. 9F  is a sectional view of the completed wellbore. 
         FIG. 10  is a cross section of a valve of the expandable liner system. 
         FIG. 11  illustrates an alternative expansion assembly, according to another embodiment of the present invention. 
         FIG. 12  is a half section of a portion of a setting tool, according to another embodiment of the present invention. 
         FIGS. 13A-D  are half-sections of an isolation valve and illustrate the operation of the isolation valve, according to another embodiment of the invention.  FIGS. 13A-1 ,  13 B- 1 ,  13 C- 1  and  13 D- 1  illustrate a J-slot arrangement of the isolation valve and operation thereof.  FIGS. 13A-2  and  13 B- 2  illustrate coupling between a ball and sleeve of the isolation valve and operation thereof. 
         FIGS. 14A-C  are half-sections of an isolation valve and illustrate the operation of the isolation valve, according to another embodiment of the invention. 
         FIGS. 15A-D  are half-sections of an expansion assembly of an expandable liner system and illustrate the operation of the system, according to another embodiment of the invention.  FIG. 15A-1  illustrates a piston and valve of the expandable liner system.  FIGS. 15C-1 ,  15 D- 1 ,  15 D- 2  are half-sections of a release mechanism of the expandable liner system and illustrate the operation of the system. 
     
    
    
     DETAILED DESCRIPTION 
       FIGS. 1A and 1B  are cross-sections of a setting tool  1 , a liner assembly  100 , and a wiper assembly  150 , according to one embodiment of the present invention. The setting tool  1 , liner assembly  100 , and wiper assembly  150  may be run into a wellbore using a run-in string  685  (see  FIG. 6 ). The run-in string  685  may include a string of tubulars, such as drill pipe, longitudinally and rotationally coupled by threaded connections. The liner assembly  100  may include an expandable liner hanger  105 , a polished bore receptacle (PBR)  110 , one or more adapters  115 , and a liner string  125 . The setting tool  1  may be operable to radially and plastically expand the liner hanger  105  into engagement with a casing or liner string  305  (see  FIG. 3A ) previously installed in the wellbore. Non-sealing members of the setting tool  1  and liner assembly  100  may be made from a metal or alloy, such as steel or stainless steel. Alternatively, the PBR  110  may be disposed between the liner hanger and the run-in string. 
     The setting tool  1  may include a connector sub  2 , a mandrel  3 , one or more piston assemblies  10   a, b , an expander assembly  25 , a latch assembly  50 , an isolation valve  200 , and a seal assembly  75 . The connector sub  2  may be a tubular member including a threaded coupling for connecting to the run-in string and a longitudinal bore therethrough. The connector sub  2  may also include a second threaded coupling engaged with a threaded coupling of the mandrel  3 . One or more fasteners, such as set screws may secure the threaded connection between the connector sub  2  and the mandrel  3 . The mandrel  3  may be a tubular member having a longitudinal bore therethrough and may include one or more segments connected by threaded couplings. 
     The piston assemblies  10   a,b  may include pistons  11   a,b , sleeves  12 - 14 , caps  15   a,b , inlets  16   a,b , outlets  17   a,b , and ratchet assembly  18 . The pistons  11   a, b  may each be T-shaped annular members. An inner surface of each piston  11   a,b  may engage an outer surface of the mandrel  3  and may include a recess having a seal, such as an o-ring disposed therein. The inlets  16   a,b  may be formed radially through a wall of the mandrel  3  and provide fluid communication between a bore of the mandrel  3  and first sides of the pistons  11   a,b . The sleeves  12 , 13  may be longitudinally coupled to the pistons  11   a,b  by threaded connections. Seals, such as o-rings, may be disposed between the pistons  11   a,b  and the sleeves  12 , 13 . Each of the sleeves  12 - 14  may be a tubular member having a longitudinal bore formed therethrough and may be disposed around the mandrel, thereby forming an annulus therebetween. The caps  15   a,b  may be annular members, disposed around the mandrel, and longitudinally coupled thereto by a threaded connection. The caps  15   a,b  may also be disposed about a shoulder formed in or disposed on an outer surface of the mandrel  3 . Seals, such as o-rings, may be disposed between the caps  15   a,b  and the mandrel  3  and between the caps  15   a,b  and the sleeves  12 , 13 . 
     An end  12   a  of the sleeve  12  may be exposed to an exterior of the setting tool  1 . The end  12   a  of the sleeve  12  may further include a profile formed therein or fastened thereto by a threaded connection. The profile may mate with a corresponding profile formed on an outer surface of the ratchet assembly  18 , thereby longitudinally coupling the ratchet  18  and the sleeve  12  when the pistons are actuated. The sleeve profile may engage the ratchet profile by compressing a spring, such as a c-ring. The c-ring may then expand to lock in a groove of the sleeve profile. Teeth formed on inner and outer surfaces of a lock ring of the ratchet assembly  18  respectively engage corresponding teeth formed on an outer surface of the mandrel  3  and an inner surface of a ring housing, thereby longitudinally locking the sleeve  12  and thus the expander assembly  25  once the sleeve  12  engages the ratchet assembly  18 . 
     The outlet  17   a  may be formed through an outer surface of the piston  11   a  and may provide fluid communication between a second side of the piston  11   a  and the exterior of the setting tool  1 . The sleeves  13 , 14  may be longitudinally coupled to the piston  11   b  by a threaded connection. The outlet  17   b  may be formed through a wall of the sleeve  14  and may provide fluid communication between a second side of the piston  11   b  and the exterior of the setting tool  1 . An end  14   a  of the sleeve  14  may be longitudinally coupled to an expander assembly  25  by a threaded connection and one or more set screws. The sleeve  14  may also be temporarily longitudinally coupled to the mandrel at  14   b  by one or more frangible members, such as shear screws. 
     The expander assembly  25  may include a body  26 , upper cone retainer  27 , a plurality of cones  28   a,b , cone base  29 , lower cone retainer  30 , sleeve  31 , and shoe  32 , pusher  33 , and one or more frangible members, such as shear screws  34 . The expander assembly  25  may be operable to radially and plastically expand the hanger  105  into engagement with a previously installed liner or casing. The expander assembly  25  may be driven through the expandable hanger  105  by the pistons  11   a,b . The pusher  33  may longitudinally coupled to the sleeve  14  by a threaded connection and one or more fasteners, such as set screws. The pusher  33  may be longitudinally coupled to the body  26  by the shear screws  34 . The cones  28   a,b  may each include a lip at each end thereof in engagement with respective lips formed at a bottom of the upper retainer  27  and a top of the lower retainer  30 , thereby radially coupling the cones to the retainers. An inner surface of each cone may be inclined for mating with an inclined outer surface of the cone base  29 , thereby holding each cone radially outward into engagement with the retainers. 
     The body  26  may be tubular, disposed along the mandrel  3 , and longitudinally movable relative to the mandrel. The upper retainer  27  may be longitudinally coupled to the body  26  by a threaded connection and one or more fasteners, such as set screws. The retainers, sleeve, and shoe may be disposed along the body. The upper retainer  27  may abut the cone base  29  and the cones  28   a,b . The cones may abut the lower retainer  30 . The lower retainer  30  may abut the sleeve  31  and the sleeve  31  may abut the shoe  32 . The shoe  32  may be longitudinally coupled to the body  26  by a threaded connection and one or more fasteners, such as set screws. 
     In operation (see  FIG. 3C ), movement of the sleeve  14  longitudinally toward the upper retainer  27  may fracture the shear screws  34  since the body  26  may be retained by engagement of the cones  28   a,b  with a top of the liner hanger  105 . Failure of the shear screws  34  may free the pusher  33  for relative longitudinal movement toward the upper retainer until a bottom of the pusher abuts a top of the upper retainer. Continued movement of the sleeve  14  may then push the cones  28   a,b  through the liner hanger  105 , thereby expanding the liner hanger  105  into engagement with the previously installed casing/liner  305 . When removing the setting tool  1  ( FIG. 3D ), a top of the override  59  may engage a bottom of the body  26 , thereby carrying the expander assembly  25  with the mandrel  3 . 
     The expandable liner hanger  105  may include a tubular body made from a ductile material, such as a metal or alloy, such as steel or stainless steel. The hanger may include one or more seals  105   a  disposed around an outer surface of the body. The seals  105   a  may be made from a soft material, such as lead or a polymer, such as an elastomer. The hanger may have teeth  105   b  embedded in the one or more of the seals  105   a  for engaging an inner surface of the previously installed casing/liner and/or supporting the seals  105   a . Alternatively, a hard material  705   b  (see  FIG. 7 ) may be disposed along an outer surface of the hanger and/or the seals  105   a  to penetrate an inner surface of the previously installed casing or liner, thereby securing the hanger  105  to the casing or liner. The hard material may be a ceramic, such as a carbide, such as tungsten carbide and disposed on the seals as dust and/or disposed on the hanger as teeth or blades. 
     The liner assembly  100  may be longitudinally and rotationally coupled to the mandrel  3  by the latch assembly  50 . The latch assembly  50  may include a piston  51 , a stop  52 , a release  53 , a collet  54 , a cap  55 , a retainer  56 , a biasing member, such as a spring  57 , one or more frangible members, such as shear screws  58 , an override  59 , a body  60 , one or more fasteners  61   a,b , and a catch  62 . Alternatively, the latch assembly  50  may include dogs (see dogs  77 ) instead of a collet. 
     The override  59  and the body  60  may each be tubular, have a bore therethrough, and include a threaded coupling at each end. The override  59  may be longitudinally and rotationally coupled to the mandrel  3  by one of the threaded couplings at a top thereof and one or more fasteners, such as set screws, and longitudinally and rotationally coupled to the body  60  by one of the threaded couplings and one or more fasteners, such as set screws  61   a . The body  60  may be longitudinally coupled to a seat  95  by one of the threaded couplings at a bottom thereof. Seals, such as o-rings, may be disposed between the override  59  and the mandrel  3 , between the override and the body  60 , and between the body and the seat  95 . The release  53  may be longitudinally and rotationally coupled to the override  59  by a threaded connection and one or more frangible members (not shown), such as shear screws. The threaded connection may be oppositely oriented (i.e. left-hand) relative to other threaded connections of the setting tool  1 . The release  53  may be longitudinally biased away from the override  59  by engagement of the spring  57  with fasteners  61   b.    
     The collet  54  may have a plurality of fingers each having a profile formed at a bottom thereof. The fingers  54   f  may engage a corresponding profile formed in an inner surface of the adapter  115 . The collet  54 , case  56 , and cap  55  may be longitudinally movable relative to the body  60  between the stop  52  and a top of the piston  51 . When weight of the liner assembly  100  is applied to the collet  54 , the collet may move downward along the body  60  until the fingers seat against a profile  95   a  formed in a top of the seat  95 , thereby longitudinally coupling the liner assembly  100  to the setting tool  1 . Keys  53   k  and keyways may be formed in an outer surface of the release  53 . The keys  53   k  and keyways may engage respective keyways and keys  115   k  formed in a top of the adapter  115 , thereby rotationally coupling the liner assembly  100  and the setting tool  1 . 
     The piston  51  may be fluidly operable to release the fingers  54   f  when actuated by a predetermined pressure. The piston  51  may be longitudinally coupled to the body  60  by the shear screws  58 . Once the liner hanger  105  has been expanded into engagement with the casing/liner  305  (see  FIG. 3C ) and weight of the liner assembly is supported by the liner hanger  105  and/or setting the liner  125  onto a bottom of the wellbore  300 , fluid pressure may be increased. The fluid pressure may push the piston  51  and fracture the shear screws  58 , thereby releasing the piston  51 . The piston  51  may then move upward toward the collet  51  until the piston  51  abuts a bottom of the collet  54 . The piston  51  may continue upward movement while carrying the collet  54  (and fingers  54   f ), case  56 , and cap  55  upward until a bottom of the release abuts the fingers  54   f , thereby pushing the fingers  54   f  radially inward. The catch  62  may be a split ring biased radially inward and disposed between the collet  54  and the case  56 . The body  60  may include a recess formed in an outer surface thereof. During upward movement of the piston  51  and members  54 - 56 , the catch  62  may align and enter the recess, thereby forming a downward stop preventing reengagement of the fingers  54   f . Movement of the piston and members  54 - 56  may continue until the cap  55  abuts the stop  52 , thereby ensuring complete disengagement of the fingers  54   f.    
