US20070227730A1 - Apparatus for radially expanding and plastically deforming a tubular member - Google Patents

Apparatus for radially expanding and plastically deforming a tubular member Download PDF

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Publication number
US20070227730A1
US20070227730A1 US11/531,041 US53104106A US2007227730A1 US 20070227730 A1 US20070227730 A1 US 20070227730A1 US 53104106 A US53104106 A US 53104106A US 2007227730 A1 US2007227730 A1 US 2007227730A1
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United States
Prior art keywords
tubular
tubular member
sealing element
support
filed
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Abandoned
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US11/531,041
Inventor
David Brisco
Brock Watson
Harold Treece
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Enventure Global Technology Inc
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Enventure Global Technology Inc
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Priority to US11/531,041 priority Critical patent/US20070227730A1/en
Assigned to ENVENTURE GLOBAL TECHNOLOGY, L.L.C. reassignment ENVENTURE GLOBAL TECHNOLOGY, L.L.C. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BRISCO, DAVID PAUL, TREECE, HAROLD OTIS, WATSON, BROCK WAYNE
Priority to US11/838,782 priority patent/US20080142213A1/en
Publication of US20070227730A1 publication Critical patent/US20070227730A1/en
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/128—Packers; Plugs with a member expanded radially by axial pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E21B43/105—Expanding tools specially adapted therefor

Definitions

  • This invention relates generally to oil and gas exploration, and in particular to forming and repairing wellbore casings to facilitate oil and gas exploration.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member, a cutting device for cutting the tubular member coupled to the support member, and an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member, an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member, and an actuator coupled to the support member for displacing the expansion device relative to the support member.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member; an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a sealing assembly for sealing an annulus defined between the support member and the tubular member.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member; a first expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a second expansion device for radially expanding and plastically deforming the tubular member coupled to the support member.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member; an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a packer coupled to the support member.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member; a cutting device for cutting the tubular member coupled to the support member; a gripping device for gripping the tubular member coupled to the support member; a sealing device for sealing an interface with the tubular member coupled to the support member; a locking device for locking the position of the tubular member relative to the support member; a first adjustable expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; a second adjustable expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; a packer coupled to the support member; and an actuator for displacing one or more of the sealing assembly, first and second adjustable expansion devices, and packer relative to the support member.
  • an apparatus for cutting a tubular member includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • an apparatus for engaging a tubular member includes a support member; and a plurality of movable elements coupled to the support member.
  • an apparatus for gripping a tubular member that includes a plurality of movable gripping elements.
  • an actuator includes a tubular housing; a tubular piston rod movably coupled to and at least partially positioned within the housing; a plurality of annular piston chambers defined by the tubular housing and the tubular piston rod; and a plurality of tubular pistons coupled to the tubular piston rod, each tubular piston movably positioned within a corresponding annular piston chamber.
  • an apparatus for controlling a packer includes a tubular support member; one or more drag blocks releasably coupled to the tubular support member; and a tubular stinger coupled to the tubular support member for engaging the packer.
  • a packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • a method of radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing includes positioning the tubular member within the borehole in overlapping relation to the wellbore casing; radially expanding and plastically deforming a portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section.
  • a method for forming a mono diameter wellbore casing includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; positioning the adjustable expansion device within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes positioning an adjustable expansion device within the expandable tubular member; supporting the expandable tubular member and the adjustable expansion device within the borehole; lowering the adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • a method for forming a mono diameter wellbore casing includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; positioning the adjustable expansion mandrel within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion mandrel out of the second expandable tubular member; increasing the outside dimension of the adjustable
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of
  • a method for forming a mono diameter wellbore casing includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; positioning first and second adjustable expansion devices within a second expandable tubular member;
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand
  • a method for forming a mono diameter wellbore casing includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radi
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member.
  • a method for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member.
  • a method of radially expanding and plastically deforming a tubular member includes applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another.
  • a system for forming a mono diameter wellbore casing includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for positioning the adjustable expansion device within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for positioning an adjustable expansion device within the expandable tubular member; means for supporting the expandable tubular member and the adjustable expansion device within the borehole; means for lowering the adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and means for pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • a system for forming a mono diameter wellbore casing includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; means for positioning the adjustable expansion mandrel within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion mandre
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein
  • a system for forming a mono diameter wellbore casing includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; means for positioning
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second
  • a system for forming a mono diameter wellbore casing includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member.
  • a system for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member.
  • a system for radially expanding and plastically deforming a tubular member includes means for positioning the tubular member within a preexisting structure; means for radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section.
  • a system of radially expanding and plastically deforming a tubular member that includes a support member; and means for applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another coupled to the support member.
  • a method of cutting a tubular member includes positioning a plurality of cutting elements within the tubular member; and bringing the cutting elements into engagement with the tubular member.
  • a method of gripping a tubular member includes positioning a plurality of gripping elements within the tubular member; bringing the gripping elements into engagement with the tubular member.
  • bringing the gripping elements into engagement with the tubular member includes displacing the gripping elements in an axial direction; and displacing the gripping elements in a radial direction.
  • a method of operating an actuator includes pressurizing a plurality of pressure chamber.
  • a method of injecting a hardenable fluidic sealing material into an annulus between a tubular member and a preexisting structure includes positioning the tubular member into the preexisting structure; sealing off an end of the tubular member; operating a valve within the end of the tubular member; and injecting a hardenable fluidic sealing material through the valve into the annulus between the tubular member and the preexisting structure.
  • a system for cutting a tubular member includes means for positioning a plurality of cutting elements within the tubular member; and means for bringing the cutting elements into engagement with the tubular member.
  • a system for gripping a tubular member includes means for positioning a plurality of gripping elements within the tubular member; and means for bringing the gripping elements into engagement with the tubular member.
  • an actuator system that includes a support member; and means for pressurizing a plurality of pressure chambers coupled to the support member.
  • the system further includes means for transmitting torsional loads.
  • a system for injecting a hardenable fluidic sealing material into an annulus between a tubular member and a preexisting structure includes means for positioning the tubular member into the preexisting structure; means for sealing off an end of the tubular member; means for operating a valve within the end of the tubular member; and means for injecting a hardenable fluidic sealing material through the valve into the annulus between the tubular member and the preexisting structure.
  • a method of engaging a tubular member includes positioning a plurality of elements within the tubular member; and bringing the elements into engagement with the tubular member.
  • a system for engaging a tubular member includes means for positioning a plurality of elements within the tubular member; and means for bringing the elements into engagement with the tubular member.
  • the elements include a first group of elements; and a second group of elements; wherein the first group of elements are interleaved with the second group of elements.
  • a locking device for locking a tubular member to a support member includes a plurality of circumferentially spaced apart locking elements coupled to the support member for engaging an interior surface of the tubular member; a plurality of spring elements coupled to the support member for biasing corresponding locking elements out of engagement with the interior surface of the tubular member; a releasable retaining element releasably coupled to the support member for releasably retaining the locking elements in engagement with the interior surface of the tubular member; an actuator coupled to the support member for controllably displacing the retaining element relative to the locking elements; and a sensor coupled to the support member for sensing an operating condition within the tubular member for controllably displacing the retaining element relative to the locking elements.
  • a method of locking a tubular member to a support member includes engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • a system for locking a tubular member to a support member includes means for engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and means for disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • a method includes positioning a packer assembly comprising a sealing element within a tubular member; setting the sealing element against an interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
  • a system includes means for positioning a packer assembly comprising a sealing element within a tubular member; means for setting the sealing element against an interior surface of the tubular member; and means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
  • a method includes positioning a packer assembly comprising a sealing element within a tubular member; applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
  • a system includes means for positioning a packer assembly comprising a sealing element within a tubular member; means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
  • a method includes coupling a packer control device to a packer assembly comprising a sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; radially expanding and plastically deforming at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • a system includes means for coupling a packer control device to a packer assembly comprising a sealing element; means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; means for radially expanding and plastically deforming at least a portion of the tubular member; means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • a method includes coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore; radially expanding and plastically deforming at least a portion of the tubular member; moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; and a stinger coupled to the second tubular support for releasably engaging the packer assembly.
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; and one or more second retaining dogs releasably engaged with the first tubular support; wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support.
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; a second configuration in which the
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; and a compressible element at least partially circumferentially extending about the first tubular support; wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed.
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second
  • an apparatus for controlling the operation of a packer assembly includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second
  • an apparatus includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer.
  • an apparatus for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer; and the packer comprising a second support member defining a passage; a shoe comprising a float valve coupled to an end of the second support member; one or more compressible packer elements movably coupled to the second support member; and a sliding sleeve valve positioned within the passage of the second support member; wherein the stinger engages the sliding sleeve valve.
  • FIG. 1 is a fragmentary cross-sectional illustration of an embodiment of a system for radially expanding and plastically deforming wellbore casing, including a tubular support member, a casing cutter, a ball gripper for gripping a wellbore casing, a force multiplier tension actuator, a safety sub, a cup sub, a casing lock, an extension actuator, a bell section adjustable expansion cone assembly, a casing section adjustable expansion cone assembly, a packer setting tool, a packer, a stinger, and an expandable wellbore casing, during the placement of the system within a wellbore.
  • FIG. 2 is a fragmentary cross-sectional illustration of the system of FIG. 1 during the subsequent displacement of the bell section adjustable expansion cone assembly, the casing section adjustable expansion cone assembly, the packer setting tool, the packer, and the stinger downwardly out of the end of the expandable wellbore casing and the expansion of the size of the bell section adjustable expansion cone assembly and the casing section adjustable expansion cone assembly.
  • FIG. 3 is a fragmentary cross-sectional illustration of the system of FIG. 2 during the subsequent operation of the tension actuator to displace the bell section adjustable expansion cone assembly upwardly into the end of the expandable wellbore casing to form a bell section in the end of the expandable wellbore casing.
  • FIG. 4 is a fragmentary cross-sectional illustration of the system of FIG. 3 during the subsequent reduction of the bell section adjustable expansion cone assembly.
  • FIG. 5 is a fragmentary cross-sectional illustration of the system of FIG. 4 during the subsequent upward displacement of the expanded casing section adjustable expansion cone assembly to radially expand the expandable wellbore casing.
  • FIG. 6 is a fragmentary cross-sectional illustration of the system of FIG. 5 during the subsequent lowering of the tubular support member, casing cutter, ball gripper, a force multiplier tension actuator, safety sub, cup sub, casing lock, extension actuator, bell section adjustable expansion cone assembly, casing section adjustable expansion cone assembly, packer setting tool, packer, and stinger and subsequent setting of the packer within the expandable wellbore casing above the bell section.
  • FIG. 7 is a fragmentary cross-sectional illustration of the system of FIG. 6 during the subsequent injection of fluidic materials into the system to displace the expanded casing section adjustable expansion cone assembly upwardly through the expandable wellbore casing to radially expand and plastically deform the expandable wellbore casing.
  • FIG. 8 is a fragmentary cross-sectional illustration of the system of FIG. 7 during the subsequent injection of fluidic materials into the system to displace the expanded casing section adjustable expansion cone assembly upwardly through the expandable wellbore casing and a surrounding preexisting wellbore casing to radially expand and plastically deform the overlapping expandable wellbore casing and the surrounding preexisting wellbore casing.
  • FIG. 9 is a fragmentary cross-sectional illustration of the system of FIG. 8 during the subsequent operation of the casing cutter to cut off an end of the expandable wellbore casing.
  • FIG. 10 is a fragmentary cross-sectional illustration of the system of FIG. 9 during the subsequent removal of the cut off end of the expandable wellbore casing.
  • FIGS. 11-1 and 11 - 2 are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of a casing cutter assembly.
  • FIGS. 12 A 1 to 12 A 4 and 12 C 1 to 12 C 4 are fragmentary cross-sectional illustrations of an exemplary embodiment of a ball gripper assembly.
  • FIG. 12B is a top view of a portion of the ball gripper assembly of FIGS. 12 A 1 to 12 A 4 and 12 C 1 to 12 C 4 .
  • FIGS. 13 A 1 to 13 A 8 and 13 B 1 to 13 B 7 are fragmentary cross-sectional illustrations of an exemplary embodiment of a tension actuator assembly.
  • FIG. 14A is a fragmentary cross-sectional illustrations of an exemplary embodiment of a safety sub assembly.
  • FIGS. 14A, 14B and 14 C are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of a cup seal assembly.
  • FIGS. 15-1 , 15 - 2 , 15 A 1 , 15 A 2 , 15 B 1 , 15 B 2 , 15 C 1 , 15 C 2 , 15 D, 15 E 1 to 15 E 5 , 15 F 1 to 15 F 5 , and 15 G 1 to 15 G 5 are fragmentary cross sectional illustrations of an exemplary embodiment of an extension actuator and casing lock assembly.
  • FIGS. 17-1 and 17 - 2 , 17 A 1 to 17 A 2 , 17 B 1 to 17 B 2 , 17 C, 17 D, 17 E, 17 F, 17 G, 17 H, 171 , 17 j , 17 K, 17 L, 17 M, 17 N, 170 , 17 P, 17 R, 17 S, 17 T, 17 U, 17 V, 17 W, 17 x , 17 Y, 17 Z 1 - 17 Z 4 , 17 AA 1 to 17 AA 4 , 17 AB 1 to 17 AB 4 , 17 AC 1 to 17 AC 4 , 17 AD, and 17 AE are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of an adjustable casing expansion cone assembly.
  • FIGS. 18A to 18 C is a fragmentary cross-sectional illustration of an exemplary embodiment of a packer setting tool assembly.
  • FIGS. 19-1 to 19 - 5 is a fragmentary cross-sectional illustration of an exemplary embodiment of a packer assembly.
  • FIGS. 20 A 1 to 20 A 5 , 20 B 1 to 20 B 5 , 20 C 1 to 20 C 5 , 20 D 1 to 20 D 5 , 20 E 1 to 20 E 6 , 20 F 1 to 20 F 6 , 20 G 1 to 20 G 6 , and 20 H 1 to 20 H 5 are fragmentary cross-sectional illustrations of an exemplary embodiment of the operation of the packer setting tool assembly of FIGS. 18A to 18 C and the packer assembly of FIGS. 19-1 to 19 - 5 .
  • FIGS. 21 and 21 A to 21 AX are fragmentary perspective and cross-sectional illustrations of an alternative embodiment of the packer assembly.
  • FIGS. 22A to 22 D is a fragmentary cross-sectional illustration of another exemplary embodiment of a packer setting tool assembly.
  • FIGS. 23A to 23 E, 24 A to 24 E, 25 A to 25 E, 26 A to 26 E, 27 A to 27 E, 28 A to 28 E, 29 A to 29 E, 30 A to 30 E, 31 A to 31 E, 32 A to 32 E and 33 A to 33 E, are fragmentary cross-sectional illustrations of an exemplary embodiment of the operation of the packer setting tool assembly of FIGS. 22A to 22 D and the packer assembly of FIGS. 19-1 to 19 - 5 .
  • an exemplary embodiment of a system 10 for radially expanding and plastically deforming a wellbore casing includes a conventional tubular support 12 having an end that is coupled to an end of a casing cutter assembly 14 .
  • the casing cutter assembly 14 may be, or may include elements, of one or more conventional commercially available casing cutters for cutting wellbore casing, or equivalents thereof.
  • sealing cup assembly 22 An end of a sealing cup assembly 22 is coupled to another end of the safety sub assembly 20 .
  • the sealing cup assembly 22 may be, or may include elements, of one or more conventional sealing cup assemblies, or other types of sealing assemblies, that sealingly engage the interior surfaces of surrounding tubular members, or equivalents thereof.
  • the extension actuator assembly 26 is then operated to move the adjustable bell section expansion cone assembly 28 , adjustable casing expansion cone assembly 30 , packer setting tool assembly 32 , stinger assembly 34 , packer assembly 36 downwardly in a direction 108 and out of an end of the expandable wellbore casing 100 .
  • the adjustable bell section expansion cone assembly 28 and adjustable casing expansion cone assembly 30 have been moved to a position out of the end of the expandable wellbore casing 100
  • the adjustable bell section expansion cone assembly and adjustable casing expansion cone assembly are then operated to increase the outside diameters of the expansion cone assemblies.
  • the increased outside diameter of the adjustable bell section expansion cone assembly 28 is greater than the increased outside diameter of the adjustable casing expansion cone assembly 30 .
  • the length of the end of the expandable wellbore casing 100 that is radially expanded and plastically deformed by the adjustable bell section expansion cone assembly 28 is limited by the stroke length of the tension actuator assembly 18 .
  • the ball gripper assembly 16 is operated to release the expandable tubular member 100 , and the tubular support 12 is moved upwardly to permit the tension actuator assembly to be re-set. In this manner, the length of the bell section 112 can be further extended by continuing to stroke and then re-set the position of the tension actuator assembly 18 . Note, that, during the upward movement of the tubular support 12 to re-set the position of the tension actuator assembly 18 , the expandable tubular wellbore casing 100 is supported by the expansion surfaces of the adjustable bell section expansion cone assembly 28 .
  • the casing lock assembly 24 is then operated to engage and maintain the position of the expandable wellbore casing 100 stationary relative to the tubular support 12 .
  • the adjustable bell section expansion cone assembly 28 , adjustable casing expansion cone assembly 30 , packer setting tool assembly 32 , stinger assembly 34 , and packer assembly 36 are displaced downwardly into the bell section 112 in a direction 114 relative to the expandable wellbore casing 100 by operating the extension actuator 26 and/or by displacing the system 10 downwardly in the direction 114 relative to the expandable wellbore casing.
  • the casing lock assembly 24 is then disengaged from the expandable wellbore casing 100 and fluidic material 116 is then injected into the system 10 through the tubular support 12 to thereby pressurize an annulus 118 defined within the expandable wellbore casing below the cup sub assembly 22 .
  • a pressure differential is created across the cup seal assembly 22 that causes the cup seal assembly to apply a tensile force in the direction 120 to the system 10 .
  • the tension actuator assembly 16 may also be operated during the injection of the fluidic material 116 to displace the adjustable casing expansion cone assembly 30 upwardly relative to the tubular support 12 . As a result, additional expansion forces may be applied to the expandable wellbore casing 100 .
  • a hardenable fluidic sealing material 122 may then be injected into the system 10 through the tubular support 12 and then out of the system through the packer assembly to thereby permit the annulus between the expandable wellbore casing and the wellbore 102 to be filled with the hardenable fluidic sealing material.
  • the hardenable fluidic sealing material 122 may then be allowed to cure to form a fluid tight annulus between the expandable wellbore casing 100 and the wellbore 102 , before, during, or after the completion of the radial expansion and plastic deformation of the expandable wellbore casing.
  • the system 10 is displaced upwardly in the direction 120 relative to the expandable wellbore casing 100 thereby pulling the adjustable casing expansion cone assembly 30 upwardly in the direction 120 through the expandable wellbore casing thereby radially expanding and plastically deforming the expandable wellbore casing and disengaging the stinger assembly 34 from the packer assembly 36 .
  • the packer assembly 36 prevents the flow of fluidic materials out of the expandable wellbore casing 100 .
  • the pressurization of the annulus 118 is rapid and efficient thereby enhancing the operational efficiency of the subsequent radial expansion and plastic deformation of the expandable wellbore casing 100 .
  • the tension actuator assembly 16 may also be operated during the re-injection of the fluidic material 116 to displace the adjustable casing expansion cone assembly 30 upwardly relative to the tubular support 12 . As a result, additional expansion forces may be applied to the expandable wellbore casing 100 .
  • the radial expansion and plastic deformation of the expandable wellbore casing using the adjustable casing expansion cone assembly 30 continues until the adjustable casing expansion cone assembly 30 reaches the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 .
  • the system 10 may radially expand the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 and the surrounding portion of the preexisting wellbore casing.
  • the tension actuator assembly 16 is also operated to displace the adjustable casing expansion cone assembly 30 upwardly relative to the tubular support 12 .
  • additional expansion forces may be applied to the expandable wellbore casing 100 and the preexisting wellbore casing 106 during the radial expansion of the portion 124 of the expandable wellbore casing that overlaps with the preexisting wellbore casing.
  • the entire length of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 is not radially expanded and plastically deformed. Rather, only part of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 is radially expanded and plastically deformed. The remaining part of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 is then cut away by operating the casing cutter assembly 14 .
  • the remaining part of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 that is cut away by operating the casing cutter assembly 14 is then also carried out of the wellbore 102 using the casing cutter assembly.
  • the inside diameter of the expandable wellbore casing 100 above the bell section 112 is equal to the inside diameter of the portion of the preexisting wellbore casing 106 that does not overlap with the expandable wellbore casing 100 .
  • a wellbore casing is constructed that includes overlapping wellbore casings that together define an internal passage having a constant cross-sectional area.
  • one or more of the operational elements of the system 10 may be omitted, at least in part, and/or combined, at least in part, with one or more of the other operational elements of the system.
  • the system 10 includes one or more of the methods and apparatus disclosed in one or more of the following: (1) U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (2) U.S. patent application Ser. No. 09/510,913, attorney docket no. 25791.7.02, filed on Feb. 23, 2000, which claims priority from provisional application 60/121,702, filed on Feb. 25, 1999, (3) U.S. patent application Ser. No. 09/502,350, attorney docket no. 25791.8.02, filed on Feb.
  • the casing cutter assembly 14 is provided and operates substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US03/29858, attorney docket number 25791.112.02, filed on Sep. 22, 2003, and/or (2) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (3) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (4) PCT patent application serial number PCT/US04/10317, attorney docket number 25791.270.02, filed on Apr.
  • the casing cutter assembly 14 includes an upper tubular tool joint 14002 that defines a longitudinal passage 14002 a and mounting holes, 14002 b and 14002 c , and includes an internal threaded connection 14002 d , an inner annular recess 14002 e , an inner annular recess 14002 f , and an internal threaded connection 14002 g .
  • a tubular torque plate 14004 that defines a longitudinal passage 14004 a and includes circumferentially spaced apart teeth 14004 b is received within, mates with, and is coupled to the internal annular recess 14002 e of the upper tubular tool joint 14002 .
  • a sealing element 14010 is received within the external annular recess 14008 y of the tubular toggle bushing 14008 for sealing the interface between the tubular toggle bushing and the upper tubular tool joint 14002 .
  • a sealing element 14012 is received within the internal annular recess 14008 z of the tubular toggle bushing 14008 for sealing the interface between the tubular toggle bushing and the tubular lower mandrel 14006 .
  • Mounting screws, 14014 a and 14014 b , mounted within and coupled to the mounting holes, 14008 w and 14008 x , respectively, of the tubular toggle bushing 14008 are also received within the mounting holes, 14002 b and 14002 c , of the upper tubular tool joint 14002 .
  • Mounting pins, 14016 a , 14016 b , 14016 c , 14016 d , and 14016 e are mounted within the mounting holes, 14008 e , 14008 f , 14008 g , 14008 h , and 14008 i , respectively.
  • Mounting pins, 14018 a , 14018 b , 14018 c , 14018 d , and 14018 e are mounted within the mounting holes, 14008 t , 14008 s , 14008 r , 14008 q , and 14008 p , respectively.
  • Mounting screws, 14020 a and 14020 b are mounted within the mounting holes, 14008 u and 14008 v , respectively.
  • a first upper toggle link 14022 defines mounting holes, 14022 a and 14022 b , for receiving the mounting pins, 14016 a and 14016 b , and includes a mounting pin 14022 c at one end.
  • a first lower toggle link 14024 defines mounting holes, 14024 a , 14024 b , and 14024 c , for receiving the mounting pins, 14022 c , 14016 c , and 14016 d , respectively and includes an engagement arm 14024 d .
  • a first trigger 14026 defines a mounting hole 14026 a for receiving the mounting pin 14016 e and includes an engagement arm 14026 b at one end, an engagement member 14026 c , and an engagement arm 14026 d at another end.
  • a second upper toggle link 14028 defines mounting holes, 14028 a and 14028 b , for receiving the mounting pins, 14018 a and 14018 b , and includes a mounting pin 14028 c at one end.
  • a second lower toggle link 14030 defines mounting holes, 14030 a , 14030 b , and 14030 c , for receiving the mounting pins, 14028 c , 14018 c , and 14018 d , respectively and includes an engagement arm 14030 d .
  • a second trigger 14032 defines a mounting hole 14032 a for receiving the mounting pin 14018 e and includes an engagement arm 14032 b at one end, an engagement member 14032 c , and an engagement arm 14032 d at another end.
  • Mounting screws, 14035 a and 14035 b are mounted within and coupled to the mounting holes, 14008 xb and 14008 xa , respectively, of the tubular toggle bushing 14008 and are received within the mounting holes, 14034 ba and 14034 ca , respectively, of the tubular spring housing 14034 .
  • a tubular retracting spring ring 14036 that defines mounting holes, 14036 a and 14036 b , receives and mates with a portion of the tubular lower mandrel 14006 and is received within and mates with a portion of the tubular spring housing 14034 .
  • Mounting screws, 14038 a and 14038 b are mounted within and coupled to the mounting holes, 14036 a and 14036 b , respectively, of the tubular retracting spring ring 14036 and extend into the mounting holes, 14034 b and 14034 c , respectively, of the tubular spring housing 14034 .
  • Casing diameter sensor springs, 14040 a and 14040 b are positioned within the longitudinal slots, 14008 c and 1408 d , respectively, of the tubular toggle bushing 14008 that engage the engagement members, 14026 c and 14032 c , and engagement arms, 14026 d and 14032 d , of the first and second triggers, 14026 and 14032 , respectively.
  • An inner flange 14042 a of an end of a tubular spring washer 14042 mates with and receives a portion of the tubular lower mandrel 14006 and an end face of the inner flange of the tubular spring washer is positioned proximate and end face of the external flange 14006 d of the tubular lower mandrel.
  • the tubular spring washer 14042 is further received within the longitudinal passage 14034 a of the tubular spring housing 14034 .
  • An end of a retracting spring 14044 that receives the tubular lower mandrel 14006 is positioned within the tubular spring washer 14042 in contact with the internal flange 14042 a of the tubular spring washer and the other end of the retracting spring is positioned in contact with an end face of the tubular retracting spring ring 14036 .
  • a sealing element 14046 is received within the external annular recess 14006 j of the tubular lower mandrel 14006 for sealing the interface between the tubular lower mandrel and the tubular spring housing 14034 .
  • a sealing element 14048 is received within the internal annular recess 14034 h of the tubular spring housing 14034 for sealing the interface between the tubular spring housing and the tubular lower mandrel 14006 .
  • An internal threaded connection 14050 a of an end of a tubular upper hinge sleeve 14050 that includes an internal flange 14050 b and an internal pivot 14050 c receives and is coupled to the external threaded connection 14034 i of the end of the tubular spring housing 14034 .
  • An external flange 14052 a of a base member 14052 b of an upper cam assembly 14052 that is mounted upon and receives the lower tubular mandrel 14006 , that includes an internal flange 14052 c that is received within the external annular recess 14006 e of the lower tubular mandrel 14006 and a plurality of circumferentially spaced apart cam arms 14052 d extending from the base member mates with and is received within the tubular upper hinge sleeve 14050 .
  • the base member 14052 b of the upper cam assembly 14052 further includes a plurality of circumferentially spaced apart teeth 14052 f that mate with and are received within a plurality of circumferentially spaced apart teeth 14034 j provided on the end face of the tubular spring housing 14034 and an end face of the external flange 14052 a of the base member of the upper cam assembly is positioned in opposing relation to an end face of the internal flange 14050 b of the tubular upper hinge sleeve 14050 .
  • Each of the cam arms 14052 d of the upper cam assembly 14052 include external cam surfaces 14052 e .
  • the teeth 14052 f of the base member 14052 b of the upper cam assembly 14052 and the teeth 14034 j provided on the end face of the tubular spring housing 14034 permit torsional loads to be transmitted between the tubular spring housing and the upper cam assembly.
  • a plurality of circumferentially spaced apart lower casing cutter segments 14058 are mounted upon and receive the lower tubular mandrel 14006 , are interleaved among the upper casing cutter segments 14054 , are oriented in the opposite direction to the upper casing cutter segments 14054 , each include an external pivot recess 14058 a , and are positioned in opposing relation to corresponding circumferentially spaced apart cam arms 14052 d of the upper cam assembly 14052 .
  • a lower cam assembly 14060 is mounted upon and receives the lower tubular mandrel 14006 that includes a base member 14060 a having an external flange 14060 b , a plurality of circumferentially spaced apart cam arms 14060 d that extend from the base member that each include external cam surfaces 14060 e and define mounting holes 14060 f and 14060 g .
  • the base member 14060 a of the lower cam assembly 14060 further includes a plurality of circumferentially spaced apart teeth 14060 h .
  • the circumferentially spaced apart cam arms 14060 d of the lower cam assembly 14060 are interleaved among the lower casing cutter segments 14058 and the circumferentially spaced apart cam arms 14052 d of the upper cam assembly 14052 and positioned in opposing relation to corresponding upper casing cutter segments 14054 .
  • Mounting screws, 14062 a , 14062 b , 14062 c , and 14062 e are mounted within the corresponding mounting holes, 14060 f and 14060 g , of the lower cam assembly 14060 and are received within the external annular recess 14006 g of the lower cam assembly 14060 .
  • Mounting screws, 14070 a and 14070 b are mounted in and coupled to the mounting holes, 14068 c and 14068 d , respectively, of the tubular member 14068 that also extend into the mounting holes, 14066 b and 14066 c , respectively, of the tubular sleeve 14066 .
  • a sealing element 14072 is received within the external annular recess 14068 e of the tubular member 14068 for sealing the interface between the tubular member and the tubular sleeve 14066 .
  • a sealing element 14076 is received within the external annular recess 14074 d of the tubular retracting piston 14074 for sealing the interface between the tubular retracting piston and the tubular sleeve 14066 .
  • a sealing element 14078 is received within the internal annular recess 14074 c of the tubular retracting piston 14074 for sealing the interface between the tubular retracting piston and the tubular lower mandrel 14006 .
  • Locking dogs 14080 mate with and receive the external teeth 14006 h of the tubular lower mandrel 14006 .
  • a spacer ring 14082 is positioned between an end face of the locking dogs 14080 and an end face of the lower cam assembly 14060 .
  • a release piston 14084 mounted upon the tubular lower mandrel 14006 defines a radial passage 14084 a for mounting a burst disk 14086 includes sealing elements, 14084 b , 14084 c , and 14084 d .
  • the sealing elements, 14084 b and 14084 d sealing the interface between the release piston 14084 and the tubular lower mandrel 14006 .
  • An end face of the release piston 14084 is positioned in opposing relation to an end face of the locking dogs 14080 .
  • the retracting spring 14044 is compressed and thereby applies a biasing spring force in a direction 14092 from the lower tubular mandrel 14006 to the tubular spring housing 14034 that, in the absence of other forces, moves and/or maintains the upper cam assembly 14052 and the upper casing cutter segments 14054 out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 .
  • an external threaded connection 12 a of an end of the tubular support member 12 is coupled to the internal threaded connection 14002 d of the upper tubular tool joint 14002 and an internal threaded connection 16 a of an end of the ball gripper assembly 16 is coupled to the external threaded connection 14068 f of the tubular member 14068 .
  • the upper cam assembly 14052 and the upper casing cutter segments 14054 may be brought into engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by pressurizing an annulus 14094 defined between the lower tubular mandrel 14006 and the tubular spring housing 14034 .
  • injection of fluidic materials into the cam cutter assembly 14 through the longitudinal passage 14006 b of the lower tubular mandrel 14006 and into the radial passage 14006 ba may pressurize the annulus 14094 thereby creating sufficient operating pressure to generate a force in a direction 14096 sufficient to overcome the biasing force of the retracting spring 14044 .
  • the spring housing 14034 may be displaced in the direction 14096 relative to the lower tubular mandrel 14006 thereby displacing the tubular upper hinge sleeve 14050 , upper cam assembly 14052 , and upper casing cutter segments 14054 in the direction 14096 .
  • the displacement of the upper cam assembly 14052 and upper casing cutter segments 14054 in the direction 14096 will cause the lower casing cutter segments 14058 to ride up the cam surfaces of the cam arms of the upper cam assembly 14052 while also pivoting about the lower tubular hinge segment 14064 , and will also cause the upper casing cutter segments 14054 to ride up the cam surfaces of the cam arms of the lower cam assembly 14060 while also pivoting about the upper tubular hinge segment 14050 .
  • the casing cutter elements of the casing cutter segments are brought into intimate contact with the interior surface of a pre-selected portion of the expandable wellbore casing 100 .
  • the casing cutter assembly 14 may then be rotated to thereby cause the casing cutter elements to cut through the expandable wellbore casing.
  • the portion of the expandable wellbore casing 100 cut away from the remaining portion on the expandable wellbore casing may then be carried out of the wellbore 102 with the cut away portion of the expandable wellbore casing supported by the casing cutter elements.
  • the upper cam assembly 14052 and the upper casing cutter segments 14054 may be moved out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by reducing the operating pressure within the annulus 14094 .
  • the upper cam assembly 14052 and the upper casing cutter segments 14054 may also be moved out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by sensing the operating pressure within the longitudinal passage 14006 b of the lower tubular mandrel 14006 .
  • the upper cam assembly 14052 and the upper casing cutter segments 14054 may also be moved out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by sensing the operating pressure within the longitudinal passage 14006 b of the lower tubular mandrel 14006 .
  • the burst disc 14086 will open the passage 14084 a thereby pressurizing the interior of the tubular release sleeve 14088 thereby displacing the tubular release sleeve 14088 downwardly in a direction 14092 away from engagement with the locking dogs 14080 .
  • the locking dogs 14080 are displaced outwardly in the radial directed and thereby released from engagement with the lower tubular mandrel 14006 thereby permitting the lower casing cutter segments 14058 and the lower cam assembly 14060 to be displaced downwardly relative to the lower tubular mandrel.
  • the operating pressure within the lower tubular mandrel 14066 may then cause the lower tubular mandrel to be displaced downwardly in the direction 14094 relative to the tubular lower mandrel 14006 and the retracting piston 14074 .
  • the lower tubular mandrel 14066 , the lower casing cutter segments 14058 , the lower cam assembly 14060 , and tubular lower hinge sleeve 14064 are displaced downwardly in the direction 14094 relative to the tubular spring housing 14034 thereby moving the lower casing cutter segments 14058 and the lower cam assembly 14060 out of engagement with the upper cam assembly 14052 and the upper casing cutter segments 14054 .
  • the casing cutter assembly 14 senses the diameter of the expandable wellbore casing 100 using the upper toggle links, 14022 and 14028 , lower toggle links, 14024 and 14030 , and triggers, 14026 and 14032 , and then prevents the engagement of the upper cam assembly 14052 and the upper casing cutter segments 14054 with the lower casing cutter segments 14058 and the lower cam assembly 14060 .
  • the triggers, 14026 and 14032 will be pivoted by the engagement arms, 14024 d and 14030 d , of the lower toggle links, 14024 and 14030 , to a position in which the triggers will no longer engage the internal flange 14034 d of the end of the tubular spring housing 14034 thereby permitting the displacement of the tubular spring housing in the direction 14096 .
  • the upper cam assembly 14052 and the upper casing cutter segments 14054 can be brought into engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 .
  • the upper toggle links, 14022 and 14028 , and the lower toggle links, 14024 and 14030 are spring biased towards the position illustrated in FIG. 11W .
  • the triggers, 14026 and 14032 will be maintained in a position in which the triggers will engage the internal flange 14034 d of the end of the tubular spring housing 14034 thereby preventing the displacement of the tubular spring housing in the direction 14096 .
  • the upper cam assembly 14052 and the upper casing cutter segments 14054 cannot be brought into engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 .
  • the triggers, 14026 and 14032 are spring biased towards the position illustrated in FIG. 11X .
  • the tubular spring housing 14034 may be displaced upwardly in the direction 14098 even if the upper toggle links, 14022 and 14028 , and lower toggle links, 14024 and 14030 , are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10 .
  • the tubular spring housing 14034 of the casing cutter assembly 14 defines internal annular recesses 14034 k and 14034 l , spaced apart by an internal flange 14034 m
  • the tubular toggle bushing 14008 defines an external annular recess 14008 ac
  • the casing cutter assembly further includes pins, 14100 a and 14100 b and 14102 a and 14102 b , mounted in holes 14008 j and 14008 o and 14008 k and 14008 n , respectively, of the tubular toggle bushing, and a one-shot deactivation device 14104 mounted on the tubular toggle bushing between the pins, 14100 a and 14100 b and 14102 a and 14102 b.
  • the one-shot deactivation device 14104 includes a tubular body 14104 a that defines radial holes, 14104 b and 14014 c , and includes an external annular recess 14104 d at one end, a centrally positioned external flange 14104 e , a centrally positioned internal annular recess 14104 f , and an external annular recess 14104 g at another end.
  • An engagement member 14106 that includes a base member 14106 a having a tapered end 14106 b and a key member 14106 c having a tapered end 14106 d is received within a portion of the internal annular recess 14104 f of the tubular body 14104 a and an engagement member 14108 that includes a base member 14108 a having a tapered end 14108 b and a key member 14108 c having a tapered end 14108 d is received within an opposite portion of the internal annular recess 14104 f of the tubular body 14104 a .
  • Spring members, 14110 and 14112 are received within the annular recess 14104 f of the tubular body 14104 a for biasing the base members, base member 14106 a and 14108 a , of the engagement members, 14106 and 14108 , respectively, radially inwardly relative to the tubular body 14104 a.
  • the one-shot deactivation device 14104 are positioned proximate and in intimate contact with the pins, 14102 a and 14102 b , with the tapered ends, 14106 b and 14108 b , of the base members, 14106 a and 14108 a , of the engagement members, 14106 and 14108 , received within the external annular recess 14008 ac of the tubular toggle bushing 14008 .
  • the one-shot deactivation device 14104 is positioned as illustrated in FIG.
  • the external annular recess 14104 d of the tubular body 14104 a of the one-shot deactivation device is moved out of engagement with the engagement arms, 14026 d and 14032 d , of the triggers, 14026 and 14032 , respectively.
  • the triggers, 14026 and 14032 may operate normally as described above with reference to FIGS. 11W, 11X , and 11 Y.
  • the one-shot deactivation device 14104 are positioned proximate and in intimate contact with the pins, 14100 a and 14100 b , with the tapered ends, 14106 b and 14108 b , of the base members, 14106 a and 14108 a , of the engagement members, 14106 and 14108 , not received within the external annular recess 14008 ac of the tubular toggle bushing 14008 .
  • the one-shot deactivation device 14104 is positioned as illustrated in FIGS.
  • the external annular recess 14104 d of the tubular body 14104 a of the one-shot deactivation device is moved into engagement with the engagement arms, 14026 d and 14032 d , of the triggers, 14026 and 14032 , respectively.
  • the triggers, 14026 and 14032 are deactivated and may not operate normally as described above with reference to FIGS. 11W, 11 x , and 11 Y.
  • the elements of the casing cutter assembly 14 that sense the diameter of the expandable wellbore casing 100 may be disabled or omitted or adjusted to sense any pre-selected internal diameter of the expandable wellbore casing.
  • the ball gripper assembly 16 is provided and operates substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, (2) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (3) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (4) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar.
  • PCT patent application serial number PCT/US04/010317 attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (6)
  • PCT patent application serial number PCT/US04/010712 attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (7)
  • PCT patent application serial number PCT/US04/010762 attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • the ball gripper assembly 16 includes an upper mandrel 1602 that defines a longitudinal passage 1602 a and a radial passage 1602 b and includes an internal threaded connection 1602 c at one end, an external flange 1602 d at an intermediate portion that includes an external annular recess 1602 e having a shoulder 1602 f and an external radial hole 1602 g , an external annular recess 1602 h , an external annular recess 1602 i , an external annular recess 1602 j having a tapered end 1602 k including an external annular recess 1602 ka , an external annular recess 1602 l , and an external annular recess 1602 m , and an external annular recess 1602 n , an external radial hole 1602 o , an external annular recess 1602
  • An upper tubular bushing 1604 defines an internally threaded radial opening 1604 a and includes an external flange 1604 b having an external annular recess 1604 c and an internal annular recess 1604 d mates with and receives the external flange 1602 d of the upper mandrel 1602 .
  • the internal annular recess 1604 d of the upper tubular bushing 1604 mates with the shoulder 1602 f of the external annular recess 1602 e of the upper mandrel 1602 .
  • a screw 1606 that is threadably coupled to the internally threaded radial opening 1604 a of the upper tubular bushing 1604 extends into the external radial hole 1602 g of the external flange 1602 d of the upper mandrel 1602 .
  • a deactivation tubular sleeve 1608 defines a radial passage 1608 a and includes an internal annular recess 1608 b that mates with and receives an end of the external annular recess 1604 c of the external flange 1604 b of the upper tubular bushing 1604 , an internal annular recess 1608 c that mates with and receives the external flange 1602 d of the upper mandrel 1602 , an internal annular recess 1608 d , an internal annular recess 1608 e , and an internal annular recess 1608 f .
  • a deactivation spring 1610 is received within an annulus 1612 defined between the internal annular recess 1608 b of the deactivation tubular sleeve 1608 , an end face of the external annular recess 1604 c of the external flange 1604 b of the upper tubular bushing 1604 , and the external annular recess 1602 h of the external flange 1602 d of the upper mandrel 1602 .
  • a sealing member 1614 is received with the external annular recess 1602 i of the external flange 1602 d of the upper mandrel 1602 for sealing the interface between the upper mandrel and the deactivation tubular sleeve 1608 .
  • An annular spacer element 1616 is received within the external annular recess 1602 ka of the tapered end 1602 k of the external annular recess 1602 j of the upper mandrel 1602 .
  • One or more inner engagement elements 1618 a of a tubular coglet 1618 engage and are received within the external annular recess 1602 ka of the tapered end 1602 k of the external annular recess 1602 j of the upper mandrel 1602 and one or more outer engagement elements 1618 b of the coglet engage and are received within the internal annular recess 1608 d of the deactivation tubular sleeve 1608 .
  • An external annular recess 1620 a of an end of a tubular coglet prop 1620 that includes an inner flange 1620 b receives and mates with the inner surfaces of the outer engagement elements 1618 b of the coglet 1618 .
  • the end of the tubular coglet prop 1620 further receives and mates with the external annular recess 1602 j of the external flange 1602 d of the upper mandrel 1602 .
  • a sealing element 1622 is received within the external annular recess 1602 l of the upper mandrel 1602 for sealing the interface between the upper mandrel and the tubular coglet prop 1620 .
  • An end of a tubular bumper sleeve 1624 that includes internal and external flanges, 1624 a and 1624 b , and a hole 1624 c at another end mates with and receives the external annular recess 1602 m of the external flange 1602 d of the upper mandrel 1602 .
  • a coglet spring 1626 is received within an annulus 1628 defined between the external annular recess 1602 m of the external flange 1602 d of the upper mandrel 1602 , the tubular coglet prop 1620 , the inner flange 1620 b of the tubular coglet prop, an end face of the tubular bumper sleeve 1624 , and the internal annular recess 1608 c of the deactivation tubular sleeve 1608 .
  • a tubular ball race 1628 that defines a plurality of tapered annular recesses 1628 a and an internally threaded radial opening 1628 b and includes one or more axial engagement elements 1628 c at one end and one or more axial engagement elements 1628 d at another end receives and mates with the other end of the upper mandrel 1602 .