     In the event that the liner assembly  100  becomes stuck in the wellbore  300  during run-in, the override  59  may be operated to release the fingers  54   f  from the liner assembly  100 . The override  59  may be operated by setting down weight of the run-in string  685  onto the liner assembly  100 , thereby moving the collet  54  upward along the body  60  and the fingers  54   f  from engagement with the profile  95   a . The run-in string may then be rotated, thereby rotating the override, fracturing the shear screws, and freeing the release from the override. The spring  57  may then move the release  53  toward the fingers  54   f  until the release  53  disengages the fingers  54   f  from the adapter. 
     The seal assembly  75  may include a lock  76 , a plurality of dogs  77 , dog retainer  78 , a cap  79 , fasteners, such as screws  80 , a catch  81 , a body  82  and one or more seal stacks  83   a,b . Each of the seal stacks  83   a,b  may include first and second end adapters (not shown), one or more first seals (not shown), a center adapter (not shown), and one or more second seals (not shown). The first seals may be directional (i.e., chevron rings), and may be disposed between the first end adapter and the center adapter. The second seals may be directional and disposed between the center adapter and the second end adapter with an orientation opposing the first seals. The body  82  may be tubular, have a bore therethrough, and include a threaded coupling at each end. The body  82  may be longitudinally coupled to the housing  214  by one of the threaded couplings at a top thereof and longitudinally coupled to the catch  81  by one of the threaded couplings and one or more fasteners, such as set screws. A seal, such as an O-ring, may be disposed between the body  82  and the catch  81 . The dogs  77  may be radially movable between an extended position and a retracted position. The dogs  77  may be disposed in respective recesses formed in the dog retainer  78  and a lip of each dog may engage a respective lip of the retainer  78  in the extended position, thereby keeping the dogs  77  disposed in the recesses. 
     The dogs  77  may be held in the extended position by abutment of protrusions of a profile formed in an inner surface of the dog with respective protrusions of a profile formed in an outer surface of the lock  76 . The dogs  77  may engage a groove formed in an inner surface of the adapter  115  in the extended position, thereby longitudinally coupling the dogs and the adapter. Each screw  80  may be received by a threaded opening formed through the retainer  78 . An end of each screw  80  may extend into a respective slot formed through the lock  76 , thereby coupling the lock and the retainer while allowing limited longitudinal movement therebetween. The cap  79  may be longitudinally coupled to the block retainer  78  by a threaded connection. Inner seal stack  83   a  may be disposed radially between the dog retainer and the body and longitudinally between a lower surface of the cap and a shoulder formed in the dog retainer. Outer seal stack  83   b  may be disposed radially between the dog retainer and the adapter  115  and longitudinally between a bottom of the cap and a shoulder formed in the dog retainer. The seal stacks  83   a,b  may fluidly isolate a bore of the liner  125  from an annulus formed between the setting tool  1  and the rest of the liner assembly  100 . 
     To release the lock  76  (see  FIG. 3D ), the body  82  may be moved upward carrying the catch  81  toward the lock  76  until a top of the catch  81  abuts a bottom of the lock and pushes the lock  76  upward toward the dog retainer  78  until recesses in the lock profile align with protrusions in the dog profile. A lower portion of the body  82  may include one or more grooves formed in an outer surface thereof for pressure equalization as the catch moves toward the lock. Alignment of the profiles allows the dogs to move from the extended position to the retracted position, thereby freeing the dogs from the adapter  115 . 
     The setting tool  1  may further include the seat  95 . The seat  95  may have a tapered inner surface  95   s  for receiving a ball or plug (not shown) and one or more ports  95   p  formed radially therethrough. The ports  95   p  may be isolated from the setting tool-adapter annulus by seals, such as O-rings, disposed between the seat and the adapter  115  and longitudinally straddling the ports  95   p . The ball or plug may be deployed as a safeguard or in response to failure of the isolation valve  200 . The ball may be released from the surface a predetermined distance behind the top plug (se  FIG. 3A ) so that the ball may be substantially pumped to the seat  95  by the displacement fluid (the ball may have to free fall a small depth once the top plug has seated against the wiper). Alternatively, should the isolation valve  200  fail, a plug may be delivered to the seat via wireline (not shown) or the ball may be deployed after the top plug has seated by free-falling to the seat  95 . As with the isolation valve  200 , landing of the ball or plug may fluidly isolate the mandrel bore from the liner bore. When the setting tool is being removed from the liner assembly  100  and the seat is removed from the liner assembly, the port seals may no longer engage a sealing surface due to the larger inside diameter of the previously installed casing or liner, thereby opening the ports  95   p . The ports  95   p  may then provide fluid communication between the setting tool bore and the wellbore, allowing drainage of the displacement fluid from the setting tool  1  and the run-in string  685  as the setting tool  1  travels to the surface. A bottom of the seat  95  may be longitudinally coupled to the housing  201  by a threaded connection. 
     The wiper assembly  150  may include a body  151 , a wiper  152 , and one or more frangible members, such as shear screws  153 . The body  151  may be longitudinally coupled to the catch  81  by the shear screws  153 . The body  151  may be tubular and have a profile  151   p  formed along an inner surface thereof for receiving a top plug  320  (see  FIG. 3A ). The top plug  320  may include a latch for engaging the profile  151   p . Additionally, the wiper assembly  150  may be a top wiper assembly and the setting tool may further include a bottom wiper assembly (not shown). The bottom wiper assembly may be longitudinally coupled to the body  151  by shear screws and have an inner diameter less than an inner diameter of the top wiper assembly  150 . In this manner a bottom plug (not shown) may be deployed before the cement is pumped for isolating the cement from circulation fluid and may be pumped through the body  151  and seat in the bottom wiper assembly. The bottom plug may include a diaphragm or valve. 
       FIG. 2  is a cross-section of the isolation valve  200 . The isolation valve may be longitudinally coupled to the mandrel  3  by a threaded connection. The isolation valve may include one or more housings  201 , 208 , 211 , 214 , one or more seals, such as o-rings  202 , 204 , 207 , 212 , one or more frangible members, such as shear screws  203  and rupture disk  216 , a piston  205 , a retaining rod  206 , one or more nuts  209 , one or more locator rings  210 , a valve member such as a flapper  213 , and one or more biasing members, such as springs  215 , 218 , and one or pins  217 ,  219 . Alternatively, the valve member may be a ball (not shown). 
     The piston  205  may be longitudinally coupled to the flapper  213  via the retaining rod  206 . The piston  205  may be longitudinally coupled to the retaining rod  206  via the pins  217 . The piston  205  may be biased away from the flapper  213  by spring  215  and longitudinally and rotationally coupled to the housing  208  by shear screws  213 . The retaining rod  206  may hold the flapper  213  in the open position. The flapper  213  may be biased towards the closed position by the spring  218  disposed on a mount, such as the pin  219 . A chamber housing the piston  205  and the spring  215  may be sealed at the surface with air at atmospheric pressure. In operation, when it is desired to close the flapper  213 , pressure may be increased in bores of the housings  201 , 208 , 211 , 214  until a predetermined pressure is reached. The rupture disk  216  may then fracture, thereby providing fluid communication between the housing bores and a bottom of the piston  205 . The resulting fluid force may fracture the shear screws  203  and (along with the spring  215 ) move the piston  205  away from the flapper  213 , thereby allowing the flapper  213  to close. 
       FIGS. 3A-D  illustrate installation of the liner assembly  100 . In operation, the setting tool  1 , liner assembly  100 , and wiper assembly  150  may be run into the wellbore  300  until the liner hanger  105  overlaps an end of the previously installed casing or liner  305  distal from the surface. A bottom of the liner  125  may or may not rest on a bottom of the wellbore. Prior to run-in, fluid, such as drilling mud, may be circulated to ensure that all of the cuttings have been removed from the wellbore. A surge reduction valve (not shown), if used, may be closed. Circulation may then be established by pumping fluid, such as drilling mud, down the run-in string and up the liner annulus. The liner assembly  100  may be reciprocated and/or rotated during circulation. If auto-fill equipment (not shown) is used, it may be released. If a bottom wiper assembly (not shown) is used, then the bottom plug may be launched. 
     Cement slurry  315  may then be pumped from the surface into the run-in string. The liner assembly  100  may be reciprocated and/or rotated during injection of the cement. A spacer fluid (not shown) may be pumped in ahead of the cement  315 . Once a predetermined quantity of cement  315  has been pumped, a top plug  320  may be pumped down the run-in string using a displacement fluid  310 , such as drilling mud. The bottom plug may seat in the bottom wiper assembly, free the bottom wiper assembly from the setting tool, and land in the float collar/shoe. The diaphragm may then rupture or the valve may open due to a density differential between the cement and the circulation fluid and/or increased pressure from the surface. 
     Pumping of the displacement fluid  310  may continue and the top plug  320  may seat in the wiper body  151 , thereby closing the bore through the wiper body  151  ( FIG. 3A ). The displacement fluid  310  may have a density substantially less than the density of the cement, thereby placing the liner  125  in compression. A latch of the plug  320  may engage the profile  151   p  and hydraulic pressure may fracture the shear screws  153 , thereby freeing the wiper assembly  150  and the plug  320 . The wiper/plug  150 ,  320  may then be pumped down the liner  125 , thereby forcing the cement  315  through the liner and out into the liner annulus. Pumping may continue until the wiper/plug  150 ,  320  seat against a landing or float collar (not shown), thereby indicating that the cement  315  is in place in the liner annulus. 
     The pressure may then be increased until the rupture disk  216  in the isolation valve  200  fractures, thereby moving the piston  205  and allowing the flapper  213  to close ( FIG. 3B ). The flapper  213  may isolate the mandrel bore from the liner bore. Pressure may then be increased to fracture the shear screws  14   b  and operate the pistons  11   a,b , thereby pushing the expander assembly  25  through the expandable liner hanger  105  ( FIG. 3C ). Once the hanger  105  is expanded into engagement with the previously installed casing or liner  305 , the latch assembly  50  may be released from the liner assembly  105  and the setting tool  1  removed ( FIG. 3D ). Before retrieval to the surface, the setting tool  1  may be raised and fluid, such as drilling mud, may be reverse circulated (not shown) to remove excess cement above the hanger before the cement sets. 
       FIG. 4  is a cross-section of an isolation valve  400 , according to another embodiment of the present invention. The isolation valve  400  may be used instead of the isolation valve  200 . The isolation valve  400  may include one or more housings  401 , 409 , 412 , 416 , 419 , 422 , one or more seals, such as o-rings  402 , 403 , 405 , 408 , 420 , one or more plugs  404 , one or more frangible members, such as shear screws  413 , one or more pistons  406 , 410 , an actuator  414 , a retaining rod  415 , a choke  407 , one or more nuts  417 , one or more locator rings  418 , a valve member, such as a flapper  421 , and one or more biasing members, such as springs  411 , 424 , and  218  (see  FIG. 2B ), one or more check valves  423 , and one or pins  217 ,  219  (see  FIGS. 2A and 2B ). 
     A top of the piston  405  may be in fluid communication with a bore of the housings  401 ,  416  via fluid path  430  defined between the housings  401 ,  416 . A chamber housing spring  411  may be in fluid communication with the liner annulus via vent  432 . A hydraulic fluid, such as oil, may be disposed between a shoulder  406   s  of the piston  406  and a top of the piston  410 . The housing  409  may include fluid ports  409   a,b  longitudinally formed therethrough. The fluid ports  409   a,b  may provide limited fluid communication between an upper hydraulic chamber formed between the shoulder  406   s  and a top of the housing  409  and a lower hydraulic chamber formed between a bottom of the housing  409  and the top of the piston  410 . 
     The check valve  423  may be disposed in the path  409   b  and operable to prevent flow of the hydraulic fluid from the upper hydraulic chamber to the lower hydraulic chamber and allow flow from the lower hydraulic chamber to the upper hydraulic chamber. The choke  407  may be disposed in the path  409   a  and operable to restrict hydraulic flow from the upper hydraulic chamber to the lower hydraulic chamber. The choke  407  may also restrict flow from the lower hydraulic chamber to the upper hydraulic chamber but this restriction may be negated by the open check valve  423 . The piston  410  may be longitudinally coupled to the piston  406  by incompressibility of the hydraulic fluid. A bottom of the piston  410  may be in fluid communication with the liner annulus via the vent  432 . The piston  410  may be biased toward the housing  409  by the spring  411 . 