  • the axial engagement elements 1628 c of the tubular ball race 1628 are received within and are coupled to the hole 1624 c of the tubular bumper sleeve 1624 .
  • An end of a tubular activation sleeve 1630 that defines a plurality of radial openings 1630 a , a radial opening 1630 b , a radial opening 1630 c , and includes an internal annular recess 1630 d receives and mates with the tubular ball race 1628 .
  • an end face of an end of the tubular activation sleeve 1630 is positioned proximate and in opposing relation to an end face of an end of the deactivation sleeve 1608 .
  • the radial openings 1630 a are aligned with and positioned in opposing relation to corresponding of tapered annular recesses 1628 a of the tubular ball race 1628 , and the radial openings are also narrowed in cross section in the radial direction for reasons to be described.
  • Balls 1632 are received within each of the of tapered annular recesses 1628 a and corresponding radial openings 1630 a of the tubular ball race 1628 and tubular activation sleeve 1630 , respectively.
  • the narrowed cross sections of the radial openings 1630 a of the tubular activation sleeve 1630 will permit the balls 1632 to be displaced outwardly in the radial direction until at least a portion of the balls extends beyond the outer perimeter of the tubular activation sleeve to thereby permit engagement of the balls with an outer structure such as, for example, a wellbore casing.
  • a lower mandrel 1634 that defines a longitudinal passage 1634 a and an internally threaded radial passage 1634 b at one end and includes internal annular recesses, 1634 c and 1634 d , for receiving and mating with the external annular recesses, 1602 p and 1602 q , of the upper mandrel 1602 , an internal annular recess 1634 e , an external flange 1634 f , and an externally threaded connection 1634 g at another end.
  • the end of the lower mandrel 1634 further includes longitudinal recesses 1634 h for receiving and mating with corresponding axial engagement elements 1628 d of the tubular ball race 1628 .
  • a sealing element 1635 is received within the internal annular recess 1634 d of the lower mandrel 1634 for sealing an interface between the lower mandrel and the external annular recess 1602 p of the upper mandrel 1602 .
  • a tubular spring retainer 1636 that defines a radial passage 1636 a and includes an external annular recess 1636 b at one end mates with and receives the end of the lower mandrel 1634 and is positioned proximate an end face of the external flange 1634 f of the lower mandrel.
  • a tubular spring retainer 1638 receives and mates with the end of the lower mandrel 1634 and is received and mates with the internal annular recess 1630 d of the tubular activation sleeve 1630 .
  • An activation spring 1640 is received within an annulus 1642 defined an end face of the tubular spring retainer 1638 , an end face of the spring retainer 1636 , the internal annular recess 1630 d of the tubular activation sleeve 1630 , and the end of the lower mandrel 1634 .
  • a retainer screw 1642 is received within and is threadably coupled to the internally threaded radial opening 1634 b of the lower mandrel 1634 that also extends into the external radial hole 1602 o of the upper mandrel 1602 .
  • the ball gripper assembly 16 may be positioned within the expandable wellbore casing 100 and the internally threaded connection 1602 c of the upper mandrel 1602 may be coupled to an externally threaded connection 14 a of an end of the casing cutter assembly 14 and the externally threaded connection 1634 g of the lower mandrel 1634 may be coupled to an internally threaded connection 18 a of an end of the tension actuator assembly 18 .
  • the internally threaded connection 1602 c of the upper mandrel 1602 may be coupled to an externally threaded connection of an end of the tension actuator assembly 18 and the externally threaded connection 1634 g of the lower mandrel 1634 may be coupled to an internally threaded connection of an end of casing cutter assembly 14 .
  • the deactivation spring 1610 has a greater spring rate than the activation spring 1640 .
  • a biasing spring force is applied to the deactivation sleeve 1608 and activation sleeve 1630 in a direction 1644 that maintains the activation sleeve in a position relative to the tubular ball race 1628 that maintains the balls 1632 within the radially inward portions of the corresponding tapered annular recesses 1628 a of the tubular ball race such that the balls do not extend beyond the perimeter of the activation sleeve to engage the expandable wellbore casing 100 .
  • the ball gripper 16 may be operated to engage the interior surface of the expandable wellbore casing 100 by injecting a fluidic material 1650 into the ball gripper assembly through the longitudinal passages 1602 a and 1634 aa , of the upper and lower mandrels, 1602 and 1634 , respectively.
  • the internal annular recess 1608 c of the deactivation tubular sleeve 1608 is pressurized.
  • the operating pressure of the fluidic material 1650 within the internal annular recess 1608 c of the deactivation tubular sleeve 1608 is sufficient to overcome the biasing spring force of the deactivation spring 1610 , the deactivation tubular sleeve is displaced in a direction 1652 .
  • the spring force provided by the activation spring 1640 then may displace the activation tubular sleeve 1630 in the direction 1652 thereby moving the balls 1632 on the corresponding tapered annular recesses 1628 a of the tubular ball race 1628 outwardly in a radial direction into engagement with the interior surface of the expandable wellbore casing 100 .
  • the operating pressure of the fluidic material 1650 sufficient to overcome the biasing spring force of the deactivation spring 1610 was about 100 psi.
  • the operating pressure of the fluidic material 1650 when the operating pressure of the fluidic material 1650 is reduced, the operating pressure of the fluidic material 1650 within the internal annular recess 1608 c of the deactivation tubular sleeve 1608 is no longer sufficient to overcome the biasing spring force of the deactivation spring 1610 , and the deactivation tubular sleeve and the activation tubular sleeve 1630 are displaced in a direction opposite to the direction 1652 thereby moving the balls 1632 radially inwardly and out of engagement with the interior surface of the expandable wellbore casing 100 .
  • the ball gripper assembly 16 is operated to engage the interior surface of the expandable wellbore casing 100 in combination with the operation of the tension actuator assembly 18 to apply an upward tensile force to one or more elements of the system 10 coupled to and positioned below the tension actuator assembly.
  • a reaction force comprising a downward tensile force is applied to the lower mandrel 1634 of the ball gripper assembly 16 in a direction opposite to the direction 1652 during the operation of the tension actuator assembly 18 .
  • the balls 1632 are driven up the tapered annular recesses 1628 a of the tubular ball race 1628 with increased force and the contact force between the balls 1632 and the interior surface of the expandable wellbore casing 100 is significantly increased thereby correspondingly increasing the gripping force and effect of the ball gripper assembly.
  • the ball gripper assembly 16 may be operated to radially expand and plastically deform discrete portions of the expandable wellbore casing 100 by controlling the amount of contact force applied to the interior surface of the expandable wellbore casing by the balls 1632 of the ball gripper assembly.
  • an expandable wellbore casing was radially expanded and plastically deformed. This was an unexpected result.
  • the tension actuator assembly 18 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (3) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (4) PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep.
  • the tension actuator assembly 18 includes an upper tubular support member 18002 that defines a longitudinal passage 18002 a , and external internally threaded radial openings, 18002 b and 18002 c , and an external annular recess 18002 d and includes an internally threaded connection 18002 e at one end and an external flange 18002 f , an external annular recess 18002 g having an externally threaded connection, and an internal annular recess 18002 h having an internally threaded connection at another end.
  • Torsional locking pins, 18006 a and 18006 b are coupled to and mounted within the external radial mounting holes, 18002 b and 18002 c , respectively, of the upper tubular support member and received within the radial passages, 18004 a and 18004 b , of the end of the tubular actuator barrel 18004 .
  • the other end of the tubular actuator barrel 18004 receives and is threadably coupled to an end of a tubular barrel connector 18008 that defines an internal annular recess 18008 a , external radial mounting holes, 18008 b and 18008 c , radial passages, 18008 d and 18008 e , and external radial mounting holes, 18008 f and 18008 g and includes circumferentially spaced apart teeth 18008 h at one end.
  • a sealing cartridge 18010 is received within and coupled to the internal annular recess 18008 a of the tubular barrel connector 18008 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge.
  • Torsional locking pins, 18012 a and 18012 b are coupled to and mounted within the external radial mounting holes, 18008 b and 18008 c , respectively, of the tubular barrel connector 18008 and received within the radial passages, 18004 c and 18004 d , of the tubular actuator barrel 18004 .
  • a tubular member 18014 that defines a longitudinal passage 18014 a having one or more internal splines 18014 b at one end and circumferentially spaced apart teeth 18014 c at another end for engaging the circumferentially spaced apart teeth 18008 h of the tubular barrel connector 18008 mates with and is received within the actuator barrel 18004 and the one end of the tubular member abuts an end face of the other end of the upper tubular support member 18002 and at another end abuts and end face of the tubular barrel connector 18008 .
  • a tubular guide member 18016 that defines a longitudinal passage 18016 a having a tapered opening 18016 aa , and radial passages, 18016 b and 18016 c , includes an external flange 18016 d having an externally threaded connection at one end that is received within and coupled to the internal annular recess 18002 h of the upper tubular support member 18002 .
  • the other end of the tubular barrel connector 18008 is threadably coupled to and is received within an end of a tubular actuator barrel 18018 that defines a longitudinal passage 18018 a , radial passages, 18018 b and 18018 c , and radial passages, 18018 d and 18018 e .
  • Torsional locking pins, 18020 a and 18020 b are coupled to and mounted within the external radial mounting holes, 18008 f and 18008 g , respectively, of the tubular barrel connector 18008 and received within the radial passages, 18018 b and 18018 c , of the tubular actuator barrel 18018 .
  • the other end of the tubular actuator barrel 18018 receives and is threadably coupled to an end of a tubular barrel connector 18022 that defines an internal annular recess 18022 a , external radial mounting holes, 18022 b and 18022 c , radial passages, 18022 d and 18022 e , and external radial mounting holes, 18022 f and 18022 g .
  • a sealing cartridge 18024 is received within and coupled to the internal annular recess 18022 a of the tubular barrel connector 18022 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge.
  • Torsional locking pins, 18024 a and 18024 b are coupled to and mounted within the external radial mounting holes, 18022 b and 18022 c , respectively, of the barrel connector 18022 and received within the radial passages, 18018 d and 18018 e , of the tubular actuator barrel 18018 .
  • the other end of the tubular barrel connector 18022 is threadably coupled to and is received within an end of a tubular actuator barrel 18026 that defines a longitudinal passage 18026 a , radial passages, 18026 b and 18026 c , and radial passages, 18026 d and 18026 e .
  • Torsional locking pins, 18028 a and 18028 b are coupled to and mounted within the external radial mounting holes, 18022 f and 18022 g , respectively, of the tubular barrel connector 18022 and received within the radial passages, 18026 b and 18026 c , of the tubular actuator barrel 18026 .
  • the other end of the tubular actuator barrel 18026 receives and is threadably coupled to an end of a tubular barrel connector 18030 that defines an internal annular recess 18030 a , external radial mounting holes, 18030 b and 18030 c , radial passages, 18030 d and 18030 e , and external radial mounting holes, 18030 f and 18030 g .
  • a sealing cartridge 18032 is received within and coupled to the internal annular recess 18030 a of the tubular barrel connector 18030 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge.
  • Torsional locking pins, 18034 a and 18034 b are coupled to and mounted within the external radial mounting holes, 18030 b and 18030 c , respectively, of the tubular barrel connector 18030 and received within the radial passages, 18026 d and 18026 e , of the tubular actuator barrel 18026 .
  • the other end of the tubular barrel connector 18030 is threadably coupled to and is received within an end of a tubular actuator barrel 18036 that defines a longitudinal passage 18036 a , radial passages, 18036 b and 18036 c , and radial passages, 18036 d and 18036 e .
  • Torsional locking pins, 18038 a and 18038 b are coupled to and mounted within the external radial mounting holes, 18030 f and 18030 g , respectively, of the tubular barrel connector 18030 and received within the radial passages, 18036 b and 18036 c , of the tubular actuator barrel 18036 .
  • the other end of the tubular actuator barrel 18036 receives and is threadably coupled to an end of a tubular barrel connector 18040 that defines an internal annular recess 18040 a , external radial mounting holes, 18040 b and 18040 c , radial passages, 18040 d and 18040 e , and external radial mounting holes, 18040 f and 18040 g .
  • a sealing cartridge 18042 is received within and coupled to the internal annular recess 18040 a of the tubular barrel connector 18040 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge.
  • Torsional locking pins, 18044 a and 18044 b are coupled to and mounted within the external radial mounting holes, 18040 b and 18040 c , respectively, of the tubular barrel connector 18040 and received within the radial passages, 18036 d and 18036 e , of the tubular actuator barrel 18036 .
  • the other end of the tubular barrel connector 18040 is threadably coupled to and is received within an end of a tubular actuator barrel 18046 that defines a longitudinal passage 18046 a , radial passages, 18046 b and 18046 c , and radial passages, 18046 d and 18046 e .
  • Torsional locking pins, 18048 a and 18048 b are coupled to and mounted within the external radial mounting holes, 18040 f and 18040 g , respectively, of the tubular barrel connector 18040 and received within the radial passages, 18046 b and 18046 c , of the tubular actuator barrel 18046 .
  • the other end of the tubular actuator barrel 18046 receives and is threadably coupled to an end of a tubular barrel connector 18050 that defines an internal annular recess 18050 a , external radial mounting holes, 18050 b and 18050 c , radial passages, 18050 d and 18050 e , and external radial mounting holes, 18050 f and 18050 g .
  • a sealing cartridge 18052 is received within and coupled to the internal annular recess 18050 a of the tubular barrel connector 18050 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge.
  • Torsional locking pins, 18054 a and 18054 b are coupled to and mounted within the external radial mounting holes, 18050 b and 18050 c , respectively, of the tubular barrel connector 18050 and received within the radial passages, 18046 d and 18046 e , of the tubular actuator barrel 18046 .
  • the other end of the tubular barrel connector 18050 is threadably coupled to and is received within an end of a tubular actuator barrel 18056 that defines a longitudinal passage 18056 a , radial passages, 18056 b and 18056 c , and radial passages, 18056 d and 18056 e .
  • Torsional locking pins, 18058 a and 18058 b are coupled to and mounted within the external radial mounting holes, 18050 f and 18050 g , respectively, of the tubular barrel connector 18050 and received within the radial passages, 18056 b and 18056 c , of the tubular actuator barrel 18056 .
  • the other end of the tubular actuator barrel 18056 receives and is threadably coupled to an end of a tubular lower stop 18060 that defines an internal annular recess 18060 a , external radial mounting holes, 18060 b and 18060 c , and an internal annular recess 18060 d that includes one or more circumferentially spaced apart locking teeth 18060 e at one end and one or more circumferentially spaced apart locking teeth 18060 f at the other end.
  • a sealing cartridge 18062 is received within and coupled to the internal annular recess 18060 a of the tubular lower stop 18060 for fluidicly sealing the interface between the tubular lower stop and the sealing cartridge.
  • Torsional locking pins, 18064 a and 18064 b are coupled to and mounted within the external radial mounting holes, 18060 b and 18060 c , respectively, of the tubular lower stop 18060 and received within the radial passages, 18056 d and 18056 e , of the tubular actuator barrel 18056 .
  • a connector tube 18066 that defines a longitudinal passage 18066 a and radial mounting holes, 18066 b and 18066 c , and includes external splines 18066 d at one end for engaging the internal splines 18014 b of the tubular member 18014 and radial mounting holes, 18066 e and 18066 f , at another end is received within and sealingly and movably engages the interior surface of the sealing cartridge 18010 mounted within the annular recess 18008 a of the tubular barrel connector 18008 . In this manner, during longitudinal displacement of the connector tube 18066 relative to the tubular barrel connector 18008 , a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the tubular barrel connector.
  • An end of the connector tube 18066 also receives and mates with the other end of the tubular guide member 18016 .
  • Mounting screws, 18068 a and 18068 b are coupled to and received within the radial mounting holes, 18066 b and 18066 c , respectively of the connector tube 18066 .
  • the other end of the connector tube 18066 is received within and threadably coupled to an end of a tubular piston 18070 that defines a longitudinal passage 18070 a , radial mounting holes, 18070 b and 18070 c , radial passages, 18070 d and 18070 e , and radial mounting holes, 18070 f and 18070 g , that includes a flange 18070 h at one end.
  • a sealing cartridge 18072 is mounted onto and sealingly coupled to the exterior of the tubular piston 18070 proximate the flange 18070 h .
  • the sealing cartridge 18072 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18018 .
  • Mounting screws, 18074 a and 18074 b are coupled to and mounted within the external radial mounting holes, 18070 b and 18070 c , respectively, of the tubular piston 18070 and received within the radial passages, 18066 e and 18066 f , of the connector tube 18066 .
  • the other end of the tubular piston 18070 receives and is threadably coupled to an end of a connector tube 18076 that defines a longitudinal passage 18076 a , radial mounting holes, 18076 b and 18076 c , at one end and radial mounting holes, 18076 d and 18076 e , at another end.
  • the connector tube 18076 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18024 mounted within the annular recess 18022 a of the tubular barrel connector 18022 . In this manner, during longitudinal displacement of the connector tube 18076 relative to the tubular barrel connector 18022 , a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector.
  • the other end of the connector tube 18076 is received within and threadably coupled to an end of a tubular piston 18080 that defines a longitudinal passage 18080 a , radial mounting holes, 18080 b and 18080 c , radial passages, 18080 d and 18080 e , and radial mounting holes, 18080 f and 18080 g , that includes a flange 18080 h at one end.
  • a sealing cartridge 18082 is mounted onto and sealingly coupled to the exterior of the tubular piston 18080 proximate the flange 18080 h .
  • the sealing cartridge 18082 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18026 .
  • Mounting screws, 18084 a and 18084 b are coupled to and mounted within the external radial mounting holes, 18080 b and 18080 c , respectively, of the tubular piston 18080 and received within the radial passages, 18076 e and 18076 f , of the connector tube 18076 .
  • the other end of the tubular piston 18080 receives and is threadably coupled to an end of a connector tube 18086 that defines a longitudinal passage 18086 a , radial mounting holes, 18086 b and 18086 c , at one end and radial mounting holes, 18086 d and 18086 e , at another end.
  • the connector tube 18086 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18032 mounted within the annular recess 18030 a of the tubular barrel connector 18030 . In this manner, during longitudinal displacement of the connector tube 18086 relative to the tubular barrel connector 18030 , a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector.
  • Mounting screws, 18088 a and 18088 b are coupled to and mounted within the external radial mounting holes, 18080 f and 18080 g , respectively, of the tubular piston 18080 and received within the radial passages, 18086 b and 18086 c , of the connector tube 18086 .
  • the other end of the connector tube 18086 is received within and threadably coupled to an end of a tubular piston 18090 that defines a longitudinal passage 18090 a , radial mounting holes, 18090 b and 18090 c , radial passages, 18090 d and 18090 e , and radial mounting holes, 18090 f and 18090 g , that includes a flange 18090 h at one end.
  • a sealing cartridge 18092 is mounted onto and sealingly coupled to the exterior of the tubular piston 18090 proximate the flange 18090 h .
  • the sealing cartridge 18092 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18036 .
  • Mounting screws, 18094 a and 18094 b are coupled to and mounted within the external radial mounting holes, 18090 b and 18090 c , respectively, of the tubular piston 18090 and received within the radial passages, 18086 e and 18086 f , of the connector tube 18086 .
  • the other end of the tubular piston 18090 receives and is threadably coupled to an end of a connector tube 18096 that defines a longitudinal passage 18096 a , radial mounting holes, 18096 b and 18096 c , at one end and radial mounting holes, 18096 d and 18096 e , at another end.
  • the connector tube 18096 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18042 mounted within the annular recess 18040 a of the tubular barrel connector 18040 . In this manner, during longitudinal displacement of the connector tube 18096 relative to the tubular barrel connector 18040 , a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector.
  • Mounting screws, 18098 a and 18098 b are coupled to and mounted within the external radial mounting holes, 18090 f and 18090 g , respectively, of the tubular piston 18090 and received within the radial passages, 18096 b and 18096 c , of the connector tube 18096 .
  • the other end of the connector tube 18096 is received within and threadably coupled to an end of a tubular piston 18100 that defines a longitudinal passage 18100 a , radial mounting holes, 18100 b and 18100 c , radial passages, 18100 d and 18100 e , and radial mounting holes, 18100 f and 18100 g , that includes a flange 18100 h at one end.
  • a sealing cartridge 18102 is mounted onto and sealingly coupled to the exterior of the tubular piston 18100 proximate the flange 18100 h .
  • the sealing cartridge 18102 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18046 .
  • Mounting screws, 18104 a and 18104 b are coupled to and mounted within the external radial mounting holes, 18100 b and 18100 c , respectively, of the tubular piston 18100 and received within the radial passages, 18096 e and 18096 f , of the connector tube 18096 .
  • the other end of the tubular piston 18100 receives and is threadably coupled to an end of a connector tube 18106 that defines a longitudinal passage 18106 a , radial mounting holes, 18106 b and 18106 c , at one end and radial mounting holes, 18106 d and 18106 e , at another end.
  • the connector tube 18106 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18052 mounted within the annular recess 18050 a of the tubular barrel connector 18050 . In this manner, during longitudinal displacement of the connector tube 18106 relative to the tubular barrel connector 18050 , a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector.
  • Mounting screws, 18108 a and 18108 b are coupled to and mounted within the external radial mounting holes, 18100 f and 18100 g , respectively, of the tubular piston 18100 and received within the radial passages, 18106 b and 18106 c , of the connector tube 18106 .
  • the sealing cartridge 18112 also mates with and sealingly engages the interior surface of the actuator barrel 18056 . In this manner, during longitudinal displacement of the tubular piston 18110 relative to the actuator barrel 18056 , a fluidic seal is maintained between the exterior surface of the piston and the interior surface of the actuator barrel.
  • Mounting screws, 18114 a and 18114 b are coupled to and mounted within the external radial mounting holes, 18110 b and 18110 c , respectively, of the tubular piston 18110 and received within the radial passages, 18106 d and 18106 e , of the connector tube 18106 .
  • the other end of the tubular piston 18110 receives and is threadably coupled to an end of a connector tube 18116 that defines a longitudinal passage 18116 a , radial mounting holes, 18116 b and 18116 c , at one end and radial mounting holes, 18116 d and 18116 e , at another end that includes an external flange 18116 f that includes circumferentially spaced apart teeth 18116 g that extend from an end face of the external flange for engaging the teeth 18060 f of the tubular lower stop 18060 , and an externally threaded connection 18116 h at another end.
  • the connector tube 18116 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18062 mounted within the annular recess 18060 a of the lower tubular stop 18060 . In this manner, during longitudinal displacement of the connector tube 18116 relative to the lower tubular stop 18060 , a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the lower tubular stop.
  • Mounting screws, 18118 a and 18118 b are coupled to and mounted within the external radial mounting holes, 18110 f and 18110 g , respectively, of the tubular piston 18110 and received within the radial passages, 18116 b and 18116 c , of the connector tube 18116 .
  • the injected fluidic material 18200 will also pass through the radial passages, 18070 d and 18070 e , 18080 d and 18080 e , 18090 d and 18090 e , 18100 d and 18100 e , 18110 d and 18110 e , of the tubular pistons, 18070 , 18080 , 18090 , 18100 , and 18110 , respectively, into annular piston chambers, 18202 , 18204 , 18206 , 18208 , 18208 , and 18210 .
  • the operating pressure of the fluidic material 18200 may then be increased by, for example, controllably blocking or limiting the flow of the fluidic material through the passage 18116 a and/or increasing the operating pressure of the outlet of a pumping device for injecting the fluidic material 18200 into the tension actuator assembly 18 .
  • the operating pressures of the annular piston chambers, 18202 , 18204 , 18206 , 18208 , 18208 , and 18210 will be increased sufficiently to displace the tubular pistons, 18070 , 18080 , 18090 , 18100 , and 18110 , upwardly in the direction 18212 thereby also displacing the connector tube 18116 .
  • a upward tensile force is applied to all elements of the system 10 coupled to and positioned below the connector tube 18116 .
  • fluidic materials displaced by the tubular pistons within discharge annular chambers, 18214 , 18216 , 18218 , 18220 , and 18222 are exhausted out of the tension actuator assembly 18 through the radial passages, 18008 d and 18008 e , 18022 d and 18022 e , 18030 d and 18030 e , 18040 d and 18040 e , 18050 d and 18050 e , respectively.
  • the upward displacement of the tubular pistons, 18070 , 18080 , 18090 , 18100 , and 18110 further causes the external splines 18066 d of the connector tube 18066 to engage the internal splines 18014 b of the tubular member 18014 and the circumferentially spaced apart teeth 18116 g of the connector tube 18116 to engage the circumferentially spaced teeth 18060 f of the tubular lower stop 18060 .
  • the safety sub assembly 20 includes a tubular body 200 a that defines a longitudinal passage 200 b and includes an external flange 200 c and an internal annular recess 200 d at one end, and external annular recesses, 200 e , 200 f , 200 g , and 200 h at another end.
  • a sealing member 202 is positioned within the external annular recess 200 h at the other end of the tubular body 200 a.
  • the sealing cup assembly 22 includes an upper tubular mandrel 2202 that defines a longitudinal passage 2202 a and internally threaded radial mounting holes, 2202 b and 2202 c , and includes an internal annular recess 2202 d at one end, an internal annular recess 2202 e , an internal annular recess 2202 f , an internal annular recess 2202 g , and an internally threaded internal annular recess 2202 h and an external flange 2202 i at another end.
  • the internal annular recesses, 2202 d , 2202 e , and 2202 f , of the upper tubular mandrel 2202 of the sealing cup assembly 22 receive, mate with, and are coupled to the other end of the tubular body 200 a of the safety sub assembly 20 .
  • Mounting screws, 2250 a and 2205 b are received within and coupled to the mounting holes, 2202 c and 2202 b , respectively, of the tubular mandrel 2202 that extend into and engage the external annular recess 2204 c of the lower tubular mandrel 2204 .
  • a tubular cup seal spacer 2206 receives and is mounted upon the lower tubular mandrel 2204 proximate the external flange 2202 i of the upper tubular mandrel 2202 .
  • a tubular cup seal retainer 2208 that includes an internal flange 2208 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the tubular cup seal spacer 2206 .
  • a tubular cup seal retainer 2210 that includes an internal flange 2210 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2208 .
  • a sealing member 2211 is received within the external annular recess 2204 b of the lower tubular mandrel 2204 for sealing the interface between the lower tubular mandrel and the upper tubular mandrel 2202 .
  • a tubular spacer 2214 receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal 2212 .
  • a tubular cup seal spacer 2216 receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular spacer 2214 .
  • a tubular cup seal retainer 2218 that includes an internal flange 2218 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal spacer 2216 .
  • a tubular cup seal retainer 2220 that includes an internal flange 2220 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2218 .
  • tubular cup seal retainer 2220 is nested within the other end of the tubular cup seal retainer 2218 .
  • a tubular cup seal 2222 that includes an internal flange 2222 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2220 .
  • the tubular cup seal 2222 is nested within the other end of the tubular cup seal retainer 2220 .
  • a tubular spacer 2224 receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal 2222 at one end and proximate the external flange 2204 d of the lower tubular mandrel at another end.
  • a retaining ring 2226 receives and is mounted upon the other end of the tubular spacer 2224 proximate the external flange 2204 d of the lower tubular mandrel 2204 .
  • the end of the tubular body 200 a of the safety sub assembly 20 is coupled to and receives and is coupled to an end of the tension actuator assembly 18 and the other end of the lower tubular mandrel 2204 of the sealing cup assembly 22 is received within and is coupled to an end of the casing lock assembly 24 .
  • the adjustable bell section expansion cone assembly 28 and/or the adjustable casing expansion cone assembly 30 may radially expand and plastically deform the expandable wellbore casing 100 .
  • the sealing cup assembly 22 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (3) PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, and/or (4) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep.
  • PCT patent application serial number PCT/US03/14153 attorney docket number 25791.104.02, filed on Nov. 13, 2003
  • PCT patent application serial number PCT/US03/18530 attorney docket number 25791.108.02, filed on Jun. 11, 2003
  • PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02 filed on Mar. 11, 2004, and/or (8)
  • PCT patent application serial number PCT/US04/009434 attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (9)
  • PCT patent application serial number PCT/US04/010317 attorney docket number 25791.270.02, filed on Apr.
  • PCT patent application serial number PCT/US04/010712 attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (11)
  • PCT patent application serial number PCT/US04/010762 attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • the casing lock assembly 24 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (3) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (4) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar.
  • PCT patent application serial number PCT/US04/009434 attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (6)
  • PCT patent application serial number PCT/US04/010317 attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (7)
  • PCT patent application serial number PCT/US04/010712 attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (8)
  • PCT patent application serial number PCT/US04/010762 attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • the extension actuator assembly 26 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (3) PCT patent application serial number PCT/US03/13787, attorney docket number 25791.107.02, filed on May 5, 2003, and/or (4) PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep.
  • the extension actuator assembly 26 combines the functionality of the casing lock assembly 24 with the functionality of the extension actuator assembly, and includes a tubular upper tool joint 26002 that defines a longitudinal passage 26002 a and mounting holes, 26002 b and 26002 c , and includes an internal threaded connection 26002 d at one end, an external flange 26002 e , an external recess 26002 f having an external threaded connection, a tapered recess 26002 g , and an external recess 26002 h and an internal recess 26002 i at another end.
  • An end of an upper pull-nut tube 26004 that defines a longitudinal passage 26004 a and includes an external recess 26004 b and an internally threaded internal recess 26004 c at another end is received within and mates with the longitudinal passage 26002 a of the tubular upper tool joint 26002 .
  • An internally threaded end of an lower pull-nut tube 26008 that defines a longitudinal passage 26008 a and includes an external recess 26008 b receives, mates with, and is coupled to externally threaded connection 26006 f of the tubular inner mandrel 26006 .
  • An internal flange 26010 a of an end of a tubular lock mandrel 26010 that defines a longitudinal passage 26010 b , radial passages, 26010 c and 26010 d , a radial passage 26010 e , and a radial passage 26010 f having an internal annular recess 26016 fa and includes an external flange 26010 g that mates with and is received within the internal recess 26002 i of the tubular upper tool joint 26002 , an external annular recess 26010 h , an external flange 26010 i , an external flange 26010 j , an external flange 26010 k , an external flange 26010 l , an external flange 26010 m that includes an external annular recess 26010 ma , an external flange 26010 n that defines mounting holes, 26010 o and 26010 p ,
  • Internal flanges, 26012 a and 26012 b , of a first locking dog 26012 that defines a radial passage 26012 c and includes spring arms, 26012 d and 26012 e , and an external flange 26012 f including external teeth 26012 g are positioned upon the external flanges, 26010 i and 26010 j , of the tubular lock mandrel 26010 .
  • Internal flanges, 26014 a and 26014 b , of a second locking dog 26014 that defines a radial passage 26014 c and includes spring arms, 26014 d and 26014 e , and an external flange 26014 f including external teeth 26014 g are positioned upon the external flanges, 26010 i and 26010 j , of the tubular lock mandrel 26010 .
  • a tubular retainer sleeve 26016 that defines a longitudinal passage 26016 a , radial passages, 26016 b and 26016 c , at one end, radial passages, 26016 d and 26016 e , for receiving and mating with the external flanges, 26012 f and 26014 f , respectively, of the first and second locking dogs, 26012 and 26014 , respectively, and radial passages, 26016 f and 26016 g , at another end and includes a tapered internal flange 26016 h , a tapered internal recess 26016 i that receives and mates with the spring arms, 26012 d and 26014 d , and ends of the first and second locking dogs, respectively, a tapered internal recess 26016 j that receives and mates with the springs arms, 26012 e and 26014 e , and other ends of the
  • the ends of the spring arms, 26012 d and 26014 d , of the first and second locking dogs, 26012 and 26014 , respectively, are held between the internal surface of the end of the tapered internal recess 26016 l of the tubular retainer sleeve 26016 and the external surface of the end of the tapered external annular recess 26002 h of the tubular upper tool joint 26002 .
  • the ends of the spring arms, 26012 e and 26014 e , of the first and second locking dogs, 26012 and 26014 , respectively, are held between the internal surface of the end of the tapered internal recess 26016 j of the tubular retainer sleeve 26016 and the external surface of the end of the tapered external annular recess 26018 e of the tubular connector 26018 .
  • a sealing member 26020 is received within the external annular recess 26010 h of the tubular lock mandrel 26010 for sealing the interface between the tubular lock mandrel and the tubular upper tool joint 26002 .
  • a sealing member 26022 is received within the external annular recess 26010 q of the tubular lock mandrel 26010 for sealing the interface between the tubular lock mandrel and the tubular connector 26018 .
  • a tubular face seal 26024 , tubular face seal back-up 26026 , a spring 26028 , and a plunger 26030 are mounted upon and retained upon the external annular recess 26018 g of the tubular connector 26018 by a snap ring 26032 that is coupled to the external annular recess of the tubular connector.
  • a burst disk 26034 and tubular burst disk bushing 26036 are mounted within the radial passage 26010 f of the tubular lock mandrel 26010 , and a sealing member 26038 is received within the internal annular recess 26010 fa of the radial passage of the tubular lock mandrel for sealing the interface between the tubular burst disk bushing and the tubular lock mandrel.
  • An internally threaded end 26040 a of a tubular release body 26040 that defines a longitudinal passage 26040 b , radial passages, 26040 c and 26040 d , radial mounting holes, 26040 e and 26040 f , radial mounting holes, 26040 g and 26040 h , and includes an internal flange 26040 i that mates with and receives the external flange 26010 n of the tubular lock mandrel 26010 , an internal flange 26040 j that mates with and receives the tubular lock mandrel receives, and an external annular recess 26040 k mates with, and is coupled to an externally threaded end 26018 h of the tubular connector 26018 .
  • Shear pins, 26046 a and 26046 b are received within and coupled to the radial mounting holes, 26010 o and 26040 e , and 26010 p and 26040 f , respectively, of the tubular lock mandrel 26010 and tubular release body 26040 , respectively.
  • Torque pins, 26048 a and 26048 b are received within and coupled to the radial mounting holes, 26018 c and 26018 d , respectively, of the tubular connector 26018 that also extend into the radial passages, 26040 c and 26040 d , respectively, of the tubular release body 26040 .
  • a sealing member 26050 received within the external annular recess 26010 r of the tubular lock mandrel 26010 seals the interface between the tubular lock mandrel and the internal flange 26040 j of the tubular release body 26040 .
  • An internally threaded end 26052 a of a tubular extender barrel 26052 that defines a longitudinal passage 26052 b , radial passages, 26052 c and 26052 d , and radial passages, 26052 e and 26052 f , and includes receives, mates with, and is coupled to an external threaded connection 26040 l of the tubular release body 26040 .
  • a sealing member 26054 received within the external annular recess 26040 k of the tubular release body 26040 seals the interface between the tubular release body and the tubular extender barrel 26052 .
  • Torque pins, 26058 a and 26058 b are mounted within and coupled to the mounting holes, 26056 c and 26056 d , respectively, of the tubular lower bushing 26056 that also extend into the radial passages, 26052 e and 26052 f , respectively, of the tubular extender barrel 26052 .
  • a tubular connecting rod 26060 that defines a longitudinal passage 26060 a that receives and mates with the lower pull-nut tube 26008 , radial passages, 26060 b and 26060 c , and radial mounting holes, 26060 d and 26060 e , and includes an external threaded connection 26060 f at one end, and an external threaded connection 26060 g at another end is slidably received within the longitudinal passage 25056 b of the tubular lower bushing 26056 .
  • An internal threaded connection 26062 a of an inner mandrel tubular piston 26062 that defines mounting holes, 26062 b and 26062 c , and includes an internal flange 26062 d at one end that receives and mates with the tubular inner mandrel 26006 , an external annular recess 26062 e , and a plurality of circumferentially spaced apart teeth 26062 f at another end receives, mates with, and is coupled to the external threaded connection 26060 f of the tubular connecting rod 26060 .
  • Torque screws, 26064 a and 26064 b are mounted within and coupled to the mounting holes, 26062 b and 26062 c , respectively, of the inner mandrel tubular piston 26062 that also extend into the radial passages, 26060 b and 26060 c , of the tubular connecting rod 26060 .
  • a sealing member 26066 positioned within the external annular recess 26062 e of the inner mandrel tubular piston 26062 seals the interface between the inner tubular piston and the tubular extender barrel 26052 .
  • a sealing member 26068 positioned within the external annular recess 26056 i of the tubular lower bushing 26056 seals the interface between the tubular lower bushing and the tubular extender barrel 26052 .
  • a packing sealing element 26070 is received within the internal annular recess 25056 f of the tubular lower bushing 26056 , and a packing retainer 26072 is received within the internal annular recess 26056 e of the tubular lower bushing for sealing the interface between the tubular lower bushing and the tubular connecting rod 26060 .
  • the packing sealing element 26070 and the packing retainer 26072 are retained within the internal annular recess 25056 f of the tubular lower bushing 26056 and internal annular recess 26056 e of the tubular lower bushing, respectively, by a snap ring 26074 that is coupled to the tubular connecting rod 26060 .
  • An internally threaded connection 26076 a of a tubular lower tool joint 26076 that defines a longitudinal passage 26076 b , radial mounting holes, 26076 c and 26076 d , and radial mounting holes, 26076 e and 26076 f , and includes an internal annular recess 26076 g and an external annular recess 26076 h receives, mates with, and is coupled to an external threaded connection 26060 g of the tubular connecting rod 26060 .
  • Torque screws, 26078 a and 26078 b are mounted within and coupled to the mounting holes, 26076 c and 26076 d , respectively, of the tubular lower tool joint 26076 that also extend into the radial passages, 26060 d and 26060 e , of the tubular connecting rod 26060 .
  • a sealing member 26080 is received within the internal annular recess 26076 g of the tubular lower tool joint 26076 for sealing the interface between the tubular lower tool joint and the tubular connecting rod 26060 .
  • the extension actuator assembly during operation of the extension actuator assembly 26 , as illustrated in FIGS. 15 E 1 to 15 E 5 , the extension actuator assembly is positioned within the wellbore 102 , the internal threaded connection 26002 d of the tubular upper tool joint 26002 receives, mates with, and is coupled to an end of the sealing cup assembly 22 , and the end of the tubular lower tool joint 26076 is received within, mates with, and is coupled to an end of the adjustable bell section expansion cone assembly 28 .
  • a portion 100 a of the expandable wellbore casing 100 includes internal teeth 100 b that engage with, and are coupled to, the external teeth, 26012 g and 26014 g , of the first and second locking dogs, 26012 and 26014 , respectively. In this manner, the expandable wellbore casing 100 is locked to the extension actuator assembly 26 of the system 10 .
  • a fluidic material 26100 may then be injected into the extension actuator assembly through the longitudinal passages 26004 a , 26006 a , and 26008 a of the upper pull-nut tube 26004 , tubular inner mandrel 26006 , and lower pull-nut tube 26008 , respectively, thereby pressurizing the longitudinal passages of the upper pull-nut tube, tubular inner mandrel, and lower pull-nut tube.
  • the fluidic material 26100 is also conveyed through the radial passage 26006 c of the tubular inner mandrel 26006 into and through an annulus 26102 defined between the tubular inner mandrel and the tubular lock mandrel 26010 .
  • the fluidic material 26100 is then conveyed into an annulus 26104 defined between the tubular inner mandrel 26006 and the tubular extender barrel 26052 proximate an end face of the inner mandrel tubular piston 26062 .
  • the continued injection of the fluidic material 26100 into the extension actuator assembly 26 will then displace the inner mandrel tubular piston 26062 downwardly in a direction 26106 .
  • the tubular connecting rod 26060 and the tubular lower tool joint 26076 are also displaced downwardly in the direction 26106 .
  • the continued injection of the fluidic material 26100 into the extension actuator assembly 26 will then further displace the inner mandrel tubular piston 26062 downwardly in the direction 26106 until an end face of the inner flange 26062 d of the inner mandrel tubular piston engages an end face of the lower pull-nut tube 26008 .
  • the lower pull-nut tube 26008 , the tubular inner mandrel 26006 , the upper pull-nut tube 26004 , and the tubular lock mandrel 26010 are also displaced downwardly in the direction 26106 thereby shearing the shear pins, 26064 a and 26064 b , and disengaging the tubular lock mandrel from the tubular release body 26040 .
  • a spring bias force in an inner radial direction is applied by the spring arms, 26012 d and 26012 e , and 26014 d and 26014 e , of the first and second locking dogs, 26012 and 26014 , respectively, to the first and second locking dogs thereby displacing the first and second locking dogs in an inner radial direction out of engagement with the portion 100 a of the expandable wellbore casing 100 .
  • the expandable wellbore casing 100 is no longer locked to the first and second locking dogs, 26012 and 26014 , of the extension actuator assembly 26 .
  • the expandable wellbore casing 100 may also be un-locked from engagement with the first and second locking dogs, 26012 and 26014 , of the extension actuator assembly by increasing the operating pressure of the fluidic material 26100 above a predetermined level sufficient to rupture the burst disk 26034 .
  • the fluidic material 26100 will enter an annulus 26108 defined between the tubular lock mandrel 26010 and the tubular release body 26040 .
  • tubular lock mandrel 26010 will be displaced downwardly in the direction 26106 thereby displacing the external flanges, 26010 i and 26010 j , of the tubular lock mandrel out of engagement with the internal flanges, 26012 a and 26012 b , and 26014 a and 26014 b , of the first and second locking dogs, 26012 and 26014 , respectively.
  • a spring bias force in an inner radial direction is applied by the spring arms, 26012 d and 26012 e , and 26014 d and 26014 e , of the first and second locking dogs, 26012 and 26014 , respectively, to the first and second locking dogs thereby displacing the first and second locking dogs in an inner radial direction out of engagement with the portion 100 a of the expandable wellbore casing 100 .
  • the expandable wellbore casing 100 is no longer locked to the first and second locking dogs, 26012 and 26014 , of the extension actuator assembly 26 .
  • the predetermined operating pressure of the fluidic material 26100 sufficient to rupture the burst disk 26034 is selected to provide a release of the expandable wellbore casing 100 from engagement with the first and second locking dogs, 26012 and 26104 , in the event of an emergency operating condition during the operation of the system 10 .
  • the pressurization of the longitudinal passages 26004 a , 26006 a , and 26008 a of the upper pull-nut tube 26004 , tubular inner mandrel 26006 , and lower pull-nut tube 26008 , respectively, caused by the injection of the fluidic material 26100 may be further enhanced by blocking the flow of the fluidic material to those portions of the system 10 downstream from the extension actuator assembly 26 by, for example, blocking flow through a flow restriction defined in one or more of the elements of the system downstream of the extension actuator assembly by placing a ball or plug in one or more of those flow restrictions.
  • the adjustable bell section expansion cone assembly 28 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (3) PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, and/or (4) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep.
  • PCT patent application serial number PCT/US03/14153 attorney docket number 25791.104.02, filed on Nov. 13, 2003
  • PCT patent application serial number PCT/US03/18530 attorney docket number 25791.108.02, filed on Jun. 11, 2003
  • PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02 filed on Mar. 11, 2004, and/or (8)
  • PCT patent application serial number PCT/US04/009434 attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (9)
  • PCT patent application serial number PCT/US04/010317 attorney docket number 25791.270.02, filed on Apr.
  • PCT patent application serial number PCT/US04/010712 attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (11)
  • PCT patent application serial number PCT/US04/010762 attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • the adjustable bell section expansion cone assembly 28 includes an upper tubular tool joint 28002 that defines a longitudinal passage 28002 a and mounting holes, 28002 b and 28002 c , and includes an internal threaded connection 28002 d , an inner annular recess 28002 e , an inner annular recess 28002 f , and an internal threaded connection
  • a tubular torque plate 28004 that defines a longitudinal passage 28004 a and includes circumferentially spaced apart teeth 28004 b is received within, mates with, and is coupled to the internal annular recess 28002 e of the upper tubular tool joint 28002 .
  • a sealing element 28010 is received within the external annular recess 28008 y of the tubular toggle bushing 28008 for sealing the interface between the tubular toggle bushing and the upper tubular tool joint 28002 .
  • a sealing element 28012 is received within the internal annular recess 28008 z of the tubular toggle bushing 28008 for sealing the interface between the tubular toggle bushing and the tubular lower mandrel 28006 .
  • Mounting screws, 28014 a and 28014 b , mounted within and coupled to the mounting holes, 28008 w and 28008 x , respectively, of the tubular toggle bushing 28008 are also received within the mounting holes, 28002 b and 28002 c , of the upper tubular tool joint 28002 .
  • Mounting pins, 28016 a , 28016 b , 28016 c , 28016 d , and 28016 e are mounted within the mounting holes, 28008 e , 28008 f , 28008 g , 28008 h , and 28008 l , respectively.
  • Mounting pins, 28018 a , 28018 b , 28018 c , 28018 d , and 28018 e are mounted within the mounting holes, 28008 t , 28008 s , 28008 r , 28008 q , and 28008 p , respectively.
  • Mounting screws, 28020 a and 28020 b are mounted within the mounting holes, 28008 u and 28008 v , respectively.
  • a first upper toggle link 28022 defines mounting holes, 28022 a and 28022 b , for receiving the mounting pins, 28016 a and 28016 b , and includes a mounting pin 28022 c at one end.
  • a first lower toggle link 28024 defines mounting holes, 28024 a , 28024 b , and 28024 c , for receiving the mounting pins, 28022 c , 28016 c , and 28016 d , respectively and includes an engagement arm 28024 d .
  • a first trigger 28026 defines a mounting hole 28026 a for receiving the mounting pin 28016 e and includes an engagement arm 28026 b at one end, an engagement member 28026 c , and an engagement arm 28026 d at another end.
  • a second upper toggle link 28028 defines mounting holes, 28028 a and 28028 b , for receiving the mounting pins, 28018 a and 28018 b , and includes a mounting pin 28028 c at one end.
  • a second lower toggle link 28030 defines mounting holes, 28030 a , 28030 b , and 28030 c , for receiving the mounting pins, 28028 c , 28018 c , and 28018 d , respectively and includes an engagement arm 28030 d .
  • a second trigger 28032 defines a mounting hole 28032 a for receiving the mounting pin 28018 e and includes an engagement arm 28032 b at one end, an engagement member 28032 c , and an engagement arm 28032 d at another end.
  • An end of a tubular spring housing 28034 that defines a longitudinal passage 28034 a , mounting holes, 28034 b and 28034 c , and mounting holes, 28034 ba and 28034 ca , and includes an internal flange 28034 d and an internal annular recess 28034 e at one end, and an internal flange 28034 f , an internal annular recess 28034 g , an internal annular recess 28034 h , and an external threaded connection 28034 i at another end receives and mates with the end of the tubular toggle bushing 28008 .
  • Mounting screws, 28035 a and 28035 b are mounted within and coupled to the mounting holes, 28008 xb and 28008 xa , respectively, of the tubular toggle bushing 28008 and are received within the mounting holes, 28034 ba and 28034 ca , respectively, of the tubular spring housing 28034 .
  • a tubular retracting spring ring 28036 that defines mounting holes, 28036 a and 28036 b , receives and mates with a portion of the tubular lower mandrel 28006 and is received within and mates with a portion of the tubular spring housing 28034 .
  • Mounting screws, 28038 a and 28038 b are mounted within and coupled to the mounting holes, 28036 a and 28036 b , respectively, of the tubular retracting spring ring 28036 and extend into the mounting holes, 28034 b and 28034 c , respectively, of the tubular spring housing 28034 .
  • Casing diameter sensor springs, 28040 a and 28040 b are positioned within the longitudinal slots, 28008 c and 2808 d , respectively, of the tubular toggle bushing 28008 that engage the engagement members, 28026 c and 28032 c , and engagement arms, 28026 d and 28032 d , of the first and second triggers, 28026 and 28032 , respectively.
  • An inner flange 28042 a of an end of a tubular spring washer 28042 mates with and receives a portion of the tubular lower mandrel 28006 and an end face of the inner flange of the tubular spring washer is positioned proximate and end face of the external flange 28006 d of the tubular lower mandrel.
  • the tubular spring washer 28042 is further received within the longitudinal passage 28034 a of the tubular spring housing 28034 .
  • An end of a retracting spring 28044 that receives the tubular lower mandrel 28006 is positioned within the tubular spring washer 28042 in contact with the internal flange 28042 a of the tubular spring washer and the other end of the retracting spring is positioned in contact with an end face of the tubular retracting spring ring 28036 .
  • a sealing element 28046 is received within the external annular recess 28006 j of the tubular lower mandrel 28006 for sealing the interface between the tubular lower mandrel and the tubular spring housing 28034 .
  • a sealing element 28048 is received within the internal annular recess 28034 h of the tubular spring housing 28034 for sealing the interface between the tubular spring housing and the tubular lower mandrel 28006 .
  • An internal threaded connection 28050 a of an end of a tubular upper hinge sleeve 28050 that includes an internal flange 28050 b and an internal pivot 28050 c receives and is coupled to the external threaded connection 28034 i of the end of the tubular spring housing 28034 .
  • An external flange 28052 a of a base member 28052 b of an upper cam assembly 28052 that is mounted upon and receives the lower tubular mandrel 28006 , that includes an internal flange 28052 c that is received within the external annular recess 28006 e of the lower tubular mandrel 28006 and a plurality of circumferentially spaced apart tapered cam arms 28052 d extending from the base member mates with and is received within the tubular upper hinge sleeve 28050 .
  • the base member 28052 b of the upper cam assembly 28052 further includes a plurality of circumferentially spaced apart teeth 28052 f that mate with and are received within a plurality of circumferentially spaced apart teeth 28034 j provided on the end face of the tubular spring housing 28034 and an end face of the external flange 28052 a of the base member of the upper cam assembly is positioned in opposing relation to an end face of the internal flange 28050 b of the tubular upper hinge sleeve 28050 .
  • Each of the cam arms 28052 d of the upper cam assembly 28052 include external cam surfaces 28052 e .
  • the teeth 28052 f of the base member 28052 b of the upper cam assembly 28052 and the teeth 28034 j provided on the end face of the tubular spring housing 28034 permit torsional loads to be transmitted between the tubular spring housing and the upper cam assembly.
  • a plurality of circumferentially spaced apart upper expansion segments 28054 are mounted upon and receive the lower tubular mandrel 28006 and each include an external pivot recess 28054 a at one end for mating with and receiving the internal pivot 28050 c of the tubular upper hinge sleeve 28050 and an external tapered expansion surface 28054 b at another end and are pivotally mounted within the tubular upper hinge sleeve and are interleaved with the circumferentially spaced apart cam arms 28052 d of the upper cam assembly 28052 .
  • the upper expansion segments 28054 are interleaved among the cam arms 28052 d of the upper cam assembly 28052 .
  • a plurality of circumferentially spaced apart lower expansion segments 28058 are mounted upon and receive the lower tubular mandrel 28006 , are interleaved among the upper expansion segments 28054 , are oriented in the opposite direction to the upper expansion segments 28054 , each include an external pivot recess 28058 a at one end and an external tapered expansion surface 28054 b at another end and are positioned in opposing relation to corresponding circumferentially spaced apart cam arms 28052 d of the upper cam assembly 28052 .
  • a lower cam assembly 28060 is mounted upon and receives the lower tubular mandrel 28006 that includes a base member 28060 a having an external flange 28060 b , a plurality of circumferentially spaced apart cam arms 28060 d that extend from the base member that each include external cam surfaces 28060 e and define mounting holes 28060 f and 28060 g .
  • the base member 28060 a of the lower cam assembly 28060 further includes a plurality of circumferentially spaced apart teeth 28060 h .
  • the circumferentially spaced apart cam arms 28060 d of the lower cam assembly 28060 are interleaved among the lower expansion segments 28058 and the circumferentially spaced apart cam arms 28052 d of the upper cam assembly 28052 and positioned in opposing relation to corresponding upper expansion segments 28054 .
  • Mounting screws, 28062 a , 28062 b , 28062 c , and 28062 e are mounted within the corresponding mounting holes, 28060 f and 28060 g , of the lower cam assembly 28060 and are received within the external annular recess 28006 g of the lower cam assembly 28060 .
  • a tubular lower hinge sleeve 28064 that receives the lower expansion segments 28058 and the lower cam assembly 28060 includes an internal flange 28064 a for engaging the external flange 28060 b of the base member of the lower cam assembly 28060 , an internal pivot 28064 b for engaging and receiving the external pivot recess 28058 a of the lower expansion segments 28058 thereby pivotally mounting the lower expansion segments within the tubular lower hinge sleeve, and an internal threaded connection 28064 c.
  • Mounting screws, 28070 a and 28070 b are mounted in and coupled to the mounting holes, 28068 c and 28068 d , respectively, of the tubular member 28068 that also extend into the mounting holes, 28066 b and 28066 c , respectively, of the tubular sleeve 28066 .
  • a sealing element 28072 is received within the external annular recess 28068 e of the tubular member 28068 for sealing the interface between the tubular member and the tubular sleeve 28066 .
  • a sealing element 28076 is received within the external annular recess 28074 d of the tubular retracting piston 28074 for sealing the interface between the tubular retracting piston and the tubular sleeve 28066 .
  • a sealing element 28078 is received within the internal annular recess 28074 c of the tubular retracting piston 28074 for sealing the interface between the tubular retracting piston and the tubular lower mandrel 28006 .
  • Locking dogs 28080 mate with and receive the external teeth 28006 h of the tubular lower mandrel 28006 .
  • a spacer ring 28082 is positioned between an end face of the locking dogs 28080 and an end face of the lower cam assembly 28060 .
  • a release piston 28084 mounted upon the tubular lower mandrel 28006 defines a radial passage 28084 a for mounting a burst disk 28086 includes sealing elements, 28084 b , 28084 c , and 28084 d .
  • the sealing elements, 28084 b and 28084 d sealing the interface between the release piston 28084 and the tubular lower mandrel 28006 .
  • An end face of the release piston 28084 is positioned in opposing relation to an end face of the locking dogs 28080 .
  • a release sleeve 28088 that receives and is mounted upon the locking dogs 28080 and the release piston 28084 includes an internal flange 28088 a at one end that sealingly engages the tubular lower mandrel 28006 .
  • a bypass sleeve 28090 that receives and is mounted upon the release sleeve 28088 includes an internal flange 28090 a at one end.
  • the retracting spring 28044 is compressed and thereby applies a biasing spring force in a direction 28092 from the lower tubular mandrel 28006 to the tubular spring housing 28034 that, in the absence of other forces, moves and/or maintains the upper cam assembly 28052 and the upper expansion segments 28054 out of engagement with the lower expansion segments 28058 and the lower cam assembly 28060 .
  • an external threaded connection 26 a of an end of the extension actuator assembly 26 is coupled to the internal threaded connection 28002 d of the upper tubular tool joint 28002 and an internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 is coupled to the external threaded connection 28068 f of the tubular member 28068 .
  • the upper cam assembly 28052 and the upper expansion segments 28054 may be brought into engagement with the lower expansion segments 28058 and the lower cam assembly 28060 by pressurizing an annulus 28094 defined between the lower tubular mandrel 28006 and the tubular spring housing 28034 .
  • injection of fluidic materials into the adjustable bell section expansion cone assembly 28 through the longitudinal passage 28006 b of the lower tubular mandrel 28006 and into the radial passage 28006 ba may pressurize the annulus 28094 thereby creating sufficient operating pressure to generate a force in a direction 28096 sufficient to overcome the biasing force of the retracting spring 28044 .
  • the spring housing 28034 may be displaced in the direction 28096 relative to the lower tubular mandrel 28006 thereby displacing the tubular upper hinge sleeve 28050 , upper cam assembly 28052 , and upper expansion segments 28054 in the direction 28096 .
  • the displacement of the upper cam assembly 28052 and upper expansion segments 28054 in the direction 28096 will cause the lower expansion segments 28058 to ride up the cam surfaces 28052 e of the cam arms 28052 d of the upper cam assembly 28052 while also pivoting about the lower tubular hinge segment 28064 , and will also cause the upper expansion segments 28054 to ride up the cam surfaces 28060 e of the cam arms 28060 d of the lower cam assembly 28060 while also pivoting about the upper tubular hinge segment 28050 .
  • the upper and lower expansion segments, 28054 and 28058 when brought into axial alignment, they define an outer expansion surface that is approximately contiguous in a circumferential direction and which provides an outer expansion surface that at least approximates a conical surface.
  • the adjustable bell section expansion cone assembly 28 when the upper and lower expansion segments, 28054 and 28058 , brought into axial alignment into a radially expanded position, the upper and lower expansion segments, 28054 and 28058 , are displaced relative to the expandable wellbore casing 100 to thereby radially expand and plastically deform at least a portion of the expandable wellbore casing.
  • the adjustable bell section expansion cone assembly 28 may then be rotated relative to the expandable wellbore casing to enhance and/or modify the rate at which the expandable wellbore casing is radially expanded and plastically deformed.
  • the upper cam assembly 28052 and the upper expansion segments 28054 may be moved out of engagement with the lower expansion segments 28058 and the lower cam assembly 28060 by reducing the operating pressure within the annulus 28094 .
  • the burst disc 28086 will open the passage 28084 a thereby pressurizing the interior of the tubular release sleeve 28088 thereby displacing the tubular release sleeve 28088 downwardly in a direction 28092 away from engagement with the locking dogs 28080 .
  • the locking dogs 28080 are displaced outwardly in the radial directed and thereby released from engagement with the lower tubular mandrel 28006 thereby permitting the lower expansion segments 28058 and the lower cam assembly 28060 to be displaced downwardly relative to the lower tubular mandrel.
  • the operating pressure within the lower tubular mandrel 28066 may then cause the lower tubular mandrel to be displaced downwardly in the direction 28094 relative to the tubular lower mandrel 28006 and the retracting piston 28074 .
  • the lower tubular mandrel 28066 , the lower expansion segments 28058 , the lower cam assembly 28060 , and tubular lower hinge sleeve 28064 are displaced downwardly in the direction 28094 relative to the tubular spring housing 28034 thereby moving the lower expansion segments 28058 and the lower cam assembly 28060 out of engagement with the upper cam assembly 28052 and the upper expansion segments 28054 .
  • the triggers, 28026 and 28032 will be pivoted by the engagement arms, 28024 d and 28030 d , of the lower toggle links, 28024 and 28030 , to a position in which the triggers will no longer engage the internal flange 28034 d of the end of the tubular spring housing 28034 thereby permitting the displacement of the tubular spring housing in the direction 28096 .
  • the upper cam assembly 28052 and the upper expansion segments 28054 can be brought into engagement with the lower expansion segments 28058 and the lower cam assembly 28060 .
  • the upper toggle links, 28022 and 28028 , and the lower toggle links, 28024 and 28030 are spring biased towards the position illustrated in FIG. 16W .
  • the tubular spring housing 28034 of the adjustable bell section expansion cone assembly 28 defines internal annular recesses 28034 k and 28034 l , spaced apart by an internal flange 28034 m
  • the tubular toggle bushing 28008 defines an external annular recess 28008 ac
  • the adjustable bell section expansion cone assembly further includes pins, 28100 a and 28100 b and 28102 a and 28102 b , mounted in holes 28008 j and 28008 o and 28008 k and 28008 n , respectively, of the tubular toggle bushing, and a one-shot deactivation device 28104 mounted on the tubular toggle bushing between the pins, 28100 a and 28100 b and 28102 a and 28102 b.
  • Spring members, 28110 and 28112 are received within the annular recess 28104 f of the tubular body 28104 a for biasing the base members, base member 28106 a and 28108 a , of the engagement members, 28106 and 28108 , respectively, radially inwardly relative to the tubular body 28104 a.
  • the one-shot deactivation device 28104 are positioned proximate and in intimate contact with the pins, 28102 a and 28102 b , with the tapered ends, 28106 b and 28108 b , of the base members, 28106 a and 28108 a , of the engagement members, 28106 and 28108 , received within the external annular recess 28008 ac of the tubular toggle bushing 28008 .
  • the one-shot deactivation device 28104 is positioned as illustrated in FIGS.
  • the one-shot deactivation device 28104 are positioned proximate and in intimate contact with the pins, 28100 a and 28100 b , with the tapered ends, 28106 b and 28108 b , of the base members, 28106 a and 28108 a , of the engagement members, 28106 and 28108 , not received within the external annular recess 28008 ac of the tubular toggle bushing 28008 .
  • the one-shot deactivation device 28104 is positioned as illustrated in FIG.
  • the external annular recess 28104 d of the tubular body 28104 a of the one-shot deactivation device is moved into engagement with the engagement arms, 28026 d and 28032 d , of the triggers, 28026 and 28032 , respectively.
  • the triggers, 28026 and 28032 are deactivated and may not operate normally as described above with reference to FIGS. 16W, 16X , and 16 Y.
  • the elements of the adjustable bell section expansion cone assembly 28 that sense the diameter of the expandable wellbore casing 100 may be disabled or omitted or adjusted to sense any pre-selected internal diameter of the expandable wellbore casing.
  • the adjustable casing expansion cone assembly 30 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (3) PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, and/or (4) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep.
  • PCT patent application serial number PCT/US03/14153 attorney docket number 25791.104.02, filed on Nov. 13, 2003
  • PCT patent application serial number PCT/US03/18530 attorney docket number 25791.108.02, filed on Jun. 11, 2003
  • PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02 filed on Mar. 11, 2004, and/or (8)
  • PCT patent application serial number PCT/US04/009434 attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (9)
  • PCT patent application serial number PCT/US04/010317 attorney docket number 25791.270.02, filed on Apr.
  • the adjustable casing expansion cone assembly 30 includes an upper tubular tool joint 30002 that defines a longitudinal passage 30002 a and mounting holes, 30002 b and 30002 c , and includes an internal threaded connection 30002 d , an inner annular recess 30002 e , an inner annular recess 30002 f , and an internal threaded connection 30002 g .
  • a tubular torque plate 30004 that defines a longitudinal passage 30004 a and includes circumferentially spaced apart teeth 30004 b is received within, mates with, and is coupled to the internal annular recess 30002 e of the upper tubular tool joint 30002 .
  • a sealing element 30010 is received within the external annular recess 30008 y of the tubular toggle bushing 30008 for sealing the interface between the tubular toggle bushing and the upper tubular tool joint 30002 .
  • a sealing element 30012 is received within the internal annular recess 30008 z of the tubular toggle bushing 30008 for sealing the interface between the tubular toggle bushing and the tubular lower mandrel 30006 .
  • Mounting screws, 30014 a and 30014 b , mounted within and coupled to the mounting holes, 30008 w and 30008 x , respectively, of the tubular toggle bushing 30008 are also received within the mounting holes, 30002 b and 30002 c , of the upper tubular tool joint 30002 .
  • Mounting pins, 30016 a , 30016 b , 30016 c , 30016 d , and 30016 e are mounted within the mounting holes, 30008 e , 30008 f , 30008 g , 30008 h , and 30008 l , respectively.
  • Mounting pins, 30018 a , 30018 b , 30018 c , 30018 d , and 30018 e are mounted within the mounting holes, 30008 t , 30008 s , 30008 r , 30008 q , and 30008 p , respectively.
  • Mounting screws, 30020 a and 30020 b are mounted within the mounting holes, 30008 u and 30008 v , respectively.
  • a second upper toggle link 30028 defines mounting holes, 30028 a and 30028 b , for receiving the mounting pins, 30018 a and 30018 b , and includes a mounting pin 30028 c at one end.
  • a second lower toggle link 30030 defines mounting holes, 30030 a , 30030 b , and 30030 c , for receiving the mounting pins, 30028 c , 30018 c , and 30018 d , respectively and includes an engagement arm 30030 d .
  • a second trigger 30032 defines a mounting hole 30032 a for receiving the mounting pin 30018 e and includes an engagement arm 30032 b at one end, an engagement member 30032 c , and an engagement arm 30032 d at another end.
  • An end of a tubular spring housing 30034 that defines a longitudinal passage 30034 a , mounting holes, 30034 b and 30034 c , and mounting holes, 30034 ba and 30034 ca , and includes an internal flange 30034 d and an internal annular recess 30034 e at one end, and an internal flange 30034 f , an internal annular recess 30034 g , an internal annular recess 30034 h , and an external threaded connection 30034 i at another end receives and mates with the end of the tubular toggle bushing 30008 .
  • Mounting screws, 30035 a and 30035 b are mounted within and coupled to the mounting holes, 30008 xb and 30008 xa , respectively, of the tubular toggle bushing 30008 and are received within the mounting holes, 30034 ba and 30034 ca , respectively, of the tubular spring housing 30034 .
  • a tubular retracting spring ring 30036 that defines mounting holes, 30036 a and 30036 b , receives and mates with a portion of the tubular lower mandrel 30006 and is received within and mates with a portion of the tubular spring housing 30034 .
  • Mounting screws, 30038 a and 30038 b are mounted within and coupled to the mounting holes, 30036 a and 30036 b , respectively, of the tubular retracting spring ring 30036 and extend into the mounting holes, 30034 b and 30034 c , respectively, of the tubular spring housing 30034 .
  • Casing diameter sensor springs, 30040 a and 30040 b are positioned within the longitudinal slots, 30008 c and 3008 d , respectively, of the tubular toggle bushing 30008 that engage the engagement members, 30026 c and 30032 c , and engagement arms, 30026 d and 30032 d , of the first and second triggers, 30026 and 30032 , respectively.
  • An inner flange 30042 a of an end of a tubular spring washer 30042 mates with and receives a portion of the tubular lower mandrel 30006 and an end face of the inner flange of the tubular spring washer is positioned proximate and end face of the external flange 30006 d of the tubular lower mandrel.
  • the tubular spring washer 30042 is further received within the longitudinal passage 30034 a of the tubular spring housing 30034 .
  • An end of a retracting spring 30044 that receives the tubular lower mandrel 30006 is positioned within the tubular spring washer 30042 in contact with the internal flange 30042 a of the tubular spring washer and the other end of the retracting spring is positioned in contact with an end face of the tubular retracting spring ring 30036 .
  • a sealing element 30046 is received within the external annular recess 30006 j of the tubular lower mandrel 30006 for sealing the interface between the tubular lower mandrel and the tubular spring housing 30034 .
  • a sealing element 30048 is received within the internal annular recess 30034 h of the tubular spring housing 30034 for sealing the interface between the tubular spring housing and the tubular lower mandrel 30006 .
  • An internal threaded connection 30050 a of an end of a tubular upper hinge sleeve 30050 that includes an internal flange 30050 b and an internal pivot 30050 c receives and is coupled to the external threaded connection 30034 i of the end of the tubular spring housing 30034 .
  • An external flange 30052 a of a base member 30052 b of an upper cam assembly 30052 that is mounted upon and receives the lower tubular mandrel 30006 , that includes an internal flange 30052 c that is received within the external annular recess 30006 e of the lower tubular mandrel 30006 and a plurality of circumferentially spaced apart tapered cam arms 30052 d extending from the base member mates with and is received within the tubular upper hinge sleeve 30050 .
  • the base member 30052 b of the upper cam assembly 30052 further includes a plurality of circumferentially spaced apart teeth 30052 f that mate with and are received within a plurality of circumferentially spaced apart teeth 30034 j provided on the end face of the tubular spring housing 30034 and an end face of the external flange 30052 a of the base member of the upper cam assembly is positioned in opposing relation to an end face of the internal flange 30050 b of the tubular upper hinge sleeve 30050 .
  • Each of the cam arms 30052 d of the upper cam assembly 30052 include external cam surfaces 30052 e .
  • a plurality of circumferentially spaced apart upper expansion segments 30054 are mounted upon and receive the lower tubular mandrel 30006 and each include an external pivot recess 30054 a at one end for mating with and receiving the internal pivot 30050 c of the tubular upper hinge sleeve 30050 and an external tapered expansion surface 30054 b at another end and are pivotally mounted within the tubular upper hinge sleeve and are interleaved with the circumferentially spaced apart cam arms 30052 d of the upper cam assembly 30052 .
  • the upper expansion segments 30054 are interleaved among the cam arms 30052 d of the upper cam assembly 30052 .
  • a plurality of circumferentially spaced apart lower expansion segments 30058 are mounted upon and receive the lower tubular mandrel 30006 , are interleaved among the upper expansion segments 30054 , are oriented in the opposite direction to the upper expansion segments 30054 , each include an external pivot recess 30058 a at one end and an external tapered expansion surface 30054 b at another end and are positioned in opposing relation to corresponding circumferentially spaced apart cam arms 30052 d of the upper cam assembly 30052 .
  • a lower cam assembly 30060 is mounted upon and receives the lower tubular mandrel 30006 that includes a base member 30060 a having an external flange 30060 b , a plurality of circumferentially spaced apart cam arms 30060 d that extend from the base member that each include external cam surfaces 30060 e and define mounting holes 30060 f and 30060 g .
  • the base member 30060 a of the lower cam assembly 30060 further includes a plurality of circumferentially spaced apart teeth 30060 h .
  • the circumferentially spaced apart cam arms 30060 d of the lower cam assembly 30060 are interleaved among the lower expansion segments 30058 and the circumferentially spaced apart cam arms 30052 d of the upper cam assembly 30052 and positioned in opposing relation to corresponding upper expansion segments 30054 .
  • Mounting screws, 30062 a , 30062 b , 30062 c , and 30062 e are mounted within the corresponding mounting holes, 30060 f and 30060 g , of the lower cam assembly 30060 and are received within the external annular recess 30006 g of the lower cam assembly 30060 .
  • a tubular lower hinge sleeve 30064 that receives the lower expansion segments 30058 and the lower cam assembly 30060 includes an internal flange 30064 a for engaging the external flange 30060 b of the base member of the lower cam assembly 30060 , an internal pivot 30064 b for engaging and receiving the external pivot recess 30058 a of the lower expansion segments 30058 thereby pivotally mounting the lower expansion segments within the tubular lower hinge sleeve, and an internal threaded connection 30064 c.
  • Mounting screws, 30070 a and 30070 b are mounted in and coupled to the mounting holes, 30068 c and 30068 d , respectively, of the tubular member 30068 that also extend into the mounting holes, 30066 b and 30066 c , respectively, of the tubular sleeve 30066 .
  • a sealing element 30072 is received within the external annular recess 30068 e of the tubular member 30068 for sealing the interface between the tubular member and the tubular sleeve 30066 .
  • a sealing element 30076 is received within the external annular recess 30074 d of the tubular retracting piston 30074 for sealing the interface between the tubular retracting piston and the tubular sleeve 30066 .
  • a sealing element 30078 is received within the internal annular recess 30074 c of the tubular retracting piston 30074 for sealing the interface between the tubular retracting piston and the tubular lower mandrel 30006 .
  • Locking dogs 30080 mate with and receive the external teeth 30006 h of the tubular lower mandrel 30006 .
  • a spacer ring 30082 is positioned between an end face of the locking dogs 30080 and an end face of the lower cam assembly 30060 .
  • a release piston 30084 mounted upon the tubular lower mandrel 30006 defines a radial passage 30084 a for mounting a burst disk 30086 includes sealing elements, 30084 b , 30084 c , and 30084 d .
  • the sealing elements, 30084 b and 30084 d sealing the interface between the release piston 30084 and the tubular lower mandrel 30006 .
  • An end face of the release piston 30084 is positioned in opposing relation to an end face of the locking dogs 30080 .
  • the upper cam assembly 30052 and the upper expansion segments 30054 may be brought into engagement with the lower expansion segments 30058 and the lower cam assembly 30060 by pressurizing an annulus 30094 defined between the lower tubular mandrel 30006 and the tubular spring housing 30034 .
  • injection of fluidic materials into the adjustable casing expansion cone assembly 30 through the longitudinal passage 30006 b of the lower tubular mandrel 30006 and into the radial passage 30006 ba may pressurize the annulus 30094 thereby creating sufficient operating pressure to generate a force in a direction 30096 sufficient to overcome the biasing force of the retracting spring 30044 .
  • the spring housing 30034 may be displaced in the direction 30096 relative to the lower tubular mandrel 30006 thereby displacing the tubular upper hinge sleeve 30050 , upper cam assembly 30052 , and upper expansion segments 30054 in the direction 30096 .
  • the displacement of the upper cam assembly 30052 and upper expansion segments 30054 in the direction 30096 will cause the lower expansion segments 30058 to ride up the cam surfaces 30052 e of the cam arms 30052 d of the upper cam assembly 30052 while also pivoting about the lower tubular hinge segment 30064 , and will also cause the upper expansion segments 30054 to ride up the cam surfaces 30060 e of the cam arms 30060 d of the lower cam assembly 30060 while also pivoting about the upper tubular hinge segment 30050 .
  • the upper and lower expansion segments, 30054 and 30058 when brought into axial alignment, they define an outer expansion surface that is approximately contiguous in a circumferential direction and which provides an outer expansion surface that at least approximates a conical surface.
  • the upper cam assembly 30052 and the upper expansion segments 30054 may be moved out of engagement with the lower expansion segments 30058 and the lower cam assembly 30060 by reducing the operating pressure within the annulus 30094 .
  • the burst disc 30086 will open the passage 30084 a thereby pressurizing the interior of the tubular release sleeve 30088 thereby displacing the tubular release sleeve 30088 downwardly in a direction 30092 away from engagement with the locking dogs 30080 .
  • the locking dogs 30080 are displaced outwardly in the radial directed and thereby released from engagement with the lower tubular mandrel 30006 thereby permitting the lower expansion segments 30058 and the lower cam assembly 30060 to be displaced downwardly relative to the lower tubular mandrel.
  • the adjustable casing expansion cone assembly senses the diameter of the expandable wellbore casing 100 using the upper toggle links, 30022 and 30028 , lower toggle links, 30024 and 30030 , and triggers, 30026 and 30032 , and then prevents the engagement of the upper cam assembly 30052 and the upper expansion segments 30054 with the lower expansion segments 30058 and the lower cam assembly 30060 .
  • the triggers, 30026 and 30032 will be pivoted by the engagement arms, 30024 d and 30030 d , of the lower toggle links, 30024 and 30030 , to a position in which the triggers will no longer engage the internal flange 30034 d of the end of the tubular spring housing 30034 thereby permitting the displacement of the tubular spring housing in the direction 30096 .
  • the upper cam assembly 30052 and the upper expansion segments 30054 can be brought into engagement with the lower expansion segments 30058 and the lower cam assembly 30060 .
  • the upper toggle links, 30022 and 30028 , and the lower toggle links, 30024 and 30030 are spring biased towards the position illustrated in FIG. 17W .
  • the triggers, 30026 and 30032 will be maintained in a position in which the triggers will engage the internal flange 30034 d of the end of the tubular spring housing 30034 thereby preventing the displacement of the tubular spring housing in the direction 30096 .
  • the upper cam assembly 30052 and the upper expansion segments 30054 cannot be brought into engagement with the lower expansion segments 30058 and the lower cam assembly 30060 .
  • the triggers, 30026 and 30032 are spring biased towards the position illustrated in FIG. 17X .
  • the tubular spring housing 30034 may be displaced upwardly in the direction 30098 even if the upper toggle links, 30022 and 30028 , and lower toggle links, 30024 and 30030 , are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10 .
  • the tubular spring housing 30034 of the adjustable casing expansion cone assembly 30 defines internal annular recesses 30034 k and 30034 , spaced apart by an internal flange 30034 m
  • the tubular toggle bushing 30008 defines an external annular recess 30008 ac
  • the adjustable casing expansion cone assembly further includes pins, 30100 a and 30100 b and 30102 a and 30102 b , mounted in holes 30008 j and 30008 o and 30008 k and 30008 n , respectively, of the tubular toggle bushing, and a one-shot deactivation device 30104 mounted on the tubular toggle bushing between the pins, 30100 a and 30100 b and 30102 a and 30102 b.
  • An engagement member 30106 that includes a base member 30106 a having a tapered end 30106 b and a key member 30106 c having a tapered end 30106 d is received within a portion of the internal annular recess 30104 f of the tubular body 30104 a and an engagement member 30108 that includes a base member 30108 a having a tapered end 30108 b and a key member 30108 c having a tapered end 30108 d is received within an opposite portion of the internal annular recess 30104 f of the tubular body 30104 a .
  • Spring members, 30110 and 30112 are received within the annular recess 30104 f of the tubular body 30104 a for biasing the base members, base member 30106 a and 30108 a , of the engagement members, 30106 and 30108 , respectively, radially inwardly relative to the tubular body 30104 a.
  • the one-shot deactivation device 30104 are positioned proximate and in intimate contact with the pins, 30102 a and 30102 b , with the tapered ends, 30106 b and 30108 b , of the base members, 30106 a and 30108 a , of the engagement members, 30106 and 30108 , received within the external annular recess 30008 ac of the tubular toggle bushing 30008 .
  • the one-shot deactivation device 30104 is positioned as illustrated in FIG.
  • the external annular recess 30104 d of the tubular body 30104 a of the one-shot deactivation device is moved out of engagement with the engagement arms, 30026 d and 30032 d , of the triggers, 30026 and 30032 , respectively.
  • the triggers, 30026 and 30032 may operate normally as described above with reference to FIGS. 17W, 17X , and 17 Y.
  • the one-shot deactivation device 30104 are positioned proximate and in intimate contact with the pins, 30100 a and 30100 b , with the tapered ends, 30106 b and 30108 b , of the base members, 30106 a and 30108 a , of the engagement members, 30106 and 30108 , not received within the external annular recess 30008 ac of the tubular toggle bushing 30008 .
  • the one-shot deactivation device 30104 is positioned as illustrated in FIGS.
  • the external annular recess 30104 d of the tubular body 30104 a of the one-shot deactivation device is moved into engagement with the engagement arms, 30026 d and 30032 d , of the triggers, 30026 and 30032 , respectively.
  • the triggers, 30026 and 30032 are deactivated and may not operate normally as described above with reference to FIGS. 17W, 17X , and 17 Y.
  • Mounting screws, 3205 a and 3205 b are received within and coupled to the mounting holes, 3204 c and 3204 d , of the tubular upper mandrel 3204 that also extend into the radial passages, 3202 d and 3202 e , of the tubular adaptor 3202 .
  • An external threaded connection 3206 a of an end of a mandrel 3206 that defines a longitudinal passage 3206 b and includes an external annular recess 3206 c and an external annular recess 3206 d having an external threaded connection is received within and is coupled to the internal threaded connection 3204 j of the tubular upper mandrel 3204 .
  • An internal flange 3212 a of a tubular key 3212 that includes an external annular recess 3212 b at one end and an internal annular recess 3212 c at another end is movably received within and engages the external annular recess 3204 f of the tubular upper mandrel 3204 .
  • a garter spring 3214 is received within and engages the external annular recess 3212 b of the tubular key 3212 .
  • An end of a tubular bushing 3216 that defines a longitudinal passage 3216 a for receiving and mating with the upper mandrel 3204 , and radial passages, 3216 b and 3216 c , and includes an external threaded connection 3216 d at an intermediate portion, and an external flange 3216 e , an internal annular recess 3216 f , circumferentially spaced apart teeth 3216 g , and external flanges, 3216 h and 3216 i , at another end is received within and mates with the internal annular recess 3212 c of the tubular key 3212 .
  • An internal threaded connection 3218 a of a tubular drag block body 3218 that defines a longitudinal passage 3218 b for receiving the tubular bushing 3216 , mounting holes, 3218 c and 3218 d , mounting holes, 3218 e and 3218 f , and includes an internal threaded connection 3218 g at one end, a centrally positioned external annular recess 3218 h , and an external threaded connection 3218 i at another end is received within and coupled to the external threaded connection 3216 d of the tubular bushing 3216 .
  • Drag blocks, 3228 and 3230 that are received within the external annular recess 3218 h of the tubular drag block body 3218 , include ends that mate with and are received within the end of the first tubular keeper 3220 , and other ends that mate with and are received within the end of the second tubular keeper 3224 .
  • the drag blocks, 3228 and 3230 further include internal annular recesses, 3228 a and 3230 a , respectively, that receive and mate with ends of springs, 3232 and 3234 , respectively.
  • the springs, 3232 and 3234 also receive and mate with the external annular recess 3218 h of the tubular drag block body 3218 .
  • An internal flange 3244 a of a tubular coupling ring 3244 that defines a longitudinal passage 3244 b and radial passages, 3244 c and 3244 d , receives and mates with the external flange 3216 h of the tubular bushing 3216 and an end face of the internal flange of the tubular coupling ring is positioned proximate and in opposing relation to an end face of the external flange 3216 i of the tubular bushing.
  • An internal flange 3246 a of a tubular retaining collet 3246 that includes a plurality of axially extending collet fingers 3246 b , each having internal flanges 3246 c at an end of each collet finger, for engaging and receiving the tubular coupling ring 3244 receives and mates with external flange 3216 e of the tubular bushing 3216 and an end face of the internal flange of the tubular retaining collet is positioned proximate and in opposing relation to an end face of the external flange 3216 h of the tubular bushing.
  • the packer assembly 36 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (2) PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep. 23, 2003, and/or (3) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (4) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar.
  • PCT patent application serial number PCT/US04/010317 attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (6)
  • PCT patent application serial number PCT/US04/010712 attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (7)
  • PCT patent application serial number PCT/US04/010762 attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • the packer assembly 36 includes a tubular upper adaptor 3602 that defines a longitudinal passage 3602 a having a tapered opening 3602 b and mounting holes, 3602 c and 3602 d , that includes a plurality of circumferentially spaced apart teeth 3602 e at one end, an external flange 3602 f , and an internal threaded connection 3602 g at another end.
  • the tubular upper adaptor 3602 is fabricated from aluminum.
  • the tubular upper mandrel 3604 is fabricated from aluminum.
  • An upper tubular spacer ring 3606 that defines mounting holes, 3606 a and 3606 b , receives and mates with the end of the tubular upper mandrel 3604 and includes an angled end face 3606 c and another end face that is positioned proximate to an end face of the tubular upper adaptor 3602 is coupled to the tubular upper mandrel by shear pins, 3608 a and 3608 b , that are mounted within and coupled to the mounting holes, 3604 c and 3606 a , and, 3604 d and 3606 b , respectively, of the tubular upper mandrel and upper tubular spacer ring, respectively.
  • a lower tubular spacer ring 3610 that includes an angled end face 3610 a receives, mates, and is coupled to the other end of the tubular upper mandrel 3604 and includes another end face that is positioned proximate to an end face of the external flange 3604 i of the tubular upper mandrel 3604 .
  • the upper and tubular spacer rings, 3606 and 3610 are fabricated from a composite material.
  • a sealing element or upper tubular slip 3612 that receives and is movably mounted upon the tubular upper mandrel 3604 defines a longitudinal passage 3612 a having a tapered opening 3612 b and includes external annular recesses, 3612 c , 3612 d , 3612 e , 3612 f , and 3612 g , and an angled end face 3612 h that mates with and is positioned proximate the angled end face 3606 c of the upper tubular spacer ring 3606 .
  • Slip retaining bands 3614 a , 3614 b , 3614 c , 3614 d , and 3614 e , are received within and coupled to the external annular recesses, 3612 c , 3612 d , 3612 e , 3612 f , and 3612 g , of the upper tubular slip 3612 .
  • a sealing element or lower tubular slip 3616 that receives and is movably mounted upon the tubular upper mandrel 3604 defines a longitudinal passage 3616 a having a tapered opening 3616 b and includes external annular recesses, 3616 c , 3616 d , 3616 e , 3616 f , and 3616 g , and an angled end face 3616 h that mates with and is positioned proximate the angled end face 3610 a of the lower tubular spacer ring 3610 .
  • Slip retaining bands, 3618 a , 3618 b , 3618 c , 3618 d , and 3618 e are received within and coupled to the external annular recesses, 3616 c , 3616 d , 3616 e , 3616 f , and 3616 g , of the lower tubular slip 3616 .
  • the upper and lower tubular slips, 3612 and 3616 are fabricated from composite materials, and at least some of the slip retaining bands, 3614 a , 3614 b , 3614 c , 3614 d , 3614 e , 3618 a , 3618 b , 3618 c , 3618 d , and 3618 e are fabricated from carbide insert materials.
  • one or more of the slip retaining bands, 3614 a , 3614 b , 3614 c , 3614 d , and 3614 e , and one or more of the respective external annular recesses, 3612 c , 3612 d , 3612 e , 3612 f , and 3612 g , of the upper tubular slip 3612 may be removed from the packer assembly 36 .
  • one or more of the slip retaining bands, 3618 a , 3618 b , 3618 c , 3618 d , and 3618 e , and one or more of the respective external annular recesses, 3616 c , 3616 d , 3616 e , 3616 f , and 3616 g , of the lower tubular slip 3616 may be removed from the packer assembly 36 .
  • An upper tubular wedge 3620 that defines an longitudinal passage 3620 a for receiving the tubular upper mandrel 3604 and mounting holes, 3620 b and 3620 c , and includes an angled end face 3620 d at one end that is received within and mates with the tapered opening 3612 b of the upper tubular slip 3612 , and an angled end face 3620 e at another end is coupled to the tubular upper mandrel by shear pins, 3622 a and 3622 b , mounted within and coupled to the mounting holes, 3604 e and 3620 b , and, 3604 f and 3620 c , respectively, of the tubular upper mandrel and upper tubular wedge, respectively.
  • a lower tubular wedge 3624 that defines an longitudinal passage 3624 a for receiving the tubular upper mandrel 3604 and mounting holes, 3624 b and 3624 c , and includes an angled end face 3624 d at one end that is received within and mates with the tapered opening 3616 b of the lower tubular slip 3616 , and an angled end face 3624 e at another end is coupled to the tubular upper mandrel by shear pins, 3626 a and 3626 b , mounted within and coupled to the mounting holes, 3604 g and 3624 b , and, 3604 h and 3624 c , respectively, of the tubular upper mandrel and lower tubular wedge, respectively.
  • the upper and lower tubular wedges, 3620 and 3624 are fabricated from composite materials.
  • An upper tubular extrusion limiter 3628 that defines a longitudinal passage 3628 a for receiving the tubular upper mandrel 3604 includes an angled end face 3628 b at one end that mates with the angled end face 3620 e of the upper tubular wedge 3620 , an angled end face 3628 c at another end having recesses 3628 d , and external annular recesses, 3628 e , 3628 f and 3628 g .
  • Retaining bands, 3630 a , 3630 b , and 3630 c are mounted within and coupled to the external annular recesses, 3628 e , 3628 f and 3628 g , respectively, of the upper tubular extrusion limiter 3628 .
  • Circular disc-shaped extrusion preventers 3632 are coupled and mounted within the recesses 3628 d .