     The actuator  414  may be longitudinally coupled to the flapper  421  via the retaining rod  415 . The actuator  414  may be longitudinally coupled to the retaining rod  415  via the pins  217 . The retaining rod  415  may hold the flapper  421  in the open position. The flapper  421  may be biased towards the closed position by the spring  218  disposed on a mount, such as the pin  219 . The actuator  414  may be longitudinally coupled to the housing  416  by the shear screws  413 . 
       FIGS. 4A-C  illustrate operation of the isolation valve  400 . Once pressure in the bore of the housings  401 ,  416  exceeds pressure in the liner annulus by an amount sufficient to overcome the bias of the spring  411  (threshold pressure), the piston  406  begins to move longitudinally downward toward the housing  409  ( FIG. 4A ). Since movement of the piston is dampened by the choke  407 , the increased pressure must be sustained for a predetermined period of time, else once the pressure is reduced, the biasing member will return the piston  406  to the position of  FIG. 4A . Once sustained threshold pressure has been applied to the top of the piston  406 , a bottom of the piston  406  abuts a top of the actuator  414  and fractures the shear screws  413  ( FIG. 4B ). Pressure may be then reduced to the annulus pressure or relieved at the surface, thereby allowing the spring  411  to return the piston  406  to the position of  FIG. 4A . The spring  424  may then longitudinally move the actuator  414  and retaining rod  420  longitudinally upward away from the flapper  421 , thereby releasing the flapper and allowing the spring  218  to close the flapper ( FIG. 4C ). 
     The choke  407  may time the movement of the piston  406  so that threshold pressure must be sustained for the piston to reach the actuator  414 . For example, when running the liner assembly  100  into the wellbore, a surge pressure may exceed the threshold pressure but may not be sustained to fully move the piston  406 . However, once the top plug  320  seats against the wiper  315 , then the threshold pressure may be applied for the sustained period. If pressure is relieved from the run-in string at the surface, the flapper  421  may allow annulus pressure to also be relieved. However, once pressure is reapplied to set the liner hanger  105 , the flapper  421  will close and isolate the liner  125  from setting pressure applied to the setting tool  1 . 
       FIG. 4D  illustrates an alternative embodiment of the isolation valve  400 . In this alternative, the piston  406  is initially longitudinally restrained by one or more frangible members, such as shear pins  455 . The shear pins  455  may keep the piston  406  from moving until a predetermined pressure has been reached. The shear pins  455  may avoid unintentional operation of the piston  406  during circulation and cementing operations. 
       FIG. 5  is a cross-section of an isolation valve  500 , according to another embodiment of the present invention. The isolation valve  500  may be used instead of the isolation valve  200 . The isolation valve may include one or more housings  501 , 510 , 512 , 513 , 518 , 521 , 524  one or more seals, such as o-rings  503 , 504 , 506 , 509 , 522  one or more plugs  505 , one or more frangible members, such as shear screws  514 , one or more pistons  507 , 511 , an actuator  515 , 516 , a retaining rod  517 , a choke  508 , one or more nuts  519 , one or more locator rings  520 , a valve member such as a flapper  523 , and one or more biasing members, such as springs  502 , 526 , and  218  (see  FIG. 2B ), one or more check valves  525 , and one or pins  217 ,  219  of (see  FIGS. 2A and 2B ). In operation, the spring  502  is used to slowly engage a release mechanism so the running of the liner and cementing of the liner can be completed before the valve closes. 
     The actuator may include a head  516  and a ring  515 . The head  516  and the ring  515  may be longitudinally and rotationally coupled to the housing  518  by the shear screws  514 . The head  516  may be longitudinally coupled to the flapper  523  via the retaining rod  517 . The head  516  may be biased away from the flapper  523  by the spring  526 . The head  516  may be longitudinally coupled to the retaining rod  517  via the pins  217 . The retaining rod  517  may hold the flapper  523  in the open position. The flapper  523  may be biased towards the closed position by the spring  218  disposed on a mount, such as the pin  219 . 
     A top of the piston  507  may be in fluid communication with a bore of the housings  501 ,  518  via fluid path  530  defined between the housings  501 ,  518 . A hydraulic fluid, such as oil, may be disposed between a shoulder  507   s  of the piston  507  and a top of the piston  511 . The housing  510  may include fluid ports  510   a,b  longitudinally formed therethrough. The fluid ports  510   a,b  may provide limited fluid communication between an upper hydraulic chamber formed between the shoulder  507   s  and a top of the housing  510  and a lower hydraulic chamber formed between a bottom of the housing  510  and the top of the piston  511 . 
     The check valve  525  may be disposed in the path  510   b  and operable to prevent flow of the hydraulic fluid from the upper hydraulic chamber to the lower hydraulic chamber and allow flow from the lower hydraulic chamber to the upper hydraulic chamber. The choke  508  may be disposed in the path  510   a  and operable to restrict hydraulic flow from the upper hydraulic chamber to the lower hydraulic chamber. The choke  510   a  may also restrict flow from the lower hydraulic chamber to the upper hydraulic chamber but this restriction may be negated by the open check valve  525 . The piston  511  may be longitudinally coupled to the piston  507  by incompressibility of the hydraulic fluid. The piston  507  may be biased longitudinally downward toward the housing  510  by the spring  502 . A chamber  535  between the housing  518  and the head  516 , a chamber  537  between the housings  513 ,  518 , and a chamber  539  between the housing  512  and the piston  507  may be sealed at the surface with air at atmospheric pressure. 
     In operation, once the isolation valve  500  is assembled, the spring  502  may begin to move the piston  507  longitudinally downward toward the flapper  523 . Since movement of the piston  507  is dampened by the choke  508 , the piston  507  may require a predetermined period of time before a bottom of the piston  507  abuts a top of the ring  515  and fractures the shear screws  514 . The predetermined period may be selected so the liner assembly  100  may be run into the wellbore and cemented before the flapper  523  closes. 
     Alternatively, the spring  502  may be omitted and fluid pressure exerted on a top of the piston via flow path  530  may be used to operate the piston  507 . 
       FIG. 6  is a cross-section of an isolation valve  600 , according to another embodiment of the present invention. The isolation valve  600  may be used instead of the isolation valve  200 . The isolation valve  600  may include one or more housings  601 , 607 , 610 , 612 , 617 , 620 , 623 , 630 , a pick  602 , one or more seals, such as o-rings  604 , 605 , 608 , 611 , 621 , one or more plugs  606 , one or more frangible members, such as shear screws  613  and rupture disk  603 , one or more pistons  609 , an actuator  614 , 615 , a retaining rod  616 , one or more nuts  618 , one or more locator rings  619 , a valve member such as a flapper  622 , one or more biasing members, such as springs  624 ,  218  (see  FIG. 2B ), one or pins  217 ,  219  (see  FIGS. 2A and 2B ), and an electronics package  650 . 
     The actuator may include a head  615  and a ring  614 . The head  615  and the ring  614  may be longitudinally and rotationally coupled to the housing  617  by the shear screws  613 . The head  615  may be longitudinally coupled to the flapper  622  via the retaining rod  616 . The head  615  may be biased away from the flapper  622  by the spring  624 . The head  615  may be longitudinally coupled to the retaining rod  616  via the pins  217 . The retaining rod  616  may hold the flapper  622  in the open position. The flapper  622  may be biased towards the closed position by the spring  218  disposed on a mount, such as the pin  219 . 
     An upper chamber between housings  601  and  630 , an intermediate chamber between a bottom of the housing  606  and a top of the piston  609 , and a lower chamber between a shoulder  609   s  of the piston  609  and a top of the housing  612  may be sealed at the surface with air at atmospheric pressure. The housing  606  may have a first fluid port  606   a  extending radially and longitudinally between a bore therethrough to the upper chamber. The rupture disk  603  may seal the first fluid port  606   a . The housing  606  may further have a second fluid port  606   b  longitudinally extending therethrough between the upper and intermediate chambers. The housing  617  may have a vent  632  formed radially therethrough providing fluid communication between a bore formed therethrough and a chamber  635  between the housing  617  and the head  615 . The chamber  635  may be in fluid communication with a chamber  637  between the housings  612 ,  617  via flow path  634  formed between ring  614  and housing  617 . 
       FIG. 6A  illustrates the electronics package  650 . The electronics package  650  may include a pressure sensor  652 , a signal amplifier  654 , a noise filter  656 , a signal detector  658 , a microprocessor  660 , a battery pack  662 , and a solenoid  664 . Pressure pulses transmitted from the surface to the isolation valve  600  via the run-in string may be transformed by the pressure sensor  652  into an electrical signal. The electrical signal may then be amplified by the signal amplifier  654  and filtered by the noise filter  656 . The filtered signal may then be demodulated by the signal detector  658  into a format usable by the microprocessor  660 . The demodulated signal may be analyzed by the microprocessor  660  to determine if the signal matches a predetermined instruction signal for closing the flapper  622 . If so, then the microprocessor may energize the solenoid, thereby longitudinally moving the pick  602  to fracture the rupture disk  603 . The pick  602  may then be retracted from the fractured rupture disk  603  by a spring (not shown) or reversing polarity to the solenoid. 
     Once the rupture disk  603  has been fractured, circulation fluid from the bore of the isolation valve  600  may flow through the port  607   a  into the upper chamber. Fluid may then flow from the upper chamber through the port  607   b  into the intermediate chamber, thereby moving the piston  609  longitudinally downward toward the flapper  622 . Since lower chamber was sealed at the surface, minimal pressure may be exerted on the shoulder  609   s . The piston  609  may move until a bottom of the piston  609  abuts the ring  614  and fractures the shear screws  613 , thereby releasing the head  615 . The spring  624  may then move the head  615  (and the rod  616 ) longitudinally upward away from the flapper  622 , thereby releasing the flapper. The spring  218  may then close the flapper  622 , thereby fluidly isolating the liner  125  from the setting tool  1 . The setting tool  1  may then be operated and the liner hanger  105  expanded. 
       FIG. 6B  illustrates surface equipment for generating pressure pulses. The pressure pulses may be generated at the surface using the displacement fluid  310 . The displacement fluid  310  may be stored in a surge tank  677 . The surge tank  677  may include a fluid barrier, such as a diaphragm  678 , separating a chamber of the tank  677  into a displacement fluid chamber and a gas chamber. A fluid line  684  may be in communication with a mud pump of the rig to fill the displacement fluid chamber. A gas line  682  may be in fluid communication with a gas source, such as a portable cylinder, and include a pressure regulator for filling and maintaining the gas chamber at a predetermined pressure. The gas  679  may be nitrogen. The pressure pulses may be applied and released from a bore of the run-in string  685  after the top plug  320  and the wiper  325  have landed in the float or landing collar. The pressure pulses may be generated by opening an inlet control valve, such as a solenoid operated ball valve  680   i , thereby providing fluid communication between the displacement fluid chamber of the surge tank  677  and the run-in string  685 . The valve  680   i  may be electrically, pneumatically, or hydraulically operated. After a predetermined period of time, the valve  680   i  may be closed while opening an outlet control valve  680   o , thereby relieving fluid pressure from the run-in string to a mud pit or tank (not shown) of the rig. Control of the valves  680   i,o  may be performed by a computer or programmable logic controller (PLC)  690  located at the surface to generate the predetermined instruction signal to close the isolation valve  600 . 
       FIG. 6C  illustrates the computer/PLC  690 . The computer/PLC may be disposed in an operator interface (not shown), such as a console. The interface may include indicator lights R, G to provide visual feedback to the operator. A first light, such as a green light G, may indicate that the computer/PLC is ready to transmit the instruction signal. The console may further include a pushbutton operable to signal the computer to begin transmission of the instruction signal. A second light, such as a red light R, may indicate that the computer is transmitting the instruction signal. The computer/PLC  690  may be in electrical communication with solenoids of the valves  680   i,o.    
     Alternatively, instead of mud pulse, the electronics package  650  may include an electromagnetic (EM) receiver or transceiver (not shown) or any other wireless telemetry system. An EM telemetry system is discussed in U.S. Pat. No. 6,736,210, which is hereby incorporated by reference in its entirety. 