  • a lower tubular extrusion limiter 3634 that defines a longitudinal passage 3634 a for receiving the tubular upper mandrel 3604 includes an angled end face 3634 b at one end that mates with the angled end face 3624 e of the lower tubular wedge 3624 , an angled end face 3634 c at another end having recesses 3634 d , and external annular recesses, 3634 e , 3634 f and 3634 g .
  • Retaining bands 3636 a , 3636 b , and 3636 c , are mounted within and coupled to the external annular recesses, 3634 e , 3634 f and 3634 g , respectively, of the lower tubular extrusion limiter 3634 .
  • Circular disc-shaped extrusion preventers 3638 are coupled and mounted within the recesses 3634 d .
  • the upper and lower extrusion limiters, 3628 and 3634 are fabricated from composite materials.
  • one or more of the retaining bands, 3630 a , 3630 b , and 3630 c , and one or more of the respective external annular recesses, 3628 e , 3628 f and 3628 g of the upper tubular extrusion limiter 3628 may be removed from the packer assembly 36 .
  • one or more of the retaining bands, 3636 a , 3636 b , and 3636 c , and one or more of the respective external annular recesses, 3634 e , 3634 f and 3634 g of the lower tubular extrusion limiter 3634 may be removed from the packer assembly 36 .
  • a sealing element or upper tubular elastomeric packer element 3640 that defines a longitudinal passage 3640 a for receiving the tubular upper mandrel 3604 includes an angled end face 3640 b at one end that mates with and is positioned proximate the angled end face 3628 c of the upper tubular extrusion limiter 3628 and an curved end face 3640 c at another end.
  • a lower tubular elastomeric packer element 3642 that defines a longitudinal passage 3642 a for receiving the tubular upper mandrel 3604 includes an angled end face 3642 b at one end that mates with and is positioned proximate the angled end face 3634 c of the lower tubular extrusion limiter 3634 and an curved end face 3642 c at another end.
  • a central tubular elastomeric packer element 3644 that defines a longitudinal passage 3644 a for receiving the tubular upper mandrel 3604 includes a curved outer surface 3644 b for mating with and engaging the curved end faces, 3640 c and 3642 c , of the upper and lower tubular elastomeric packer elements, 3640 and 3642 , respectively.
  • An external threaded connection 3646 a of a tubular lower mandrel 3646 that defines a longitudinal passage 3646 b having throat passages, 3646 c and 3646 d , and flow ports, 3646 e and 3646 f , and a mounting hole 3646 g , and includes an internal annular recess 3646 h at one end, and an external flange 3646 i , internal annular recess 3646 j , and internal threaded connection 3646 k at another end.
  • the tubular lower mandrel 3646 is fabricated from aluminum.
  • a sealing element 3648 is received within the inner annular recess 3604 j of the other end of the tubular upper mandrel 3604 for sealing an interface between the tubular upper mandrel and the tubular lower mandrel 3646 .
  • a tubular sliding sleeve valve 3650 that defines a longitudinal passage 3650 a and radial flow ports, 3650 b and 3650 c , and includes collet fingers 3650 d at one end for engaging the internal annular recess 3646 h of the lower tubular mandrel 3646 , an external annular recess 3650 e , an external annular recess 3650 f , an external annular recess 3650 g , and circumferentially spaced apart teeth 3650 h at another end is received within and is slidably coupled to the longitudinal passage 3646 b of the tubular lower mandrel 3646 .
  • the tubular sliding sleeve valve 3650 is fabricated from aluminum.
  • a set screw 3652 is mounted within and coupled to the mounting hole 3646 g of the tubular lower mandrel 3646 that is received within the external annular recess 3650 e of the tubular sliding sleeve 3650 .
  • Sealing elements, 3654 and 3656 are mounted within the external annular recesses, 3650 f and 3650 g , respectively, of the tubular sliding sleeve valve 3650 for sealing an interface between the tubular sliding sleeve valve and the tubular lower mandrel 3646 .
  • An end of a tubular outer sleeve 3658 that defines a longitudinal passage 3658 a , radial passages, 3658 b and 3658 c , upper flow ports, 3658 d and 3658 e , lower flow ports, 3658 f and 3658 g , and radial passages, 3658 h and 3658 i , receives, mates with, and is coupled to the other end of the tubular upper mandrel 3604 and an end face of the end of the tubular outer sleeve is positioned proximate and end face of the lower tubular spacer ring 3610 .
  • the other end of the tubular outer sleeve 3658 receives, mates with, and is coupled to the other end of the tubular lower mandrel 3646 .
  • An external threaded connection 3660 a of an end of a tubular bypass mandrel 3660 that defines a longitudinal passage 3660 b , upper flow ports, 3660 c and 3660 d , lower flow ports, 3660 e and 3660 f , and a mounting hole 3660 g and includes an internal annular recess 3660 h and an external threaded connection 3660 i at another end is received within and coupled to the internal threaded connection 3646 k of the tubular lower mandrel 3646 .
  • a sealing element 3662 is received within the internal annular recess 3646 j of the tubular lower mandrel 3646 for sealing an interface between the tubular lower mandrel and the tubular bypass mandrel 3660 .
  • a tubular plug seat 3664 that defines a longitudinal passage 3664 a having a tapered opening 3664 b at one end, and flow ports, 3664 c and 3664 d , and includes an external annular recess 3664 e , an external annular recess 3664 f , an external annular recess 3664 g , an external annular recess 3664 h , and an external annular recess 3664 i having an external threaded connection at another end is received within and is movably coupled to the longitudinal passage 3660 b of the tubular bypass mandrel 3660 .
  • a tubular nose 3666 is threadably coupled to and mounted upon the external annular recess 3664 i of the tubular plug seat 3664 .
  • the tubular plug seat 3664 is fabricated from aluminum. Sealing elements, 3668 , 3670 , and 3672 , are received within the external annular recesses, 3664 e , 3664 g , and 3664 h , respectively, of the tubular plug seat 3664 for sealing an interface between the tubular plug seat and the tubular bypass mandrel 3660 .
  • a set screw 3674 is mounted within and coupled to the mounting hole 3660 g of the tubular bypass mandrel 3660 that is received within the external annular recess 3664 f of the tubular plug seat 3664 .
  • tubular bypass sleeve 3676 that defines a longitudinal passage 3676 a and includes an internal annular recess 3676 b at one end and an internal threaded connection 3676 c at another end is coupled to the other end of the tubular outer sleeve 3658 and mates with and receives the tubular bypass mandrel 3660 .
  • the tubular bypass sleeve 3676 is fabricated from aluminum.
  • the tubular valve seat 3678 is fabricated from aluminum.
  • a sealing element 3680 is received within the external annular recess 3678 g of the tubular valve seat 3678 for fluidicly sealing an interface between the tubular valve seat and the tubular bypass sleeve 3676 .
  • a poppet valve 3682 mates with and is positioned within the valve seat 3678 c of the tubular valve seat 3678 .
  • An end of the poppet valve 3682 is coupled to an end of a stem bolt 3684 that is slidingly supported for longitudinal displacement by the spring retainer 3678 f
  • a valve spring 3686 that surrounds a portion of the stem bolt 3684 is positioned in opposing relation to the head of the stem bolt and a support 3678 fa of the spring retainer 3678 f for biasing the poppet valve 3682 into engagement with the valve seat 3678 c of the tubular valve seat 3678 .
  • the packer setting tool and packer assembly are coupled to one another by inserting the end of the tubular upper adaptor 3602 into the other end of the tubular coupling ring 3244 , bringing the circumferentially spaced teeth 3216 g of the other end of the tubular bushing 3216 into engagement with the circumferentially spaced teeth 3602 e of the end of the tubular upper adaptor, and mounting shear pins, 36100 a and 36100 b , within the mounting holes, 3244 c and 3602 c , and, 3244 d and 3602 d , respectively, of the tubular coupling ring and tubular upper adaptor, respectively.
  • tubular mandrel 3206 and tubular stinger 3208 of the packer setting tool assembly 32 are thereby positioned within the longitudinal passage 3604 a of the tubular upper mandrel 3604 with the 3208 e of the tubular stinger positioned within the longitudinal passage 3646 b of the tubular lower mandrel 3646 proximate the collet fingers 3650 d of the tubular sliding sleeve valve 3650 .
  • the packer setting tool and packer assembly are positioned within the expandable wellbore casing 100 and an internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 receives and is coupled to the external threaded connection 3202 f of the end of the tubular adaptor 3202 of the packer setting tool assembly.
  • shear pins, 36102 a and 36102 b mounted within the mounting holes, 3658 b and 3658 c , of the tubular outer sleeve 3658 couple the tubular outer sleeve to the expandable wellbore casing.
  • torsion loads may transferred between the tubular outer sleeve 3658 and the expandable wellbore casing 100 .
  • a conventional plug 36104 is then injected into the setting tool assembly 32 and packer assembly 36 by injecting a fluidic material 36106 into the setting tool assembly and packer assembly through the longitudinal passages, 3202 a , 3204 b , 3206 b , 3208 b , 3650 a , 3646 a , 3660 b , and 3664 a of the tubular adaptor 3202 , tubular upper mandrel 3204 , tubular mandrel 3206 , tubular stinger 3208 , tubular sliding sleeve valve 3650 , tubular lower mandrel 3646 , tubular bypass mandrel 3660 , and tubular plug seat 3664 , respectively.
  • the plug 36104 is thereby positioned within the longitudinal passage 3664 a of the tubular plug seat 3664 .
  • Continued injection of the fluidic material 36106 following the seating of the plug 1606 within the longitudinal passage 3664 a of the tubular plug seat 3664 causes the plug and the tubular plug seat to be displaced downwardly in a direction 36108 until further movement of the tubular plug seat is prevented by interaction of the set screw 3674 with the external annular recess 3664 f of the tubular plug seat.
  • the flow ports, 3664 c and 3664 d , of the tubular plug seat 3664 are moved out of alignment with the upper flow ports, 3660 c and 3660 d , of the tubular bypass mandrel 3660 .
  • the setting tool assembly 32 and packer assembly 36 are then moved upwardly to a position within the expandable wellbore casing 100 above the bell section.
  • the tubular adaptor 3202 is then rotated, by rotating the tool string of the system 10 above the setting tool assembly 32 , to displace and position the drag blocks, 3228 and 3230 , into engagement with the interior surface of the expandable wellbore casing 100 .
  • the setting sleeve 3242 engages and displaces the upper tubular spacer ring 3606 thereby shearing the shear pins, 3622 a and 3622 b , and driving the upper tubular slip 3612 onto and up the angled end face 3620 d of the upper tubular wedge 3620 and into engagement with the interior surface of the expandable wellbore casing 100 .
  • longitudinal displacement of the upper tubular slip 3612 relative to the expandable wellbore casing 100 is prevented.
  • the 3246 b collet fingers of the tubular retaining collet 3246 are disengaged from the tubular upper adaptor 3602 .
  • an upward tensile force is applied to the tubular support member 12 , and the ball gripper assembly 16 is then operate to engage the interior surface of the expandable wellbore casing.
  • the tension actuator assembly 18 is then operated to apply an upward tensile force to the tubular adaptor 3202 thereby pulling the upper tubular spacer ring 3606 , lower tubular spacer ring 3610 , upper tubular slip 3612 , lower tubular slip 3616 , upper tubular wedge 3620 , lower tubular wedge 3624 , upper tubular extrusion limiter 3628 , lower tubular extrusion limiter 3634 , and central tubular elastomeric element 3644 upwardly into contact with the 3242 thereby compressing the upper tubular spacer ring, lower tubular spacer ring, upper tubular slip, lower tubular slip, upper tubular wedge, lower tubular wedge, upper tubular extrusion limiter, lower tubular extrusion limiter, and central tubular elastomeric element.
  • the upper tubular slip 3612 , lower tubular slip 3616 , and central tubular elastomeric element 3644 engage the interior surface of the expandable wellbore casing 100 .
  • an upward tensile force is then applied to the tubular adaptor 3202 thereby compressing the lower tubular slip 3616 , lower tubular wedge 3624 , central elastomeric packer element 3644 , upper tubular extrusion limiter 3628 , and upper tubular wedge 3620 between the lower tubular spacer ring 3610 and the stationary upper tubular slip 3612 .
  • the lower tubular slip 3616 is driven onto and up the angled end face 3624 d of the lower tubular wedge 3624 and into engagement with the interior surface of the expandable wellbore casing 100 , and the central elastomeric packer element 3644 is compressed radially outwardly into engagement with the interior surface of the expandable tubular member.
  • further longitudinal displacement of the upper tubular slip 3612 , lower tubular slip 3616 , and central elastomeric packer element 3644 relative to the expandable wellbore casing 100 is prevented.
  • tubular adaptor 3202 In an exemplary embodiment, as illustrated in FIGS. 20 E 1 to 20 E 6 , continued application of the upward tensile force to tubular adaptor 3202 will then shear the shear pins, 1602 a and 1602 b , thereby disengaging the setting tool assembly 32 from the packer assembly 36 .
  • a fluidic material 36114 is then injected into the setting tool assembly 32 and the packer assembly 36 through the longitudinal passages 3202 a , 3204 b , 3206 b , 3208 b , 3604 b , 3650 a , and 3646 b of the tubular adaptor 3202 , tubular upper mandrel 3204 , tubular mandrel 3206 , tubular stinger 3208 , tubular upper mandrel 3604 , tubular sliding sleeve valve 3650 , and tubular lower mandrel 3646 , respectively.
  • the plug 36104 is seated within and blocks the longitudinal passage 3664 a of the tubular plug seat 3664 , the longitudinal passages 3604 b , 3650 a , and 3646 b of the tubular upper mandrel 3604 , tubular sliding sleeve valve 3650 , and tubular lower mandrel 3646 are pressurized thereby displacing the tubular upper adaptor 3602 and tubular upper mandrel 3604 downwardly until the end face of the tubular upper mandrel impacts the end face of the upper tubular spacer ring 3606 .
  • the setting tool assembly 32 is brought back into engagement with the packer assembly 36 until the engagement shoulder 3208 e of the other end of the tubular stinger 3208 engages the collet fingers 3650 d of the end of the tubular sliding sleeve valve 3650 .
  • further downward displacement of the tubular stinger 3208 displaces the tubular sliding sleeve valve 3650 downwardly until the radial flow ports, 3650 b and 3650 c , of the tubular sliding sleeve valve are aligned with the flow ports, 3646 e and 3646 f , of the tubular lower mandrel 3646 .
  • a hardenable fluidic sealing material 36116 may then be injected into the setting tool assembly 32 and the packer assembly 36 through the longitudinal passages 3202 a , 3204 b , 3206 b , 3208 b , and 3650 a of the tubular adaptor 3202 , tubular upper mandrel 3204 , tubular mandrel 3206 , tubular stinger 3208 , and tubular sliding sleeve valve 3650 , respectively.
  • the hardenable fluidic sealing material may then flow out of the packer assembly 36 through the upper flow ports, 3658 d and 3658 e , into the annulus between the expandable wellbore casing 100 and the wellbore 102 .
  • the tubular sliding sleeve valve 3650 may then be returned to its original position, with the radial flow ports, 3650 b and 3650 c , of the tubular sliding sleeve valve out of alignment with the flow ports, 3646 e and 3646 f , of the tubular lower mandrel 3646 .
  • the hardenable fluidic sealing material 36116 may then be allowed to cure before, during, or after the continued operation of the system 10 to further radially expand and plastically deform the expandable wellbore casing.
  • the packer assembly 36 includes an upper tubular spacer ring 36200 receives and mates with the end of the tubular upper mandrel 3604 and includes an angled end face 36200 a that includes a plurality of spaced apart radial grooves 36200 b and another end face that is positioned proximate to an end face of the tubular upper adaptor 3602 is coupled to the tubular upper mandrel by shear pins, 36202 a , 36202 b , 36202 c , and 36202 d .
  • a lower tubular spacer ring 36204 that includes an angled end face 36204 a that includes a plurality of spaced apart radial grooves 36204 b receives, mates, and is coupled to the other end of the tubular upper mandrel 3604 and includes another end face that is positioned proximate to an end face of the external flange 3604 i of the tubular upper mandrel 3604 .
  • the upper and tubular spacer rings, 3606 and 3610 are fabricated from a composite material.
  • An upper tubular slip assembly 36206 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical slip elements 36206 a that each include an exterior arcuate cylindrical surface 36206 aa including mounting holes, 36206 ab , 36206 ac , 36206 ad , 36206 ae , 36206 af , 36206 ag , 36206 ah , 36206 ai , and 36206 aj , and grooves, 36206 aj and 36206 ak , a front end face 36206 al , a rear end face 36206 am including a mounting hole 36206 an , side faces, 36206 ao and 36206 ap , an interior arcuate cylindrical surface 36206 aq that mates with the exterior surface of the tubular upper mandrel 3604 , and an interior tapered surface 36206 ar including a mounting hole 36206 as .
  • Mounting pins 36206 at are received within and coupled to the mounting holes 36206 an and are received within corresponding radial grooves 36200 b of the angled end face 36200 a of the upper tubular spacer ring 36200 .
  • Retaining pins 36206 au are mounted within and coupled to the mounting holes 36206 as that include heads 36206 av .
  • Slip retaining bands, 36206 aw and 36206 ax are received within and coupled to grooves, 36206 aj and 36206 ak , respectively, of the slip elements 36206 a .
  • Slip gripping elements 36206 ay , 36206 az , 36206 aaa , 36206 aab , 36206 aac , 36206 aad , 36206 aae , 36206 aaf , and 36206 aag , are mounted within, coupled to, and extend out of the mounting holes, 36206 ab , 36206 ac , 36206 ad , 36206 ae , 36206 af , 36206 ag , 36206 ah , 36206 ai , and 36206 aj , respectively.
  • the adjacent exterior arcuate cylindrical surfaces 36206 aa of the identical slip elements 36206 a of the upper tubular slip assembly 36206 together define a substantially contiguous cylindrical surface.
  • a lower tubular slip assembly 36208 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical slip elements 36208 a that each include an exterior arcuate cylindrical surface 36208 aa including mounting holes, 36208 ab , 36208 ac , 36208 ad , 36208 ae , 36208 af , 36208 ag , 36208 ah , 36208 ai , and 36208 aj , and grooves, 36208 aj and 36208 ak , a front end face 36208 al , a rear end face 36208 am including a mounting hole 36208 an , side faces, 36208 ao and 36208 ap , an interior arcuate cylindrical surface 36208 aq that mates with the exterior surface of the tubular upper mandrel 3604 , and an interior tapered surface 36208 ar including a mounting hole 36208 as .
  • Mounting pins 36208 at are received within and coupled to the mounting holes 36208 an and are received within corresponding radial grooves 36204 b of the angled end face 36204 a of the lower tubular spacer ring 36204 .
  • Retaining pins 36208 au are mounted within and coupled to the mounting holes 36208 as that include heads 36208 av .
  • Slip retaining bands, 36208 aw and 36208 ax are received within and coupled to grooves, 36208 aj and 36208 ak , respectively, of the slip elements 36208 a .
  • Slip gripping elements 36208 ay , 36208 az , 36208 aaa , 36208 aab , 36208 aac , 36208 aad , 36208 aae , 36208 aaf , and 36208 aag , are mounted within, coupled to, and extend out of the mounting holes, 36208 ab , 36208 ac , 36208 ad , 36208 ae , 36208 af , 36208 ag , 36208 ah , 36208 ai , and 36208 aj , respectively.
  • the adjacent exterior arcuate cylindrical surfaces 36208 aa of the identical slip elements 36208 a of the upper tubular slip assembly 36208 together define a substantially contiguous cylindrical surface.
  • An upper tubular wedge 36210 that receives the tubular upper mandrel 3604 includes an angled front end face 36210 a including spaced apart radial grooves 36210 b , a rear end face 36210 c , an exterior cylindrical surface 36210 d , a plurality of spaced apart faceted tapered exterior surface segments 36210 e that mate with corresponding tapered internal surfaces 36206 ar of corresponding slip elements 36206 a of the upper tubular slip assembly 36206 , and T-shaped exterior grooves 36210 f aligned with the midline of corresponding faceted tapered exterior surface segments that extend from the angled end face to the rear end face that receive and mate with corresponding retaining pins 36206 au of corresponding slip elements of the upper tubular slip assembly.
  • the upper tubular wedge 36210 is releasably coupled to the tubular upper mandrel 3604 by shear pins 36211 .
  • a lower tubular wedge 36212 that receives the tubular upper mandrel 3604 includes an angled front end face 36212 a including spaced apart radial grooves 36212 b , a rear end face 36212 c , an exterior cylindrical surface 36212 d , a plurality of spaced apart faceted tapered exterior surface segments 36212 e that mate with corresponding tapered internal surfaces 36208 ar of corresponding slip elements 36208 a of the upper tubular slip assembly 36208 , and T-shaped exterior grooves 36212 f aligned with the midline of corresponding faceted tapered exterior surface segments that extend from the angled end face to the rear end face that receive and mate with corresponding retaining pins 36208 au of corresponding slip elements of the lower tubular slip assembly.
  • the lower tubular wedge 36212 is releasably coupled to the tubular upper mandrel 3604 by shear pins 36213 .
  • An upper tubular extrusion limiter assembly 36214 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical extrusion limiter elements 36214 a that each include an angled front end face 36214 aa having a recessed portion 36214 ab , an angled rear end face 36214 ac that defines a mounting hole 36214 ad , an interior arcuate cylindrical surface 36214 ae that mates with the tubular upper mandrel, and an exterior arcuate cylindrical surface 36214 af including grooves, 36214 ag , 36214 ah , and 36214 ai .
  • Disk extrusion preventers 36214 aj are mounted within and coupled to the recessed portions 36214 ab of adjacent extrusion limiter elements 36214 a
  • mounting pins 36214 ak are mounted within and coupled to mounting holes 36214 ad of corresponding extrusion limiter elements 36214 a that are received within corresponding radial grooves 36210 b of the front end face 36210 a of the upper tubular wedge 36210 .
  • Retaining bands, 36214 al , 36214 am , and 36214 an are positioned within and coupled to the grooves, 36214 ai , 36214 ah , and 36214 ag , respectively, of the extrusion limiter elements 36214 a.
  • a lower tubular extrusion limiter assembly 36216 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical extrusion limiter elements 36216 a that each include an angled front end face 36216 aa having a recessed portion 36216 ab , an angled rear end face 36216 ac that defines a mounting hole 36216 ad , an interior arcuate cylindrical surface 36216 ae that mates with the tubular upper mandrel, and an exterior arcuate cylindrical surface 36216 af including grooves, 36216 ag , 36216 ah , and 36216 ai .
  • Disk extrusion preventers 36216 aj are mounted within and coupled to the recessed portions 36216 ab of adjacent extrusion limiter elements 36216 a , and mounting pins 36216 ak are mounted within and coupled to mounting holes 36216 ad of corresponding extrusion limiter elements 36216 a that are received within corresponding radial grooves 36212 b of the front end face 36212 a of the lower tubular wedge 36212 .
  • Retaining bands, 36216 al , 36216 am , and 36216 an are positioned within and coupled to the grooves, 36216 ag , 36216 ah , and 36216 ai , of the extrusion limiter elements 36216 a.
  • the angled end face 3640 b of the upper tubular elastomeric packer element 3640 mates with and is positioned proximate the angled end faces 36214 aa and disk extrusion preventers 36214 aj of the extrusion limiter elements 36214 a of the upper tubular extrusion limiter assembly 36214
  • the angled end face 3642 b of the lower tubular elastomeric packer element 3642 mates with and is positioned proximate the angled end faces 36216 aa and disk extrusion preventers 36216 aj of the extrusion limiter elements 36216 a of the lower tubular extrusion limiter assembly 36216 .
  • the first step in setting the packer assembly 36 includes pushing the slip elements, 36206 a and 36208 a , of the upper and lower slip assemblies, 36206 and 36208 , respectively, up the upper and lower tubular wedges, 36210 and 36212 , respectively, which breaks the retaining rings, 36206 aw and 36206 ax , and 36208 aw and 36208 ax , respectively, and moves the slip elements outwardly against the interior surface of the expandable wellbore casing 100 .
  • the retaining pins, 36206 au and 36208 au , respectively, and the mounting pins, 36206 at and 36208 at , respectively maintain the slip elements in an evenly spaced apart configuration.
  • the mounting pins, 36214 ak and 36216 ak maintain the extrusion limiter elements, 36214 a and 36216 a , of the upper and lower tubular extrusion limiter assemblies, 36214 and 36216 , respectively, in an evenly spaced apart configuration.
  • 21 and 21 A to 21 AX is otherwise substantially identical to the operation of the packer assembly described above with reference to FIGS. 20 A 1 to 20 A 5 , 20 B 1 to 20 B 5 , 20 C 1 to 20 C 5 , 20 D 1 to 20 D 5 , 20 E 1 to 20 E 6 , 20 F 1 to 20 F 6 , 20 G 1 to 20 G 6 , and 20 H 1 to 20 H 5 .
  • a packer setting tool assembly 38 includes a tubular adapter 3802 that defines a longitudinal passage 3802 a , radial external mounting holes, 3802 b and 3802 c , radial passages, 3802 d and 3802 e , and includes an external threaded connection 3802 f at one end and an internal annular recess 3802 g having an internal threaded connection at the other end.
  • the tubular upper mandrel 3804 further includes external mounting holes, 3804 k and 3804 l , radial passages, 3804 m and 3804 n , and external mounting holes, 3804 o and 3804 p.
  • Torque pins, 3805 a and 3805 b are received within and coupled to the mounting holes, 3804 c and 3804 d , respectively, of the tubular upper mandrel 3804 and also extend into the radial passages, 3802 d and 3802 e , respectively, of the tubular adaptor 3802 .
  • An external threaded connection 3806 a of an end of a tubular support or tubular mandrel 3806 that defines a longitudinal passage 3806 b and includes an external annular recess 3806 c and an external annular recess 3806 d having an external threaded connection is received within and is coupled to the internal threaded connection 3804 j of the tubular upper mandrel 3804 .
  • a sealing member 3810 is mounted upon and coupled to the external annular recess 3806 d of the mandrel 3806 .
  • Internal splines 3812 aa of a key 3812 a that includes an internal annular recess 3812 ab at one end are movably received within and engage the external splines 3804 g of the tubular upper mandrel 3804 .
  • internal splines 3812 ba of a key 3812 b that includes an internal annular recess 3812 bb at one end are movably received within and engage the external splines 3804 g of the tubular upper mandrel 3804 .
  • An end of a tubular support or tubular bushing 3816 that defines a longitudinal passage 3816 a for receiving and mating with the upper mandrel 3804 , and radial passages, 3816 b and 3816 c , and includes an external flange 3816 d , an internal annular recess 3816 e , circumferentially spaced apart teeth 3816 f , and external flanges, 3816 g and 3816 h , at another end mates with the other ends of the keys, 3812 a and 3812 b .
  • the external flange 3804 h of the upper mandrel 3804 extends within the internal annular recess 3816 e of the tubular bushing 3816 so that the tubular bushing 3816 is retained between the keys, 3812 a and 3812 b , and the external flange 3804 h of the upper mandrel 3804 .
  • the tubular bushing 3816 further includes radial holes, 3816 i and 3816 j , through which the keys, 3812 a and 3812 b , respectively, radially extend so that the keys, 3812 a and 3812 b , lock the bushing 3816 to the upper mandrel 3804 .
  • the tubular bushing 3816 further includes an external annular recess 3816 k.
  • a tubular support or tubular spacer 3818 defines a longitudinal passage 3818 a for receiving the upper mandrel 3804 , includes an annular portion 3818 b at one end that is near or adjacent the other end of the tubular adaptor 3802 , further defines radial passages, 3818 c and 3818 d , and further includes an external annular recess 3818 e , an external annular recess 3818 f , an internal annular recess 3818 g , and counterbores, 3818 h and 3818 i , that are axially aligned with the holes, 3804 k and 3804 l , respectively, of the upper mandrel 3804 .
  • the external annular recesses, 3818 e and 3818 f define an annular protrusion 3818 j .
  • Screws 3820 a and 3820 b are threadably engaged with the counterbores, 3818 h and 3818 i , respectively, of the tubular spacer 3818 , and extend into the holes 3804 m and 3804 l , respectively, of the upper mandrel 3804 , thereby coupling the tubular spacer 3818 to the upper mandrel 3804 .
  • a retaining ring 3824 is disposed in the external annular recess 3804 e of the upper mandrel 3804 and extends into the internal annular recess 3822 c of the packer cup sleeve 3822 , retaining the end of the packer cup sleeve 3822 in the internal annular recess 3818 g of the tubular spacer 3818 , thereby coupling the packer cup sleeve 3822 to the upper mandrel 3804 .
  • a packer cup 3824 is disposed in the external annular recess 3822 b of the packer cup sleeve 3822
  • a packer ring 3825 is disposed in the external annular recess 3822 b of the packer cup sleeve 3822 and is axially positioned between the packer cup 3824 and the tubular spacer 3818 .
  • Radial holes, 3826 h and 3826 i extend through the internal annular recess 3826 b
  • radial holes, 3826 j and 3286 k extend through the internal annular recess 3826 d .
  • the packer cup 3824 sealingly engages the internal annular recess 3826 c of the upper sleeve 3826 .
  • Upper retaining dogs, 3828 a and 3828 b including internal annular recesses 3828 aa and 3828 ba , respectively, extend through the radial holes 3826 h and 3826 i , respectively, and are coupled to the tubular upper sleeve 3826 .
  • the upper retaining dogs, 3828 a and 3828 b are adapted to further extend into the external annular recess 3818 e to releasably engage the tubular spacer 3818 , as shown in FIG. 22A and under conditions to be described.
  • a retaining ring 3829 extends into the external annular recess 3804 f of the upper mandrel 3804 and extends into an internal annular recess 3830 a of a lower dog retainer 3830 .
  • the lower dog retainer 3830 further includes an internal annular recess 3830 b , an external annular recess 3830 c , counterbores, 3830 d and 3830 e , that are axially aligned with the external mounting holes, 3804 o and 3804 p , respectively, of the upper mandrel 3804 , and radial holes 3830 f and 3830 g .
  • Screws, 3832 a and 3832 b are threadably engaged with the counterbores, 3830 d and 3830 e , respectively, of the lower dog retainer 3830 , and extend into the external mounting holes, 3804 o and 3804 p , respectively, of the upper mandrel 3804 , which, along with the retaining ring 3829 , couple the lower dog retainer 3830 to the upper mandrel 3804 .
  • a tubular support or tubular retaining sleeve 3834 includes an external annular recess 3834 a and an external annular recess 3834 b , and mates with the exterior surface of the upper mandrel 3804 and with the interior surface of the upper sleeve 3826 .
  • Lower retaining dogs, 3836 a and 3836 b including respective internal annular recesses, 3836 aa and 3836 ab , engage the internal annular recess 3826 d and extend through the radial holes, 3830 f and 3830 g , respectively, to mate with the retaining sleeve 3834 .
  • the retaining sleeve 3834 retains the lower retaining dogs, 3836 a and 3836 b , so that any relative movement between the lower retaining dogs, 3836 a and 3836 b , and the upper mandrel 3804 is substantially prevented.
  • Rupture discs, 3838 a and 3838 b are received and mounted within the radial passages, 3804 m and 3804 n.
  • An external threaded connection 3840 a of an external annular recess 3840 b of a tubular support or spring mandrel 3840 is received within the internal annular recess 3826 f of the upper sleeve 3826 and is coupled to the internal threaded connection 3826 g of the upper sleeve 3826 .
  • the spring mandrel 3840 further includes an external annular recess 3840 c , an external annular recess 3840 d , an external annular recess 3840 e , an external threaded connection 3840 f , an internal annular recess 3840 g and an internal annular recess 3840 h .
  • a locking dog 3841 is received within the internal annular recess 3840 h of the spring mandrel 3840 and engages the exterior surface of the bushing 3816 .
  • An internal threaded connection 3842 a of a tubular support or tubular spring retainer 3842 is coupled to the external threaded connection 3840 f of the spring mandrel 3840 , and includes a external flange 3842 b .
  • a tubular spring sleeve 3844 engages the external flange 3842 b of the spring retainer 3842 and includes an internal annular recess 3844 a , radial passages, 3844 b and 3844 c , an external annular recess 3844 d and an external threaded connection 3844 e .
  • a compressible element such as a spring 3846 is retained and extends within an annular region 3848 defined by the internal annular recess 3844 a of the spring sleeve 3844 , the exterior of the spring retainer 3842 and at least an end of the spring mandrel 3840 , thereby circumferentially extending about the tubular upper mandrel 3804 .
  • a tubular locking dog retainer 3843 is received within the internal annular recess 3826 f of the upper sleeve 3826 and includes an internal flange 3843 a that engages the keys, 3812 a and 3812 b , and is received within the internal annular recess 3840 g of the spring mandrel 3840 .
  • An internal threaded connection 3850 a of an end of a tubular setting sleeve 3850 that defines a longitudinal passage 3850 b , radial passages, 3850 c and 3850 d , radial passages, 3850 e and 3850 f , and includes an internal flange 3850 g at another end, engages the external threaded connection 3844 e of the spring retainer 3842 .
  • An internal flange 3852 a of a tubular coupling ring 3852 that defines a longitudinal passage 3852 b and radial passages, 3852 c and 3852 d , and includes an external annular recess 3852 e , receives and mates with the external flange 3816 h of the bushing 3816 .
  • An internal flange 3854 a of a tubular retaining collet 3854 that includes a plurality of axially extending collet fingers 3854 b , each finger 3854 b having internal flanges 3854 c at an end of each collet finger, receives the tubular coupling ring 3852 and engages the external annular recess 3852 e of the tubular coupling ring 3852 .
  • the packer setting tool assembly 38 and the packer assembly 36 are coupled to one another by inserting the end of the tubular upper adaptor 3602 into the other end of the tubular coupling ring 3852 , bringing the circumferentially spaced teeth 3816 f of the other end of the tubular bushing 3816 into engagement with the circumferentially spaced teeth 3602 e of the end of the tubular upper adaptor 3602 , and mounting shear pins, 36100 a and 36100 b , within the radial passages, 3852 c and 3852 d , respectively, of the tubular coupling ring 3852 and within the mounting holes, 3602 c and 3602 d , respectively, of the tubular upper adaptor 3602 .
  • tubular mandrel 3806 and the tubular stinger 3808 of the packer setting tool assembly 38 are thereby positioned within the longitudinal passage 3604 b of the tubular upper mandrel 3604 with the engagement shoulder 3808 e of the tubular stinger 3808 positioned within the longitudinal passage 3646 b of the tubular lower mandrel 3646 proximate the collet fingers 3650 d of the tubular sliding sleeve valve 3650 .
  • the packer setting tool assembly 38 and the packer assembly 36 are positioned within the expandable wellbore casing 100 , and the internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 receives and is coupled to the external threaded connection 3802 f of the tubular adaptor 3802 of the packer setting tool assembly 38 .
  • the upper retaining dogs, 3828 a and 3828 b , and/or the outer diameter of the tubular upper sleeve 3826 are sized so that the upper retaining dogs, 3828 a and 3828 b , and/or at least a portion of the exterior surface of the tubular upper sleeve 3826 , engage the wellbore casing 100 , and the tubular upper sleeve 3826 is radially inwardly biased so that the upper retaining dogs, 3828 a and 3828 b , extend into the external annular recess 3818 e and are forced to mate with the tubular spacer 3818 , thereby releasably engaging the tubular spacer 3818 , including releasably engaging the annular protrusion 3818 j .
  • torque pins, 3676 d and 3676 e may be mounted within mounting holes, 3676 f and 3676 g , respectively, of the tubular bypass sleeve 3676 to couple the tubular bypass sleeve 3676 to the expandable wellbore casing 100 .
  • torsion loads may be transferred between the tubular bypass sleeve 3676 and the expandable wellbore casing 100 .
  • the plug 36104 is then injected into the setting tool assembly 38 and the packer assembly 36 by injecting the fluidic material 36106 into the setting tool assembly 38 and the packer assembly 36 through the longitudinal passages, 3802 a , 3804 b , 3806 b , 3808 b , 3650 a , 3646 b and 3664 a of the tubular adaptor 3802 , tubular upper mandrel 3804 , tubular mandrel 3806 , tubular stinger 3808 , tubular sliding sleeve valve 3650 , tubular lower mandrel 3646 , and tubular plug seat 3664 , respectively.
  • the plug 36104 is thereby positioned within the longitudinal passage 3664 a of the tubular plug seat 3664 .
  • the flow ports, 3664 c and 3664 d , of the tubular plug seat 3664 are aligned with the upper flow ports, 3660 c and 3660 d , respectively, of the tubular bypass mandrel 3660 .
  • continued injection of the fluidic material 36106 following the prevention of further movement of the tubular plug seat 3664 actuates the extension actuator assembly 26 in a manner substantially similar to that described above so that the extension actuator assembly 26 pushes the adjustable bell section expansion cone assembly 28 , the adjustable casing expansion cone assembly 30 , the packer setting tool assembly 38 and the packer assembly 36 out of the wellbore casing 100 .
  • the upper retaining dogs, 3828 a and 3828 b , and the tubular upper sleeve 3826 no longer engage the wellbore casing 100 and thus the tubular upper sleeve 3826 is no longer radially inwardly biased.
  • the upper retaining dogs, 3828 a and 3828 b are released from mating with the tubular spacer 3818 and engaging the annular protrusion 3818 j.
  • the upper sleeve 3826 is displaced in a direction toward the packer assembly 36 in a manner to be described below, thereby causing the spring sleeve 3844 , the setting sleeve 3850 and the upper tubular spacing ring 3606 of the packer assembly 36 to move in a direction towards the upper tubular wedge 3620 in a manner described below.
  • the upper tubular slip 3612 is forced to move along the upper tubular wedge 3620 until the upper tubular slip 3612 is pushed off of the packer assembly 36 , thereby permitting the packer setting tool assembly 38 and the packer assembly 36 to be retrieved.
  • the upper retaining dogs, 3828 a and 3828 b continue to mate with the tubular spacer 3818 and to engage the annular protrusion 3818 j , thereby preventing the upper sleeve 3826 from moving in a direction towards the packer assembly 36 in a manner, and for reasons, to be described below, and permitting the packer setting tool assembly 38 and the packer assembly 36 to be retrieved.
  • the wellbore casing 100 is radially expanded and plastically deformed using the ball gripper assembly 16 , the tension actuator assembly 18 , the casing lock assembly 24 , the extension actuator assembly 26 and the expansion cone assemblies, 28 and 30 , in a manner of operation substantially similar to any one of the manners of operation described and/or referenced above, and/or any combination thereof.
  • the lower retaining dogs, 3836 a and 386 b no longer engage the internal annular recess 3826 d of the upper sleeve 3826 , but instead move radially inward to engage the external annular recesses, 3834 a and 3834 b , of the tubular retaining sleeve 3834 .
  • the lower retaining dogs, 3836 a and 3836 b are released from the upper sleeve 3826 .
  • the operating pressure of the fluidic material 36106 in the annulus 3856 causes the upper sleeve 3826 , the spring mandrel 3840 , the spring sleeve 3844 and the setting sleeve 3850 to be displaced in the downward direction 36108 until the setting sleeve 3850 engages the upper tubular spacer ring 3606 of the packer assembly 36 , which is mated with the upper tubular slip 3612 of the packer assembly 36 .
  • the operating pressure of the fluidic material 36106 in the annulus 3856 continues to cause the upper sleeve 3826 , the spring mandrel 3840 and the spring sleeve 3844 to be displaced in the downward direction 36108 , relative to the setting sleeve 3850 .
  • the external annular recess 3840 d of the spring mandrel 3840 compresses the spring 3846 against an end face 3844 aa defined by the internal annular recess 3844 a of the spring sleeve 3844 .
  • the operating pressure of the fluidic material 36106 in the annulus 3856 causes the upper sleeve 3826 to force the upper tubular slip 3612 of the packer assembly 36 , via force transmission across the spring mandrel 3840 , the compressed spring 3846 , the spring sleeve 3844 , the setting sleeve 3850 and the upper tubular spacer ring 3606 , to move along the upper tubular wedge 3620 of the packer assembly 36 .
  • the shear pins, 3608 a and 3608 b may be broken to enable the upper tubular slip 3612 to move along the upper tubular wedge 3620 .
  • one or more of the slip retaining bands, 3612 c , 3612 d , 3612 e , 3612 f , 3612 g , 3614 a , 3614 b , 3614 c , 3614 d , and 3614 e may be broken to enable the upper tubular slip 3612 to move along the upper tubular wedge 3620 .
  • the upper sleeve 3826 continues to force the upper tubular slip 3612 to move along the upper tubular wedge 3620 until the spring mandrel 3840 engages the external flange 3816 d of the tubular bushing 3816 , the end of which, in turn, is engaged with the external flange 3804 h of the upper mandrel 3804 .
  • any further displacement of the upper sleeve 3826 in the downward direction 36108 is substantially prevented.
  • the keys, 3812 a and 3812 b are released from their engagement with the internal flange 3843 a of the locking dog retainer 3843 .
  • the locking dog 3841 is displaced in the downward direction 36018 so that the locking dog 3841 is received within the external annular recess 3816 k of the bushing 3816 .
  • the keys, 3812 a and 3812 b lock the bushing 3816 to the upper mandrel 3804 , and allow torque and load top to be transmitted from the upper mandrel 3804 to the tubular bushing 3816 , and to the packer assembly 36 via the above-described coupling between the packer setting tool assembly 38 and the packer assembly 36 .
  • the keys, 3812 a and 3812 b prevent the stinger 3808 from engaging and displacing the sliding sleeve valve 3650 , thereby preventing the radial flow ports, 3650 b and 3650 c , of the sliding sleeve valve 3650 from being axially aligned with the flow ports, 3646 e and 3646 f , of the tubular lower mandrel 3646 of the packer assembly 36 .
  • the upper tubular slip 3612 is substantially prevented from applying an impact load against the interior surface of the wellbore casing 100 .
  • FIGS. 30A through 30E after the upper tubular slip 3612 is set against the wellbore casing 100 , an upward tensile force is applied to the tubular support member 12 , and the ball gripper assembly 16 is then operated to engage the interior surface of the wellbore casing 100 in a manner of operation substantially similar to any one of the manners of operation described and/or referenced above, and/or any combination thereof.
  • the tension actuator assembly 18 is then operated to apply a tensile force to the tubular adaptor 3802 in an upward direction 3860 , in any one of the manners of operation described and/or referenced above, and/or any combination thereof, thereby compressing the lower tubular slip 3616 , the lower tubular wedge 3624 , the lower tubular extrusion limiter 3634 , the central elastomeric packer element 3644 , the upper tubular extrusion limiter 3628 and the upper tubular wedge 3620 between the lower tubular spacer ring 3610 and the stationary upper tubular slip 3612 .
  • the lower tubular slip 3616 moves along the lower tubular wedge 3624 and into engagement with the interior surface of the wellbore casing 100 , forcing the lower tubular slip 3616 to set against the interior surface of the wellbore casing 100 .
  • the elastomeric packer element 3644 is compressed radially outwardly into engagement with the interior surface of the wellbore casing 100 , forcing the packer element 3644 to set against the interior surface of the wellbore casing 100 .
  • further longitudinal displacement of the upper tubular slip 3612 , the lower tubular slip 3616 and the packer element 3644 , relative to the wellbore casing 100 is prevented.
  • the packer setting tool assembly 38 continues to move away from the packer assembly 36 , in the direction 3860 , at least until at least a portion of the stinger 3808 no longer extends within the longitudinal passage 3602 a of the tubular upper adaptor 3602 of the packer assembly 36 , and the adjustable expansion cone assembly 30 engages and mates with at least a portion of the interior surface of the unexpanded portion of the wellbore casing 100 .
  • continued injection of the fluidic material 36106 causes the packer setting tool assembly 38 to move in the direction 36108 until the tubular spacer ring 3606 engages the stationary upper tubular slip 3612 .
  • the continued injection of the fluidic material 36106 also causes the packer assembly 36 , including the tubular upper mandrel 3604 , to move in the direction 36108 so that the lower tubular spacer ring 3610 moves away from the stationary lower tubular slip 3616 .
  • the portion of the interior of the wellbore casing 100 within which at least a portion of the packer assembly 36 extends is pressurized, thereby testing the ability of the engagement between the wellbore casing 100 and one or more of the upper tubular slip 3612 , the upper tubular extrusion limiter 3628 , the elastomeric packer element 3644 , the lower tubular extrusion limiter 3634 and the lower tubular slip 3616 to maintain a pressure seal against the interior surface of the wellbore casing 100 .
  • the continued injection of the fluidic material 36106 is stopped, and the operating pressure within the longitudinal passages, 3802 a , 3804 b , 3806 b , 3808 b , 3650 a , 3646 b and 3664 a of the tubular adaptor 3802 , tubular upper mandrel 3804 , tubular mandrel 3806 , tubular stinger 3808 , tubular sliding sleeve valve 3650 , tubular lower mandrel 3646 , and tubular plug seat 3664 , respectively, is released.
  • the packer setting tool assembly 38 is brought back into engagement with the packer assembly 36 until the engagement shoulder 3808 e of the other end of the tubular stinger 3808 engages the collet fingers 3650 d of the end of the tubular sliding sleeve valve 3650 .
  • further downward displacement of the tubular stinger 3808 displaces the tubular sliding sleeve valve 3650 downwardly until the radial flow ports, 3650 b and 3650 c , of the tubular sliding sleeve valve 3650 are aligned with the radial flow ports, 3646 e and 3646 f , of the tubular lower mandrel 3646 .
  • the locking dog 3841 engages the external annular recess 3816 k of the bushing 3816 and the internal annular recess 3840 h of the spring mandrel 3840 to further separate the bushing 3816 , the coupling ring 3852 and the retaining collet 3854 from the packer assembly 36 .
  • a hardenable fluidic sealing material 36116 may then be injected into the packer setting tool assembly 38 and the packer assembly 36 through the longitudinal passages 3802 a , 3804 b , 3806 b , 3808 b and 3650 a of the tubular adaptor 3802 , tubular upper mandrel 3804 , tubular mandrel 3806 , tubular stinger 3808 and the tubular sliding sleeve valve 3650 , respectively.
  • the hardenable fluidic sealing material 3116 may then flow out of the longitudinal passage 3650 a , through the radial ports, 3650 b and 3650 c , of the tubular sliding sleeve valve 3650 , through the radial ports, 3646 e and 3646 f , of the tubular lower mandrel 3646 , and into an annulus 36118 defined by the exterior surface of the tubular lower mandrel 3646 and the interior surface of the tubular outer sleeve 3658 .
  • the hardenable sealing material 3116 may then flow out of the annulus 36118 , through the upper flow ports, 3658 d and 3658 e , and the lower flow ports, 3658 f and 3658 g , and into the annulus between the wellbore casing 100 and the wellbore 102 .
  • the hardenable fluidic sealing material 36116 in addition to, or instead of the injection of the hardenable fluidic sealing material 36116 , it is understood that other well fluids may be injected into the packer setting tool assembly 38 and the packer assembly 36 in a manner similar to the injection of the hardenable fluidic sealing material 36116 .
  • the tubular sliding sleeve valve 3650 may then be returned to its original position, with the radial flow ports, 3650 b and 3650 c , of the tubular sliding sleeve valve out of alignment with the flow ports, 3646 e and 3646 f , of the tubular lower mandrel 3646 .
  • the hardenable fluidic sealing material 36116 may then be allowed to cure before, during, or after the continued operation of the system 10 to further radially expand and plastically deform the expandable wellbore casing 100 .
  • the packer setting tool assembly 38 and the packer assembly 36 are operated in the above-described manner so that the upper tubular slip 3612 , the lower tubular slip 3616 and the packer element 3644 engage and set against the interior surface of the bell section 112 of the wellbore casing 100 , thereby permitting the packer setting tool assembly 38 to be retrieved, that is, to be moved in a direction away from the upper tubular slip 3612 , the lower tubular slip 3614 and the packer element 3644 .
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member, a cutting device for cutting the tubular member coupled to the support member, and an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member.
  • the apparatus further includes a gripping device for gripping the tubular member coupled to the support member.
  • the gripping device comprises a plurality of movable gripping elements.
  • the gripping elements are moveable in a radial direction relative to the support member.
  • the gripping elements are moveable in an axial direction relative to the support member.
  • the gripping elements are moveable in a radial and an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member.
  • the gripping device grips the tubular member; and, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position.
  • the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator.
  • the apparatus further includes a sealing device for sealing an interface with the tubular member coupled to the support member.
  • the sealing device seals an annulus defines between the support member and the tubular member.
  • the apparatus further includes a locking device for locking the position of the tubular member relative to the support member.
  • the apparatus further includes a packer assembly coupled to the support member.
  • the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member.
  • the packer includes: a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer.
  • the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device includes: a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve.
  • the apparatus further includes an actuator for displacing the expansion device relative to the support member.
  • the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device.
  • the actuator includes means for transferring torsional loads between the support member and the expansion device.
  • the first and second actuators include means for transferring torsional loads between the support member and the expansion device.
  • the actuator includes a plurality of pistons positioned within corresponding piston chambers.
  • the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member.
  • the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the cutting elements includes a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements.
  • the first position in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements.
  • the first set of cutting elements are axially aligned with the second set of cutting elements.
  • the expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member.
  • apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements.
  • the first position in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements.
  • the first set of expansion elements in the second position, are axially aligned with the second set of expansion elements.
  • the expansion device includes an adjustable expansion device.
  • the expansion device includes a plurality of expansion devices.
  • at least one of the expansion devices includes an adjustable expansion device.
  • the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements.
  • the first set of expansion elements in the first position, are not axially aligned with the second set of expansion elements.
  • in the second position the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member, an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member, and an actuator coupled to the support member for displacing the expansion device relative to the support member.
  • the apparatus further includes a cutting device coupled to the support member for cutting the tubular member.
  • the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements.
  • the apparatus further includes a gripping device for gripping the tubular member coupled to the support member.
  • the gripping device includes a plurality of movable gripping elements.
  • the gripping elements are moveable in a radial direction relative to the support member.
  • the gripping elements are moveable in an axial direction relative to the support member.
  • the gripping elements are moveable in a radial and an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member.
  • the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position.
  • the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator.
  • the apparatus further includes a sealing device for sealing an interface with the tubular member coupled to the support member.
  • the sealing device seals an annulus defines between the support member and the tubular member.
  • the apparatus further includes a locking device for locking the position of the tubular member relative to the support member.
  • the apparatus further includes a packer assembly coupled to the support member.
  • the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member.
  • the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer.
  • the expansion device includes an adjustable expansion device.
  • the expansion device includes a plurality of expansion devices.
  • at least one of the expansion devices includes an adjustable expansion device.
  • the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member.
  • the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position.
  • the expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • an apparatus for radially expanding and plastically deforming an expandable tubular member includes a support member; a first expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a second expansion device for radially expanding and plastically deforming the tubular member coupled to the support member.
  • the apparatus further includes a gripping device for gripping the tubular member coupled to the support member.
  • the gripping device includes a plurality of movable gripping elements.
  • the gripping elements are moveable in a radial direction relative to the support member.
  • the gripping elements are moveable in an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member.
  • the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member.
  • the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member.
  • the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements.
  • the first position in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements.
  • the first set of expansion elements are axially aligned with the second set of expansion elements.
  • the gripping elements are moveable in a radial and an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member.
  • the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position.
  • the actuator includes means for transferring torsional loads between the support member and the expansion device.
  • the first and second actuators include means for transferring torsional loads between the support member and the expansion device.
  • the actuator includes a plurality of pistons positioned within corresponding piston chambers.
  • the apparatus further includes a cutting device coupled to the support member for cutting the tubular member.
  • the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member.
  • the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements.
  • the first position in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements.
  • the first set of expansion elements are axially aligned with the second set of expansion elements.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member.
  • the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve.
  • the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device.
  • the actuator includes means for transferring torsional loads between the support member and the expansion device.
  • the first and second actuators include means for transferring torsional loads between the support member and the expansion device.
  • the actuator includes a plurality of pistons positioned within corresponding piston chambers.
  • the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member.
  • the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements.
  • the first position in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements.
  • the first set of cutting elements are axially aligned with the second set of cutting elements.
  • at least one of the adjustable expansion devices include a support member; and a plurality of movable expansion elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements.
  • the first set of expansion elements are not axially aligned with the second set of expansion elements.
  • the first set of expansion elements are axially aligned with the second set of expansion elements.
  • at least one of the adjustable expansion devices comprise a plurality of expansion devices.
  • at least one of the adjustable expansion devices include a support member; and a plurality of movable expansion elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements.
  • the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for cutting a tubular member includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements.
  • the first set of cutting elements in the first position, are not axially aligned with the second set of cutting elements.
  • in the second position the first set of cutting elements are axially aligned with the second set of cutting elements.
  • An apparatus for engaging a tubular member includes a support member; and a plurality of movable elements coupled to the support member.
  • the apparatus further includes an actuator coupled to the support member for moving the elements between a first position and a second position; wherein in the first position, the elements do not engage the tubular member; and wherein in the second position, the elements engage the tubular member.
  • the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value.
  • the elements include a first set of elements; and a second set of elements; wherein the first set of elements are interleaved with the second set of elements.
  • the first set of elements in the first position, are not axially aligned with the second set of elements.
  • the first set of elements in the second position, are axially aligned with the second set of elements.
  • An apparatus for gripping a tubular member includes a plurality of movable gripping elements.
  • the gripping elements are moveable in a radial direction.
  • the gripping elements are moveable in an axial direction.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction.
  • the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction.
  • the gripping device in a first axial direction, grips the tubular member; and wherein, in a second axial direction, the gripping device does not grip the tubular member.
  • the apparatus further includes an actuator for moving the gripping elements.
  • the gripping elements include a plurality of separate and distinct gripping elements.
  • An actuator has been described that includes a tubular housing; a tubular piston rod movably coupled to and at least partially positioned within the housing; a plurality of annular piston chambers defined by the tubular housing and the tubular piston rod; and a plurality of tubular pistons coupled to the tubular piston rod, each tubular piston movably positioned within a corresponding annular piston chamber.
  • the actuator further includes means for transmitting torsional loads between the tubular housing and the tubular piston rod.
  • An apparatus for controlling a packer includes a tubular support member; one or more drag blocks releasably coupled to the tubular support member; and a tubular stinger coupled to the tubular support member for engaging the packer.
  • the apparatus further includes a tubular sleeve coupled to the drag blocks.
  • the tubular support member includes one or more axially aligned teeth for engaging the packer.
  • a packer has been described that includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • a method of radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing includes positioning the tubular member within the borehole in overlapping relation to the wellbore casing; radially expanding and plastically deforming a portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section.
  • radially expanding and plastically deforming a portion of the tubular member to form a bell section includes positioning an adjustable expansion device within the expandable tubular member; supporting the expandable tubular member and the adjustable expansion device within the borehole; lowering the adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member, wherein n is greater than or equal to 1.
  • a method for forming a mono diameter wellbore casing includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; positioning the adjustable expansion device within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole.
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes positioning an adjustable expansion device within the expandable tubular member; supporting the expandable tubular member and the adjustable expansion device within the borehole; lowering the adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • a method for forming a mono diameter wellbore casing includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; positioning the adjustable expansion mandrel within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion mandrel out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion mandrel; displac
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • a method for forming a mono diameter wellbore casing includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; positioning first and second adjustable expansion devices within a second expandable tubular member; supporting the first expandable tubular member and
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expand
  • a method for forming a mono diameter wellbore casing includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of
  • a method for radially expanding and plastically deforming an expandable tubular member within a borehole includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member.
  • the method further includes reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed.
  • the method further includes fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device.
  • the method further includes permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member.
  • the method further includes injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and a preexisting structure after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the method further includes increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the method further includes displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform another portion of the expandable tubular member.
  • the method further includes if the end of the other portion of the expandable tubular member overlaps with a preexisting structure, then not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the other portion of the expandable tubular member that overlaps with the preexisting structure.
  • a method for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member.
  • the method further includes reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed. In an exemplary embodiment, the method further includes fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device. In an exemplary embodiment, the method further includes permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member.
  • the method further includes injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the borehole after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the method further includes increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the method further includes displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member.
  • the method further includes not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the remaining portion of the expandable tubular member that overlaps with the preexisting wellbore casing after not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • a method of radially expanding and plastically deforming a tubular member includes positioning the tubular member within a preexisting structure; radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section.
  • positioning the tubular member within a preexisting structure includes locking the tubular member to an expansion device.
  • the outside diameter of the expansion device is less than the inside diameter of the tubular member.
  • the expansion device is positioned within the tubular member.
  • the expansion device includes an adjustable expansion device.
  • the adjustable expansion device is adjustable to a plurality of sizes.
  • the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices includes an adjustable expansion device. In an exemplary embodiment, at least one of the adjustable expansion device is adjustable to a plurality of sizes.
  • radially expanding and plastically deforming a lower portion of the tubular member to form a bell section includes lowering an expansion device out of an end of the tubular member; and pulling the expansion device through the end of the tubular member. In an exemplary embodiment, lowering an expansion device out of an end of the tubular member includes lowering the expansion device out of the end of the tubular member; and adjusting the size of the expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes.
  • the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes.
  • pulling the expansion device through the end of the tubular member includes gripping the tubular member; and pulling an expansion device through an end of the tubular member.
  • gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction.
  • pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using an actuator.
  • radially expanding and plastically deforming a portion of the tubular member above the bell section includes lowering an expansion device out of an end of the tubular member; and pulling the expansion device through the end of the tubular member.
  • lowering an expansion device out of an end of the tubular member includes lowering the expansion device out of the end of the tubular member; and adjusting the size of the expansion device.
  • the adjustable expansion device is adjustable to a plurality of sizes.
  • the expansion device includes a plurality of adjustable expansion devices.
  • at least one of the adjustable expansion devices is adjustable to a plurality of sizes.
  • pulling the expansion device through the end of the tubular member includes gripping the tubular member; and pulling an expansion device through an end of the tubular member.
  • gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction.
  • pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using an actuator.
  • pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using fluid pressure.
  • pulling the expansion device through the end of the tubular member using fluid pressure includes pressurizing an annulus within the tubular member above the expansion device.
  • radially expanding and plastically deforming a portion of the tubular member above the bell section includes fluidicly sealing an end of the tubular member; and pulling the expansion device through the tubular member.
  • the expansion device is adjustable.
  • the expansion device is adjustable to a plurality of sizes.
  • the expansion device comprises a plurality of adjustable expansion devices.
  • at least one of the adjustable expansion devices is adjustable to a plurality of sizes.
  • pulling the expansion device through the end of the tubular member includes gripping the tubular member; and pulling an expansion device through an end of the tubular member.
  • gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction.
  • pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using an actuator.
  • pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using fluid pressure.
  • pulling the expansion device through the end of the tubular member using fluid pressure includes pressurizing an annulus within the tubular member above the expansion device.
  • radially expanding and plastically deforming a portion of the tubular member above the bell section includes overlapping the portion of the tubular member above the bell section with an end of a preexisting tubular member; and pulling an expansion device through the overlapping portions of the tubular member and the preexisting tubular member.
  • the expansion device is adjustable.
  • the expansion device is adjustable to a plurality of sizes.
  • the expansion device includes a plurality of adjustable expansion devices.
  • at least one of the adjustable expansion devices is adjustable to a plurality of sizes.
  • pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes gripping the tubular member; and pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member.
  • gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction.
  • pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using an actuator.
  • pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using fluid pressure.
  • pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using fluid pressure includes pressurizing an annulus within the tubular member above the expansion device.
  • the method further includes cutting an end of the portion of the tubular member that overlaps with the preexisting tubular member.
  • the method further includes removing the cut off end of the expandable tubular member from the preexisting structure.
  • the method further includes injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the preexisting structure. In an exemplary embodiment, the method further includes cutting off an end of the expandable tubular member. In an exemplary embodiment, the method further includes removing the cut off end of the expandable tubular member from the preexisting structure.
  • a method of radially expanding and plastically deforming a tubular member includes applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another.
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing includes means for positioning the tubular member within the borehole in overlapping relation to the wellbore casing; means for radially expanding and plastically deforming a portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section.
  • means for radially expanding and plastically deforming a portion of the tubular member to form a bell section includes means for positioning an adjustable expansion device within the expandable tubular member; means for supporting the expandable tubular member and the adjustable expansion device within the borehole; means for lowering the adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member, wherein n is greater than or equal to 1.
  • a system for forming a mono diameter wellbore casing includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for positioning the adjustable expansion device within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for positioning an adjustable expansion device within the expandable tubular member; means for supporting the expandable tubular member and the adjustable expansion device within the borehole; means for lowering the adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and means for pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • a system for forming a mono diameter wellbore casing includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; means for positioning the adjustable expansion mandrel within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion mandrel out of the second expandable tubular tubular
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device
  • a system for forming a mono diameter wellbore casing includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; means for positioning first and second adjustable expansion devices within a
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular
  • a system for forming a mono diameter wellbore casing includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the
  • a system for radially expanding and plastically deforming an expandable tubular member within a borehole includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member.
  • the system further includes means for reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed.
  • the system further includes means for fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device.
  • the system further includes means for permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member.
  • the system further includes means for injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and a preexisting structure after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the system further includes if the end of the other portion of the expandable tubular member overlaps with a preexisting structure, then means for not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the other portion of the expandable tubular member that overlaps with the preexisting structure.
  • a system for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member.
  • the system further includes means for reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed. In an exemplary embodiment, the system further includes means for fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device. In an exemplary embodiment, the system further includes means for permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member.
  • the system further includes means for injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the borehole after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the system further includes means for increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • the system further includes means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member.
  • the system further includes means for not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the remaining portion of the expandable tubular member that overlaps with the preexisting wellbore casing after not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • a system for radially expanding and plastically deforming a tubular member includes means for positioning the tubular member within a preexisting structure; means for radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section.
  • positioning the tubular member within a preexisting structure includes means for locking the tubular member to an expansion device.
  • the outside diameter of the expansion device is less than the inside diameter of the tubular member.
  • the expansion device is positioned within the tubular member.
  • the expansion device includes an adjustable expansion device.
  • means for lowering an expansion device out of an end of the tubular member includes means for lowering the expansion device out of the end of the tubular member; and means for adjusting the size of the expansion device.
  • the adjustable expansion device is adjustable to a plurality of sizes.
  • the expansion device includes a plurality of adjustable expansion devices.
  • at least one of the adjustable expansion devices is adjustable to a plurality of sizes.
  • means for pulling the expansion device through the end of the tubular member includes means for gripping the tubular member; and means for pulling an expansion device through an end of the tubular member.
  • means for lowering an expansion device out of an end of the tubular member includes means for lowering the expansion device out of the end of the tubular member; and means for adjusting the size of the expansion device.
  • the adjustable expansion device is adjustable to a plurality of sizes.
  • the expansion device comprises a plurality of adjustable expansion devices.
  • at least one of the adjustable expansion devices is adjustable to a plurality of sizes.
  • means for pulling the expansion device through the end of the tubular member includes means for gripping the tubular member; and means for pulling an expansion device through an end of the tubular member.
  • a system of radially expanding and plastically deforming a tubular member has been described that includes a support member; and means for applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another coupled to the support member.
  • bringing the cutting elements into engagement with the tubular member further includes pivoting the cutting elements; and translating the cutting elements.
  • bringing the cutting elements into engagement with the tubular member includes rotating the cutting elements about a common axis.
  • bringing the cutting elements into engagement with the tubular member includes pivoting the cutting elements about corresponding axes; translating the cutting elements; and rotating the cutting elements about a common axis.
  • the method further includes preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value.
  • preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes sensing the inside diameter of the tubular member.
  • a method of operating an actuator has been described that includes pressurizing a plurality of pressure chamber.
  • the method further includes transmitting torsional loads.
  • a system for cutting a tubular member includes means for positioning a plurality of cutting elements within the tubular member; and means for bringing the cutting elements into engagement with the tubular member.
  • the cutting elements include a first group of cutting elements; and a second group of cutting elements; wherein the first group of cutting elements are interleaved with the second group of cutting elements.
  • means for bringing the cutting elements into engagement with the tubular member includes means for bringing the cutting elements into axial alignment.
  • means for bringing the cutting elements into engagement with the tubular member further includes means for pivoting the cutting elements.
  • means for bringing the cutting elements into engagement with the tubular member further includes means for translating the cutting elements.
  • means for bringing the cutting elements into engagement with the tubular member further includes means for pivoting the cutting elements; and means for translating the cutting elements.
  • means for bringing the cutting elements into engagement with the tubular member includes means for rotating the cutting elements about a common axis.
  • means for bringing the cutting elements into engagement with the tubular member includes means for pivoting the cutting elements about corresponding axes; means for translating the cutting elements; and means for rotating the cutting elements about a common axis.
  • the system further includes means for preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value.
  • means for preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes means for sensing the inside diameter of the tubular member.
  • An actuator system has been described that includes a support member; and means for pressurizing a plurality of pressure chambers coupled to the support member.
  • the system further includes means for transmitting torsional loads.
  • bringing the elements into engagement with the tubular member includes rotating the elements about a common axis. In an exemplary embodiment, bringing the elements into engagement with the tubular member includes pivoting the elements about corresponding axes; translating the elements; and rotating the elements about a common axis. In an exemplary embodiment, the method further includes preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes sensing the inside diameter of the tubular member.
  • a system for engaging a tubular member includes means for positioning a plurality of elements within the tubular member; and means for bringing the elements into engagement with the tubular member.
  • the elements include a first group of elements; and a second group of elements; wherein the first group of elements are interleaved with the second group of elements.
  • means for bringing the elements into engagement with the tubular member includes means for bringing the elements into axial alignment.
  • means for bringing the elements into engagement with the tubular member further includes means for pivoting the elements.
  • means for bringing the elements into engagement with the tubular member further includes means for translating the elements.
  • means for bringing the elements into engagement with the tubular member further includes means for pivoting the elements; and means for translating the elements.
  • means for bringing the elements into engagement with the tubular member includes means for rotating the elements about a common axis.
  • means for bringing the elements into engagement with the tubular member includes means for pivoting the elements about corresponding axes; means for translating the elements; and means for rotating the elements about a common axis.
  • the system further includes means for preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value.
  • means for preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes means for sensing the inside diameter of the tubular member.
  • a locking device for locking a tubular member to a support member includes a plurality of circumferentially spaced apart locking elements coupled to the support member for engaging an interior surface of the tubular member; a plurality of spring elements coupled to the support member for biasing corresponding locking elements out of engagement with the interior surface of the tubular member; a releasable retaining element releasably coupled to the support member for releasably retaining the locking elements in engagement with the interior surface of the tubular member; an actuator coupled to the support member for controllably displacing the retaining element relative to the locking elements; and a sensor coupled to the support member for sensing an operating condition within the tubular member for controllably displacing the retaining element relative to the locking elements.
  • a method of locking a tubular member to a support member includes engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • a method includes positioning a packer assembly comprising a sealing element within a tubular member; setting the sealing element against an interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
  • setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member.
  • preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member comprises preventing further application of the first force against the sealing element.
  • a method has been described that includes positioning a packer assembly comprising a sealing element within a tubular member; applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
  • the method comprises preventing further application of the first force against the sealing element.
  • the method comprises preventing further application of the first force against the sealing element.
  • preventing further application of the first force against the sealing element prevents the application of an impact load against the interior surface of the tubular member.
  • the method comprises coupling a packer control device to the packer assembly.
  • the tubular member extends within a wellbore; and the method further comprises positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore.
  • the method comprises radially expanding and plastically deforming at least a portion of the tubular member.
  • the method comprises moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member.
  • the packer assembly further comprises at least one other sealing element; and the method further comprises setting the at least one other sealing element against the interior surface of the tubular member.
  • the method comprises decoupling the packer control device from the packer assembly.
  • the method comprises testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • the system comprises means for decoupling the packer control device from the packer assembly. In an exemplary embodiment, the system comprises means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • a method includes coupling a packer control device to a packer assembly comprising a sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; radially expanding and plastically deforming at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • a method includes coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore; radially expanding and plastically deforming at least a portion of the tubular member; moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application
  • a system has been described that includes means for coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; means for positioning the packer control device and the packer outside of the tubular member and in the wellbore; means for radially expanding and plastically deforming at least a portion of the tubular member; means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; means for preventing the application of an impact load against the interior surface of the tub
  • An apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; and a stinger coupled to the second tubular support for releasably engaging the packer assembly.
  • the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support.
  • the apparatus comprises one or more second retaining dogs releasably engaged with the first tubular support.
  • the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support.
  • the apparatus comprises a third tubular support coupled to the second tubular support and the stinger.
  • the apparatus comprises a compressible element at least partially circumferentially extending about the third tubular support.
  • the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed.
  • the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration.
  • the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly.
  • the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration.
  • the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly.
  • the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
  • the compressible element comprises a spring.
  • the apparatus comprises a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support; a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration.
  • the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support.
  • the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support.
  • the apparatus comprises one or more rupture discs coupled to the third tubular support; wherein an exterior surface of the third tubular support and an interior surface of the first tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the annular region.
  • the apparatus comprises the packer assembly.
  • the apparatus comprises a tubular member within which the packer assembly at least partially extends.
  • the packer assembly comprises a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more sealing elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; and one or more second retaining dogs releasably engaged with the first tubular support; wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support.
  • An apparatus for controlling the operation of a packer assembly includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; a second configuration in which the compressible element is at least partially compressed
  • the compressible element comprises a spring.
  • the apparatus comprises a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support; a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration.
  • the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support.
  • the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support.
  • the apparatus comprises one or more rupture discs coupled to the third tubular support; wherein an exterior surface of the third tubular support and the interior surface of the first tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the annular region.
  • the apparatus comprises the packer assembly.
  • the apparatus comprises a tubular member within which the packer assembly at least partially extends.
  • An apparatus for controlling the operation of a packer assembly includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; and a compressible element at least partially circumferentially extending about the first tubular support; wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed.
  • the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly.
  • the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
  • the apparatus comprises one or more first retaining dogs coupled to the third tubular support for releasably engaging the second tubular support.
  • the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support.
  • the apparatus comprises a fourth tubular support coupled to the first tubular support and through which the first tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the first tubular support; a spring mandrel coupled to the third tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration.
  • the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the third tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the first tubular support.
  • the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support.
  • the apparatus comprises one or more rupture discs coupled to the first tubular support; wherein an exterior surface of the first tubular support and an interior surface of the third tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the third tubular support in response to the flow of the fluidic material into the annular region.
  • the apparatus comprises the packer assembly.
  • the apparatus comprises a tubular member within which the packer assembly at least partially extends.
  • An apparatus for controlling the operation of a packer assembly includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element
  • the compressible element comprises a spring.
  • the apparatus comprises a fourth tubular support coupled to the first tubular support and through which the first tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the first tubular support; a spring mandrel coupled to the third tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration.
  • the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support.
  • the packer assembly comprises a support member to which the at least one sealing element is movably coupled, the support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer.
  • the apparatus comprises the packer comprising a second support member defining a passage; a shoe comprising a float valve coupled to an end of the second support member; one or more compressible packer elements movably coupled to the second support member; and a sliding sleeve valve positioned within the passage of the second support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer; and the packer comprising a second support member defining a passage; a shoe comprising a float valve coupled to an end of the second support member; one or more compressible packer elements movably coupled to the second support member; and a sliding sleeve valve positioned within the passage of the second support member; wherein the stinger engages the sliding sleeve valve.
  • teachings of the present illustrative embodiments may be used to provide a wellbore casing, a pipeline, or a structural support.
  • the elements and teachings of the various illustrative embodiments may be combined in whole or in part in some or all of the illustrative embodiments.
  • one or more of the elements and teachings of the various illustrative embodiments may be omitted, at least in part, and/or combined, at least in part, with one or more of the other elements and teachings of the various illustrative embodiments.

Abstract

An apparatus for radially expanding and plastically deforming a tubular member.

Description

    CROSS REFERENCE TO RELATED APPLICATIONS
  • This application claims the benefit of the filing date of U.S. provisional patent application Ser. No. 60/717,391, attorney docket number 25791.214, filed on Sep. 15, 2006, the disclosure of which is incorporated herein by reference.
  • The present application is a continuation-in-part of the following: (1) U.S. National Stage application Ser. No. 10/495,347, attorney docket no. 25791.87.05, filed on May 12, 2004 (now U.S. Publication 2005-0056434), which was filed from PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, (2) U.S. National Stage application Ser. No. 10/495,344, attorney docket no. 25791.88.05, filed on May 12, 2004 (now U.S. Publication 2005-0056433), which was filed from PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, (3) U.S. National Stage application Ser. No. 10/507,567, attorney docket no. 25791.95.03, filed on Sep. 13, 2004 (now U.S. Publication 2005-0103502), which was filed from PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, (4) U.S. National Stage application Ser. No. 10/528,219, attorney docket no. 25791.102.08, filed on Nov. 8, 2005 (now U.S. Publication 2006-0054330), which was filed from PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, (5) U.S. National Stage application Ser. No. 10/513,614, attorney docket no. 25791.104.05, filed on Nov. 5, 2004 (now U.S. Publication 2005-0217866), which was filed from PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, (6) U.S. National Stage application Ser. No. 10/517,755, attorney docket no. 25791.108.05, filed on Dec. 13, 2004, which was filed from PCT patent application serial number PCT/US03/18530, attorney docket number 25791.108.02, filed on Jun. 11, 2003, (7) U.S. National Stage application Ser. No. 10/528,221, attorney docket no. 25791.112.04, filed on Mar. 18, 2005 (now U.S. Publication 2006-0137877), which was filed from PCT patent application serial number PCT/US03/29858, attorney docket number 25791.112.02, (8) U.S. National Stage application Ser. No. 10/528,497, attorney docket no. 25791.114.08, filed on Oct. 28, 2005 (now U.S. Publication 2006-0065403), which was filed from PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep. 23, 2003, filed on Sep. 22, 2003, (9) U.S. National Stage application Ser. No. 10/548,934, attorney docket no. 25791.253.05, filed on Sep. 12, 2005, which was filed from PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, (10) U.S. National Stage application Ser. No. 10/550,906, attorney docket no. 25791.260.06, filed on Sep. 27, 2005 which was filed from PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, (11) U.S. National Stage application Ser. No. 10/551,880, attorney docket no. 25791.270.06, filed on Sep. 30, 2005 which was filed from PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, (12) U.S. National Stage application Ser. No. 10/552,790, attorney docket no. 25791.272.06, filed on Oct. 11, 2005 which was filed from PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, (13) U.S. National Stage application Ser. No. 10/552,253, attorney docket no. 25791.273.06, filed on Oct. 4, 2005 which was filed from PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and (14) U.S. National Stage application Ser. No. 10/553,566, attorney docket no. 25791.277.06, filed on Oct. 17, 2005 which was filed from PCT patent application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • This application is related to the following co-pending applications: (1) U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (2) U.S. patent application Ser. No. 09/510,913, attorney docket no. 25791.7.02, filed on Feb. 23, 2000, which claims priority from provisional application 60/121,702, filed on Feb. 25, 1999, (3) U.S. patent application Ser. No. 09/502,350, attorney docket no. 25791.8.02, filed on Feb. 10, 2000, which claims priority from provisional application 60/119,611, filed on Feb. 11, 1999, (4) U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (5) U.S. patent application Ser. No. 10/169,434, attorney docket no. 25791.10.04, filed on Jul. 1, 2002, which claims priority from provisional application 60/183,546, filed on Feb. 18, 2000, (6) U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (7) U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (8) U.S. Pat. No. 6,575,240, which was filed as patent application Ser. No. 09/511,941, attorney docket no. 25791.16.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,907, filed on Feb. 26, 1999, (9) U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (10) U.S. patent application Ser. No. 09/981,916, attorney docket no. 25791.18, filed on Oct. 18, 2001 as a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (11) U.S. Pat. No. 6,604,763, which was filed as application Ser. No. 09/559,122, attorney docket no. 25791.23.02, filed on Apr. 26, 2000, which claims priority from provisional application 60/131,106, filed on Apr. 26, 1999, (12) U.S. patent application Ser. No. 10/030,593, attorney docket no. 25791.25.08, filed on Jan. 8, 2002, which claims priority from provisional application 60/146,203, filed on Jul. 29, 1999, (13) U.S. provisional patent application Ser. No. 60/143,039, attorney docket no. 25791.26, filed on Jul. 9, 1999, (14) U.S. patent application Ser. No. 10/111,982, attorney docket no. 25791.27.08, filed on Apr. 30, 2002, which claims priority from provisional patent application Ser. No. 60/162,671, attorney docket no. 25791.27, filed on Nov. 1, 1999, (15) U.S. provisional patent application Ser. No. 60/154,047, attorney docket no. 25791.29, filed on Sep. 16, 1999, (16) U.S. provisional patent application Ser. No. 60/438,828, attorney docket no. 25791.31, filed on Jan. 9, 2003, (17) U.S. Pat. No. 6,564,875, which was filed as application Ser. No. 09/679,907, attorney docket no. 25791.34.02, on Oct. 5, 2000, which claims priority from provisional patent application Ser. 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No. 60/455,051, attorney docket no. 25791.40, filed on Mar. 14, 2003, (23) PCT application US02/2477, filed on Jun. 26, 2002, attorney docket no. 25791.44.02, which claims priority from U.S. provisional patent application Ser. No. 60/303,711, attorney docket no. 25791.44, filed on Jul. 6, 2001, (24) U.S. patent application Ser. No. 10/311,412, filed on Dec. 12, 2002, attorney docket no. 25791.45.07, which claims priority from provisional patent application Ser. No. 60/221,443, attorney docket no. 25791.45, filed on Jul. 28, 2000, (25) U.S. patent application Ser. No. 10/______, filed on Dec. 18, 2002, attorney docket no. 25791.46.07, which claims priority from provisional patent application Ser. No. 60/221,645, attorney docket no. 25791.46, filed on Jul. 28, 2000, (26) U.S. patent application Ser. No. 10/322,947, filed on Jan. 22, 2003, attorney docket no. 25791.47.03, which claims priority from provisional patent application Ser. No. 60/233,638, attorney docket no. 25791.47, filed on Sep. 18, 2000, (27) U.S. patent application Ser. No. 10/406,648, filed on Mar. 31, 2003, attorney docket no. 25791.48.06, which claims priority from provisional patent application Ser. No. 60/237,334, attorney docket no. 25791.48, filed on Oct. 2, 2000, (28) PCT application US02/04353, filed on Feb. 14, 2002, attorney docket no. 25791.50.02, which claims priority from U.S. provisional patent application Ser. No. 60/270,007, attorney docket no. 25791.50, filed on Feb. 20, 2001, (29) U.S. patent application Ser. No. 10/465,835, filed on Jun. 13, 2003, attorney docket no. 25791.51.06, which claims priority from provisional patent application Ser. No. 60/262,434, attorney docket no. 25791.51, filed on Jan. 17, 2001, (30) U.S. patent application Ser. No. 10/465,831, filed on Jun. 13, 2003, attorney docket no. 25791.52.06, which claims priority from U.S. provisional patent application Ser. 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    • BACKGROUND OF THE INVENTION
  • This invention relates generally to oil and gas exploration, and in particular to forming and repairing wellbore casings to facilitate oil and gas exploration.
    • SUMMARY OF THE INVENTION
  • According to one aspect of the present invention, an apparatus for radially expanding and plastically deforming an expandable tubular member is provided that includes a support member, a cutting device for cutting the tubular member coupled to the support member, and an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member.
  • According to another aspect of the present invention, an apparatus for radially expanding and plastically deforming an expandable tubular member is provided that includes a support member, an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member, and an actuator coupled to the support member for displacing the expansion device relative to the support member.
  • According to another aspect of the present invention, an apparatus for radially expanding and plastically deforming an expandable tubular member is provided that includes a support member; an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a sealing assembly for sealing an annulus defined between the support member and the tubular member.
  • According to another aspect of the present invention, an apparatus for radially expanding and plastically deforming an expandable tubular member is provided that includes a support member; a first expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a second expansion device for radially expanding and plastically deforming the tubular member coupled to the support member.
  • According to another aspect of the present invention, an apparatus for radially expanding and plastically deforming an expandable tubular member is provided that includes a support member; an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a packer coupled to the support member.
  • According to another aspect of the present invention, an apparatus for radially expanding and plastically deforming an expandable tubular member is provided that includes a support member; a cutting device for cutting the tubular member coupled to the support member; a gripping device for gripping the tubular member coupled to the support member; a sealing device for sealing an interface with the tubular member coupled to the support member; a locking device for locking the position of the tubular member relative to the support member; a first adjustable expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; a second adjustable expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; a packer coupled to the support member; and an actuator for displacing one or more of the sealing assembly, first and second adjustable expansion devices, and packer relative to the support member.
  • According to another aspect of the present invention, an apparatus for cutting a tubular member is provided that includes a support member; and a plurality of movable cutting elements coupled to the support member.
  • According to another aspect of the present invention, an apparatus for engaging a tubular member is provided that includes a support member; and a plurality of movable elements coupled to the support member.
  • According to another aspect of the present invention, an apparatus for gripping a tubular member is provided that includes a plurality of movable gripping elements.
  • According to another aspect of the present invention, an actuator is provided that includes a tubular housing; a tubular piston rod movably coupled to and at least partially positioned within the housing; a plurality of annular piston chambers defined by the tubular housing and the tubular piston rod; and a plurality of tubular pistons coupled to the tubular piston rod, each tubular piston movably positioned within a corresponding annular piston chamber.
  • According to another aspect of the present invention, an apparatus for controlling a packer is provided that includes a tubular support member; one or more drag blocks releasably coupled to the tubular support member; and a tubular stinger coupled to the tubular support member for engaging the packer.
  • According to another aspect of the present invention, a packer is provided that includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • According to another aspect of the present invention, a method of radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing is provided that includes positioning the tubular member within the borehole in overlapping relation to the wellbore casing; radially expanding and plastically deforming a portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section.
  • According to another aspect of the present invention, a method for forming a mono diameter wellbore casing is provided that includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; positioning the adjustable expansion device within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole.
  • According to another aspect of the present invention, a method for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes positioning an adjustable expansion device within the expandable tubular member; supporting the expandable tubular member and the adjustable expansion device within the borehole; lowering the adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • According to another aspect of the present invention, a method for forming a mono diameter wellbore casing is provided that includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; positioning the adjustable expansion mandrel within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion mandrel out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion mandrel; displacing the adjustable expansion mandrel upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole; and pressurizing an interior region of the second expandable tubular member above the adjustable expansion mandrel during the radial expansion and plastic deformation of the second expandable tubular member within the borehole.
  • According to another aspect of the present invention, a method for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a method for forming a mono diameter wellbore casing is provided that includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; positioning first and second adjustable expansion devices within a second expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; lowering the first adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; and displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a method for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; and pressurizing an interior region of the expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the expandable tubular member above the lower portion of the expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a method for forming a mono diameter wellbore casing is provided that includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; pressurizing an interior region of the first expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the first expandable tubular member above the lower portion of the first expandable tubular member by the second adjustable expansion device; positioning first and second adjustable expansion devices within a second expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; lowering the first adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; pressurizing an interior region of the second expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the second expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; and pressurizing an interior region of the second expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the second expandable tubular member above the lower portion of the second expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a method for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member.
  • According to another aspect of the present invention, a method for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing is provided that includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member.
  • According to another aspect of the present invention, a method of radially expanding and plastically deforming a tubular member is provided that includes positioning the tubular member within a preexisting structure; radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section.
  • According to another aspect of the present invention, a method of radially expanding and plastically deforming a tubular member is provided that includes applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another.
  • According to another aspect of the present invention, a system for radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing is provided that includes means for positioning the tubular member within the borehole in overlapping relation to the wellbore casing; means for radially expanding and plastically deforming a portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section.
  • According to another aspect of the present invention, a system for forming a mono diameter wellbore casing is provided that includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for positioning the adjustable expansion device within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole.
  • According to another aspect of the present invention, a system for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes means for positioning an adjustable expansion device within the expandable tubular member; means for supporting the expandable tubular member and the adjustable expansion device within the borehole; means for lowering the adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and means for pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • According to another aspect of the present invention, a system for forming a mono diameter wellbore casing is provided that includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; means for positioning the adjustable expansion mandrel within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion mandrel out of the second expandable tubular member; means for increasing the outside dimension of the adjustable expansion mandrel; means for displacing the adjustable expansion mandrel upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole; and means for pressurizing an interior region of the second expandable tubular member above the adjustable expansion mandrel during the radial expansion and plastic deformation of the second expandable tubular member within the borehole.
  • According to another aspect of the present invention, a system for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a system for forming a mono diameter wellbore casing is provided that includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; means for positioning first and second adjustable expansion devices within a second expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; means for lowering the first adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; and means for displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a system for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; and means for pressurizing an interior region of the expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the expandable tubular member above the lower portion of the expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a system for forming a mono diameter wellbore casing is provided that includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; means for pressurizing an interior region of the first expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the first expandable tubular member above the lower portion of the first expandable tubular member by the second adjustable expansion device; means for positioning first and second adjustable expansion devices within a second expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; means for lowering the first adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; means for pressurizing an interior region of the second expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the second expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; and means for pressurizing an interior region of the second expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the second expandable tubular member above the lower portion of the second expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • According to another aspect of the present invention, a system for radially expanding and plastically deforming an expandable tubular member within a borehole is provided that includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member.
  • According to another aspect of the present invention, a system for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing is provided that includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member.
  • According to another aspect of the present invention, a system for radially expanding and plastically deforming a tubular member is provided that includes means for positioning the tubular member within a preexisting structure; means for radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section.
  • According to another aspect of the present invention, a system of radially expanding and plastically deforming a tubular member is provided that includes a support member; and means for applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another coupled to the support member.
  • According to another aspect of the present invention, a method of cutting a tubular member is provided that includes positioning a plurality of cutting elements within the tubular member; and bringing the cutting elements into engagement with the tubular member.
  • According to another aspect of the present invention, a method of gripping a tubular member is provided that includes positioning a plurality of gripping elements within the tubular member; bringing the gripping elements into engagement with the tubular member. In an exemplary embodiment, bringing the gripping elements into engagement with the tubular member includes displacing the gripping elements in an axial direction; and displacing the gripping elements in a radial direction.