       FIG. 7  is a cross-section of a portion of a setting tool  700  and a liner assembly, according to another embodiment of the present invention. The remaining portion of the setting tool  700  and liner assembly may be similar to the setting tool  1  and liner assembly  100  except that the PBR  710  may be moved to between the expandable liner hanger and the run-in string and the isolation valve  200  may be omitted. 
     The setting tool  700  may include a mandrel  703 , a piston  711 , a damping chamber  714 , a choke  716 , an atmospheric chamber  718 , a piston actuator, and an expander assembly  725 . The mandrel  703  may be a tubular member including a threaded coupling for connecting to the run-in string  685  and a longitudinal bore therethrough. Although shown as one piece, the mandrel  703  may include a plurality of pieces connected by threaded connections and seals to facilitate manufacture and assembly thereof. The piston  711  may be a tubular member having a longitudinal bore therethrough. Although shown as one piece, the piston  711  may include a plurality of pieces connected by threaded connections to facilitate manufacture and assembly thereof. The piston  711  may be disposed between inner and outer walls of the mandrel  703 . The piston  711  may include a head formed at a top thereof. One or more seals, such as O-rings, may be disposed between an inner surface of the head and the inner wall and between an outer surface of the head and the outer wall. 
     The chambers  714 ,  718  may be formed between the piston  711  and the outer wall of the mandrel  703 . The mandrel may include a partition dividing the chambers  714 ,  718 . A seal, such as an O-ring may be disposed between the piston  711  and the partition. One or more chokes  716  may be disposed in the partition. The chokes  716  may provide limited fluid communication between the chambers  714 ,  718 , thereby damping longitudinal movement of the piston. The chambers  714 ,  718  may be sealed at the surface under atmospheric pressure. The damping chamber  714  may be filled with a hydraulic fluid, such as oil. The atmospheric chamber  718  may be filled with a gas, such as air. 
     The expander assembly  725  may include an actuator  726 , one or more frangible members, such as shear screws  727 , a pusher  728 , a mandrel  729 , a collet  730 , a biasing member, such as a spring  731 , one or more retainers  732 , and a spacer  733 . The expander mandrel  729  may be tubular and disposed along an outer surface of the setting mandrel  703  so that the expander mandrel is longitudinally movable relative to the setting mandrel  703 . The expander mandrel may include a shoulder formed at a bottom thereof. The collet  730  may be disposed along an outer surface of the expander mandrel and include a base ring formed at a bottom thereof. 
     The spring may be disposed between the base ring and the expander mandrel shoulder, thereby biasing the collet  730  longitudinally away from the expander mandrel shoulder. The collet  730  may include a plurality of radially split cones  730   c  each extending longitudinally from the base ring. The cones  730   c  may be radially split so that the cones may be radially movable between an expanded position (shown) and a retracted position. An inner surface of the cones  730   c  may be held in the expanded position by abutment with the spacer  733 . An outer surface of the cones may abut the liner hanger  705 . A top of the cones  730   c  may abut a bottom of the pusher  728 . The spacer  733  may be longitudinally coupled to the actuator  726  by one or more fasteners, such as screws. The pusher  728  may be longitudinally coupled to the actuator  726  by the shear screws  727 . 
     The actuator  726  may be tubular and have a head formed at a top thereof. The actuator may further have one or more windows formed through a wall thereof. One of the retainers  732  may be disposed through each window. Each retainer may be received by a groove formed in an outer surface of the expander mandrel and fastened to the expander mandrel. Each retainer may also be disposed through a respective opening formed through a wall of the pusher. The retainers may be blocks and longitudinally couple the pusher to the mandrel. The windows may be sized to allow relative longitudinal movement of the actuator relative to the blocks should the shear screws fail. The collet  730  may have a recessed inner surface formed between the base ring and the cones  730   c  for receiving a lower portion of the actuator and the spacer  733  should the shear screws fail. The bottom shoulder of the piston may also include a recessed inner surface for receiving an upper portion of the expander mandrel should the shear screws fail. The actuator head may abut the bottom shoulder of the piston  711 . 
     In operation, longitudinal movement of the piston  711  may push the expander assembly  725  downward along the hanger  705 , thereby expanding the hanger into engagement with the previously set liner/casing. If the annulus between the hanger  705  and the liner/casing is sufficient, the hanger  705  may expand as forced by the expanded cones  730   c . However, if the annulus is insufficient, the reaction force may increase to fracture the shear screws  727 . As shown in  FIG. 7B , the actuator  726  and the spacer  733  may then be free to move longitudinally relative to the rest of the expander assembly, thereby moving the spacer  733  from the inner surface of the cones and replacing the spacer  733  with the outer surface of the actuator  726  which may have a reduced outer diameter. The reduced outer diameter may allow the cones to move radially inward to the retracted position. Movement of the actuator  726  may continue until a lower surface of the actuator head abuts a top of the pusher  728 , thereby resuming movement of the expander assembly  725  downward through the hanger  705 . The reduced outer diameter of the cones  730   c  may reduce the expanded outer diameter of the hanger  705  which may suitable for the smaller annulus. 
     As illustrated in  FIG. 7C , after expansion of the liner hanger  705  into engagement with an existing casing  735  or at some other point during operation of the setting tool  700 , when the expander assembly  725  is removed from the liner assembly the cones  730   c  are operable to collapse into an even further reduced outer diameter configuration. The spacer  733  may be releasably coupled to the actuator  726  by one or more frangible members, such as shear screws  734 . The cones  730   c , which are seated on the outer surface of the actuator  726 , may be forced against the end of the spacer  733  to shear the shear screws  734  and allow the cones  730   c  to move relative to the actuator  726 . The cones  730   c  may then be moved off of the actuator  726  outer surface until the cones  730  and the spacer  733  are seated on the outer surface of the mandrel  729 , thereby further reducing the outer diameter of the cones  730   c . In one embodiment, during retrieval of the expansion assembly  725 , a restriction, such as an inner diameter shoulder of a component of the liner assembly or a narrowed inner diameter portion of the existing casing  735  may engage the cones  730   c  and obstruct passage theretherough. An upward or pull force applied to the run-in string and/or the mandrel  703  may cause a reaction force to be applied to the cones  730   c  against the restriction. The reaction force may be transferred through the cones  730   c  and applied to the spacer  733  until the shear screws  734  release engagement with the actuator  726 . The reaction force may then move the cones  730   c  and the spacer  733  relative to the actuator  726  onto the outer surface of the mandrel  729 , thereby reducing the outer diameter of the cones  730   c  and allowing the expander assembly  725  to be moved past the restriction. 
       FIG. 7A  is an enlarged view of the piston actuator. The piston actuator may include the electronics package  650 , one or more heating coils  706 , one or more ports  708 , one or more retainers, such as fusible rods  715 , and a plug  712 . The ports may provide fluid communication between the wellbore and a first chamber formed in the mandrel  703 . The plug may be disposed in a passage between the first chamber and a second chamber in communication with a top of the piston head. The second chamber may be sealed at the surface under atmospheric pressure and be filled with a gas, such as air. One or more seals, such as O-rings, may be disposed between each plug and the passage. Each plug may be longitudinally restrained in the passage by a respective rod. 
     In operation, when the electronics package detects an instruction signal from the surface, the microprocessor may supply electricity to the heating coil, thereby heating the rod. The increased temperature of the rod may weaken the rod until hydrostatic pressure exerted on a top of the plug fractures the rod, thereby freeing the plug. The plug may be pushed into the second chamber by wellbore fluid, thereby opening the passage. Wellbore fluid may enter the second chamber through the open passage and exert hydrostatic pressure on the top of the piston head, thereby longitudinally moving the piston downward toward the expander assembly. The piston head may push the oil through the choke  716  and into the atmospheric chamber  718 , thereby controlling a rate of movement of the piston. As discussed above, movement of the piston may operate the expander assembly  725 , thereby setting the hanger  705 . Cementing may occur as discussed above in relation to  FIGS. 3A-3D . 
     Since the mud pulse signal can be varied, several difference devices can be operated down hole each with a unique signal, e.g. a surge reduction valve (see U.S. Pat. No. 6,834,726, which is hereby incorporated by reference in its entirety) that allows for faster run in of the liner before cementing can be closed prior to cementing; setting the liner hanger with a vacuum operated jack system—note several vacuum chambers can be operated in series if the hydrostatic pressure is too low for a single vacuum chamber jack to set the liner hanger; releasing the running tool from the liner hanger after the liner hanger is set; etc. 
       FIG. 8A  illustrates a radio-frequency identification (RFID) electronics package  800 , according to another embodiment of the present invention.  FIG. 8B  illustrates an active RFID tag  850   a .  FIG. 8C  illustrates a passive RFID tag  850   p . The RFID electronics package  800  may be used instead of the electronics package  650  in the isolation valve  600  and/or the electronics package  750  in the setting tool  700 . The electronics package  800  may communicate with a passive RFID tag  850   p  or an active RFID tag  850   a . Either of the RFID tags  850   a,p  may be embedded in the top plug  320  so that the electronics package  800  may detect passage of the top plug  320  thereby. Alternatively, either of the RFID tags may be embedded in a ball, plug, bar or some other device used to initiate the release of a downhole valve. 
     The RFID electronics package  800  may include a receiver  802 , an amplifier  804 , a filter and detector  806 , a transceiver  808 , a microprocessor  810 , a pressure sensor  812 , battery pack  814 , a transmitter  816 , an RF switch  818 , a pressure switch  820 , and an RF field generator  822 . If the active RFID tag  850   a  is used, the components  816 - 822  may be omitted. 
     If a passive tag  850   p  is used, once the isolation valve  600  or setting tool  700  is deployed to a sufficient depth in the wellbore, the pressure switch  820  may close. The pressure switch may remain open at the surface to prevent the electronics package  800  from becoming an ignition source. The microprocessor may also detect deployment in the wellbore using pressure sensor  812 . The microprocessor  810  may delay activation of the transmitter for a predetermined period of time to conserve the battery pack  814 . The microprocessor may then begin transmitting a signal and listening for a response. Once the top plug is pumped into proximity of the transmitter  816 , the passive tag  850   p  may receive the signal, convert the signal to electricity, and transmit a response signal. The electronics package  800  may receive the response signal, amplify, filter, demodulate, and analyze the signal. If the signal matches a predetermined instruction signal, then the microprocessor  810  may monitor pressure for a predetermined threshold indicative that the top plug  320  has seated against the wiper and/or wait a predetermined period for the top plug to seat. Once the predetermined threshold is detected and/or the time period has passed, the microprocessor may close the isolation valve or operate the setting tool. 
     If the active tag  850   a  is used, then the tag  850   a  may include its own battery, pressure switch, and timer so that the tag  850   a  may perform the function of the components  816 - 822 . 
     Since the tags send out unique signals, multiple receivers may be used. For example one receiver may be used to close a surge reduction valve; another receiver may start a sequence leading to the operation of the setting tool  700  to set the liner hanger and release the running tool. 
       FIG. 9A  is a sectional view of an expandable liner system  900  disposed in a wellbore  910  proximate a lower end of a string of casing  920 , according to another embodiment of the present invention. The system  900  may include a liner assembly  925  and an expander assembly  950 . The expandable liner system  900  may be run-into the wellbore  910  using the run-in string  685 . The wellbore section below the casing  920  may be drilled without an underreamer. The liner assembly  925  may be set in the casing  920  by positioning an upper portion of the liner assembly  925  in an overlapping relationship with a lower portion of the casing  920 . Thereafter, the expansion assembly  950  may be employed to expand the liner assembly  925  into engagement with the casing  920  and the surrounding wellbore  910 . 
     The liner assembly  925  may include a tubular section  930  at an upper end thereof and a shaped or a corrugated liner section  935  disposed at the lower end thereof. It must be noted that the shape or corrugation of the liner section  935  is optional such that the liner section  935  is substantially cylindrical. Alternatively, the corrugated liner section  935  may be located at any position along the liner assembly  925 . A cross section of a suitable corrugated liner section may be found at FIG. 2G of U.S. Pat. No. 7,121,351, which is herein incorporated by reference in its entirety. The corrugated liner section  935  and the substantially cylindrical liner section  930  may be connected by a threaded connection or may be one continuous tubular body. The corrugated liner section  935  may be fabricated from a drillable material, such as aluminum or a pliable composite. The corrugated liner section  935  may have a folded wall having an initial inner diameter which may be reformed to define a larger second folded inner diameter and subsequently may be expanded to an even larger unfolded diameter. The corrugated liner section  935  may be folded or deformed prior to insertion into the wellbore  910 , to a non-tubular-shape, such as a hypocycloid, so that grooves are formed along the length of the corrugated liner section  935 . The grooves may be symmetric or asymmetric. 
     The liner assembly  925  may further include a shoe  940  at the lower end thereof. The shoe  940  may be longitudinally coupled to the corrugated portion, such as by a threaded connection. The shoe  940  may be a tapered or bullet-shaped and may guide the liner assembly  925  toward the center of the wellbore  910 . The shoe  940  may minimize problems associated with hitting rock ledges or washouts in the wellbore  910  as the liner assembly  925  is lowered into the wellbore. An outer portion of the shoe  940  may be made from steel. An inner portion of the shoe  940  may be made of a drillable material, such as cement, aluminum or thermoplastic, so that the inner portion may be drilled through if the wellbore is to be further drilled. A bore may be partially formed longitudinally through the shoe  940  and in fluid communication with one or more ports radially formed through the shoe. A sleeve  970  may be disposed in the bore and longitudinally movable between an open position exposing the ports and a closed position covering the ports, thereby fluidly isolating the ports from the bore. The sleeve  970  may be restrained in the open position by one or more frangible members  972 , such as shear screws. 
     Alternatively, the sleeve may have one or more ports formed radially therethrough and aligned with the shoe ports in the open position. The sleeve may be restrained in the open position by the threaded coupling between the valve  1000  and the shoe  940  and biased toward the closed position by a spring. Unthreading of the valve  1000  from the shoe  940  may release the sleeve, thereby allowing the spring to move the sleeve so that a solid portion of the sleeve covers the ports, thereby fluidly isolating the ports from the bore. 
     The expander assembly  950  may be disposed in the liner assembly  925 . The expander assembly  950  may include a tubular mandrel  955 . An upper end of the mandrel  955  may be connected to the work string  685  by a threaded connection and a lower end of the mandrel  955  may be releasably connected to the shoe  940 , such as by a threaded connection. The mandrel  955  may have a bore  990  formed therethrough in fluid communication with the surface of the wellbore  910  via a bore of the run-in string  685 . The mandrel  955  may support the liner assembly  925  during run-in. 
     The expander assembly  950  may further include a seal  960  longitudinally coupled to the mandrel  955  and engaged with an inner surface of the tubular portion  930 . The seal  960  may be fabricated from a pliable material, such as an elastomer. The seal  960  may act as a piston to move the expansion assembly  950  through the tubular section  930  upon introduction of fluid pressure below the seal  960 . Additionally or alternatively, tension from the run-in string may  685  be used to move the expansion assembly  950  through the tubular section  930 . 
     The expander assembly  950  may further include a two-position expander  975 . Detailed views of a suitable two-position expander may be found at FIGS. 3A and 3B of U.S. Pat. No. 7,121,351. The two-position expander may include a first assembly and a second assembly. The first assembly may include a first end plate and a plurality of first cone segments and the second assembly may include a second end plate and a plurality of second cone segments. Each end plate may be substantially round and have a plurality of T-shaped grooves formed therein. Each groove may match a T-shaped profile formed at an end of each cone segment. 
     An outer surface of each cone segment may include a first taper and an adjacent second taper. The first taper may have a gradual slope to form the leading shaped profile of the two-position expander  975 . The second taper may have a relatively steep slope to form the trailing profile of the two-position expander  975 . The inner surface of each cone segment may have a substantially semi-circular shape to allow the cone segments to slide along an outer surface of the mandrel  955 . A track portion may be formed on each first cone segment. The track portion may be used with a mating track portion formed on each second cone segment to align and interconnect the cone segments. The track portions may be a tongue and groove arrangement. 
     The first assembly and the second assembly may be urged longitudinally toward each other along the mandrel. As the first assembly and the second assembly approach each other, the first and second cone segments may be urged radially outward. As the first and second segments travel longitudinally along respective track portions, a front end of each second cone segment wedges the first cone segments apart, thereby causing the first shaped profiles to travel radially outward along the first shaped grooves of the first end plate. Simultaneously, a front end of each first cone segment wedges the second cone segments apart, thereby causing the second shaped profiles to travel radially outward along the second shaped grooves of the second end plate. The radial and longitudinal movement of the cone segments continues until each front end contacts a stop surface on each end plate, respectively. In this manner, the two-position expander  975  is moved from a retracted position having a first diameter to an expanded position having a second diameter that is larger than the first diameter. 
       FIG. 10  is a cross section of an electric valve  1000 . The expander assembly may further include the valve  1000 . The valve  1000  may include a body  1005  having a bore  1010  therethrough. The body  1005  may include an upper sub  1021 , a lower sub  1022 , and a sliding sleeve  1025  disposed therebetween. The upper and lower subs  1021 ,  1022  may include threaded couplings for connection to the mandrel  955  and shoe  940 , respectively. A series of ports  1015  may be formed through a wall of the body  1005  for fluid communication between the interior and the exterior of the valve  1000 . One or more seals  1030  may be provided to prevent leakage between the sleeve  1025  and the subs  1021 ,  1022 . The sliding sleeve  1025  may be longitudinally movable relative to the body  1005  for selectively opening and closing the ports  1015 . 
     The valve  1000  may further include an actuator  1045  for moving the sliding sleeve  1025 . The actuator  1045  may be a linear actuator. The valve may further include the RFID electronics package  800  for operating the actuator in response to instruction from a ball  995  having one of the RFID tags  850   p,a  embedded therein. Alternatively, the electronics package  650  may be used instead. The sub  1022  may include a ball seat  1040  disposed therein and longitudinally movable relative thereto for receiving the RFID ball  995 , thereby closing the bore  1010  and longitudinally moving a longitudinal end of the ball seat  1040  into engagement with the sleeve  970 . 
     The expandable liner system  900  may be lowered into the wellbore  910  while receiving displaced wellbore fluid through the shoe  940 . Alternatively or additionally, fluid may be circulated to remove debris from the wellbore. After the system  900  is positioned within the wellbore  910 , the RFID ball  995  may be pumped from the surface through the run-in string  685  and the bores  990 ,  1005  to the seat  1040 . Once the ball  995  has seated, fluid pressure may increase and cause the seat  1040  to push the sleeve  970 , thereby fracturing the shear screws  972  and closing the shoe ports. 
     The RFID ball  995  may include instructions for the electronics package  850  to open the ports  1015  after a predetermined time sufficient to sufficient for the sleeve  970  to close the shoe ports and/or after detecting a pressure sufficient to close the sleeve  970 . 
       FIG. 9B  is a sectional view illustrating the reforming or unfolding of the corrugated liner  935  to form a launcher. The launcher may be formed to house the unactuated two-position-expander  975  prior to expanding the liner assembly  925  into contact with the wellbore  910 . The mandrel  955  may be released from the shoe  940 , such as by rotation of the mandrel from the surface. Fluid may then be pumped from the surface through the bore  990  and into the liner assembly  925  via the open ports  1015 . As fluid pressure increases in the liner assembly  925 , the corrugated liner section  935  may start to reform or unfold from the folded diameter to the larger folded diameter due to the fluid pressure. In this manner, the launcher is formed in the liner assembly  925 . 
       FIG. 9C  is a sectional view of the expansion system  900  after positioning the two-position expander  975  in the launcher. After the launcher is formed, the fluid pressure below the seal  960  may be released by allowing fluid to exit through the tubular member  955 . The expander  975  may then be lowered into the launcher. The electronics package  850  may close the ports  1015  after a predetermined time sufficient to sufficient for the launcher to be formed and pressure to be relieved and/or after detecting the pressure sequence for forming the launcher and relieving pressure from the liner assembly. 
       FIG. 9D  is a sectional view of the expandable liner system  900  illustrating the expansion of the corrugated liner section  935 . Once the ports  1015  have been closed, pressure in the bore  990  may be increased to activate a hydraulic actuator (not shown). The hydraulic actuator may move the expander  975  from the retracted position to the expanded position. The hydraulic actuator may be similar to any of the hydraulic actuators used in any of the isolation valves or setting tools discussed herein. 
     The electronics package  850  may open the ports  1015  after a predetermined time sufficient for actuation of the expander  975  to the expanded position and/or after detecting pressure sufficient for actuation of the expander  975  to the expanded position. 
     Once the expander  975  has been moved to the expanded position and the ports  1015  have opened, additional fluid pressure may be introduced through the bore  990  and the ports  1015  and into the liner assembly  925  (below the seal  960 ) to move the expander assembly  950  relative to the liner assembly  925 . The two-position expander  975  may expand the corrugated liner section  935  from the folded diameter to the unfolded diameter. During expansion, the two-position expander  975  may “iron out” the crinkles in the corrugated liner section  935  so that the corrugated liner section  935  is substantially reformed into its initial, substantially tubular shape. Reforming and subsequently expanding allows further overall expansion of the corrugated liner section  935  than would be possible with a tubular shape. 
       FIG. 9E  is a sectional view of the expandable liner system  900  illustrating the expansion of the upper liner section  930 . Additional fluid may be introduced through the bore  990  and the ports  1015  and into the liner assembly  925  (below the seal  960 ) to continue the movement of the expansion assembly  950  relative to the liner assembly  925  until substantially the entire length of liner sections  930 ,  935  are expanded into contact with the surrounding wellbore  910  and the casing  920 . 
       FIG. 9F  is a sectional view of the completed wellbore  910 . Once the expander  975  has reached the bottom of the casing and expanded the overlapping liner into engagement with the bottom of the casing, the expander assembly  950  may be removed from the wellbore. A drill string (not shown) having a drill bit disposed on a lower end thereof may be deployed into the wellbore  910  and a lower portion of the liner  935  and the shoe  940  may be drilled through. Drilling of the wellbore  910  may then be continued. Cementing of the expanded liner assembly  935  may not be required. Alternatively, cement may be employed (before unfolding the corrugated portion and expanding the liner) to seal an annulus formed between the liner sections  930 , 935  and the surrounding wellbore  910 . 
       FIG. 11  illustrates an alternative expansion assembly  1150 , according to another embodiment of the present invention. Instead of the hydraulic actuator and valve  1000  used in the expansion assembly  950 , the expansion assembly may include an electric motor  1102  operated by the RFID electronics package  800 . The sleeve  970  may be replaced by a ball seat. The RFID ball  995  may then be pumped to the ball seat in the shoe. The electronics package  800  may then wait for the launcher to be formed and the expander  1175  to be moved into the launcher. The electronics package may then operate the motor  1102 . A portion of the expander  1175  may be longitudinally coupled to a gear (not shown), such as a worm gear, rotationally coupled to the motor  1102  such that rotation of the motor may move the portion of the expander longitudinally relative to another portion of the expander, thereby moving the expander between the retracted and expanded positions. 
     Alternatively, the corrugated portion  935  may be formed into the launcher using a lower cone (not shown) instead of or in addition to fluid pressure. Such an expansion system is illustrated in FIGS. 5A-D of the '351 patent. The alternative expansion system may utilize a hydraulic actuator to drive the lower cone into the corrugate portion  935  similar to  FIGS. 9A-9F  or the electric motor  1102 . Alternatively, the expansion system 550 illustrated in FIGS. 5A-D of the '351 patent may be used instead of the expansion systems  950 ,  1150  and modified by replacing the hydraulic valve 555 with the electric valve  1000  in order to selectively open and close hydraulic ports 520, 565. A second actuator may be added to the electric valve and the ball seat  1040  may be replaced by the sleeve that closes port 565 in FIGS. 5A-D of the '351 patent. The second actuator may then move the sleeve to close the port. The first actuator  1045  and the ports  1015  may replace the ports 520 of the hydraulic valve 555. The shoe 590 may be modified to include a ball seat for catching the RFID ball  995 . The rest of the operation of the modified expansion system may be similar to that of the expansion system 555 discussed and illustrated in the '351 patent. 
       FIG. 12  is a half section of a portion of a setting tool  1200 , according to another embodiment of the present invention. The remainder of the setting tool  1200  may be similar to the setting tool  1  or the setting tool  700  except that the isolation valve  200  may be omitted. 