  • According to another aspect of the present invention, a method of operating an actuator is provided that includes pressurizing a plurality of pressure chamber.
  • According to another aspect of the present invention, a method of injecting a hardenable fluidic sealing material into an annulus between a tubular member and a preexisting structure is provided that includes positioning the tubular member into the preexisting structure; sealing off an end of the tubular member; operating a valve within the end of the tubular member; and injecting a hardenable fluidic sealing material through the valve into the annulus between the tubular member and the preexisting structure.
  • According to another aspect of the present invention, a system for cutting a tubular member is provided that includes means for positioning a plurality of cutting elements within the tubular member; and means for bringing the cutting elements into engagement with the tubular member.
  • According to another aspect of the present invention, a system for gripping a tubular member is provided that includes means for positioning a plurality of gripping elements within the tubular member; and means for bringing the gripping elements into engagement with the tubular member.
  • According to another aspect of the present invention, an actuator system is provided that includes a support member; and means for pressurizing a plurality of pressure chambers coupled to the support member. In an exemplary embodiment, the system further includes means for transmitting torsional loads.
  • According to another aspect of the present invention, a system for injecting a hardenable fluidic sealing material into an annulus between a tubular member and a preexisting structure is provided that includes means for positioning the tubular member into the preexisting structure; means for sealing off an end of the tubular member; means for operating a valve within the end of the tubular member; and means for injecting a hardenable fluidic sealing material through the valve into the annulus between the tubular member and the preexisting structure.
  • According to another aspect of the present invention, a method of engaging a tubular member is provided that includes positioning a plurality of elements within the tubular member; and bringing the elements into engagement with the tubular member.
  • According to another aspect of the present invention, a system for engaging a tubular member is provided that includes means for positioning a plurality of elements within the tubular member; and means for bringing the elements into engagement with the tubular member. In an exemplary embodiment, the elements include a first group of elements; and a second group of elements; wherein the first group of elements are interleaved with the second group of elements.
  • According to another aspect of the present invention, a locking device for locking a tubular member to a support member is provided that includes a plurality of circumferentially spaced apart locking elements coupled to the support member for engaging an interior surface of the tubular member; a plurality of spring elements coupled to the support member for biasing corresponding locking elements out of engagement with the interior surface of the tubular member; a releasable retaining element releasably coupled to the support member for releasably retaining the locking elements in engagement with the interior surface of the tubular member; an actuator coupled to the support member for controllably displacing the retaining element relative to the locking elements; and a sensor coupled to the support member for sensing an operating condition within the tubular member for controllably displacing the retaining element relative to the locking elements.
  • According to another aspect of the present invention, a method of locking a tubular member to a support member is provided that includes engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • According to another aspect of the present invention, a system for locking a tubular member to a support member is provided that includes means for engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and means for disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • According to another aspect of the present invention, a method is provided that includes positioning a packer assembly comprising a sealing element within a tubular member; setting the sealing element against an interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
  • According to another aspect of the present invention, a system is provided that includes means for positioning a packer assembly comprising a sealing element within a tubular member; means for setting the sealing element against an interior surface of the tubular member; and means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
  • According to another aspect of the present invention, a method is provided that includes positioning a packer assembly comprising a sealing element within a tubular member; applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
  • According to another aspect of the present invention, a system is provided that includes means for positioning a packer assembly comprising a sealing element within a tubular member; means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
  • According to another aspect of the present invention, a method is provided that includes coupling a packer control device to a packer assembly comprising a sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; radially expanding and plastically deforming at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • According to another aspect of the present invention, a system is provided that includes means for coupling a packer control device to a packer assembly comprising a sealing element; means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; means for radially expanding and plastically deforming at least a portion of the tubular member; means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • According to another aspect of the present invention, a method is provided that includes coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore; radially expanding and plastically deforming at least a portion of the tubular member; moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element; setting the at least one other sealing element against the interior surface of the tubular member; decoupling the packer control device from the packer assembly; and testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • According to another aspect of the present invention, a system is provided that includes means for coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; means for positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore; means for radially expanding and plastically deforming at least a portion of the tubular member; means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element; means for setting the at least one other sealing element against the interior surface of the tubular member; means for decoupling the packer control device from the packer assembly; and means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; and a stinger coupled to the second tubular support for releasably engaging the packer assembly.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; and one or more second retaining dogs releasably engaged with the first tubular support; wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; a second configuration in which the compressible element is at least partially compressed; wherein, when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration; wherein, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; and wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; wherein, when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration; wherein, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; and wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element; wherein the compressible element comprises a spring; wherein the apparatus further comprises a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support; a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining a first annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the first annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration; wherein the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and wherein movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support; wherein the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; wherein the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support; one or more rupture discs coupled to the third tubular support; and the packer assembly; wherein an exterior surface of the third tubular support and the interior surface of the first tubular support define a second annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the second annular region; wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the second annular region; and wherein the packer assembly comprises a support member to which the at least one sealing element is movably coupled, the support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; and a compressible element at least partially circumferentially extending about the first tubular support; wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
  • According to another aspect of the present invention, an apparatus for controlling the operation of a packer assembly is provided that includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element; and wherein the apparatus further comprises one or more first retaining dogs coupled to the third tubular support for releasably engaging the second tubular support; and one or more second retaining dogs releasably engaged with the third tubular support; wherein the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the third tubular support.
  • According to another aspect of the present invention, an apparatus is provided that includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer.
  • According to another aspect of the present invention, an apparatus is provided that includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer; and the packer comprising a second support member defining a passage; a shoe comprising a float valve coupled to an end of the second support member; one or more compressible packer elements movably coupled to the second support member; and a sliding sleeve valve positioned within the passage of the second support member; wherein the stinger engages the sliding sleeve valve.
    • BRIEF DESCRIPTION OF THE DRAWINGS
  • FIG. 1 is a fragmentary cross-sectional illustration of an embodiment of a system for radially expanding and plastically deforming wellbore casing, including a tubular support member, a casing cutter, a ball gripper for gripping a wellbore casing, a force multiplier tension actuator, a safety sub, a cup sub, a casing lock, an extension actuator, a bell section adjustable expansion cone assembly, a casing section adjustable expansion cone assembly, a packer setting tool, a packer, a stinger, and an expandable wellbore casing, during the placement of the system within a wellbore.
  • FIG. 2 is a fragmentary cross-sectional illustration of the system of FIG. 1 during the subsequent displacement of the bell section adjustable expansion cone assembly, the casing section adjustable expansion cone assembly, the packer setting tool, the packer, and the stinger downwardly out of the end of the expandable wellbore casing and the expansion of the size of the bell section adjustable expansion cone assembly and the casing section adjustable expansion cone assembly.
  • FIG. 3 is a fragmentary cross-sectional illustration of the system of FIG. 2 during the subsequent operation of the tension actuator to displace the bell section adjustable expansion cone assembly upwardly into the end of the expandable wellbore casing to form a bell section in the end of the expandable wellbore casing.
  • FIG. 4 is a fragmentary cross-sectional illustration of the system of FIG. 3 during the subsequent reduction of the bell section adjustable expansion cone assembly.
  • FIG. 5 is a fragmentary cross-sectional illustration of the system of FIG. 4 during the subsequent upward displacement of the expanded casing section adjustable expansion cone assembly to radially expand the expandable wellbore casing.
  • FIG. 6 is a fragmentary cross-sectional illustration of the system of FIG. 5 during the subsequent lowering of the tubular support member, casing cutter, ball gripper, a force multiplier tension actuator, safety sub, cup sub, casing lock, extension actuator, bell section adjustable expansion cone assembly, casing section adjustable expansion cone assembly, packer setting tool, packer, and stinger and subsequent setting of the packer within the expandable wellbore casing above the bell section.
  • FIG. 7 is a fragmentary cross-sectional illustration of the system of FIG. 6 during the subsequent injection of fluidic materials into the system to displace the expanded casing section adjustable expansion cone assembly upwardly through the expandable wellbore casing to radially expand and plastically deform the expandable wellbore casing.
  • FIG. 8 is a fragmentary cross-sectional illustration of the system of FIG. 7 during the subsequent injection of fluidic materials into the system to displace the expanded casing section adjustable expansion cone assembly upwardly through the expandable wellbore casing and a surrounding preexisting wellbore casing to radially expand and plastically deform the overlapping expandable wellbore casing and the surrounding preexisting wellbore casing.
  • FIG. 9 is a fragmentary cross-sectional illustration of the system of FIG. 8 during the subsequent operation of the casing cutter to cut off an end of the expandable wellbore casing.
  • FIG. 10 is a fragmentary cross-sectional illustration of the system of FIG. 9 during the subsequent removal of the cut off end of the expandable wellbore casing.
  • FIGS. 11-1 and 11-2, 11A1 to 11A2, 11B1 to 11B2, 11C, 11D, 11E, 11F, 11G, 11H, 11I, 11 j, 11K, 11L, 11M, 11N, 11O, 11P, 11Q, 11R, 11S, 11T, 11U, 11V, 11W, 11 x, 11Y, 11Z1 to 11Z4, 11AA1 to 11AA4, 11AB1 to 11AB4, 11AC1 to 11AC4, 11AD, and 11AE are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of a casing cutter assembly.
  • FIGS. 12A1 to 12A4 and 12C1 to 12C4 are fragmentary cross-sectional illustrations of an exemplary embodiment of a ball gripper assembly.
  • FIG. 12B is a top view of a portion of the ball gripper assembly of FIGS. 12A1 to 12A4 and 12C1 to 12C4.
  • FIGS. 13A1 to 13A8 and 13B1 to 13B7 are fragmentary cross-sectional illustrations of an exemplary embodiment of a tension actuator assembly.
  • FIG. 14A is a fragmentary cross-sectional illustrations of an exemplary embodiment of a safety sub assembly.
  • FIGS. 14A, 14B and 14C are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of a cup seal assembly.
  • FIGS. 15-1, 15-2, 15A1, 15A2, 15B1, 15B2, 15C1, 15C2, 15D, 15E1 to 15E5, 15F1 to 15F5, and 15G1 to 15G5 are fragmentary cross sectional illustrations of an exemplary embodiment of an extension actuator and casing lock assembly.
  • FIGS. 16-1 and 16-2, 16A1 to 16A2, 16B1 to 16B2, 16C, 16D, 16E, 16F, 16G, 16H, 161, 16 j, 16K, 16L, 16M, 16N, 16O, 16P, 16R, 16S, 16T, 16U, 16V, 16W, 16X, 16Y, 16Z1 to 16Z4, 16AA1 to 16AA4, 16AB1 to 16AB4, 16AC1 to 16AC4, 16AD, and 16AE are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of an adjustable bell section expansion cone assembly.
  • FIGS. 17-1 and 17-2, 17A1 to 17A2, 17B1 to 17B2, 17C, 17D, 17E, 17F, 17G, 17H, 171, 17 j, 17K, 17L, 17M, 17N, 170, 17P, 17R, 17S, 17T, 17U, 17V, 17W, 17 x, 17Y, 17Z1-17Z4, 17AA1 to 17AA4, 17AB1 to 17AB4, 17AC1 to 17AC4, 17AD, and 17AE are fragmentary cross-sectional and perspective illustrations of an exemplary embodiment of an adjustable casing expansion cone assembly.
  • FIGS. 18A to 18C is a fragmentary cross-sectional illustration of an exemplary embodiment of a packer setting tool assembly.
  • FIGS. 19-1 to 19-5 is a fragmentary cross-sectional illustration of an exemplary embodiment of a packer assembly.
  • FIGS. 20A1 to 20A5, 20B1 to 20B5, 20C1 to 20C5, 20D1 to 20D5, 20E1 to 20E6, 20F1 to 20F6, 20G1 to 20G6, and 20H1 to 20H5, are fragmentary cross-sectional illustrations of an exemplary embodiment of the operation of the packer setting tool assembly of FIGS. 18A to 18C and the packer assembly of FIGS. 19-1 to 19-5.
  • FIGS. 21 and 21A to 21AX are fragmentary perspective and cross-sectional illustrations of an alternative embodiment of the packer assembly.
  • FIGS. 22A to 22D is a fragmentary cross-sectional illustration of another exemplary embodiment of a packer setting tool assembly.
  • FIGS. 23A to 23E, 24A to 24E, 25A to 25E, 26A to 26E, 27A to 27E, 28A to 28E, 29A to 29E, 30A to 30E, 31A to 31E, 32A to 32E and 33A to 33E, are fragmentary cross-sectional illustrations of an exemplary embodiment of the operation of the packer setting tool assembly of FIGS. 22A to 22D and the packer assembly of FIGS. 19-1 to 19-5.
    • DETAILED DESCRIPTION OF THE ILLUSTRATIVE EMBODIMENTS
  • Referring initially to FIGS. 1-10, an exemplary embodiment of a system 10 for radially expanding and plastically deforming a wellbore casing includes a conventional tubular support 12 having an end that is coupled to an end of a casing cutter assembly 14. In an exemplary embodiment, the casing cutter assembly 14 may be, or may include elements, of one or more conventional commercially available casing cutters for cutting wellbore casing, or equivalents thereof.
  • An end of a ball gripper assembly 16 is coupled to another end of the casing cutter assembly 14. In an exemplary embodiment, the ball gripper assembly 14 may be, or may include elements, of one or more conventional commercially available ball grippers, or other types of gripping devices, for gripping wellbore casing, or equivalents thereof.
  • An end of a tension actuator assembly 18 is coupled to another end of the ball gripper assembly 16. In an exemplary embodiment, the tension actuator assembly 18 may be, or may include elements, of one or more conventional commercially actuators, or equivalents thereof.
  • An end of a safety sub assembly 20 is coupled to another end of the tension actuator assembly 18. In an exemplary embodiment, the safety sub assembly 20 may be, or may include elements, of one or more conventional apparatus that provide quick connection and/or disconnection of tubular members, or equivalents thereof.
  • An end of a sealing cup assembly 22 is coupled to another end of the safety sub assembly 20. In an exemplary embodiment, the sealing cup assembly 22 may be, or may include elements, of one or more conventional sealing cup assemblies, or other types of sealing assemblies, that sealingly engage the interior surfaces of surrounding tubular members, or equivalents thereof.
  • An end of a casing lock assembly 24 is coupled to another end of the sealing cup assembly 22. In an exemplary embodiment, the casing lock assembly 24 may be, or may include elements, of one or more conventional casing lock assemblies that lock the position of wellbore casing, or equivalents thereof.
  • An end of an extension actuator assembly 26 is coupled to another end of the casing lock assembly 24. In an exemplary embodiment, the extension actuator assembly 26 may be, or may include elements, of one or more conventional actuators, or equivalents thereof.
  • An end of an adjustable bell section expansion cone assembly 28 is coupled to another end of the extension actuator assembly 26. In an exemplary embodiment, the adjustable bell section expansion cone assembly 28 may be, or may include elements, of one or more conventional adjustable expansion devices for radially expanding and plastically deforming wellbore casing, or equivalents thereof.
  • An end of an adjustable casing expansion cone assembly 30 is coupled to another end of the adjustable bell section expansion cone assembly 28. In an exemplary embodiment, the adjustable casing expansion cone assembly 30 may be, or may include elements, of one or more conventional adjustable expansion devices for radially expanding and plastically deforming wellbore casing, or equivalents thereof.
  • An end of a packer setting tool assembly 32 is coupled to another end of the adjustable casing expansion cone assembly 30. In an exemplary embodiment, the packer setting tool assembly 32 may be, or may include elements, of one or more conventional adjustable expansion devices for controlling the operation of a conventional packer, or equivalents thereof.
  • An end of a stinger assembly 34 is coupled to another end of the packer setting tool assembly 32. In an exemplary embodiment, the stinger assembly 34 may be, or may include elements, of one or more conventional devices for engaging a conventional packer, or equivalents thereof.
  • An end of a packer control device or packer assembly 36 is coupled to another end of the stinger assembly 34. In an exemplary embodiment, the packer assembly 36 may be, or may include elements, of one or more conventional packers.
  • In an exemplary embodiment, one or more of the elements of the system 10 may be omitted, at least in part, and/or combined, at least in part, with one or more of the other elements of the system.
  • As illustrated in FIG. 1, in an exemplary embodiment, during operation of the system 10, an expandable wellbore casing 100 is coupled to and supported by the casing lock assembly 24 of the system. The system 10 is then positioned within a wellbore 102 that traverses a subterranean formation 104 and includes a preexisting wellbore casing 106.
  • As illustrated in FIG. 2, in an exemplary embodiment, the extension actuator assembly 26 is then operated to move the adjustable bell section expansion cone assembly 28, adjustable casing expansion cone assembly 30, packer setting tool assembly 32, stinger assembly 34, packer assembly 36 downwardly in a direction 108 and out of an end of the expandable wellbore casing 100. After the adjustable bell section expansion cone assembly 28 and adjustable casing expansion cone assembly 30 have been moved to a position out of the end of the expandable wellbore casing 100, the adjustable bell section expansion cone assembly and adjustable casing expansion cone assembly are then operated to increase the outside diameters of the expansion cone assemblies. In an exemplary embodiment, the increased outside diameter of the adjustable bell section expansion cone assembly 28 is greater than the increased outside diameter of the adjustable casing expansion cone assembly 30.
  • As illustrated in FIG. 3, in an exemplary embodiment, the ball gripper assembly 16 is then operated to engage and hold the position of the expandable tubular member 100 stationary relative to the tubular support member 12. The tension actuator assembly 18 is then operated to move the adjustable bell section expansion cone assembly 28, adjustable casing expansion cone assembly 30, packer setting tool assembly 32, stinger assembly 34, packer assembly 36 upwardly in a direction 110 into and through the end of the expandable wellbore casing 100. As a result, the end of the expandable wellbore casing 100 is radially expanded and plastically deformed by the adjustable bell section expansion cone assembly 28 to form a bell section 112. In an exemplary embodiment, during the operation of the system 10 described above with reference to FIG. 3, the casing lock assembly 24 may or may not be coupled to the expandable wellbore casing 100.
  • In an exemplary embodiment, the length of the end of the expandable wellbore casing 100 that is radially expanded and plastically deformed by the adjustable bell section expansion cone assembly 28 is limited by the stroke length of the tension actuator assembly 18. In an exemplary embodiment, once the tension actuator assembly 18 completes a stroke, the ball gripper assembly 16 is operated to release the expandable tubular member 100, and the tubular support 12 is moved upwardly to permit the tension actuator assembly to be re-set. In this manner, the length of the bell section 112 can be further extended by continuing to stroke and then re-set the position of the tension actuator assembly 18. Note, that, during the upward movement of the tubular support 12 to re-set the position of the tension actuator assembly 18, the expandable tubular wellbore casing 100 is supported by the expansion surfaces of the adjustable bell section expansion cone assembly 28.
  • As illustrated in FIG. 4, in an exemplary embodiment, the casing lock assembly 24 is then operated to engage and maintain the position of the expandable wellbore casing 100 stationary relative to the tubular support 12. The adjustable bell section expansion cone assembly 28, adjustable casing expansion cone assembly 30, packer setting tool assembly 32, stinger assembly 34, and packer assembly 36 are displaced downwardly into the bell section 112 in a direction 114 relative to the expandable wellbore casing 100 by operating the extension actuator 26 and/or by displacing the system 10 downwardly in the direction 114 relative to the expandable wellbore casing. After the adjustable bell section expansion cone assembly 28 and adjustable casing expansion cone assembly 30 have been moved downwardly in the direction 114 into the bell section 112 of the expandable wellbore casing 100, the adjustable bell section expansion cone assembly is then operated to decrease the outside diameter of the adjustable bell section expansion cone assembly. In an exemplary embodiment, the decreased outside diameter of the adjustable bell section expansion cone assembly 28 is less than the increased outside diameter of the adjustable casing expansion cone assembly 30. In an exemplary embodiment, during the operation of the system illustrated and described above with reference to FIG. 4, the ball gripper 16 may or may not be operated to engage the expandable wellbore casing 100.
  • As illustrated in FIG. 5, in an exemplary embodiment, the casing lock assembly 24 is then disengaged from the expandable wellbore casing 100 and fluidic material 116 is then injected into the system 10 through the tubular support 12 to thereby pressurize an annulus 118 defined within the expandable wellbore casing below the cup sub assembly 22. As a result, a pressure differential is created across the cup seal assembly 22 that causes the cup seal assembly to apply a tensile force in the direction 120 to the system 10. As a result, the system 10 is displaced upwardly in the direction 120 relative to the expandable wellbore casing 100 thereby pulling the adjustable casing expansion cone assembly 30 upwardly in the direction 120 through the expandable wellbore casing thereby radially expanding and plastically deforming the expandable wellbore casing.
  • In an exemplary embodiment, the tension actuator assembly 16 may also be operated during the injection of the fluidic material 116 to displace the adjustable casing expansion cone assembly 30 upwardly relative to the tubular support 12. As a result, additional expansion forces may be applied to the expandable wellbore casing 100.
  • As illustrated in FIG. 6, in an exemplary embodiment, the radial expansion and plastic deformation of the expandable wellbore casing using the adjustable casing expansion cone assembly 30 continues until the packer assembly 36 is positioned within a portion of the expandable tubular member above the bell section 112. The packer assembly 36 may then be operated to engage the interior surface of the expandable wellbore casing 100 above the bell section 112.
  • In an exemplary embodiment, after the packer assembly 36 is operated to engage the interior surface of the expandable wellbore casing 100 above the bell section 112, a hardenable fluidic sealing material 122 may then be injected into the system 10 through the tubular support 12 and then out of the system through the packer assembly to thereby permit the annulus between the expandable wellbore casing and the wellbore 102 to be filled with the hardenable fluidic sealing material. The hardenable fluidic sealing material 122 may then be allowed to cure to form a fluid tight annulus between the expandable wellbore casing 100 and the wellbore 102, before, during, or after the completion of the radial expansion and plastic deformation of the expandable wellbore casing.
  • As illustrated in FIG. 7, in an exemplary embodiment, the fluidic material 116 is then re-injected into the system 10 through the tubular support 12 to thereby re-pressurize the annulus 118 defined within the expandable wellbore casing below the cup sub assembly 22. As a result, a pressure differential is once again created across the cup seal assembly 22 that causes the cup seal assembly to once again apply a tensile force in the direction 120 to the system 10. As a result, the system 10 is displaced upwardly in the direction 120 relative to the expandable wellbore casing 100 thereby pulling the adjustable casing expansion cone assembly 30 upwardly in the direction 120 through the expandable wellbore casing thereby radially expanding and plastically deforming the expandable wellbore casing and disengaging the stinger assembly 34 from the packer assembly 36. In an exemplary embodiment, during this operational mode, the packer assembly 36 prevents the flow of fluidic materials out of the expandable wellbore casing 100. As a result, the pressurization of the annulus 118 is rapid and efficient thereby enhancing the operational efficiency of the subsequent radial expansion and plastic deformation of the expandable wellbore casing 100.
  • In an exemplary embodiment, the tension actuator assembly 16 may also be operated during the re-injection of the fluidic material 116 to displace the adjustable casing expansion cone assembly 30 upwardly relative to the tubular support 12. As a result, additional expansion forces may be applied to the expandable wellbore casing 100.
  • As illustrated in FIG. 8, in an exemplary embodiment, the radial expansion and plastic deformation of the expandable wellbore casing using the adjustable casing expansion cone assembly 30 continues until the adjustable casing expansion cone assembly 30 reaches the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106. At which point, the system 10 may radially expand the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 and the surrounding portion of the preexisting wellbore casing. Consequently, in an exemplary embodiment, during the radial expansion of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106, the tension actuator assembly 16 is also operated to displace the adjustable casing expansion cone assembly 30 upwardly relative to the tubular support 12. As a result, additional expansion forces may be applied to the expandable wellbore casing 100 and the preexisting wellbore casing 106 during the radial expansion of the portion 124 of the expandable wellbore casing that overlaps with the preexisting wellbore casing.
  • As illustrated in FIG. 9, in an exemplary embodiment, the entire length of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 is not radially expanded and plastically deformed. Rather, only part of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 is radially expanded and plastically deformed. The remaining part of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 is then cut away by operating the casing cutter assembly 14.
  • As illustrated in FIG. 10, the remaining part of the portion 124 of the expandable wellbore casing 100 that overlaps with the preexisting wellbore casing 106 that is cut away by operating the casing cutter assembly 14 is then also carried out of the wellbore 102 using the casing cutter assembly.
  • Furthermore, in an exemplary embodiment, the inside diameter of the expandable wellbore casing 100 above the bell section 112 is equal to the inside diameter of the portion of the preexisting wellbore casing 106 that does not overlap with the expandable wellbore casing 100. As a result, a wellbore casing is constructed that includes overlapping wellbore casings that together define an internal passage having a constant cross-sectional area.
  • In an exemplary embodiment, one or more of the operational elements of the system 10 may be omitted, at least in part, and/or combined, at least in part, with one or more of the other operational elements of the system.
  • In several exemplary embodiments, the system 10 includes one or more of the methods and apparatus disclosed in one or more of the following: (1) U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (2) U.S. patent application Ser. No. 09/510,913, attorney docket no. 25791.7.02, filed on Feb. 23, 2000, which claims priority from provisional application 60/121,702, filed on Feb. 25, 1999, (3) U.S. patent application Ser. No. 09/502,350, attorney docket no. 25791.8.02, filed on Feb. 10, 2000, which claims priority from provisional application 60/119,611, filed on Feb. 11, 1999, (4) U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (5) U.S. patent application Ser. No. 10/169,434, attorney docket no. 25791.10.04, filed on Jul. 1, 2002, which claims priority from provisional application 60/183,546, filed on Feb. 18, 2000, (6) U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (7) U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (8) U.S. Pat. No. 6,575,240, which was filed as patent application Ser. No. 09/511,941, attorney docket no. 25791.16.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,907, filed on Feb. 26, 1999, (9) U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (10) U.S. patent application Ser. No. 09/981,916, attorney docket no. 25791.18, filed on Oct. 18, 2001 as a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (11) U.S. Pat. No. 6,604,763, which was filed as application Ser. No. 09/559,122, attorney docket no. 25791.23.02, filed on Apr. 26, 2000, which claims priority from provisional application 60/131,106, filed on Apr. 26, 1999, (12) U.S. patent application Ser. No. 10/030,593, attorney docket no. 25791.25.08, filed on Jan. 8, 2002, which claims priority from provisional application 60/146,203, filed on Jul. 29, 1999, (13) U.S. provisional patent application Ser. No. 60/143,039, attorney docket no. 25791.26, filed on Jul. 9, 1999, (14) U.S. patent application Ser. No. 10/111,982, attorney docket no. 25791.27.08, filed on Apr. 30, 2002, which claims priority from provisional patent application serial no. 60/162,671, attorney docket no. 25791.27, filed on Nov. 1, 1999, (15) U.S. provisional patent application Ser. No. 60/154,047, attorney docket no. 25791.29, filed on Sep. 16, 1999, (16) U.S. provisional patent application Ser. No. 60/438,828, attorney docket no. 25791.31, filed on Jan. 9, 2003, (17) U.S. Pat. No. 6,564,875, which was filed as application Ser. No. 09/679,907, attorney docket no. 25791.34.02, on Oct. 5, 2000, which claims priority from provisional patent application Ser. No. 60/159,082, attorney docket no. 25791.34, filed on Oct. 12, 1999, (18) U.S. patent application Ser. No. 10/089,419, filed on Mar. 27, 2002, attorney docket no. 25791.36.03, which claims priority from provisional patent application Ser. No. 60/159,039, attorney docket no. 25791.36, filed on Oct. 12, 1999, (19) U.S. patent application Ser. No. 09/679,906, filed on Oct. 5, 2000, attorney docket no. 25791.37.02, which claims priority from provisional patent application Ser. No. 60/159,033, attorney docket no. 25791.37, filed on Oct. 12, 1999, (20) U.S. patent application Ser. No. 10/303,992, filed on Nov. 22, 2002, attorney docket no. 25791.38.07, which claims priority from provisional patent application Ser. No. 60/212,359, attorney docket no. 25791.38, filed on Jun. 19, 2000, (21) U.S. provisional patent application Ser. No. 60/165,228, attorney docket no. 25791.39, filed on Nov. 12, 1999, (22) U.S. provisional patent application Ser. No. 60/455,051, attorney docket no. 25791.40, filed on Mar. 14, 2003, (23) PCT application US02/2477, filed on Jun. 26, 2002, attorney docket no. 25791.44.02, which claims priority from U.S. provisional patent application Ser. No. 60/303,711, attorney docket no. 25791.44, filed on Jul. 6, 2001, (24) U.S. patent application Ser. No. 10/311,412, filed on Dec. 12, 2002, attorney docket no. 25791.45.07, which claims priority from provisional patent application Ser. No. 60/221,443, attorney docket no. 25791.45, filed on Jul. 28, 2000, (25) U.S. patent application Ser. No. 10/______, filed on Dec. 18, 2002, attorney docket no. 25791.46.07, which claims priority from provisional patent application Ser. No. 60/221,645, attorney docket no. 25791.46, filed on Jul. 28, 2000, (26) U.S. patent application Ser. No. 10/322,947, filed on Jan. 22, 2003, attorney docket no. 25791.47.03, which claims priority from provisional patent application Ser. No. 60/233,638, attorney docket no. 25791.47, filed on Sep. 18, 2000, (27) U.S. patent application Ser. No. 10/406,648, filed on Mar. 31, 2003, attorney docket no. 25791.48.06, which claims priority from provisional patent application Ser. No. 60/237,334, attorney docket no. 25791.48, filed on Oct. 2, 2000, (28) PCT application US02/04353, filed on Feb. 14, 2002, attorney docket no. 25791.50.02, which claims priority from U.S. provisional patent application Ser. No. 60/270,007, attorney docket no. 25791.50, filed on Feb. 20, 2001, (29) U.S. patent application Ser. No. 10/465,835, filed on Jun. 13, 2003, attorney docket no. 25791.51.06, which claims priority from provisional patent application Ser. No. 60/262,434, attorney docket no. 25791.51, filed on Jan. 17, 2001, (30) U.S. patent application Ser. No. 10/465,831, filed on Jun. 13, 2003, attorney docket no. 25791.52.06, which claims priority from U.S. provisional patent application Ser. No. 60/259,486, attorney docket no. 25791.52, filed on Jan. 3, 2001, (31) U.S. provisional patent application Ser. No. 60/452,303, filed on Mar. 5, 2003, attorney docket no. 25791.53, (32) U.S. Pat. No. 6,470,966, which was filed as patent application Ser. No. 09/850,093, filed on May 7, 2001, attorney docket no. 25791.55, as a divisional application of U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (33) U.S. Pat. No. 6,561,227, which was filed as patent application Ser. No. 09/852,026, filed on May 9, 2001, attorney docket no. 25791.56, as a divisional application of U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (34) U.S. patent application Ser. No. 09/852,027, filed on May 9, 2001, attorney docket no. 25791.57, as a divisional application of U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, attorney docket no. 25791.03.02, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (35) PCT Application US02/25608, attorney docket no. 25791.58.02, filed on Aug. 13, 2002, which claims priority from provisional application 60/318,021, filed on Sep. 7, 2001, attorney docket no. 25791.58, (36) PCT Application US02/24399, attorney docket no. 25791.59.02, filed on Aug. 1, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/313,453, attorney docket no. 25791.59, filed on Aug. 20, 2001, (37) PCT Application US02/29856, attorney docket no. 25791.60.02, filed on Sep. 19, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/326,886, attorney docket no. 25791.60, filed on Oct. 3, 2001, (38) PCT Application US02/20256, attorney docket no. 25791.61.02, filed on Jun. 26, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/303,740, attorney docket no. 25791.61, filed on Jul. 6, 2001, (39) U.S. patent application Ser. No. 09/962,469, filed on Sep. 25, 2001, attorney docket no. 25791.62, which is a divisional of U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (40) U.S. patent application Ser. No. 09/962,470, filed on Sep. 25, 2001, attorney docket no. 25791.63, which is a divisional of U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (41) U.S. patent application Ser. No. 09/962,471, filed on Sep. 25, 2001, attorney docket no. 25791.64, which is a divisional of U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (42) U.S. patent application Ser. No. 09/962,467, filed on Sep. 25, 2001, attorney docket no. 25791.65, which is a divisional of U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (43) U.S. patent application Ser. No. 09/962,468, filed on Sep. 25, 2001, attorney docket no. 25791.66, which is a divisional of U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (44) PCT application US02/25727, filed on Aug. 14, 2002, attorney docket no. 25791.67.03, which claims priority from U.S. provisional patent application Ser. No. 60/317,985, attorney docket no. 25791.67, filed on Sep. 6, 2001, and U.S. provisional patent application Ser. No. 60/318,386, attorney docket no. 25791.67.02, filed on Sep. 10, 2001, (45) PCT application US02/39425, filed on Dec. 10, 2002, attorney docket no. 25791.68.02, which claims priority from U.S. provisional patent application Ser. No. 60/343,674, attorney docket no. 25791.68, filed on Dec. 27, 2001, (46) U.S. utility patent application Ser. No. 09/969,922, attorney docket no. 25791.69, filed on Oct. 3, 2001, which is a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (47) U.S. utility patent application Ser. No. 10/516,467, attorney docket no. 25791.70, filed on Dec. 10, 2001, which is a continuation application of U.S. utility patent application Ser. No. 09/969,922, attorney docket no. 25791.69, filed on Oct. 3, 2001, which is a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (48) PCT application US03/00609, filed on Jan. 9, 2003, attorney docket no. 25791.71.02, which claims priority from U.S. provisional patent application Ser. No. 60/357,372, attorney docket no. 25791.71, filed on Feb. 15, 2002, (49) U.S. patent application Ser. No. 10/074,703, attorney docket no. 25791.74, filed on Feb. 12, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (50) U.S. patent application Ser. No. 10/074,244, attorney docket no. 25791.75, filed on Feb. 12, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (51) U.S. patent application Ser. No. 10/076,660, attorney docket no. 25791.76, filed on Feb. 15, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on 2/24/2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (52) U.S. patent application Ser. No. 10/076,661, attorney docket no. 25791.77, filed on Feb. 15, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (53) U.S. patent application Ser. No. 10/076,659, attorney docket no. 25791.78, filed on Feb. 15, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (54) U.S. patent application Ser. No. 10/078,928, attorney docket no. 25791.79, filed on Feb. 20, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (55) U.S. patent application Ser. No. 10/078,922, attorney docket no. 25791.80, filed on Feb. 20, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (56) U.S. patent application Ser. No. 10/078,921, attorney docket no. 25791.81, filed on Feb. 20, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (57) U.S. patent application Ser. No. 10/261,928, attorney docket no. 25791.82, filed on Oct. 1, 2002, which is a divisional of U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (58) U.S. patent application Ser. No. 10/079,276, attorney docket no. 25791.83, filed on Feb. 20, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (59) U.S. patent application Ser. No. 10/262,009, attorney docket no. 25791.84, filed on Oct. 1, 2002, which is a divisional of U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (60) U.S. patent application Ser. No. 10/092,481, attorney docket no. 25791.85, filed on Mar. 7, 2002, which is a divisional of U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, attorney docket no. 25791.12.02, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (61) U.S. patent application Ser. No. 10/261,926, attorney docket no. 25791.86, filed on Oct. 1, 2002, which is a divisional of U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (62) PCT application US02/36157, filed on Nov. 12, 2002, attorney docket no. 25791.87.02, which claims priority from U.S. provisional patent application Ser. No. 60/338,996, attorney docket no. 25791.87, filed on Nov. 12, 2001, (63) PCT application US02/36267, filed on Nov. 12, 2002, attorney docket no. 25791.88.02, which claims priority from U.S. provisional patent application Ser. No. 60/339,013, attorney docket no. 25791.88, filed on Nov. 12, 2001, (64) PCT application US03/11765, filed on Apr. 16, 2003, attorney docket no. 25791.89.02, which claims priority from U.S. provisional patent application Ser. No. 60/383,917, attorney docket no. 25791.89, filed on May 29, 2002, (65) PCT application US03/15020, filed on May 12, 2003, attorney docket no. 25791.90.02, which claims priority from U.S. provisional patent application Ser. No. 60/391,703, attorney docket no. 25791.90, filed on Jun. 26, 2002, (66) PCT application US02/39418, filed on Dec. 10, 2002, attorney docket no. 25791.92.02, which claims priority from U.S. provisional patent application Ser. No. 60/346,309, attorney docket no. 25791.92, filed on Jan. 7, 2002, (67) PCT application US03/06544, filed on Mar. 4, 2003, attorney docket no. 25791.93.02, which claims priority from U.S. provisional patent application Ser. No. 60/372,048, attorney docket no. 25791.93, filed on Apr. 12, 2002, (68) U.S. patent application Ser. No. 10/331,718, attorney docket no. 25791.94, filed on Dec. 30, 2002, which is a divisional U.S. patent application Ser. No. 09/679,906, filed on Oct. 5, 2000, attorney docket no. 25791.37.02, which claims priority from provisional patent application Ser. No. 60/159,033, attorney docket no. 25791.37, filed on Oct. 12, 1999, (69) PCT application US03/04837, filed on Feb. 29, 2003, attorney docket no. 25791.95.02, which claims priority from U.S. provisional patent application Ser. No. 60/363,829, attorney docket no. 25791.95, filed on Mar. 13, 2002, (70) U.S. patent application Ser. No. 10/261,927, attorney docket no. 25791.97, filed on Oct. 1, 2002, which is a divisional of U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (71) U.S. patent application Ser. No. 10/262,008, attorney docket no. 25791.98, filed on Oct. 1, 2002, which is a divisional of U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (72) U.S. patent application Ser. No. 10/261,925, attorney docket no. 25791.99, filed on Oct. 1, 2002, which is a divisional of U.S. Pat. No. 6,557,640, which was filed as patent application Ser. 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No. 60/412,542, attorney docket no. 25791.102, filed on Sep. 20, 2002, (76) PCT application US03/14153, filed on May 6, 2003, attorney docket no. 25791.104.02, which claims priority from U.S. provisional patent application Ser. No. 60/380,147, attorney docket no. 25791.104, filed on May 6, 2002, (77) PCT application US03/19993, filed on Jun. 24, 2003, attorney docket no. 25791.106.02, which claims priority from U.S. provisional patent application Ser. No. 60/397,284, attorney docket no. 25791.106, filed on Jul. 19, 2002, (78) PCT application US03/13787, filed on May 5, 2003, attorney docket no. 25791.107.02, which claims priority from U.S. provisional patent application Ser. No. 60/387,486, attorney docket no. 25791.107, filed on Jun. 10, 2002, (79) PCT application US03/18530, filed on Jun. 11, 2003, attorney docket no. 25791.108.02, which claims priority from U.S. provisional patent application Ser. No. 60/387,961, attorney docket no. 25791.108, filed on Jun. 12, 2002, (80) PCT application US03/20694, filed on Jul. 1, 2003, attorney docket no. 25791.110.02, which claims priority from U.S. provisional patent application Ser. No. 60/398,061, attorney docket no. 25791.110, filed on Jul. 24, 2002, (81) PCT application US03/20870, filed on Jul. 2, 2003, attorney docket no. 25791.111.02, which claims priority from U.S. provisional patent application Ser. No. 60/399,240, attorney docket no. 25791.111, filed on Jul. 29, 2002, (82) U.S. provisional patent application Ser. No. 60/412,487, attorney docket no. 25791.112, filed on Sep. 20, 2002, (83) U.S. provisional patent application Ser. No. 60/412,488, attorney docket no. 25791.114, filed on Sep. 20, 2002, (84) U.S. patent application Ser. No. 10/280,356, attorney docket no. 25791.115, filed on Oct. 25, 2002, which is a continuation of U.S. Pat. No. 6,470,966, which was filed as patent application Ser. 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No. 09/588,946, attorney docket no. 25791.17.02, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (96) U.S. patent application Ser. No. 10/624,842, attorney docket no. 25791.151, filed on Jul. 22, 2003, which is a divisional of U.S. patent application Ser. No. 09/502,350, attorney docket no. 25791.8.02, filed on Feb. 10, 2000, which claims priority from provisional application 60/119,611, filed on Feb. 11, 1999, (97) U.S. provisional patent application Ser. No. 60/431,184, attorney docket no. 25791.157, filed on Dec. 5, 2002, (98) U.S. provisional patent application Ser. No. 60/448,526, attorney docket no. 25791.185, filed on Feb. 18, 2003, (99) U.S. provisional patent application Ser. No. 60/461,539, attorney docket no. 25791.186, filed on Apr. 9, 2003, (100) U.S. provisional patent application Ser. No. 60/462,750, attorney docket no. 25791.193, filed on Apr. 14, 2003, (101) U.S. provisional patent application Ser. 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No. 60/453,678, attorney docket no. 25791.253, filed on Mar. 11, 2003, (110) U.S. patent application Ser. No. 10/421,682, attorney docket no. 25791.256, filed on Apr. 23, 2003, which is a continuation of U.S. patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (111) U.S. provisional patent application Ser. No. 60/457,965, attorney docket no. 25791.260, filed on Mar. 27, 2003, (112) U.S. provisional patent application Ser. No. 60/455,718, attorney docket no. 25791.262, filed on Mar. 18, 2003, (113) U.S. Pat. No. 6,550,821, which was filed as patent application Ser. No. 09/811,734, filed on Mar. 19, 2001, (114) U.S. patent application Ser. No. 10/436,467, attorney docket no. 25791.268, filed on May 12, 2003, which is a continuation of U.S. Pat. No. 6,604,763, which was filed as application Ser. No. 09/559,122, attorney docket no. 25791.23.02, filed on Apr. 26, 2000, which claims priority from provisional application 60/131,106, filed on Apr. 26, 1999, (115) U.S. provisional patent application Ser. No. 60/459,776, attorney docket no. 25791.270, filed on Apr. 2, 2003, (116) U.S. provisional patent application Ser. No. 60/461,094, attorney docket no. 25791.272, filed on Apr. 8, 2003, (117) U.S. provisional patent application Ser. No. 60/461,038, attorney docket no. 25791.273, filed on Apr. 7, 2003, (118) U.S. provisional patent application Ser. No. 60/463,586, attorney docket no. 25791.277, filed on Apr. 17, 2003, (119) U.S. provisional patent application Ser. No. 60/472,240, attorney docket no. 25791.286, filed on May 20, 2003, (120) U.S. patent application Ser. No. 10/619,285, attorney docket no. 25791.292, filed on Jul. 14, 2003, which is a continuation-in-part of U.S. utility patent application Ser. No. 09/969,922, attorney docket no. 25791.69, filed on Oct. 3, 2001, which is a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, attorney docket number 25791.9.02, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (121) U.S. utility patent application Ser. No. 10/418,688, attorney docket no. 25791.257, which was filed on Apr. 18, 2003, as a division of U.S. utility patent application Ser. No. 09/523,468, attorney docket no. 25791.11.02, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (122) PCT patent application serial no. PCT/US04/06246, attorney docket no. 25791.238.02, filed on Feb. 26, 2004, (123) PCT patent application serial number PCT/US04/08170, attorney docket number 25791.40.02, filed on Mar. 15, 2004, (124) PCT patent application serial number PCT/US04/08171, attorney docket number 25791.236.02, filed on Mar. 15, 2004, (125) PCT patent application serial number PCT/US04/08073, attorney docket number 25791.262.02, filed on Mar. 18, 2004, (126) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, (127) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, (128) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, (129) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and (130) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, the casing cutter assembly 14 is provided and operates substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US03/29858, attorney docket number 25791.112.02, filed on Sep. 22, 2003, and/or (2) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (3) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (4) PCT patent application serial number PCT/US04/10317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, (5) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (6) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 11-1 and 11-2, 11A1 to 11A2, 11B1 to 11B2, 11C, 11D, 11E, 11F, 11G, 11H, 111, 11 j, 11K, 11L, 11M, 11N, 11O, 11P, 11Q, 11R, 11S, 11T, 11U, 11V, 11W, 11 x, 11Y, 11Z1 to 11Z4, 11AA1 to 11AA4, 11AB1 to 11AB4, 11AC1 to 11AC4, 11AD, and 11AE, the casing cutter assembly 14 includes an upper tubular tool joint 14002 that defines a longitudinal passage 14002 a and mounting holes, 14002 b and 14002 c, and includes an internal threaded connection 14002 d, an inner annular recess 14002 e, an inner annular recess 14002 f, and an internal threaded connection 14002 g. A tubular torque plate 14004 that defines a longitudinal passage 14004 a and includes circumferentially spaced apart teeth 14004 b is received within, mates with, and is coupled to the internal annular recess 14002 e of the upper tubular tool joint 14002.