     The setting tool  1200  may include a connector sub  1202 , a mandrel  1203 , a piston assembly  1210   a , a pump  1205 , and the electronics package  800 . The connector sub  1202  may be a tubular member including a threaded coupling for connecting to the run-in string  685  and a longitudinal bore therethrough. The connector sub  1202  may also include a second threaded coupling engaged with a threaded coupling of the mandrel  1203 . One or more fasteners, such as set screws may secure the threaded connection between the connector sub  1202  and the mandrel  1203 . The mandrel  1203  may be a tubular member having a longitudinal bore therethrough and may include one or more segments connected by threaded couplings. 
     The piston assembly  1210  may include piston  1211 , sleeves  1212 ,  1214 , housing  1215 , inlets  1216 , flow path  1209 , and ratchet assembly  1218 . The piston  1211  may be an annular member. An inner surface of the piston  1211  may engage an outer surface of the mandrel  1203  and may include a recess having a seal, such as an o-ring disposed therein. The inlet  1216  may be formed radially through a wall of the mandrel  1203  and provide fluid communication between a bore of the mandrel  1203  and an inlet of the pump  1205 . The sleeves  1212 ,  1214  may be longitudinally coupled to the piston  1211  by threaded connections. A seal, such as an o-ring, may be disposed between the piston  1211  and the sleeves  1212 . Each of the sleeves  1212 ,  1214  may be a tubular member having a longitudinal bore formed therethrough and may be disposed around the mandrel  1203 , thereby forming an annulus therebetween. The housing  1215  may be a tubular member, disposed around the mandrel  1203 , and longitudinally coupled thereto by a threaded connection. The housing  1215  may also be disposed about a shoulder formed in or disposed on an outer surface of the mandrel  1203 . Seals, such as o-rings, may be disposed between the housing  1215  and the mandrel  1203  and between the housing  1215  and the sleeve  1212 . 
     An end of the sleeve  1212  may be exposed to an exterior of the setting tool  1200 . The end of the sleeve  1212  may further include a profile formed therein or fastened thereto by a threaded connection. The profile may mate with a corresponding profile formed on an outer surface of the ratchet assembly  1218 , thereby longitudinally coupling the ratchet  1218  and the sleeve  1212  when the piston  1211  is actuated. The sleeve profile may engage the ratchet profile by compressing a spring, such as a c-ring. The c-ring may then expand to lock in a groove of the sleeve profile. Teeth formed on inner and outer surfaces of a lock ring of the ratchet assembly  1218  respectively engage corresponding teeth formed on an outer surface of the mandrel  1203  and an inner surface of a ring housing, thereby longitudinally locking the sleeve  1212  and thus the expander assembly  25  once the sleeve  1212  engages the ratchet assembly  1218 . 
     The pump  1205  and the electronics package may be disposed in the housing  1215 . The housing  1215  may include an inlet providing fluid communication between an inlet of the pump and the mandrel inlet. The housing may include an outlet providing fluid communication between an outlet of the pump and the flow path  1209 . The flow path  1209  may be formed between a recessed outer surface of the housing  1215  and an inner surface of the sleeve  1212 . The flow path  1209  may provide fluid communication between an outlet of the pump  1205  and a top of the piston  1211 . 
     In operation, one of the RFID tags  850   a,p  may be embedded in the top plug  320 . When the top plug passes the electronics package  800 , the microprocessor may receive an instruction signal from the tag  850   a,p . The microprocessor  810  may then wait a predetermined period of time and/or detect a pressure indicative of seating of the top plug against the float collar/shoe. The microprocessor may then supply electricity from the battery pack  814  to an electric motor of the pump  1205 . The pump may intake the displacement fluid from the mandrel bore via inlet  1216 , pressurize the displacement fluid, and discharge the pressurized displacement fluid into the flow path  1209 , thereby longitudinally moving the piston  1211  and setting the hanger  105 . 
     Additionally, the microprocessor  810  may detect setting of the hanger  105 , such as by including a switch (not shown) in the ratchet assembly that is closed when the sleeve  1212  engages the ratchet assembly or a flow meter or stroke counter in the pump  1205 . Once the microprocessor  810  detects setting of the hanger  105 , the microprocessor may cease the electricity supply to the pump  1205  and then intermittently supply and cease electricity to the pump  1205 , thereby creating pressure pulses that may be detected at the surface. Alternatively, the microprocessor may intermittently supply and cease reversed polarity electricity to the pump, thereby reversing flow through the pump. 
     If the latch  50  does not release upon application of pressure in the mandrel bore, then a ball may be dropped through the run-in string and the mandrel bore to the ball seat, thereby isolating the liner from the mandrel bore. Pressure may then be further increased to release the latch. 
     Alternatively, the latch  50  may include an actuator, such as any of the actuators discussed above for the isolation valves, setting tools, or expanders, and the electronics package  650 . The microprocessor  660  may detect the pressure pulses and operate the actuator, thereby releasing the latch  50  and allowing the setting tool  1200  to be removed from the wellbore. Instead of the electronics package  650 , the latch actuator may be in electrical communication with the microprocessor  850  via a wire (not shown) extending through a wall of the mandrel  1203 . 
       FIGS. 13A-D  illustrate a cross-section of an isolation valve  1300 , according to one embodiment of the invention. The isolation valve  1300  may be used instead of the isolation valve  200  described above. The isolation valve  1300  may include an upper adapter  1305 , a lower adapter  1395 , one or more couplers  1335 , one or more housings  1310 ,  1340 ,  1360 , one or more seals, such as o-rings  1301 ,  1302 ,  1303 ,  1306 ,  1307 ,  1308 ,  1309 ,  1311 ,  1312 ,  1313 ,  1314 , an upper piston member  1345 , a lower piston member  1347 , one or more sleeves  1315 , one or more pins  1317 ,  1319 , an upper retaining member  1320 , a lower retaining member  1325 , an upper seat  1321 , a lower seat  1327 , one or more valve members, such as a ball  1330 , and one or more biasing members, such as a spring  1350 , and one or more lug rings  1365 . 
       FIG. 13A  illustrates an open position of the isolation valve  1300 . The upper and lower adapters  1305 ,  1395  may include cylindrical members having flow bores therethrough to provide fluid communication to the isolation valve  1300 . In one embodiment, the upper and lower adapters  1305 ,  1395  include threaded ends configured to couple the isolation valve  1300  to the setting tool  1  and the wiper assembly  150 , respectively, as described above. In one embodiment, the isolation valve  1300  may be located in the setting tool  1  below the seal assembly  75 . The housing  1310  is coupled to the exterior surface of the upper adapter  1305  and the upper retaining member  1320  is coupled to the interior surface of the upper adapter  1305 , such that the sleeves  1315  are movably disposed between the housing  1310  and the upper retaining member  1320 . The sleeves  1315  may include cylindrically shaped bodies that are spaced apart and/or include grooves on their outer surfaces to provide fluid passages between the sleeves  1315  and the housing  1310  for fluid communication with one or more chambers  1329  disposed above the upper piston member  1345 . The upper and lower retaining members  1320 ,  1325  are configured to retain the ball  1330  within the housing  1310 , as well as retain the upper and lower seats  1321 ,  1327  into a sealed engagement with the outer surface of the ball  1330 , using one or more retainers  1323  (shown in  FIG. 13A-2 ). The ball  1330  includes a spherical shape having a cylindrical bore disposed therethrough. The one or more pins  1317  may be connected to the ball  1330  and may extend into a slot in the sleeve  1315 . The one or more pins  1319  may be connected to the sleeve  1315  and may extend into an opening in the ball  1330  (shown in  FIG. 13B-2 ). The sleeve  1315 , ball  1330 , and one or more pins  1317 ,  1319  are configured to provide rotational movement of the ball  1330  upon relative axial movement of the sleeve  1315 , thereby opening and closing fluid communication through the bore of the isolation valve  1300 . As the sleeve  1315  moves relative to the ball  1330 , the pin  1319  moves the ball  1330  and uses the pin  1317  located in the slot of the sleeve  1315  as a pivot point to rotate the ball  1330 . The bore of the ball  1330  is rotated into and out of alignment with the bore of the isolation valve  1300  to open and close fluid communication therethrough. 
     The lower end of the sleeve  1315  is coupled to the upper end of the upper piston member  1345  to allow limited relative movement therebetween and further permit the piston member  1345  to move the sleeve  1315  relative to the ball  1330 . The upper piston member  1345  is disposed within the housings  1310 ,  1340 , which are connected together using the coupler  1335 , such as with threaded connections. The upper piston member  1345  is coupled to the lower piston member  1347 , such as with a threaded connection. The lower piston member  1347  includes an upper shoulder that engages the spring  1350 , which is retained at its opposite end by the housing  1360 , which is coupled to the lower end of the housing  1340 . The spring  1350  is surrounded by the housing  1340  and is located within a chamber  1353  that is in fluid communication with the bore of the isolation valve  1300  via an opening  1349  in the wall of the lower piston member  1347 . The lower piston member  1347  extends through the housing  1360  and is coupled to the lower adapter  1395 . A nozzle  1343  may be disposed in the bore of the isolation valve  1300  above the opening  1349  to restrict the flow fluid therethrough prior to communicating with the opening  1349  and to create a pressure differential across the upper and lower ends of the isolation valve  1300 . 
     The upper piston member  1345 , the lower piston member  1347 , and the lower adapter  1395  are movable relative to the housings  1310 ,  1340 ,  1360 , and may be controlled using a J-slot arrangement that is provided between the housing  1360  and the lower piston member  1347 . The J-slot arrangement includes a channel  1363  machined in the inner wall of the housing  1360 . The channel  1363  is shown in  FIG. 13A-1  in a “rolled-out,” flattened orientation. This pattern is preferably formed three times in the wall of housing  1360  so that each complete J-slot cycle covers 120 degrees of arc of the inner surface of housing  1360 . The lower piston member  1347  includes a recessed shoulder that carries one or more rotatable lug rings  1365 . The lug rings  1365  include an annular ring base which carries a projecting lug portion thereon. 
       FIG. 13A  illustrates a first operational position of the isolation valve  1300  having both fluid pressure and flow through the bore of the isolation valve  1300 . As the isolation valve  1300  is pressurized, fluid pressure is communicated to the chambers  1329 , which generates a force (greater than the spring  1350  force) on the upper end of the upper piston member  1345 , thereby moving the upper piston member  1345 , the lower piston member  1347 , and the lug rings  1365  relative to the housing  1360  until a shoulder on the upper piston member  1345  abuts the coupler  1335 . The spring  1350  is compressed between the lower piston member  1347  and the housing  1360 , and the lug rings  1365  are moved in an extended portion of the channel  1363  to the position shown in  FIG. 13A-1 . A shoulder on the upper end of the upper piston member  1345  engages a shoulder on the lower end of the sleeves  1315  and moves the sleeves  1315  and thus the pins  1317 ,  1319  to rotate the ball  1330  so that the bore of the ball  1330  permits fluid flow through the bore of the isolation valve  1300 . 
     As illustrated in  FIG. 13B , when the pressure in the isolation valve  1300  is reduced, the spring  1350  returns the lower piston member  1347 , the upper piston member  1345 , and the sleeves  1315 , so that the ball  1330  is rotated using the pins  1317 ,  1319  into a closed position to prevent fluid flow through the bore of the isolation valve  1300 . The lower piston member  1347  moves the lug rings  1356  relative to the housing  1360 , and the lug rings  1356  are rotated and directed by the channel  1363  into the position shown in  FIG. 13B-1 , which may also stop the retraction of the spring  1350 . As illustrated in  FIG. 13C , pressure may then be applied above and to the isolation valve  1300  to conduct another operation, such as actuation of the expander assembly  25  described above, without opening fluid communication through the bore of the isolation valve  1300 . The upper piston member  1345  is moved within a recess of the sleeve  1315  a limited distance relative to the sleeve  1315  until the lug rings  1365  are moved by the lower piston member  1347  and are rotated and directed by the channel  1363  into the position shown in  FIG. 13C-1 , which may prevent the upper piston member  1345  from moving the sleeves  1315  and potentially re-opening fluid communication through the isolation valve  1300 . As illustrated in  FIG. 13D , when the pressure in the isolation valve  1300  is reduced or removed, the spring  1350  returns the upper piston member  1345  back to the position shown in  FIG. 13B . However, the lower piston member  1347  moves the lug rings  1356  into the channel  1363  to the position shown in  FIG. 13D-1 . From the position illustrated in  FIG. 13D-1 , when the isolation valve  1300  is pressurized again, the lug rings  1365  will be directed into an extended portion of the channel  1363  (similar to the position shown in  FIG. 13A-1 ) to permit movement of the sleeve  1315  via the upper and lower piston members  1345 ,  1347 , thereby moving the ball  1330  and opening fluid communication through the bore of the isolation valve  1300 . The isolation valve  1300  can be opened and closed indefinitely by following this procedure. 
       FIGS. 14A-C  illustrate a cross-section of an isolation valve  1400 , according to one embodiment of the invention. The isolation valve  1400  may be used instead of the isolation valve  200  described above. The isolation valve  1400  may include an upper housing  1410 , a lower housing  1420 , an upper mandrel  1430 , a lower mandrel  1440 , a retainer  1417 , one or more seals, such as o-rings  1403 ,  1405 ,  1407 ,  1409 ,  1411 ,  1413 , one or more biasing members, such as a spring  1450 , a flapper valve insert  1460 , a flapper valve  1465 , an adapter  1470 , and one or more frangible members, such as shear screws  1475 . 
     The upper mandrel  1430  may include a cylindrical body having a bore disposed therethrough and one or more check valves  1435  located through the body of the upper mandrel  1430 . The check valve  1435  may optionally include a removable plug  1437  to prevent fluid from escaping through the top end of the upper mandrel  1430 . The upper mandrel  1430  may be coupled to the upper end of the upper housing  1410 , which may also include a cylindrical body having a bore disposed therethrough. The retainer  1417  may include a snap ring disposed within the inner surface of the upper housing  1410  and may be operable to retain the upper mandrel  1430  within the upper housing  1410 . The lower mandrel  1440  is disposed in the upper housing  1410  and extends through the lower housing  1420 , and further includes a cylindrical body having a bore disposed therethrough that sealingly engages the upper mandrel  1430 . 
     The lower mandrel  1440  includes a shoulder that sealingly engages the upper housing  1410  and has one or more check valves  1445  disposed through the wall of the shoulder. A chamber  1480  is formed between the bottom end of the upper mandrel  1430 , the inner surface of the upper housing  1410 , the outer surface of the lower mandrel  1440 , and the top end of the shoulder of the lower mandrel  1440 . The chamber  1480  is filled with a hydraulic fluid, such as silicon oil. The upper housing  1410  includes a shoulder at its lower end that sealingly engages the lower mandrel  1440  and the lower housing  1420  and has one or more check valves  1415  disposed through the wall of the shoulder. A chamber  1455  is formed between the bottom end of the shoulder of the lower mandrel  1440 , the inner surface of the upper housing  1410 , top end of the shoulder of the upper housing  1410 , and the outer surface of the lower mandrel  1440 . The chamber  1455  is filled with a hydraulic fluid, such as silicon oil. The check valve  1415  may be configured to allow some of the fluid to escape from the chamber  1455  as an increase in temperature may cause expansion of the fluid. The check valve  1445  may be configured to direct the fluid from the chamber  1455  into the chamber  1480  and prevent fluid flow in the reverse direction. The spring  1450  is housed in the chamber  1455  and is operable to telescope apart the lower mandrel  1440  and the upper housing  1410 . 
     The lower housing  1420  is coupled to the upper housing  1410 , such as through a threaded connection, and includes a cylindrical body having a bore disposed therethrough. A recess in the inner surface of the lower housing  1420  is configured to retain the flapper valve insert  1460 , which supports the flapper valve  1465  and abuts the bottom end of the upper housing  1410 . The flapper valve insert  1460  and the flapper valve  1465  are further retained by the outer surface of the lower mandrel  1440 . The lower end of the lower mandrel  1440  is positioned to maintain the flapper valve  1465  in an open position, which includes a spring member configured to bias the flapper valve  1465  into a closed position when unrestrained. The lower mandrel  1440  is releaseably coupled to the adapter  1470  via the one or more shear screws  1475  below the lower housing  1420 . The adapter  1470  includes a solid cylindrical member that provides a closed end of the isolation valve  1400  and is operable to couple the isolation valve  1400  to a device, such as a dart  1490  (shown in  FIG. 14C ) or a cement plug. 
     In operation, the isolation valve  1400  is coupled to the dart  1490  via the adapter  1470 . The dart  1490  and the isolation valve  1400  may then be dropped from the surface of a wellbore into the setting tool  1 , the liner assembly  100 , or the wiper assembly  150  located in the wellbore. The dart  1490  may guide the isolation valve  1400  into the setting tool  1 , the liner assembly  100 , or the wiper assembly  150  until a shoulder  1425  of the lower housing  1420  engages and seals on a seat, such as a shoulder disposed in the bore of the seat  95 , the seal assembly  75 , the wiper assembly  150 , or other similar component. In an optional embodiment, the isolation valve  1400  may also include a c-ring coupled to the outer surface of the lower housing  1420  that is operable to engage a corresponding shoulder or recess to secure the isolation valve  1400  within the setting tool  1 , the liner assembly  100 , or the wiper assembly  150 . In one embodiment, the upper end of the upper housing  1410  may include a tapered shoulder configured to engage and seal on a seat, such as a shoulder disposed in the bore of the seat  95 , the seal assembly  75 , the wiper assembly  150 , or other similar component. 
     After the isolation valve  1400  is secured, pressure above the isolation valve  1400  may be applied against the top of the adapter  1470  to shear the shear screws  1475  and release the adapter  1470  and the dart  1490  from the lower mandrel  1440  and open fluid communication through the isolation valve  1400 . The release of the adapter  1470  and the dart  1490  from the lower mandrel  1440  allows the spring  1455  to move the lower mandrel  1440  to remove its lower end from preventing the flapper valve  1465  to bias into a closed position, as illustrated in  FIG. 14B . The fluid in the chamber  1480  and the check valves  1435 ,  1445  provide a configuration operable to delay the closure of the flapper valve  1465  after the adapter  1470  is released from the lower mandrel  1440 . As the chamber  1480  is collapsed between the upper mandrel  1430  and the lower mandrel  1440 , the fluid in the chamber  1480  is prevented from flowing into the chamber  1455  by the check valve  1445  but is allowed to be slowly dissipated through the check valve  1435  into the bore of the isolation valve  1400 . The pressure developed in the chamber  1480  after release of the lower mandrel  1440  may first release the plug  1437  from the flow path of the check valve  1435  to open fluid communication therethrough. As the fluid is ejected from the chamber  1480 , the portion of the fluid remaining in the chamber  1480  provides a resistance to the force of the spring  1450  and slows the movement of the lower mandrel  1440 . The sizing of the check valve  1435  may determine the rate at which the fluid is removed from the chamber  1480  and the sizing of the chamber  1480  may determine the amount of fluid which can be filled in the chamber  1480 . These two factors may be used to provide a predetermined timed resistance against the force of the spring  1450  to delay the movement of the lower mandrel  1440  away from the flapper valve  1465  and thus the closure of the flapper valve  1465 . During the time delayed closing of the flapper valve  1465 , the released adapter  1470  and dart  1490  may be directed through the remaining assembly, such as the liner assembly  100 , to facilitate removal of any remaining fluids, such as cement, from the assembly. As illustrated in  FIG. 14C , the dart  1490  may include a c-ring  1493  and a seal  1495 , such as an o-ring, configured to engage and seal with the body  151  of the wiper assembly  150 , the operation of which may then begin as described above after engagement with the dart  1490  and during the time delayed closing of the flapper valve  1465 . After the flapper valve  1465  closes fluid communication through the isolation valve  1400 , pressure may then be applied above and to the isolation valve  1400  to conduct another operation, such as actuation of the expander assembly  25  described above, without opening fluid communication through the bore of the isolation valve  1400 . 
       FIG. 15A  is a sectional view of an expandable liner system  1500  disposed in a wellbore  1510  according to one embodiment of the invention. The expandable liner system  1500  may be run-into the wellbore  1510  using the run-in string  685 . The system  1500  may include a liner assembly  1525  and an expander assembly  1550 . In one embodiment, the expandable liner system  1500  may be located proximate a lower end of a string of casing and the liner assembly  1525  may be set in the casing by positioning an upper portion of the liner assembly  1525  in an overlapping relationship with a lower portion of the casing. Thereafter, the expansion assembly  1550  may be employed to expand the liner assembly  1525  into engagement with the casing and/or the surrounding wellbore  1510 . 
     The liner assembly  1525  may include a tubular section  1530  at an upper end thereof and a shaped or a corrugated liner section  1535  disposed at the lower end thereof. It must be noted that the shape or corrugation of the liner section  1535  is optional such that the liner section  1535  is substantially cylindrical. Alternatively, the corrugated liner section  1535  may be located at any position along the liner assembly  1525 . A cross section of a suitable corrugated liner section may be found at FIG. 2G of U.S. Pat. No. 7,121,351, which is herein incorporated by reference in its entirety. The corrugated liner section  1535  and the substantially cylindrical liner section  1530  may be connected by a threaded connection or may be one continuous tubular body. The corrugated liner section  1535  may be fabricated from a drillable material, such as aluminum or a pliable composite. The corrugated liner section  1535  may have a folded wall having an initial inner diameter which may be reformed to define a larger second folded inner diameter and subsequently may be expanded to an even larger unfolded diameter. The corrugated liner section  1535  may be folded or deformed prior to insertion into the wellbore  1510 , to a non-tubular-shape, such as a hypocycloid, so that grooves are formed along the length of the corrugated liner section  1535 . The grooves may be symmetric or asymmetric. 
     The liner assembly  1525  may further include a shoe  1540  at the lower end thereof. The shoe  1540  may be longitudinally coupled to the corrugated portion, such as by a threaded connection. The shoe  1540  may be a tapered or bullet-shaped and may guide the liner assembly  1525  toward the center of the wellbore  1510 . The shoe  1540  may minimize problems associated with hitting rock ledges or washouts in the wellbore  1510  as the liner assembly  1525  is lowered into the wellbore. An outer portion of the shoe  1540  may be made from steel. An inner portion of the shoe  1540  may be made of a drillable material, such as cement, aluminum or thermoplastic, so that the inner portion may be drilled through if the wellbore is to be further drilled. A bore may be partially formed longitudinally through the shoe  1540  and in fluid communication with the wellbore  1510 . 
     The expander assembly  1550  may be disposed in the liner assembly  1525 . The expander assembly  1550  may include a tubular mandrel  1555 . An upper end of the mandrel  1555  may be connected to the run-in string  685  by a threaded connection and a lower end of the mandrel  1555  may be releasably connected to the shoe  1540 , such as by a threaded connection. The mandrel  1555  may have a bore formed therethrough in fluid communication with the surface of the wellbore  1510  via a bore of the run-in string  685 . The mandrel  1555  may support the liner assembly  1525  during run-in. 
     The expander assembly  1550  may further include one or more seals  1560  longitudinally coupled to the mandrel  1555  and engaged with an inner surface of the tubular portion  1530 . The seals  1560  may be fabricated from a pliable material, such as an elastomer. The seals  1560  may act as a piston to move the expansion assembly  1550  through the tubular section  1530  upon introduction of fluid pressure below the seals  1560 . Additionally or alternatively, tension from the run-in string may  685  be used to move the expansion assembly  1550  through the tubular section  1530 . 
     The expander assembly  1550  may further include a piston member  1570  disposed between the tubular section  1530  and the mandrel  1555  and movable relative to the tubular section and the mandrel. As illustrated in  FIG. 15A-1 , the piston member  1570  may form one or more vacuum chambers  1513  and one or more piston chambers  1515  with the mandrel  1555 . One or more seals, such as o-rings  1511 ,  1512 , and  1514  may be used to seal the chambers  1513  and  1515 . The mandrel  1555  may include a shoulder disposed on its outer surface having a flow path  1557  providing fluid communication between the bore of the mandrel  1555  and the piston chamber  1515 . A valve  1559 , such as a rupture disk, may be located in the flow path  1557  to control fluid communication to the piston chamber  1515 . 
     The expander assembly  1550  may further include a valve  1600  having a member  1610 , such as a pick, configured to actuate the valve  1559  to open fluid communication between the mandrel  1555  bore and the piston chamber  1515  for actuation of the piston member  1570 . In one embodiment, the valve  1600  may include the electronics package  650  or the RFID electronic package  800  described above. The valve  1600  may be actuated using an active or passive RFID tag embedded in a device, such as a dart  1580 , shown in  FIG. 15B , or using mud pulses received from the surface. In one embodiment, alternative means of operating the valve  1600  may include a spring force, a gas spring, or an electric motor. In one embodiment, actuation of the valve  1600  may cause the member  1610 , such as a pick, to fracture the valve  1590 , such as a rupture disk, thereby opening fluid communication between the bore of the mandrel  1555  and the piston chamber  1515 . 