  • Circumferentially spaced apart teeth 14006 a of an end of a tubular lower mandrel 14006 that defines a longitudinal passage 14006 b, a radial passage 14006 ba, and a radial passage 14006 bb and includes an external threaded connection 14006 c, an external flange 14006 d, an external annular recess 14006 e having a step 14006 f at one end, an external annular recess 14006 g, external teeth 14006 h, an external threaded connection 14006 i, and an external annular recess 14006 j engage the circumferentially spaced apart teeth 14004 b of the tubular torque plate 14004. An internal threaded connection 14008 a of an end of a tubular toggle bushing 14008 that defines a longitudinal passage 14008 b, an upper longitudinal slot 14008 c, a lower longitudinal slot 14008 d, mounting holes, 14008 e, 14008 f, 14008 g, 14008 h, 14008 i, 14008 j, 14008 k, 14008 l, 14008 m, 14008 n, 14008 o, 14008 p, 14008 q, 14008 r, 14008 s, 14008 t, 14008 u, 14008 v, 14008 w, 14008 x, 14008 xa, and 14008 xb, and includes an external annular recess 14008 y, internal annular recess 14008 z, external annular recess 14008 aa, and an external annular recess 14008 ab receives and is coupled to the external threaded connection 14006 c of the tubular lower mandrel 14006.
  • A sealing element 14010 is received within the external annular recess 14008 y of the tubular toggle bushing 14008 for sealing the interface between the tubular toggle bushing and the upper tubular tool joint 14002. A sealing element 14012 is received within the internal annular recess 14008 z of the tubular toggle bushing 14008 for sealing the interface between the tubular toggle bushing and the tubular lower mandrel 14006.
  • Mounting screws, 14014 a and 14014 b, mounted within and coupled to the mounting holes, 14008 w and 14008 x, respectively, of the tubular toggle bushing 14008 are also received within the mounting holes, 14002 b and 14002 c, of the upper tubular tool joint 14002. Mounting pins, 14016 a, 14016 b, 14016 c, 14016 d, and 14016 e, are mounted within the mounting holes, 14008 e, 14008 f, 14008 g, 14008 h, and 14008 i, respectively. Mounting pins, 14018 a, 14018 b, 14018 c, 14018 d, and 14018 e, are mounted within the mounting holes, 14008 t, 14008 s, 14008 r, 14008 q, and 14008 p, respectively. Mounting screws, 14020 a and 14020 b, are mounted within the mounting holes, 14008 u and 14008 v, respectively.
  • A first upper toggle link 14022 defines mounting holes, 14022 a and 14022 b, for receiving the mounting pins, 14016 a and 14016 b, and includes a mounting pin 14022 c at one end. A first lower toggle link 14024 defines mounting holes, 14024 a, 14024 b, and 14024 c, for receiving the mounting pins, 14022 c, 14016 c, and 14016 d, respectively and includes an engagement arm 14024 d. A first trigger 14026 defines a mounting hole 14026 a for receiving the mounting pin 14016 e and includes an engagement arm 14026 b at one end, an engagement member 14026 c, and an engagement arm 14026 d at another end.
  • A second upper toggle link 14028 defines mounting holes, 14028 a and 14028 b, for receiving the mounting pins, 14018 a and 14018 b, and includes a mounting pin 14028 c at one end. A second lower toggle link 14030 defines mounting holes, 14030 a, 14030 b, and 14030 c, for receiving the mounting pins, 14028 c, 14018 c, and 14018 d, respectively and includes an engagement arm 14030 d. A second trigger 14032 defines a mounting hole 14032 a for receiving the mounting pin 14018 e and includes an engagement arm 14032 b at one end, an engagement member 14032 c, and an engagement arm 14032 d at another end.
  • An end of a tubular spring housing 14034 that defines a longitudinal passage 14034 a, mounting holes, 14034 b and 14034 c, and mounting holes, 14034 ba and 14034 ca, and includes an internal flange 14034 d and an internal annular recess 14034 e at one end, and an internal flange 14034 f, an internal annular recess 14034 g, an internal annular recess 14034 h, and an external threaded connection 14034 i at another end receives and mates with the end of the tubular toggle bushing 14008. Mounting screws, 14035 a and 14035 b, are mounted within and coupled to the mounting holes, 14008 xb and 14008 xa, respectively, of the tubular toggle bushing 14008 and are received within the mounting holes, 14034 ba and 14034 ca, respectively, of the tubular spring housing 14034.
  • A tubular retracting spring ring 14036 that defines mounting holes, 14036 a and 14036 b, receives and mates with a portion of the tubular lower mandrel 14006 and is received within and mates with a portion of the tubular spring housing 14034. Mounting screws, 14038 a and 14038 b, are mounted within and coupled to the mounting holes, 14036 a and 14036 b, respectively, of the tubular retracting spring ring 14036 and extend into the mounting holes, 14034 b and 14034 c, respectively, of the tubular spring housing 14034.
  • Casing diameter sensor springs, 14040 a and 14040 b, are positioned within the longitudinal slots, 14008 c and 1408 d, respectively, of the tubular toggle bushing 14008 that engage the engagement members, 14026 c and 14032 c, and engagement arms, 14026 d and 14032 d, of the first and second triggers, 14026 and 14032, respectively. An inner flange 14042 a of an end of a tubular spring washer 14042 mates with and receives a portion of the tubular lower mandrel 14006 and an end face of the inner flange of the tubular spring washer is positioned proximate and end face of the external flange 14006 d of the tubular lower mandrel. The tubular spring washer 14042 is further received within the longitudinal passage 14034 a of the tubular spring housing 14034.
  • An end of a retracting spring 14044 that receives the tubular lower mandrel 14006 is positioned within the tubular spring washer 14042 in contact with the internal flange 14042 a of the tubular spring washer and the other end of the retracting spring is positioned in contact with an end face of the tubular retracting spring ring 14036.
  • A sealing element 14046 is received within the external annular recess 14006 j of the tubular lower mandrel 14006 for sealing the interface between the tubular lower mandrel and the tubular spring housing 14034. A sealing element 14048 is received within the internal annular recess 14034 h of the tubular spring housing 14034 for sealing the interface between the tubular spring housing and the tubular lower mandrel 14006.
  • An internal threaded connection 14050 a of an end of a tubular upper hinge sleeve 14050 that includes an internal flange 14050 b and an internal pivot 14050 c receives and is coupled to the external threaded connection 14034 i of the end of the tubular spring housing 14034.
  • An external flange 14052 a of a base member 14052 b of an upper cam assembly 14052, that is mounted upon and receives the lower tubular mandrel 14006, that includes an internal flange 14052 c that is received within the external annular recess 14006 e of the lower tubular mandrel 14006 and a plurality of circumferentially spaced apart cam arms 14052 d extending from the base member mates with and is received within the tubular upper hinge sleeve 14050. The base member 14052 b of the upper cam assembly 14052 further includes a plurality of circumferentially spaced apart teeth 14052 f that mate with and are received within a plurality of circumferentially spaced apart teeth 14034 j provided on the end face of the tubular spring housing 14034 and an end face of the external flange 14052 a of the base member of the upper cam assembly is positioned in opposing relation to an end face of the internal flange 14050 b of the tubular upper hinge sleeve 14050. Each of the cam arms 14052 d of the upper cam assembly 14052 include external cam surfaces 14052 e. In an exemplary embodiment, the teeth 14052 f of the base member 14052 b of the upper cam assembly 14052 and the teeth 14034 j provided on the end face of the tubular spring housing 14034 permit torsional loads to be transmitted between the tubular spring housing and the upper cam assembly.
  • A plurality of circumferentially spaced apart upper casing cutter segments 14054 are mounted upon and receive the lower tubular mandrel 14006 and each include an external pivot recess 14054 a for mating with and receiving the internal pivot 14050 c of the tubular upper hinge sleeve 14050 and an external flange 14054 b and are pivotally mounted within the tubular upper hinge sleeve and are interleaved with the circumferentially spaced apart cam arms 14052 d of the upper cam assembly 14052. A casing cutter element 14056 is coupled to and supported by the upper surface of each upper casing cutter segments 14054 proximate the external flange 14054 b.
  • A plurality of circumferentially spaced apart lower casing cutter segments 14058 are mounted upon and receive the lower tubular mandrel 14006, are interleaved among the upper casing cutter segments 14054, are oriented in the opposite direction to the upper casing cutter segments 14054, each include an external pivot recess 14058 a, and are positioned in opposing relation to corresponding circumferentially spaced apart cam arms 14052 d of the upper cam assembly 14052.
  • A lower cam assembly 14060 is mounted upon and receives the lower tubular mandrel 14006 that includes a base member 14060 a having an external flange 14060 b, a plurality of circumferentially spaced apart cam arms 14060 d that extend from the base member that each include external cam surfaces 14060 e and define mounting holes 14060 f and 14060 g. The base member 14060 a of the lower cam assembly 14060 further includes a plurality of circumferentially spaced apart teeth 14060 h. The circumferentially spaced apart cam arms 14060 d of the lower cam assembly 14060 are interleaved among the lower casing cutter segments 14058 and the circumferentially spaced apart cam arms 14052 d of the upper cam assembly 14052 and positioned in opposing relation to corresponding upper casing cutter segments 14054.
  • Mounting screws, 14062 a, 14062 b, 14062 c, and 14062 e, are mounted within the corresponding mounting holes, 14060 f and 14060 g, of the lower cam assembly 14060 and are received within the external annular recess 14006 g of the lower cam assembly 14060.
  • A tubular lower hinge sleeve 14064 that receives the lower casing cutter segments 14058 and the lower cam assembly 14060 includes an internal flange 14064 a for engaging the external flange 14060 b of the base member of the lower cam assembly 14060, an internal pivot 14064 b for engaging and receiving the external pivot recess 14058 a of the lower casing cutter segments 14058 thereby pivotally mounting the lower casing cutter segments within the tubular lower hinge sleeve, and an internal threaded connection 14064 c.
  • An external threaded connection 14066 a of an end of a tubular sleeve 14066 that defines mounting holes, 14066 b and 14066 c, and includes an internal annular recess 14066 d having a shoulder 14066 e, an internal flange 14066 f, and an internal threaded connection 14066 g at another end is received within and coupled to the internal threaded connection 14064 c of the tubular lower hinge sleeve 14064. An external threaded connection 14068 a of an end of a tubular member 14068 that defines a longitudinal passage 14068 b and mounting holes, 14068 c and 14068 d, and includes an external annular recess 14068 e, and an external threaded connection 14068 f at another end is received within and is coupled to the internal threaded connection 14066 g of the tubular sleeve 14066.
  • Mounting screws, 14070 a and 14070 b, are mounted in and coupled to the mounting holes, 14068 c and 14068 d, respectively, of the tubular member 14068 that also extend into the mounting holes, 14066 b and 14066 c, respectively, of the tubular sleeve 14066. A sealing element 14072 is received within the external annular recess 14068 e of the tubular member 14068 for sealing the interface between the tubular member and the tubular sleeve 14066.
  • An internal threaded connection 14074 a of a tubular retracting piston 14074 that defines a longitudinal passage 14074 b and includes an internal annular recess 14074 c and an external annular recess 14074 d receives and is coupled to the external threaded connection 14006 i of the tubular lower mandrel 14006. A sealing element 14076 is received within the external annular recess 14074 d of the tubular retracting piston 14074 for sealing the interface between the tubular retracting piston and the tubular sleeve 14066. A sealing element 14078 is received within the internal annular recess 14074 c of the tubular retracting piston 14074 for sealing the interface between the tubular retracting piston and the tubular lower mandrel 14006.
  • Locking dogs 14080 mate with and receive the external teeth 14006 h of the tubular lower mandrel 14006. A spacer ring 14082 is positioned between an end face of the locking dogs 14080 and an end face of the lower cam assembly 14060. A release piston 14084 mounted upon the tubular lower mandrel 14006 defines a radial passage 14084 a for mounting a burst disk 14086 includes sealing elements, 14084 b, 14084 c, and 14084 d. The sealing elements, 14084 b and 14084 d, sealing the interface between the release piston 14084 and the tubular lower mandrel 14006. An end face of the release piston 14084 is positioned in opposing relation to an end face of the locking dogs 14080.
  • A release sleeve 14088 that receives and is mounted upon the locking dogs 14080 and the release piston 14084 includes an internal flange 14088 a at one end that sealingly engages the tubular lower mandrel 14006. A bypass sleeve 14090 that receives and is mounted upon the release sleeve 14088 includes an internal flange 14090 a at one end.
  • In an exemplary embodiment, during operation of the casing cutter assembly 14, the retracting spring 14044 is compressed and thereby applies a biasing spring force in a direction 14092 from the lower tubular mandrel 14006 to the tubular spring housing 14034 that, in the absence of other forces, moves and/or maintains the upper cam assembly 14052 and the upper casing cutter segments 14054 out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060. In an exemplary embodiment, during operation of the casing cutter assembly 14, an external threaded connection 12 a of an end of the tubular support member 12 is coupled to the internal threaded connection 14002 d of the upper tubular tool joint 14002 and an internal threaded connection 16 a of an end of the ball gripper assembly 16 is coupled to the external threaded connection 14068 f of the tubular member 14068.
  • The upper cam assembly 14052 and the upper casing cutter segments 14054 may be brought into engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by pressurizing an annulus 14094 defined between the lower tubular mandrel 14006 and the tubular spring housing 14034. In particular, injection of fluidic materials into the cam cutter assembly 14 through the longitudinal passage 14006 b of the lower tubular mandrel 14006 and into the radial passage 14006 ba may pressurize the annulus 14094 thereby creating sufficient operating pressure to generate a force in a direction 14096 sufficient to overcome the biasing force of the retracting spring 14044. As a result, the spring housing 14034 may be displaced in the direction 14096 relative to the lower tubular mandrel 14006 thereby displacing the tubular upper hinge sleeve 14050, upper cam assembly 14052, and upper casing cutter segments 14054 in the direction 14096.
  • In an exemplary embodiment, as illustrated in FIGS. 11P, 11Q and 11R, the displacement of the upper cam assembly 14052 and upper casing cutter segments 14054 in the direction 14096 will cause the lower casing cutter segments 14058 to ride up the cam surfaces of the cam arms of the upper cam assembly 14052 while also pivoting about the lower tubular hinge segment 14064, and will also cause the upper casing cutter segments 14054 to ride up the cam surfaces of the cam arms of the lower cam assembly 14060 while also pivoting about the upper tubular hinge segment 14050.
  • In an exemplary embodiment, during the operation of the casing cutter assembly 14, when the upper and lower casing cutter segments, 14054 and 14058, brought into axial alignment in a radially expanded position, the casing cutter elements of the casing cutter segments are brought into intimate contact with the interior surface of a pre-selected portion of the expandable wellbore casing 100. The casing cutter assembly 14 may then be rotated to thereby cause the casing cutter elements to cut through the expandable wellbore casing. The portion of the expandable wellbore casing 100 cut away from the remaining portion on the expandable wellbore casing may then be carried out of the wellbore 102 with the cut away portion of the expandable wellbore casing supported by the casing cutter elements.
  • In an exemplary embodiment, the upper cam assembly 14052 and the upper casing cutter segments 14054 may be moved out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by reducing the operating pressure within the annulus 14094.
  • In an alternative embodiment, as illustrated in FIGS. 11S, 11T, 11U and 11V, during operation of the casing cutter assembly 14, the upper cam assembly 14052 and the upper casing cutter segments 14054 may also be moved out of engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060 by sensing the operating pressure within the longitudinal passage 14006 b of the lower tubular mandrel 14006. In particular, as illustrated in FIG. 11T, if the operating pressure within the longitudinal passage 14006 b and radial passage 14006 bb of the lower tubular mandrel 14006 exceeds a predetermined value, the burst disc 14086 will open the passage 14084 a thereby pressurizing the interior of the tubular release sleeve 14088 thereby displacing the tubular release sleeve 14088 downwardly in a direction 14092 away from engagement with the locking dogs 14080.
  • As a result, as illustrated in FIG. 11U, the locking dogs 14080 are displaced outwardly in the radial directed and thereby released from engagement with the lower tubular mandrel 14006 thereby permitting the lower casing cutter segments 14058 and the lower cam assembly 14060 to be displaced downwardly relative to the lower tubular mandrel.
  • As a result, as illustrated in FIG. 11V, the operating pressure within the lower tubular mandrel 14066 may then cause the lower tubular mandrel to be displaced downwardly in the direction 14094 relative to the tubular lower mandrel 14006 and the retracting piston 14074. As a result, the lower tubular mandrel 14066, the lower casing cutter segments 14058, the lower cam assembly 14060, and tubular lower hinge sleeve 14064 are displaced downwardly in the direction 14094 relative to the tubular spring housing 14034 thereby moving the lower casing cutter segments 14058 and the lower cam assembly 14060 out of engagement with the upper cam assembly 14052 and the upper casing cutter segments 14054.
  • In an exemplary embodiment, as illustrated in FIGS. 11W, 11X, and 11Y, during operation of the casing cutter assembly 14, the casing cutter assembly 14 senses the diameter of the expandable wellbore casing 100 using the upper toggle links, 14022 and 14028, lower toggle links, 14024 and 14030, and triggers, 14026 and 14032, and then prevents the engagement of the upper cam assembly 14052 and the upper casing cutter segments 14054 with the lower casing cutter segments 14058 and the lower cam assembly 14060.
  • In particular, as illustrated in FIG. 11W, anytime the upper toggle links, 14022 and 14028, and lower toggle links, 14024 and 14030, are positioned within a portion of the expandable wellbore casing 100 that has been radially expanded and plastically deformed by the system 10, the triggers, 14026 and 14032, will be pivoted by the engagement arms, 14024 d and 14030 d, of the lower toggle links, 14024 and 14030, to a position in which the triggers will no longer engage the internal flange 14034 d of the end of the tubular spring housing 14034 thereby permitting the displacement of the tubular spring housing in the direction 14096. As a result, the upper cam assembly 14052 and the upper casing cutter segments 14054 can be brought into engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060. In an exemplary embodiment, the upper toggle links, 14022 and 14028, and the lower toggle links, 14024 and 14030, are spring biased towards the position illustrated in FIG. 11W.
  • Conversely, as illustrated in FIG. 11X, anytime the upper toggle links, 14022 and 14028, and lower toggle links, 14024 and 14030, are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10, the triggers, 14026 and 14032, will be maintained in a position in which the triggers will engage the internal flange 14034 d of the end of the tubular spring housing 14034 thereby preventing the displacement of the tubular spring housing in the direction 14096. As a result, the upper cam assembly 14052 and the upper casing cutter segments 14054 cannot be brought into engagement with the lower casing cutter segments 14058 and the lower cam assembly 14060. In an exemplary embodiment, the triggers, 14026 and 14032, are spring biased towards the position illustrated in FIG. 11X.
  • In an exemplary embodiment, as illustrated in FIG. 11Y, the tubular spring housing 14034 may be displaced upwardly in the direction 14098 even if the upper toggle links, 14022 and 14028, and lower toggle links, 14024 and 14030, are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10.
  • In an exemplary embodiment, as illustrated in FIGS. 11Z1 to 11Z4, 11AA1 to 11AA4, 11AB1 to 11AB4, 11AC1 to 11AC4, 11AD, and 11AE, the tubular spring housing 14034 of the casing cutter assembly 14 defines internal annular recesses 14034 k and 14034 l, spaced apart by an internal flange 14034 m, the tubular toggle bushing 14008 defines an external annular recess 14008 ac, and the casing cutter assembly further includes pins, 14100 a and 14100 b and 14102 a and 14102 b, mounted in holes 14008 j and 14008 o and 14008 k and 14008 n, respectively, of the tubular toggle bushing, and a one-shot deactivation device 14104 mounted on the tubular toggle bushing between the pins, 14100 a and 14100 b and 14102 a and 14102 b.
  • The one-shot deactivation device 14104 includes a tubular body 14104 a that defines radial holes, 14104 b and 14014 c, and includes an external annular recess 14104 d at one end, a centrally positioned external flange 14104 e, a centrally positioned internal annular recess 14104 f, and an external annular recess 14104 g at another end. An engagement member 14106 that includes a base member 14106 a having a tapered end 14106 b and a key member 14106 c having a tapered end 14106 d is received within a portion of the internal annular recess 14104 f of the tubular body 14104 a and an engagement member 14108 that includes a base member 14108 a having a tapered end 14108 b and a key member 14108 c having a tapered end 14108 d is received within an opposite portion of the internal annular recess 14104 f of the tubular body 14104 a. Spring members, 14110 and 14112, are received within the annular recess 14104 f of the tubular body 14104 a for biasing the base members, base member 14106 a and 14108 a, of the engagement members, 14106 and 14108, respectively, radially inwardly relative to the tubular body 14104 a.
  • In an exemplary embodiment, during operation of the casing cutter assembly 14, as illustrated in FIGS. 11Z1 to 11Z4, the one-shot deactivation device 14104 are positioned proximate and in intimate contact with the pins, 14102 a and 14102 b, with the tapered ends, 14106 b and 14108 b, of the base members, 14106 a and 14108 a, of the engagement members, 14106 and 14108, received within the external annular recess 14008 ac of the tubular toggle bushing 14008. When the one-shot deactivation device 14104 is positioned as illustrated in FIG. 11Z, the external annular recess 14104 d of the tubular body 14104 a of the one-shot deactivation device is moved out of engagement with the engagement arms, 14026 d and 14032 d, of the triggers, 14026 and 14032, respectively. As a result, the triggers, 14026 and 14032, may operate normally as described above with reference to FIGS. 11W, 11X, and 11Y.
  • Conversely, in an exemplary embodiment, during operation of the casing cutter assembly 14, as illustrated in FIGS. 11AA1 to 11AA4, the one-shot deactivation device 14104 are positioned proximate and in intimate contact with the pins, 14100 a and 14100 b, with the tapered ends, 14106 b and 14108 b, of the base members, 14106 a and 14108 a, of the engagement members, 14106 and 14108, not received within the external annular recess 14008 ac of the tubular toggle bushing 14008. When the one-shot deactivation device 14104 is positioned as illustrated in FIGS. 11AA1 to 11AA4, the external annular recess 14104 d of the tubular body 14104 a of the one-shot deactivation device is moved into engagement with the engagement arms, 14026 d and 14032 d, of the triggers, 14026 and 14032, respectively. As a result, the triggers, 14026 and 14032, are deactivated and may not operate normally as described above with reference to FIGS. 11W, 11 x, and 11Y.
  • In an alternative embodiment, the elements of the casing cutter assembly 14 that sense the diameter of the expandable wellbore casing 100 may be disabled or omitted or adjusted to sense any pre-selected internal diameter of the expandable wellbore casing.
  • In an exemplary embodiment, the ball gripper assembly 16 is provided and operates substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, (2) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (3) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (4) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (5) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (6) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (7) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 12A1 to 12A4, 12B and 12C1 to 12C4, the ball gripper assembly 16 includes an upper mandrel 1602 that defines a longitudinal passage 1602 a and a radial passage 1602 b and includes an internal threaded connection 1602 c at one end, an external flange 1602 d at an intermediate portion that includes an external annular recess 1602 e having a shoulder 1602 f and an external radial hole 1602 g, an external annular recess 1602 h, an external annular recess 1602 i, an external annular recess 1602 j having a tapered end 1602 k including an external annular recess 1602 ka, an external annular recess 1602 l, and an external annular recess 1602 m, and an external annular recess 1602 n, an external radial hole 1602 o, an external annular recess 1602 p, and an external annular recess 1602 q at another end.
  • An upper tubular bushing 1604 defines an internally threaded radial opening 1604 a and includes an external flange 1604 b having an external annular recess 1604 c and an internal annular recess 1604 d mates with and receives the external flange 1602 d of the upper mandrel 1602. In particular, the internal annular recess 1604 d of the upper tubular bushing 1604 mates with the shoulder 1602 f of the external annular recess 1602 e of the upper mandrel 1602. A screw 1606 that is threadably coupled to the internally threaded radial opening 1604 a of the upper tubular bushing 1604 extends into the external radial hole 1602 g of the external flange 1602 d of the upper mandrel 1602.
  • A deactivation tubular sleeve 1608 defines a radial passage 1608 a and includes an internal annular recess 1608 b that mates with and receives an end of the external annular recess 1604 c of the external flange 1604 b of the upper tubular bushing 1604, an internal annular recess 1608 c that mates with and receives the external flange 1602 d of the upper mandrel 1602, an internal annular recess 1608 d, an internal annular recess 1608 e, and an internal annular recess 1608 f. A deactivation spring 1610 is received within an annulus 1612 defined between the internal annular recess 1608 b of the deactivation tubular sleeve 1608, an end face of the external annular recess 1604 c of the external flange 1604 b of the upper tubular bushing 1604, and the external annular recess 1602 h of the external flange 1602 d of the upper mandrel 1602.
  • A sealing member 1614 is received with the external annular recess 1602 i of the external flange 1602 d of the upper mandrel 1602 for sealing the interface between the upper mandrel and the deactivation tubular sleeve 1608. An annular spacer element 1616 is received within the external annular recess 1602 ka of the tapered end 1602 k of the external annular recess 1602 j of the upper mandrel 1602.
  • One or more inner engagement elements 1618 a of a tubular coglet 1618 engage and are received within the external annular recess 1602 ka of the tapered end 1602 k of the external annular recess 1602 j of the upper mandrel 1602 and one or more outer engagement elements 1618 b of the coglet engage and are received within the internal annular recess 1608 d of the deactivation tubular sleeve 1608.
  • An external annular recess 1620 a of an end of a tubular coglet prop 1620 that includes an inner flange 1620 b receives and mates with the inner surfaces of the outer engagement elements 1618 b of the coglet 1618. The end of the tubular coglet prop 1620 further receives and mates with the external annular recess 1602 j of the external flange 1602 d of the upper mandrel 1602. A sealing element 1622 is received within the external annular recess 1602 l of the upper mandrel 1602 for sealing the interface between the upper mandrel and the tubular coglet prop 1620.
  • An end of a tubular bumper sleeve 1624 that includes internal and external flanges, 1624 a and 1624 b, and a hole 1624 c at another end mates with and receives the external annular recess 1602 m of the external flange 1602 d of the upper mandrel 1602. A coglet spring 1626 is received within an annulus 1628 defined between the external annular recess 1602 m of the external flange 1602 d of the upper mandrel 1602, the tubular coglet prop 1620, the inner flange 1620 b of the tubular coglet prop, an end face of the tubular bumper sleeve 1624, and the internal annular recess 1608 c of the deactivation tubular sleeve 1608.
  • A tubular ball race 1628 that defines a plurality of tapered annular recesses 1628 a and an internally threaded radial opening 1628 b and includes one or more axial engagement elements 1628 c at one end and one or more axial engagement elements 1628 d at another end receives and mates with the other end of the upper mandrel 1602. In an exemplary embodiment, the axial engagement elements 1628 c of the tubular ball race 1628 are received within and are coupled to the hole 1624 c of the tubular bumper sleeve 1624. An end of a tubular activation sleeve 1630 that defines a plurality of radial openings 1630 a, a radial opening 1630 b, a radial opening 1630 c, and includes an internal annular recess 1630 d receives and mates with the tubular ball race 1628. In an exemplary embodiment, an end face of an end of the tubular activation sleeve 1630 is positioned proximate and in opposing relation to an end face of an end of the deactivation sleeve 1608. In an exemplary embodiment, the radial openings 1630 a are aligned with and positioned in opposing relation to corresponding of tapered annular recesses 1628 a of the tubular ball race 1628, and the radial openings are also narrowed in cross section in the radial direction for reasons to be described.
  • Balls 1632 are received within each of the of tapered annular recesses 1628 a and corresponding radial openings 1630 a of the tubular ball race 1628 and tubular activation sleeve 1630, respectively. In an exemplary embodiment, the narrowed cross sections of the radial openings 1630 a of the tubular activation sleeve 1630 will permit the balls 1632 to be displaced outwardly in the radial direction until at least a portion of the balls extends beyond the outer perimeter of the tubular activation sleeve to thereby permit engagement of the balls with an outer structure such as, for example, a wellbore casing.
  • A lower mandrel 1634 that defines a longitudinal passage 1634 a and an internally threaded radial passage 1634 b at one end and includes internal annular recesses, 1634 c and 1634 d, for receiving and mating with the external annular recesses, 1602 p and 1602 q, of the upper mandrel 1602, an internal annular recess 1634 e, an external flange 1634 f, and an externally threaded connection 1634 g at another end. In an exemplary embodiment, as illustrated in FIG. 12B, the end of the lower mandrel 1634 further includes longitudinal recesses 1634 h for receiving and mating with corresponding axial engagement elements 1628 d of the tubular ball race 1628. A sealing element 1635 is received within the internal annular recess 1634 d of the lower mandrel 1634 for sealing an interface between the lower mandrel and the external annular recess 1602 p of the upper mandrel 1602.
  • A tubular spring retainer 1636 that defines a radial passage 1636 a and includes an external annular recess 1636 b at one end mates with and receives the end of the lower mandrel 1634 and is positioned proximate an end face of the external flange 1634 f of the lower mandrel. A tubular spring retainer 1638 receives and mates with the end of the lower mandrel 1634 and is received and mates with the internal annular recess 1630 d of the tubular activation sleeve 1630.
  • An activation spring 1640 is received within an annulus 1642 defined an end face of the tubular spring retainer 1638, an end face of the spring retainer 1636, the internal annular recess 1630 d of the tubular activation sleeve 1630, and the end of the lower mandrel 1634. A retainer screw 1642 is received within and is threadably coupled to the internally threaded radial opening 1634 b of the lower mandrel 1634 that also extends into the external radial hole 1602 o of the upper mandrel 1602.
  • During operation of the ball gripper assembly 16, in an exemplary embodiment, as illustrated in FIGS. 12A1 to 12A4, the ball gripper assembly may be positioned within the expandable wellbore casing 100 and the internally threaded connection 1602 c of the upper mandrel 1602 may be coupled to an externally threaded connection 14 a of an end of the casing cutter assembly 14 and the externally threaded connection 1634 g of the lower mandrel 1634 may be coupled to an internally threaded connection 18 a of an end of the tension actuator assembly 18.
  • In an alternative embodiment, the internally threaded connection 1602 c of the upper mandrel 1602 may be coupled to an externally threaded connection of an end of the tension actuator assembly 18 and the externally threaded connection 1634 g of the lower mandrel 1634 may be coupled to an internally threaded connection of an end of casing cutter assembly 14.
  • In an exemplary embodiment, the deactivation spring 1610 has a greater spring rate than the activation spring 1640. As a result, in an initial operating mode, as illustrated in FIGS. 12A1 to 12A4, a biasing spring force is applied to the deactivation sleeve 1608 and activation sleeve 1630 in a direction 1644 that maintains the activation sleeve in a position relative to the tubular ball race 1628 that maintains the balls 1632 within the radially inward portions of the corresponding tapered annular recesses 1628 a of the tubular ball race such that the balls do not extend beyond the perimeter of the activation sleeve to engage the expandable wellbore casing 100.
  • As illustrated in FIGS. 12C1 to 12C4, in an exemplary embodiment, the ball gripper 16 may be operated to engage the interior surface of the expandable wellbore casing 100 by injecting a fluidic material 1650 into the ball gripper assembly through the longitudinal passages 1602 a and 1634 aa, of the upper and lower mandrels, 1602 and 1634, respectively.
  • In particular, when the longitudinal and radial passages, 1602 a and 1602 b, respectively, of the upper mandrel 1602 are pressurized by the injection of the fluidic material 1650, the internal annular recess 1608 c of the deactivation tubular sleeve 1608 is pressurized. When the operating pressure of the fluidic material 1650 within the internal annular recess 1608 c of the deactivation tubular sleeve 1608 is sufficient to overcome the biasing spring force of the deactivation spring 1610, the deactivation tubular sleeve is displaced in a direction 1652. As a result, the spring force provided by the activation spring 1640 then may displace the activation tubular sleeve 1630 in the direction 1652 thereby moving the balls 1632 on the corresponding tapered annular recesses 1628 a of the tubular ball race 1628 outwardly in a radial direction into engagement with the interior surface of the expandable wellbore casing 100. In an exemplary embodiment, the operating pressure of the fluidic material 1650 sufficient to overcome the biasing spring force of the deactivation spring 1610 was about 100 psi.
  • In an exemplary embodiment, when the operating pressure of the fluidic material 1650 is reduced, the operating pressure of the fluidic material 1650 within the internal annular recess 1608 c of the deactivation tubular sleeve 1608 is no longer sufficient to overcome the biasing spring force of the deactivation spring 1610, and the deactivation tubular sleeve and the activation tubular sleeve 1630 are displaced in a direction opposite to the direction 1652 thereby moving the balls 1632 radially inwardly and out of engagement with the interior surface of the expandable wellbore casing 100.
  • In an exemplary embodiment, the ball gripper assembly 16 is operated to engage the interior surface of the expandable wellbore casing 100 in combination with the operation of the tension actuator assembly 18 to apply an upward tensile force to one or more elements of the system 10 coupled to and positioned below the tension actuator assembly. As a result, a reaction force comprising a downward tensile force is applied to the lower mandrel 1634 of the ball gripper assembly 16 in a direction opposite to the direction 1652 during the operation of the tension actuator assembly 18. Consequently, due to the geometry of the tapered 1628 a of the tubular ball race 1628, the balls 1632 are driven up the tapered annular recesses 1628 a of the tubular ball race 1628 with increased force and the contact force between the balls 1632 and the interior surface of the expandable wellbore casing 100 is significantly increased thereby correspondingly increasing the gripping force and effect of the ball gripper assembly.
  • In an exemplary embodiment, the ball gripper assembly 16 may be operated to radially expand and plastically deform discrete portions of the expandable wellbore casing 100 by controlling the amount of contact force applied to the interior surface of the expandable wellbore casing by the balls 1632 of the ball gripper assembly. In an experimental test of an exemplary embodiment of the ball gripper assembly 16, an expandable wellbore casing was radially expanded and plastically deformed. This was an unexpected result.
  • In an exemplary embodiment, the tension actuator assembly 18 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (3) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (4) PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep. 23, 2003, and/or (5) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (6) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (7) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (8) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (9) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 13A1 to 13A8 and 13B1 to 13B7, the tension actuator assembly 18 includes an upper tubular support member 18002 that defines a longitudinal passage 18002 a, and external internally threaded radial openings, 18002 b and 18002 c, and an external annular recess 18002 d and includes an internally threaded connection 18002 e at one end and an external flange 18002 f, an external annular recess 18002 g having an externally threaded connection, and an internal annular recess 18002 h having an internally threaded connection at another end. An end of a tubular actuator barrel 18004 that defines radial passages, 18004 a and 18004 b, at one end and radial passages, 18004 c and 18004 d, includes an internally threaded connection 18004 e at one end that mates with, receives, and is threadably coupled to the external annular recess 18002 g of the upper tubular support member 18002 and abuts and end face of the external flange 18002 f of the upper tubular support member and an internally threaded connection 18004 f at another end.
  • Torsional locking pins, 18006 a and 18006 b, are coupled to and mounted within the external radial mounting holes, 18002 b and 18002 c, respectively, of the upper tubular support member and received within the radial passages, 18004 a and 18004 b, of the end of the tubular actuator barrel 18004. The other end of the tubular actuator barrel 18004 receives and is threadably coupled to an end of a tubular barrel connector 18008 that defines an internal annular recess 18008 a, external radial mounting holes, 18008 b and 18008 c, radial passages, 18008 d and 18008 e, and external radial mounting holes, 18008 f and 18008 g and includes circumferentially spaced apart teeth 18008 h at one end. A sealing cartridge 18010 is received within and coupled to the internal annular recess 18008 a of the tubular barrel connector 18008 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge. Torsional locking pins, 18012 a and 18012 b, are coupled to and mounted within the external radial mounting holes, 18008 b and 18008 c, respectively, of the tubular barrel connector 18008 and received within the radial passages, 18004 c and 18004 d, of the tubular actuator barrel 18004.
  • A tubular member 18014 that defines a longitudinal passage 18014 a having one or more internal splines 18014 b at one end and circumferentially spaced apart teeth 18014 c at another end for engaging the circumferentially spaced apart teeth 18008 h of the tubular barrel connector 18008 mates with and is received within the actuator barrel 18004 and the one end of the tubular member abuts an end face of the other end of the upper tubular support member 18002 and at another end abuts and end face of the tubular barrel connector 18008. A tubular guide member 18016 that defines a longitudinal passage 18016 a having a tapered opening 18016 aa, and radial passages, 18016 b and 18016 c, includes an external flange 18016 d having an externally threaded connection at one end that is received within and coupled to the internal annular recess 18002 h of the upper tubular support member 18002.
  • The other end of the tubular barrel connector 18008 is threadably coupled to and is received within an end of a tubular actuator barrel 18018 that defines a longitudinal passage 18018 a, radial passages, 18018 b and 18018 c, and radial passages, 18018 d and 18018 e. Torsional locking pins, 18020 a and 18020 b, are coupled to and mounted within the external radial mounting holes, 18008 f and 18008 g, respectively, of the tubular barrel connector 18008 and received within the radial passages, 18018 b and 18018 c, of the tubular actuator barrel 18018. The other end of the tubular actuator barrel 18018 receives and is threadably coupled to an end of a tubular barrel connector 18022 that defines an internal annular recess 18022 a, external radial mounting holes, 18022 b and 18022 c, radial passages, 18022 d and 18022 e, and external radial mounting holes, 18022 f and 18022 g. A sealing cartridge 18024 is received within and coupled to the internal annular recess 18022 a of the tubular barrel connector 18022 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge. Torsional locking pins, 18024 a and 18024 b, are coupled to and mounted within the external radial mounting holes, 18022 b and 18022 c, respectively, of the barrel connector 18022 and received within the radial passages, 18018 d and 18018 e, of the tubular actuator barrel 18018.
  • The other end of the tubular barrel connector 18022 is threadably coupled to and is received within an end of a tubular actuator barrel 18026 that defines a longitudinal passage 18026 a, radial passages, 18026 b and 18026 c, and radial passages, 18026 d and 18026 e. Torsional locking pins, 18028 a and 18028 b, are coupled to and mounted within the external radial mounting holes, 18022 f and 18022 g, respectively, of the tubular barrel connector 18022 and received within the radial passages, 18026 b and 18026 c, of the tubular actuator barrel 18026. The other end of the tubular actuator barrel 18026 receives and is threadably coupled to an end of a tubular barrel connector 18030 that defines an internal annular recess 18030 a, external radial mounting holes, 18030 b and 18030 c, radial passages, 18030 d and 18030 e, and external radial mounting holes, 18030 f and 18030 g. A sealing cartridge 18032 is received within and coupled to the internal annular recess 18030 a of the tubular barrel connector 18030 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge. Torsional locking pins, 18034 a and 18034 b, are coupled to and mounted within the external radial mounting holes, 18030 b and 18030 c, respectively, of the tubular barrel connector 18030 and received within the radial passages, 18026 d and 18026 e, of the tubular actuator barrel 18026.
  • The other end of the tubular barrel connector 18030 is threadably coupled to and is received within an end of a tubular actuator barrel 18036 that defines a longitudinal passage 18036 a, radial passages, 18036 b and 18036 c, and radial passages, 18036 d and 18036 e. Torsional locking pins, 18038 a and 18038 b, are coupled to and mounted within the external radial mounting holes, 18030 f and 18030 g, respectively, of the tubular barrel connector 18030 and received within the radial passages, 18036 b and 18036 c, of the tubular actuator barrel 18036. The other end of the tubular actuator barrel 18036 receives and is threadably coupled to an end of a tubular barrel connector 18040 that defines an internal annular recess 18040 a, external radial mounting holes, 18040 b and 18040 c, radial passages, 18040 d and 18040 e, and external radial mounting holes, 18040 f and 18040 g. A sealing cartridge 18042 is received within and coupled to the internal annular recess 18040 a of the tubular barrel connector 18040 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge. Torsional locking pins, 18044 a and 18044 b, are coupled to and mounted within the external radial mounting holes, 18040 b and 18040 c, respectively, of the tubular barrel connector 18040 and received within the radial passages, 18036 d and 18036 e, of the tubular actuator barrel 18036.
  • The other end of the tubular barrel connector 18040 is threadably coupled to and is received within an end of a tubular actuator barrel 18046 that defines a longitudinal passage 18046 a, radial passages, 18046 b and 18046 c, and radial passages, 18046 d and 18046 e. Torsional locking pins, 18048 a and 18048 b, are coupled to and mounted within the external radial mounting holes, 18040 f and 18040 g, respectively, of the tubular barrel connector 18040 and received within the radial passages, 18046 b and 18046 c, of the tubular actuator barrel 18046. The other end of the tubular actuator barrel 18046 receives and is threadably coupled to an end of a tubular barrel connector 18050 that defines an internal annular recess 18050 a, external radial mounting holes, 18050 b and 18050 c, radial passages, 18050 d and 18050 e, and external radial mounting holes, 18050 f and 18050 g. A sealing cartridge 18052 is received within and coupled to the internal annular recess 18050 a of the tubular barrel connector 18050 for fluidicly sealing the interface between the tubular barrel connector and the sealing cartridge. Torsional locking pins, 18054 a and 18054 b, are coupled to and mounted within the external radial mounting holes, 18050 b and 18050 c, respectively, of the tubular barrel connector 18050 and received within the radial passages, 18046 d and 18046 e, of the tubular actuator barrel 18046.
  • The other end of the tubular barrel connector 18050 is threadably coupled to and is received within an end of a tubular actuator barrel 18056 that defines a longitudinal passage 18056 a, radial passages, 18056 b and 18056 c, and radial passages, 18056 d and 18056 e. Torsional locking pins, 18058 a and 18058 b, are coupled to and mounted within the external radial mounting holes, 18050 f and 18050 g, respectively, of the tubular barrel connector 18050 and received within the radial passages, 18056 b and 18056 c, of the tubular actuator barrel 18056. The other end of the tubular actuator barrel 18056 receives and is threadably coupled to an end of a tubular lower stop 18060 that defines an internal annular recess 18060 a, external radial mounting holes, 18060 b and 18060 c, and an internal annular recess 18060 d that includes one or more circumferentially spaced apart locking teeth 18060 e at one end and one or more circumferentially spaced apart locking teeth 18060 f at the other end. A sealing cartridge 18062 is received within and coupled to the internal annular recess 18060 a of the tubular lower stop 18060 for fluidicly sealing the interface between the tubular lower stop and the sealing cartridge. Torsional locking pins, 18064 a and 18064 b, are coupled to and mounted within the external radial mounting holes, 18060 b and 18060 c, respectively, of the tubular lower stop 18060 and received within the radial passages, 18056 d and 18056 e, of the tubular actuator barrel 18056.