     The expansion assembly  1550  further includes a two-position expander  1575  and a cone  1577 . The cone  1577  is a tapered member that is operatively attached to the piston member  1570 , whereby movement of the piston member  1570  in relation to the liner assembly  1525  will also move the cone  1577 . Adjacent to the cone  1577  is the two-position expander  1575 . During run-in, both the two-position expander  1575  and the cone  1577  are disposed adjacent an end of the corrugated liner section  1535 . 
     Detailed views of a suitable two-position expander may be found at FIGS. 3A and 3B of U.S. Pat. No. 7,121,351. The two-position expander  1575  may include a first assembly and a second assembly. The first assembly may include a first end plate and a plurality of first cone segments and the second assembly may include a second end plate and a plurality of second cone segments. Each end plate may be substantially round and have a plurality of T-shaped grooves formed therein. Each groove may match a T-shaped profile formed at an end of each cone segment. 
     An outer surface of each cone segment may include a first taper and an adjacent second taper. The first taper may have a gradual slope to form the leading shaped profile of the two-position expander  1575 . The second taper may have a relatively steep slope to form the trailing profile of the two-position expander  1575 . The inner surface of each cone segment may have a substantially semi-circular shape to allow the cone segments to slide along an outer surface of the mandrel  1555 . A track portion may be formed on each first cone segment. The track portion may be used with a mating track portion formed on each second cone segment to align and interconnect the cone segments. The track portions may be a tongue and groove arrangement. 
     The first assembly and the second assembly may be urged longitudinally toward each other along the mandrel. As the first assembly and the second assembly approach each other, the first and second cone segments may be urged radially outward. As the first and second segments travel longitudinally along respective track portions, a front end of each second cone segment wedges the first cone segments apart, thereby causing the first shaped profiles to travel radially outward along the first shaped grooves of the first end plate. Simultaneously, a front end of each first cone segment wedges the second cone segments apart, thereby causing the second shaped profiles to travel radially outward along the second shaped grooves of the second end plate. The radial and longitudinal movement of the cone segments continues until each front end contacts a stop surface on each end plate, respectively. In this manner, the two-position expander  1575  is moved from a retracted position having a first diameter to an expanded position having a second diameter that is larger than the first diameter. 
     In operation, the expandable liner system  1500  may be lowered into the wellbore  1510  adjacent an area of interest, such as an end of an existing casing section. Wellbore fluids may flow up through the bore of the mandrel  1555  and the run-in string  685  as the system  1500  is run into the wellbore  1510 . A dart  1580  may be dropped from the surface of the wellbore  1510 , directed through the expandable liner system  1500 , and seated in the shoe  1540 , thereby closing fluid communication between the wellbore  1510  and the bore of the mandrel  1555 . The dart  1580  may include an embedded RFID tag used to communicate with the valve  1600 . A radio frequency communication may be directed between the dart  1580  and the valve  1600  to actuate the valve  1600  and move the member  1610  to open the valve  1559 . The pressure in the bore of the mandrel  1555  may be increased and communicated to the piston chamber  1513  via the flow path  1557  to move the piston member  1570 . The piston member  1570  causes the two-position expander  1575  and the cone  1577  to move relative to the mandrel  1555  and the liner assembly  1525 , thereby allowing the cone  1577  to reform the corrugated liner section  1535 . The cone  1577  reforms the corrugated liner section  1535  and may engage a shoulder disposed on the outer surface of the mandrel  1555  or the end of the shoe  1540 , which prevents further movement of the cone  1577 . Fluid pressure continues to be introduced into the piston chamber  1515 , thereby causing the two-position expander  1575  to move closer to the cone  1577  to begin the activating process. As the fluid pressure continues to urge the two-position expander  1575  against the cone  1577 , the first and second cone segments of the two-position expander  1575  move radially outward into contact with the surrounding liner  1535  (actuation of the two-position expander  1575  was described above). 
       FIG. 15C  illustrates the two-position expander  1575  expanding the corrugated liner section  1535  and the liner section  1530 . As shown, the two-position expander  1575  has expanded a portion of the liner section  1535  from the folded diameter to the unfolded diameter. In other words, during the expansion process, the two-position expander  1575  basically “irons out” the crinkles in the corrugated liner section  1535  so that the liner section  1535  is substantially reformed into its initial tubular shape. Reforming and subsequently expanding allows further expansion of the liner section  1535  than was previously possible because the reformation process may not use up the 25% limit on expansion past the elastic limit. Subsequently, the expansion assembly  1550  is rotated in one direction to release the connection between the mandrel  1555  and the shoe  1540  and/or dart  1580 . At this point, the expansion assembly  1550  and the liner assembly  1525  are disconnected, thereby unlocking the one or more seals  1560 . As additional fluid pressure is introduced through the bore of the mandrel  1555 , the entire expansion assembly  1550  is moved relative to the liner assembly  1525  as fluid pressure acts upon seals  1560 . In this manner, substantially the entire length of liner sections  1530  and  1535  are expanded into contact with the surrounding wellbore  1510 . 
       FIG. 15D  illustrates the removal of the expander assembly  1550  from the liner assembly  1525 . As illustrated, a device  1590 , such as a ball, may be dropped from the surface of the wellbore  1510  and landed into a seat of the mandrel  1555 , thereby closing fluid communication between the bore of the mandrel  1555  and the surrounding annulus of the wellbore  1510 . Pressure may then be increased in the expander assembly  1550  and used to collapse the two-position expander  1575  into an unexpanded (reduced outer diameter) position to facilitate removal of the expander assembly  1550 . The cone segments of the two-position expander  1575  may be retracted to provide a reduced outer diameter of the expansion assembly  1550  to allow the assembly to be removed from the liner assembly  1525  and/or the wellbore  1510 . 
       FIGS. 15C-1 ,  15 D- 1 , and  15 D- 2  illustrate an embodiment of the expander assembly  1550  having a release mechanism  1700  used to retract the two-position expander  1575  into an unexpanded position as stated above. The release mechanism  1700  is configured to retract the two-position expander  1575  into an unexpanded position using fluid pressure and/or mechanical rotation of the expander assembly  1550 . The release mechanism  1700  may be disposed between the two-position expander  1575  and the cone  1577  of the expansion assembly  1550 . 
     The release mechanism  1700  may include an adapter  1710  coupled to the two-position expander  1575  at an upper end and rotatively coupled to a first inner mandrel  1715  via one or more screws  1719 . The screws  1719  may reside in a slot in the body of the adapter  1710  to allow relative axial movement between the adapter  1710  and the first inner mandrel  1715 . The adapter  1710  and the first inner mandrel  1715  may include cylindrical members having bores disposed through the bodies of the members. The first inner mandrel  1715  may similarly be coupled at its upper end to a mandrel  1717 , which is disposed between the two-position expander  1575  and the mandrel  1555  and is operable to facilitate make-up of the expander assembly  1500  and the release mechanism  1700 . 
     The release mechanism  1700  may include an upper sleeve  1720 , a middle sleeve  1725 , and a lower sleeve  1730 , each comprising cylindrical members having bores located through the bodies of the members. The upper sleeve  1720  may abut a shoulder disposed on the outer surface of the adapter  1710  and may be releaseably coupled to the middle sleeve  1725  via one or more frangible members, such as shear screws  1721 . An opening  1731  is disposed through the body of the upper sleeve  1720 , which is in communication with a chamber formed between the upper sleeve  1720  and the middle sleeve  1725 . The chamber is sealed using one or more seals, such as o-rings  1754 ,  1753 ,  1756 , and  1752 . The chamber is also in communication with an opening  1733  disposed through the body of the first inner mandrel  1715 , which is further in communication with an opening  1734  disposed through the body of the mandrel  1555  and thus the inner bore of the expander assembly  1550 . When the inner bore of the expander assembly  1550  is pressurized, the fluid pressure is directed to the chamber via the openings  1734 ,  1733 ,  1731 , which then telescopes apart the upper sleeve  1720  and the middle sleeve  1725  to shear the shear screws  1721  and allow relative movement between the upper and middle sleeves. The pressure also telescopes apart the adapter  1720  and the upper and middle sleeves  1720 ,  1725  relative to the first inner mandrel  1715 . 
     As illustrated in  FIG. 15C-1 , a set of dogs  1735  may be located in a slot of the upper sleeve  1720  and may extend into recesses disposed on the outer surface of the first inner mandrel  1715 . The dogs  1735  may include a cylindrical member having one or more shoulder portions extending from the inner diameter and one or more recesses disposed on the outer diameter of the member. The dogs  1735  may be surrounded by the lower sleeve  1730 , which is coupled to the upper end of a lower housing  1760 . The lower sleeve  1730  engages the outer surface of the dogs  1735  adjacent the recesses disposed on the outer diameter of the dogs  1735  to prevent the dogs  1735  from releasing engagement with the first inner mandrel  1715 . The dogs  1735  are engaged with the first inner mandrel  1715  to prevent relative movement between the adapter  1710  (via the upper sleeve  1720 ) and the first inner mandrel  1715 , thereby preventing retraction of the two-position expander  1575 . A guide member  1740  is coupled to the lower end of the upper sleeve  1720  to facilitate translation of the upper sleeve  1720  relative to the lower housing  1760 . The housing  1760  may be releasably coupled to a second inner mandrel  1750  via one or more frangible members, such as shear screws  1722 . The second inner mandrel  1750  may also be coupled to the first inner mandrel  1715  at one end and the cone  1577  at the opposite end. A seal, such as a packing element  1751 , may be disposed between the first inner mandrel  1715 , the second inner mandrel  1750 , and the mandrel  1555 . 
     As illustrated in  FIG. 15D-1 , the device  1590  (shown in  FIG. 15D ) may close fluid communication through the expander assembly  1550  and allow the bore of the mandrel  1555  to be pressurized, which may be communicated to the chamber between the upper sleeve  1720  and the middle sleeve  1725 . The shear screws  1721  between the upper sleeve  1720  and the middle sleeve  1725  (and the shear screws  1722  between the lower housing  1760  and the second inner mandrel  1750 ) have been sheared (as described above) and the middle sleeve  1725  is used to direct a shoulder portion on the inner diameter of the lower sleeve  1730  into the recesses on the outer diameter the dogs  1735 . This engagement allows the dogs  1735  to move radially outward away from the first inner mandrel  1715 . The upper sleeve  1720  directs the dogs  1735  axially relative to the first inner mandrel  1715  to allow the dogs to disengage from the recesses in the first inner mandrel  1715  and retract into the middle sleeve  1725 . When the dogs  1735  are disengaged from the first inner mandrel  1715 , the adapter  1710  may move downward relative to the first inner mandrel  1715  to retract and pull apart the two-position expander  1575 . The movement relative to the first inner mandrel  1715  may be stopped when the guide member  1740  abuts the upper end of the second inner mandrel  1750 . The expander assembly  1550  may then be removed from the wellbore with the two-position expander  1775  in the retracted position. 
     As illustrated in  FIG. 15D-2 , the two-position expander  1575  may be retracted into an unexpanded position by rotation of the mandrel  1555 . Rotation of the mandrel  1555  may be used to induce relative movement between the second inner mandrel  1570  and the lower housing  1760  and thus shear the shear screws  1722  therebetween. Release of the shear screws  1722  allows the middle sleeve  1730  to move relative to the dogs  1735 , which may then retract into the middle sleeve  1730  and radially outward relative to the first inner mandrel  1715  as described above. Relative movement between the upper sleeve  1720  and the first inner mandrel  1715  may allow the lower end of the upper sleeve  1720  to move the dogs  1735  out of the recesses in the first inner mandrel  1715  and release the engagement therebetween to allow retraction of the two-position expander  1775  into the unexpanded position. 
     Any of the above discussed setting tools and/or liner assemblies may be installed in a pre-drilled wellbore or drilled in using a drilling with liner operation. Further, any of the above discussed setting tools may be used with a conventional liner hanger, discussed in the Background section. Further, any of the setting tool actuators may be used for the isolation valves and vice versa. 
     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.