  • A connector tube 18066 that defines a longitudinal passage 18066 a and radial mounting holes, 18066 b and 18066 c, and includes external splines 18066 d at one end for engaging the internal splines 18014 b of the tubular member 18014 and radial mounting holes, 18066 e and 18066 f, at another end is received within and sealingly and movably engages the interior surface of the sealing cartridge 18010 mounted within the annular recess 18008 a of the tubular barrel connector 18008. In this manner, during longitudinal displacement of the connector tube 18066 relative to the tubular barrel connector 18008, a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the tubular barrel connector. An end of the connector tube 18066 also receives and mates with the other end of the tubular guide member 18016. Mounting screws, 18068 a and 18068 b, are coupled to and received within the radial mounting holes, 18066 b and 18066 c, respectively of the connector tube 18066.
  • The other end of the connector tube 18066 is received within and threadably coupled to an end of a tubular piston 18070 that defines a longitudinal passage 18070 a, radial mounting holes, 18070 b and 18070 c, radial passages, 18070 d and 18070 e, and radial mounting holes, 18070 f and 18070 g, that includes a flange 18070 h at one end. A sealing cartridge 18072 is mounted onto and sealingly coupled to the exterior of the tubular piston 18070 proximate the flange 18070 h. The sealing cartridge 18072 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18018. In this manner, during longitudinal displacement of the tubular piston 18070 relative to the actuator barrel 18018, a fluidic seal is maintained between the exterior surface of the piston and the interior surface of the actuator barrel. Mounting screws, 18074 a and 18074 b, are coupled to and mounted within the external radial mounting holes, 18070 b and 18070 c, respectively, of the tubular piston 18070 and received within the radial passages, 18066 e and 18066 f, of the connector tube 18066.
  • The other end of the tubular piston 18070 receives and is threadably coupled to an end of a connector tube 18076 that defines a longitudinal passage 18076 a, radial mounting holes, 18076 b and 18076 c, at one end and radial mounting holes, 18076 d and 18076 e, at another end. The connector tube 18076 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18024 mounted within the annular recess 18022 a of the tubular barrel connector 18022. In this manner, during longitudinal displacement of the connector tube 18076 relative to the tubular barrel connector 18022, a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector. Mounting screws, 18078 a and 18078 b, are coupled to and mounted within the external radial mounting holes, 18070 f and 18070 g, respectively, of the tubular piston 18070 and received within the radial passages, 18076 b and 18076 c, of the connector tube 18076.
  • The other end of the connector tube 18076 is received within and threadably coupled to an end of a tubular piston 18080 that defines a longitudinal passage 18080 a, radial mounting holes, 18080 b and 18080 c, radial passages, 18080 d and 18080 e, and radial mounting holes, 18080 f and 18080 g, that includes a flange 18080 h at one end. A sealing cartridge 18082 is mounted onto and sealingly coupled to the exterior of the tubular piston 18080 proximate the flange 18080 h. The sealing cartridge 18082 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18026. In this manner, during longitudinal displacement of the tubular piston 18080 relative to the tubular actuator barrel 18026, a fluidic seal is maintained between the exterior surface of the piston and the interior surface of the actuator barrel. Mounting screws, 18084 a and 18084 b, are coupled to and mounted within the external radial mounting holes, 18080 b and 18080 c, respectively, of the tubular piston 18080 and received within the radial passages, 18076 e and 18076 f, of the connector tube 18076.
  • The other end of the tubular piston 18080 receives and is threadably coupled to an end of a connector tube 18086 that defines a longitudinal passage 18086 a, radial mounting holes, 18086 b and 18086 c, at one end and radial mounting holes, 18086 d and 18086 e, at another end. The connector tube 18086 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18032 mounted within the annular recess 18030 a of the tubular barrel connector 18030. In this manner, during longitudinal displacement of the connector tube 18086 relative to the tubular barrel connector 18030, a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector. Mounting screws, 18088 a and 18088 b, are coupled to and mounted within the external radial mounting holes, 18080 f and 18080 g, respectively, of the tubular piston 18080 and received within the radial passages, 18086 b and 18086 c, of the connector tube 18086.
  • The other end of the connector tube 18086 is received within and threadably coupled to an end of a tubular piston 18090 that defines a longitudinal passage 18090 a, radial mounting holes, 18090 b and 18090 c, radial passages, 18090 d and 18090 e, and radial mounting holes, 18090 f and 18090 g, that includes a flange 18090 h at one end. A sealing cartridge 18092 is mounted onto and sealingly coupled to the exterior of the tubular piston 18090 proximate the flange 18090 h. The sealing cartridge 18092 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18036. In this manner, during longitudinal displacement of the tubular piston 18090 relative to the tubular actuator barrel 18036, a fluidic seal is maintained between the exterior surface of the piston and the interior surface of the actuator barrel. Mounting screws, 18094 a and 18094 b, are coupled to and mounted within the external radial mounting holes, 18090 b and 18090 c, respectively, of the tubular piston 18090 and received within the radial passages, 18086 e and 18086 f, of the connector tube 18086.
  • The other end of the tubular piston 18090 receives and is threadably coupled to an end of a connector tube 18096 that defines a longitudinal passage 18096 a, radial mounting holes, 18096 b and 18096 c, at one end and radial mounting holes, 18096 d and 18096 e, at another end. The connector tube 18096 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18042 mounted within the annular recess 18040 a of the tubular barrel connector 18040. In this manner, during longitudinal displacement of the connector tube 18096 relative to the tubular barrel connector 18040, a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector. Mounting screws, 18098 a and 18098 b, are coupled to and mounted within the external radial mounting holes, 18090 f and 18090 g, respectively, of the tubular piston 18090 and received within the radial passages, 18096 b and 18096 c, of the connector tube 18096.
  • The other end of the connector tube 18096 is received within and threadably coupled to an end of a tubular piston 18100 that defines a longitudinal passage 18100 a, radial mounting holes, 18100 b and 18100 c, radial passages, 18100 d and 18100 e, and radial mounting holes, 18100 f and 18100 g, that includes a flange 18100 h at one end. A sealing cartridge 18102 is mounted onto and sealingly coupled to the exterior of the tubular piston 18100 proximate the flange 18100 h. The sealing cartridge 18102 also mates with and sealingly engages the interior surface of the tubular actuator barrel 18046. In this manner, during longitudinal displacement of the tubular piston 18100 relative to the tubular actuator barrel 18046, a fluidic seal is maintained between the exterior surface of the piston and the interior surface of the actuator barrel. Mounting screws, 18104 a and 18104 b, are coupled to and mounted within the external radial mounting holes, 18100 b and 18100 c, respectively, of the tubular piston 18100 and received within the radial passages, 18096 e and 18096 f, of the connector tube 18096.
  • The other end of the tubular piston 18100 receives and is threadably coupled to an end of a connector tube 18106 that defines a longitudinal passage 18106 a, radial mounting holes, 18106 b and 18106 c, at one end and radial mounting holes, 18106 d and 18106 e, at another end. The connector tube 18106 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18052 mounted within the annular recess 18050 a of the tubular barrel connector 18050. In this manner, during longitudinal displacement of the connector tube 18106 relative to the tubular barrel connector 18050, a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the barrel connector. Mounting screws, 18108 a and 18108 b, are coupled to and mounted within the external radial mounting holes, 18100 f and 18100 g, respectively, of the tubular piston 18100 and received within the radial passages, 18106 b and 18106 c, of the connector tube 18106.
  • The other end of the connector tube 18106 is received within and threadably coupled to an end of a tubular piston 18110 that defines a longitudinal passage 18110 a, radial mounting holes, 18110 b and 18110 c, radial passages, 18110 d and 18110 e, radial mounting holes, 18110 f and 18110 g, that includes a flange 18110 h at one end and circumferentially spaced teeth 18110 i at another end for engaging the one or more circumferentially spaced apart locking teeth 18060 e of the tubular lower stop 18060. A sealing cartridge 18112 is mounted onto and sealingly coupled to the exterior of the tubular piston 18110 proximate the flange 18110 h. The sealing cartridge 18112 also mates with and sealingly engages the interior surface of the actuator barrel 18056. In this manner, during longitudinal displacement of the tubular piston 18110 relative to the actuator barrel 18056, a fluidic seal is maintained between the exterior surface of the piston and the interior surface of the actuator barrel. Mounting screws, 18114 a and 18114 b, are coupled to and mounted within the external radial mounting holes, 18110 b and 18110 c, respectively, of the tubular piston 18110 and received within the radial passages, 18106 d and 18106 e, of the connector tube 18106.
  • The other end of the tubular piston 18110 receives and is threadably coupled to an end of a connector tube 18116 that defines a longitudinal passage 18116 a, radial mounting holes, 18116 b and 18116 c, at one end and radial mounting holes, 18116 d and 18116 e, at another end that includes an external flange 18116 f that includes circumferentially spaced apart teeth 18116 g that extend from an end face of the external flange for engaging the teeth 18060 f of the tubular lower stop 18060, and an externally threaded connection 18116 h at another end. The connector tube 18116 is received within and sealingly and movably engages the interior surface of the sealing cartridge 18062 mounted within the annular recess 18060 a of the lower tubular stop 18060. In this manner, during longitudinal displacement of the connector tube 18116 relative to the lower tubular stop 18060, a fluidic seal is maintained between the exterior surface of the connector tube and the interior surface of the lower tubular stop. Mounting screws, 18118 a and 18118 b, are coupled to and mounted within the external radial mounting holes, 18110 f and 18110 g, respectively, of the tubular piston 18110 and received within the radial passages, 18116 b and 18116 c, of the connector tube 18116.
  • In an exemplary embodiment, as illustrated in FIGS. 13A1 to 13A8, the internally threaded connection 18002 e of the upper tubular support member 18002 receives and is coupled to the externally threaded connection 1234 g of the lower mandrel 1234 of the ball grabber assembly 16 and the externally threaded connection 18116 h of the connector tube 18116 is received within and is coupled to an internally threaded connection 20 a of an end of the safety sub assembly 20.
  • In an exemplary embodiment, as illustrated in FIGS. 13A1 to 13A8, during operation of the tension actuator assembly 18, the tension actuator assembly is positioned within the expandable wellbore casing 100 and fluidic material 18200 is injected into the tension actuator assembly through the passages 18002 a, 18016 a, 18066 a, 18070 a, 18076 a, 18080 a, 18086 a, 18090 a, 18096 a, 18100 a, 18106 a, 18110 a, and 18116 a. The injected fluidic material 18200 will also pass through the radial passages, 18070 d and 18070 e, 18080 d and 18080 e, 18090 d and 18090 e, 18100 d and 18100 e, 18110 d and 18110 e, of the tubular pistons, 18070, 18080, 18090, 18100, and 18110, respectively, into annular piston chambers, 18202, 18204, 18206, 18208, 18208, and 18210.
  • As illustrated in FIGS. 13B1 to 13B7, the operating pressure of the fluidic material 18200 may then be increased by, for example, controllably blocking or limiting the flow of the fluidic material through the passage 18116 a and/or increasing the operating pressure of the outlet of a pumping device for injecting the fluidic material 18200 into the tension actuator assembly 18. As a result, of the increased operating pressure of the fluidic material 18200 within the tension actuator assembly 18, the operating pressures of the annular piston chambers, 18202, 18204, 18206, 18208, 18208, and 18210, will be increased sufficiently to displace the tubular pistons, 18070, 18080, 18090, 18100, and 18110, upwardly in the direction 18212 thereby also displacing the connector tube 18116. As a result, a upward tensile force is applied to all elements of the system 10 coupled to and positioned below the connector tube 18116. In an exemplary embodiment, during the upward displacement of the tubular pistons, 18070, 18080, 18090, 18100, and 18110, fluidic materials displaced by the tubular pistons within discharge annular chambers, 18214, 18216, 18218, 18220, and 18222 are exhausted out of the tension actuator assembly 18 through the radial passages, 18008 d and 18008 e, 18022 d and 18022 e, 18030 d and 18030 e, 18040 d and 18040 e, 18050 d and 18050 e, respectively. Furthermore, in an exemplary embodiment, the upward displacement of the tubular pistons, 18070, 18080, 18090, 18100, and 18110, further causes the external splines 18066 d of the connector tube 18066 to engage the internal splines 18014 b of the tubular member 18014 and the circumferentially spaced apart teeth 18116 g of the connector tube 18116 to engage the circumferentially spaced teeth 18060 f of the tubular lower stop 18060. As a result of the interaction of the external splines 18066 d of the connector tube 18066 to engage the internal splines 18014 b of the tubular member 18014 and the circumferentially spaced apart teeth 18116 g of the connector tube 18116 to engage the circumferentially spaced teeth 18060 f of the tubular lower stop 18060, torsional loads may be transmitted through the tension actuator assembly 18.
  • In an exemplary embodiment, as illustrated in FIG. 14A, the safety sub assembly 20 includes a tubular body 200 a that defines a longitudinal passage 200 b and includes an external flange 200 c and an internal annular recess 200 d at one end, and external annular recesses, 200 e, 200 f, 200 g, and 200 h at another end. A sealing member 202 is positioned within the external annular recess 200 h at the other end of the tubular body 200 a.
  • In an exemplary embodiment, as illustrated in FIGS. 14A, 14B and 14C, the sealing cup assembly 22 includes an upper tubular mandrel 2202 that defines a longitudinal passage 2202 a and internally threaded radial mounting holes, 2202 b and 2202 c, and includes an internal annular recess 2202 d at one end, an internal annular recess 2202 e, an internal annular recess 2202 f, an internal annular recess 2202 g, and an internally threaded internal annular recess 2202 h and an external flange 2202 i at another end. The internal annular recesses, 2202 d, 2202 e, and 2202 f, of the upper tubular mandrel 2202 of the sealing cup assembly 22 receive, mate with, and are coupled to the other end of the tubular body 200 a of the safety sub assembly 20.
  • An externally threaded end of a lower tubular mandrel 2204 that defines a longitudinal passage 2204 a and includes an external annular recess 2204 b at one end, an external annular recess 2204 c, an external flange 2204 d, an external annular recess 2204 e, an externally threaded external flange 2204 f, and an external annular recess 2204 g at another end mates with, is received within, and is coupled to the internal annular recesses, 2202 g and 2202 h, of the other end of the upper tubular mandrel 2202.
  • Mounting screws, 2250 a and 2205 b, are received within and coupled to the mounting holes, 2202 c and 2202 b, respectively, of the tubular mandrel 2202 that extend into and engage the external annular recess 2204 c of the lower tubular mandrel 2204.
  • A tubular cup seal spacer 2206 receives and is mounted upon the lower tubular mandrel 2204 proximate the external flange 2202 i of the upper tubular mandrel 2202. A tubular cup seal retainer 2208 that includes an internal flange 2208 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the tubular cup seal spacer 2206. A tubular cup seal retainer 2210 that includes an internal flange 2210 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2208. In an exemplary embodiment, the tubular cup seal retainer 2210 is nested within the other end of the tubular cup seal retainer 2208. A tubular cup seal 2212 that includes an internal flange 2212 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2210. In an exemplary embodiment, the tubular cup seal 2212 is nested within the other end of the tubular cup seal retainer 2210.
  • A sealing member 2211 is received within the external annular recess 2204 b of the lower tubular mandrel 2204 for sealing the interface between the lower tubular mandrel and the upper tubular mandrel 2202.
  • A tubular spacer 2214 receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal 2212.
  • A tubular cup seal spacer 2216 receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular spacer 2214. A tubular cup seal retainer 2218 that includes an internal flange 2218 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal spacer 2216. A tubular cup seal retainer 2220 that includes an internal flange 2220 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2218. In an exemplary embodiment, the tubular cup seal retainer 2220 is nested within the other end of the tubular cup seal retainer 2218. A tubular cup seal 2222 that includes an internal flange 2222 a at one end receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal retainer 2220. In an exemplary embodiment, the tubular cup seal 2222 is nested within the other end of the tubular cup seal retainer 2220.
  • A tubular spacer 2224 receives and is mounted upon the lower tubular mandrel 2204 proximate the other end of the tubular cup seal 2222 at one end and proximate the external flange 2204 d of the lower tubular mandrel at another end. A retaining ring 2226 receives and is mounted upon the other end of the tubular spacer 2224 proximate the external flange 2204 d of the lower tubular mandrel 2204.
  • In an exemplary embodiment, during operation of the system 10, the end of the tubular body 200 a of the safety sub assembly 20 is coupled to and receives and is coupled to an end of the tension actuator assembly 18 and the other end of the lower tubular mandrel 2204 of the sealing cup assembly 22 is received within and is coupled to an end of the casing lock assembly 24.
  • In an exemplary embodiment, during operation of the system 10, the tubular cup seals, 2212 and/or 2222, sealingly engage the interior surface of the expandable tubular member 100. In this manner, when an annulus defined between the system 10 and the expandable wellbore casing 10, below the tubular cup seals, 2212 and/or 2222, is pressurized, the resulting pressure differential across the tubular cup seals applies an upward tensile force to the system thereby pulling the adjustable bell section expansion cone assembly 28 and/or the adjustable casing expansion cone assembly 30 through the expandable wellbore casing. In this manner, the adjustable bell section expansion cone assembly 28 and/or the adjustable casing expansion cone assembly 30, if either or both are adjusted to an outside diameter suitable for a radial expansion operation, may radially expand and plastically deform the expandable wellbore casing 100.
  • In an exemplary embodiment, the sealing cup assembly 22 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (3) PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, and/or (4) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (5) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (6) PCT patent application serial number PCT/US03/18530, attorney docket number 25791.108.02, filed on Jun. 11, 2003, and/or (7) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (8) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (9) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (10) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (11) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, the casing lock assembly 24 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (3) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (4) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (5) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (6) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (7) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (8) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, the extension actuator assembly 26 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (3) PCT patent application serial number PCT/US03/13787, attorney docket number 25791.107.02, filed on May 5, 2003, and/or (4) PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep. 22, 2003, and/or (5) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (6) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (7) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (8) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2003, and/or (9) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2003, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 15-1, 15-2, 15A1, 15A2, 15B1, 15B2, 15C1, 15C2, 15D, 15E1 to 15E5, 15F1 to 15F5, and 15G1 to 15G5, the extension actuator assembly 26, combines the functionality of the casing lock assembly 24 with the functionality of the extension actuator assembly, and includes a tubular upper tool joint 26002 that defines a longitudinal passage 26002 a and mounting holes, 26002 b and 26002 c, and includes an internal threaded connection 26002 d at one end, an external flange 26002 e, an external recess 26002 f having an external threaded connection, a tapered recess 26002 g, and an external recess 26002 h and an internal recess 26002 i at another end. An end of an upper pull-nut tube 26004 that defines a longitudinal passage 26004 a and includes an external recess 26004 b and an internally threaded internal recess 26004 c at another end is received within and mates with the longitudinal passage 26002 a of the tubular upper tool joint 26002.
  • An externally threaded end of a tubular inner mandrel 26006 that defines a longitudinal passage 26006 a and radial passages, 26006 b, 26006 c, 26006 d, and 26006 e, and includes an externally threaded connection 26006 f at another end mates with, is received within, and is coupled to the internally threaded recess 26004 c of the upper pull-nut tube 26004. An internally threaded end of an lower pull-nut tube 26008 that defines a longitudinal passage 26008 a and includes an external recess 26008 b receives, mates with, and is coupled to externally threaded connection 26006 f of the tubular inner mandrel 26006.
  • An internal flange 26010 a of an end of a tubular lock mandrel 26010 that defines a longitudinal passage 26010 b, radial passages, 26010 c and 26010 d, a radial passage 26010 e, and a radial passage 26010 f having an internal annular recess 26016 fa and includes an external flange 26010 g that mates with and is received within the internal recess 26002 i of the tubular upper tool joint 26002, an external annular recess 26010 h, an external flange 26010 i, an external flange 26010 j, an external flange 26010 k, an external flange 26010 l, an external flange 26010 m that includes an external annular recess 26010 ma, an external flange 26010 n that defines mounting holes, 26010 o and 26010 p, an external annular recess 26010 q, an external annular recess 26010 r, and a tapered annular recess 26010 s at another end receives and mates with the tubular inner mandrel 26006. Internal flanges, 26012 a and 26012 b, of a first locking dog 26012 that defines a radial passage 26012 c and includes spring arms, 26012 d and 26012 e, and an external flange 26012 f including external teeth 26012 g are positioned upon the external flanges, 26010 i and 26010 j, of the tubular lock mandrel 26010. Internal flanges, 26014 a and 26014 b, of a second locking dog 26014 that defines a radial passage 26014 c and includes spring arms, 26014 d and 26014 e, and an external flange 26014 f including external teeth 26014 g are positioned upon the external flanges, 26010 i and 26010 j, of the tubular lock mandrel 26010.
  • An internally threaded end of a tubular retainer sleeve 26016 that defines a longitudinal passage 26016 a, radial passages, 26016 b and 26016 c, at one end, radial passages, 26016 d and 26016 e, for receiving and mating with the external flanges, 26012 f and 26014 f, respectively, of the first and second locking dogs, 26012 and 26014, respectively, and radial passages, 26016 f and 26016 g, at another end and includes a tapered internal flange 26016 h, a tapered internal recess 26016 i that receives and mates with the spring arms, 26012 d and 26014 d, and ends of the first and second locking dogs, respectively, a tapered internal recess 26016 j that receives and mates with the springs arms, 26012 e and 26014 e, and other ends of the first and second locking dogs, respectively, a tapered internal flange 26016 k, and an internal threaded connection 26016 l at another end receives, mates with, and is coupled to the externally threaded connection 26002 f of the end of the tubular upper tool joint 26002. The ends of the spring arms, 26012 d and 26014 d, of the first and second locking dogs, 26012 and 26014, respectively, are held between the internal surface of the end of the tapered internal recess 26016 l of the tubular retainer sleeve 26016 and the external surface of the end of the tapered external annular recess 26002 h of the tubular upper tool joint 26002.
  • An externally threaded connection 26018 a of an end of a tubular connector 26018 that defines mounting holes, 26018 a and 26018 b, and mounting holes, 26018 c and 26018 d, and includes a tapered external annular recess 26018 e at one end, an external annular recess 26018 f and an external annular recess 26018 g at another end is received within, mates with, and is coupled to the internal threaded connection 26016 l of the end of the tubular retainer sleeve 26016. The ends of the spring arms, 26012 e and 26014 e, of the first and second locking dogs, 26012 and 26014, respectively, are held between the internal surface of the end of the tapered internal recess 26016 j of the tubular retainer sleeve 26016 and the external surface of the end of the tapered external annular recess 26018 e of the tubular connector 26018.
  • A sealing member 26020 is received within the external annular recess 26010 h of the tubular lock mandrel 26010 for sealing the interface between the tubular lock mandrel and the tubular upper tool joint 26002. A sealing member 26022 is received within the external annular recess 26010 q of the tubular lock mandrel 26010 for sealing the interface between the tubular lock mandrel and the tubular connector 26018.
  • A tubular face seal 26024, tubular face seal back-up 26026, a spring 26028, and a plunger 26030 are mounted upon and retained upon the external annular recess 26018 g of the tubular connector 26018 by a snap ring 26032 that is coupled to the external annular recess of the tubular connector. A burst disk 26034 and tubular burst disk bushing 26036 are mounted within the radial passage 26010 f of the tubular lock mandrel 26010, and a sealing member 26038 is received within the internal annular recess 26010 fa of the radial passage of the tubular lock mandrel for sealing the interface between the tubular burst disk bushing and the tubular lock mandrel.
  • An internally threaded end 26040 a of a tubular release body 26040 that defines a longitudinal passage 26040 b, radial passages, 26040 c and 26040 d, radial mounting holes, 26040 e and 26040 f, radial mounting holes, 26040 g and 26040 h, and includes an internal flange 26040 i that mates with and receives the external flange 26010 n of the tubular lock mandrel 26010, an internal flange 26040 j that mates with and receives the tubular lock mandrel receives, and an external annular recess 26040 k mates with, and is coupled to an externally threaded end 26018 h of the tubular connector 26018. A sealing member 26042 received within the external annular recess 26018 f of the tubular connector 26018 seals the interface between the tubular connector and the tubular release body 26040. A sealing member 26044 received within the external annular recess 26010 ma of the tubular lock mandrel 26010 seals the interface between the tubular lock mandrel and the tubular release body 26040. Shear pins, 26046 a and 26046 b, are received within and coupled to the radial mounting holes, 26010 o and 26040 e, and 26010 p and 26040 f, respectively, of the tubular lock mandrel 26010 and tubular release body 26040, respectively. Torque pins, 26048 a and 26048 b, are received within and coupled to the radial mounting holes, 26018 c and 26018 d, respectively, of the tubular connector 26018 that also extend into the radial passages, 26040 c and 26040 d, respectively, of the tubular release body 26040. A sealing member 26050 received within the external annular recess 26010 r of the tubular lock mandrel 26010 seals the interface between the tubular lock mandrel and the internal flange 26040 j of the tubular release body 26040.
  • An internally threaded end 26052 a of a tubular extender barrel 26052 that defines a longitudinal passage 26052 b, radial passages, 26052 c and 26052 d, and radial passages, 26052 e and 26052 f, and includes receives, mates with, and is coupled to an external threaded connection 26040 l of the tubular release body 26040. A sealing member 26054 received within the external annular recess 26040 k of the tubular release body 26040 seals the interface between the tubular release body and the tubular extender barrel 26052.
  • An external threaded connection 26056 a of an end of a tubular lower bushing 26056 that defines a longitudinal passage 26056 b and mounting holes, 26056 c and 26056 d, and includes an internal annular recess 26056 e, an internal annular recess 26056 f, a plurality of circumferentially spaced apart teeth 26056 g at one end, a plurality of circumferentially spaced apart teeth 26056 h at another end, and an external annular recess 26056 i is received within, mates with, and is coupled to an internal threaded connection 26052 m of the tubular extender barrel 26052. Torque pins, 26058 a and 26058 b, are mounted within and coupled to the mounting holes, 26056 c and 26056 d, respectively, of the tubular lower bushing 26056 that also extend into the radial passages, 26052 e and 26052 f, respectively, of the tubular extender barrel 26052.
  • A tubular connecting rod 26060 that defines a longitudinal passage 26060 a that receives and mates with the lower pull-nut tube 26008, radial passages, 26060 b and 26060 c, and radial mounting holes, 26060 d and 26060 e, and includes an external threaded connection 26060 f at one end, and an external threaded connection 26060 g at another end is slidably received within the longitudinal passage 25056 b of the tubular lower bushing 26056. An internal threaded connection 26062 a of an inner mandrel tubular piston 26062 that defines mounting holes, 26062 b and 26062 c, and includes an internal flange 26062 d at one end that receives and mates with the tubular inner mandrel 26006, an external annular recess 26062 e, and a plurality of circumferentially spaced apart teeth 26062 f at another end receives, mates with, and is coupled to the external threaded connection 26060 f of the tubular connecting rod 26060.
  • Torque screws, 26064 a and 26064 b, are mounted within and coupled to the mounting holes, 26062 b and 26062 c, respectively, of the inner mandrel tubular piston 26062 that also extend into the radial passages, 26060 b and 26060 c, of the tubular connecting rod 26060. A sealing member 26066 positioned within the external annular recess 26062 e of the inner mandrel tubular piston 26062 seals the interface between the inner tubular piston and the tubular extender barrel 26052. A sealing member 26068 positioned within the external annular recess 26056 i of the tubular lower bushing 26056 seals the interface between the tubular lower bushing and the tubular extender barrel 26052.
  • A packing sealing element 26070 is received within the internal annular recess 25056 f of the tubular lower bushing 26056, and a packing retainer 26072 is received within the internal annular recess 26056 e of the tubular lower bushing for sealing the interface between the tubular lower bushing and the tubular connecting rod 26060. The packing sealing element 26070 and the packing retainer 26072 are retained within the internal annular recess 25056 f of the tubular lower bushing 26056 and internal annular recess 26056 e of the tubular lower bushing, respectively, by a snap ring 26074 that is coupled to the tubular connecting rod 26060.
  • An internally threaded connection 26076 a of a tubular lower tool joint 26076 that defines a longitudinal passage 26076 b, radial mounting holes, 26076 c and 26076 d, and radial mounting holes, 26076 e and 26076 f, and includes an internal annular recess 26076 g and an external annular recess 26076 h receives, mates with, and is coupled to an external threaded connection 26060 g of the tubular connecting rod 26060. Torque screws, 26078 a and 26078 b, are mounted within and coupled to the mounting holes, 26076 c and 26076 d, respectively, of the tubular lower tool joint 26076 that also extend into the radial passages, 26060 d and 26060 e, of the tubular connecting rod 26060. A sealing member 26080 is received within the internal annular recess 26076 g of the tubular lower tool joint 26076 for sealing the interface between the tubular lower tool joint and the tubular connecting rod 26060.
  • In an exemplary embodiment, during operation of the extension actuator assembly 26, as illustrated in FIGS. 15E1 to 15E5, the extension actuator assembly is positioned within the wellbore 102, the internal threaded connection 26002 d of the tubular upper tool joint 26002 receives, mates with, and is coupled to an end of the sealing cup assembly 22, and the end of the tubular lower tool joint 26076 is received within, mates with, and is coupled to an end of the adjustable bell section expansion cone assembly 28. In an exemplary embodiment, a portion 100 a of the expandable wellbore casing 100 includes internal teeth 100 b that engage with, and are coupled to, the external teeth, 26012 g and 26014 g, of the first and second locking dogs, 26012 and 26014, respectively. In this manner, the expandable wellbore casing 100 is locked to the extension actuator assembly 26 of the system 10.
  • In an exemplary embodiment, during the operation of the extension actuator assembly 26, a fluidic material 26100 may then be injected into the extension actuator assembly through the longitudinal passages 26004 a, 26006 a, and 26008 a of the upper pull-nut tube 26004, tubular inner mandrel 26006, and lower pull-nut tube 26008, respectively, thereby pressurizing the longitudinal passages of the upper pull-nut tube, tubular inner mandrel, and lower pull-nut tube. As a result, the fluidic material 26100 is also conveyed through the radial passage 26006 c of the tubular inner mandrel 26006 into and through an annulus 26102 defined between the tubular inner mandrel and the tubular lock mandrel 26010. The fluidic material 26100 is then conveyed into an annulus 26104 defined between the tubular inner mandrel 26006 and the tubular extender barrel 26052 proximate an end face of the inner mandrel tubular piston 26062.
  • In an exemplary embodiment, as illustrated in FIGS. 15F1 to 15F5, the continued injection of the fluidic material 26100 into the extension actuator assembly 26 will then displace the inner mandrel tubular piston 26062 downwardly in a direction 26106. As a result, the tubular connecting rod 26060 and the tubular lower tool joint 26076 are also displaced downwardly in the direction 26106.
  • In an exemplary embodiment, as illustrated in FIGS. 15G1 to 15G5, the continued injection of the fluidic material 26100 into the extension actuator assembly 26 will then further displace the inner mandrel tubular piston 26062 downwardly in the direction 26106 until an end face of the inner flange 26062 d of the inner mandrel tubular piston engages an end face of the lower pull-nut tube 26008. As a result, the lower pull-nut tube 26008, the tubular inner mandrel 26006, the upper pull-nut tube 26004, and the tubular lock mandrel 26010 are also displaced downwardly in the direction 26106 thereby shearing the shear pins, 26064 a and 26064 b, and disengaging the tubular lock mandrel from the tubular release body 26040.
  • The continued injection of the fluidic material 26100 into the extension actuator assembly 26 will then further displace the tubular lock mandrel 26010 downwardly in the direction 26106 thereby displacing the external flanges, 26010 i and 26010 j, of the tubular lock mandrel out of engagement with the internal flanges, 26012 a and 26012 b, and 26014 a and 26014 b, of the first and second locking dogs, 26012 and 26014, respectively. As a result, a spring bias force in an inner radial direction is applied by the spring arms, 26012 d and 26012 e, and 26014 d and 26014 e, of the first and second locking dogs, 26012 and 26014, respectively, to the first and second locking dogs thereby displacing the first and second locking dogs in an inner radial direction out of engagement with the portion 100 a of the expandable wellbore casing 100. As a result, the expandable wellbore casing 100 is no longer locked to the first and second locking dogs, 26012 and 26014, of the extension actuator assembly 26.
  • In an exemplary embodiment, during operation of the extension actuator assembly 26, the expandable wellbore casing 100 may also be un-locked from engagement with the first and second locking dogs, 26012 and 26014, of the extension actuator assembly by increasing the operating pressure of the fluidic material 26100 above a predetermined level sufficient to rupture the burst disk 26034. As a result, the fluidic material 26100 will enter an annulus 26108 defined between the tubular lock mandrel 26010 and the tubular release body 26040. As a result, the tubular lock mandrel 26010 will be displaced downwardly in the direction 26106 thereby displacing the external flanges, 26010 i and 26010 j, of the tubular lock mandrel out of engagement with the internal flanges, 26012 a and 26012 b, and 26014 a and 26014 b, of the first and second locking dogs, 26012 and 26014, respectively. As a result, a spring bias force in an inner radial direction is applied by the spring arms, 26012 d and 26012 e, and 26014 d and 26014 e, of the first and second locking dogs, 26012 and 26014, respectively, to the first and second locking dogs thereby displacing the first and second locking dogs in an inner radial direction out of engagement with the portion 100 a of the expandable wellbore casing 100. As a result, the expandable wellbore casing 100 is no longer locked to the first and second locking dogs, 26012 and 26014, of the extension actuator assembly 26. In an exemplary embodiment, the predetermined operating pressure of the fluidic material 26100 sufficient to rupture the burst disk 26034 is selected to provide a release of the expandable wellbore casing 100 from engagement with the first and second locking dogs, 26012 and 26104, in the event of an emergency operating condition during the operation of the system 10.
  • In an exemplary embodiment, the pressurization of the longitudinal passages 26004 a, 26006 a, and 26008 a of the upper pull-nut tube 26004, tubular inner mandrel 26006, and lower pull-nut tube 26008, respectively, caused by the injection of the fluidic material 26100 may be further enhanced by blocking the flow of the fluidic material to those portions of the system 10 downstream from the extension actuator assembly 26 by, for example, blocking flow through a flow restriction defined in one or more of the elements of the system downstream of the extension actuator assembly by placing a ball or plug in one or more of those flow restrictions.
  • In an exemplary embodiment, the adjustable bell section expansion cone assembly 28 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (3) PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, and/or (4) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (5) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (6) PCT patent application serial number PCT/US03/18530, attorney docket number 25791.108.02, filed on Jun. 11, 2003, and/or (7) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (8) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (9) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (10) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (11) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 16-1 and 16-2, 16A1 to 16A2, 16B1 to 16B2, 16C, 16D, 16E, 16F, 16G, 16H, 16I, 16 j, 16K, 16L, 16M, 16N, 16O, 16P, 16R, 16S, 16T, 16U, 16V, 16W, 16 x, 16Y, 16Z1 to 16Z4, 16AA1 to 16AA4, 16AB1 to 16AB4, 16AC1 to 16AC4, 16AD, and 16AE, the adjustable bell section expansion cone assembly 28 includes an upper tubular tool joint 28002 that defines a longitudinal passage 28002 a and mounting holes, 28002 b and 28002 c, and includes an internal threaded connection 28002 d, an inner annular recess 28002 e, an inner annular recess 28002 f, and an internal threaded connection 28002 g. A tubular torque plate 28004 that defines a longitudinal passage 28004 a and includes circumferentially spaced apart teeth 28004 b is received within, mates with, and is coupled to the internal annular recess 28002 e of the upper tubular tool joint 28002.
  • Circumferentially spaced apart teeth 28006 a of an end of a tubular lower mandrel 28006 that defines a longitudinal passage 28006 b, a radial passage 28006 ba, and a radial passage 28006 bb and includes an external threaded connection 28006 c, an external flange 28006 d, an external annular recess 28006 e having a step 28006 f at one end, an external annular recess 28006 g, external teeth 28006 h, an external threaded connection 28006 i, and an external annular recess 28006 j engage the circumferentially spaced apart teeth 28004 b of the tubular torque plate 28004. An internal threaded connection 28008 a of an end of a tubular toggle bushing 28008 that defines a longitudinal passage 28008 b, an upper longitudinal slot 28008 c, a lower longitudinal slot 28008 d, mounting holes, 28008 e, 28008 f, 28008 g, 28008 h, 28008 i, 28008 j, 28008 k, 28008 l, 28008 m, 28008 n, 28008 o, 28008 p, 28008 q, 28008 r, 28008 s, 28008 t, 28008 u, 28008 v, 28008 w, 28008 x, 28008 xa, and 28008 xb, and includes an external annular recess 28008 y, internal annular recess 28008 z, external annular recess 28008 aa, and an external annular recess 28008 ab receives and is coupled to the external threaded connection 28006 c of the tubular lower mandrel 28006.
  • A sealing element 28010 is received within the external annular recess 28008 y of the tubular toggle bushing 28008 for sealing the interface between the tubular toggle bushing and the upper tubular tool joint 28002. A sealing element 28012 is received within the internal annular recess 28008 z of the tubular toggle bushing 28008 for sealing the interface between the tubular toggle bushing and the tubular lower mandrel 28006.
  • Mounting screws, 28014 a and 28014 b, mounted within and coupled to the mounting holes, 28008 w and 28008 x, respectively, of the tubular toggle bushing 28008 are also received within the mounting holes, 28002 b and 28002 c, of the upper tubular tool joint 28002. Mounting pins, 28016 a, 28016 b, 28016 c, 28016 d, and 28016 e, are mounted within the mounting holes, 28008 e, 28008 f, 28008 g, 28008 h, and 28008 l, respectively. Mounting pins, 28018 a, 28018 b, 28018 c, 28018 d, and 28018 e, are mounted within the mounting holes, 28008 t, 28008 s, 28008 r, 28008 q, and 28008 p, respectively. Mounting screws, 28020 a and 28020 b, are mounted within the mounting holes, 28008 u and 28008 v, respectively.
  • A first upper toggle link 28022 defines mounting holes, 28022 a and 28022 b, for receiving the mounting pins, 28016 a and 28016 b, and includes a mounting pin 28022 c at one end. A first lower toggle link 28024 defines mounting holes, 28024 a, 28024 b, and 28024 c, for receiving the mounting pins, 28022 c, 28016 c, and 28016 d, respectively and includes an engagement arm 28024 d. A first trigger 28026 defines a mounting hole 28026 a for receiving the mounting pin 28016 e and includes an engagement arm 28026 b at one end, an engagement member 28026 c, and an engagement arm 28026 d at another end.
  • A second upper toggle link 28028 defines mounting holes, 28028 a and 28028 b, for receiving the mounting pins, 28018 a and 28018 b, and includes a mounting pin 28028 c at one end. A second lower toggle link 28030 defines mounting holes, 28030 a, 28030 b, and 28030 c, for receiving the mounting pins, 28028 c, 28018 c, and 28018 d, respectively and includes an engagement arm 28030 d. A second trigger 28032 defines a mounting hole 28032 a for receiving the mounting pin 28018 e and includes an engagement arm 28032 b at one end, an engagement member 28032 c, and an engagement arm 28032 d at another end.
  • An end of a tubular spring housing 28034 that defines a longitudinal passage 28034 a, mounting holes, 28034 b and 28034 c, and mounting holes, 28034 ba and 28034 ca, and includes an internal flange 28034 d and an internal annular recess 28034 e at one end, and an internal flange 28034 f, an internal annular recess 28034 g, an internal annular recess 28034 h, and an external threaded connection 28034 i at another end receives and mates with the end of the tubular toggle bushing 28008. Mounting screws, 28035 a and 28035 b, are mounted within and coupled to the mounting holes, 28008 xb and 28008 xa, respectively, of the tubular toggle bushing 28008 and are received within the mounting holes, 28034 ba and 28034 ca, respectively, of the tubular spring housing 28034.
  • A tubular retracting spring ring 28036 that defines mounting holes, 28036 a and 28036 b, receives and mates with a portion of the tubular lower mandrel 28006 and is received within and mates with a portion of the tubular spring housing 28034. Mounting screws, 28038 a and 28038 b, are mounted within and coupled to the mounting holes, 28036 a and 28036 b, respectively, of the tubular retracting spring ring 28036 and extend into the mounting holes, 28034 b and 28034 c, respectively, of the tubular spring housing 28034.
  • Casing diameter sensor springs, 28040 a and 28040 b, are positioned within the longitudinal slots, 28008 c and 2808 d, respectively, of the tubular toggle bushing 28008 that engage the engagement members, 28026 c and 28032 c, and engagement arms, 28026 d and 28032 d, of the first and second triggers, 28026 and 28032, respectively. An inner flange 28042 a of an end of a tubular spring washer 28042 mates with and receives a portion of the tubular lower mandrel 28006 and an end face of the inner flange of the tubular spring washer is positioned proximate and end face of the external flange 28006 d of the tubular lower mandrel. The tubular spring washer 28042 is further received within the longitudinal passage 28034 a of the tubular spring housing 28034.
  • An end of a retracting spring 28044 that receives the tubular lower mandrel 28006 is positioned within the tubular spring washer 28042 in contact with the internal flange 28042 a of the tubular spring washer and the other end of the retracting spring is positioned in contact with an end face of the tubular retracting spring ring 28036.
  • A sealing element 28046 is received within the external annular recess 28006 j of the tubular lower mandrel 28006 for sealing the interface between the tubular lower mandrel and the tubular spring housing 28034. A sealing element 28048 is received within the internal annular recess 28034 h of the tubular spring housing 28034 for sealing the interface between the tubular spring housing and the tubular lower mandrel 28006.
  • An internal threaded connection 28050 a of an end of a tubular upper hinge sleeve 28050 that includes an internal flange 28050 b and an internal pivot 28050 c receives and is coupled to the external threaded connection 28034 i of the end of the tubular spring housing 28034.
  • An external flange 28052 a of a base member 28052 b of an upper cam assembly 28052, that is mounted upon and receives the lower tubular mandrel 28006, that includes an internal flange 28052 c that is received within the external annular recess 28006 e of the lower tubular mandrel 28006 and a plurality of circumferentially spaced apart tapered cam arms 28052 d extending from the base member mates with and is received within the tubular upper hinge sleeve 28050. The base member 28052 b of the upper cam assembly 28052 further includes a plurality of circumferentially spaced apart teeth 28052 f that mate with and are received within a plurality of circumferentially spaced apart teeth 28034 j provided on the end face of the tubular spring housing 28034 and an end face of the external flange 28052 a of the base member of the upper cam assembly is positioned in opposing relation to an end face of the internal flange 28050 b of the tubular upper hinge sleeve 28050. Each of the cam arms 28052 d of the upper cam assembly 28052 include external cam surfaces 28052 e. In an exemplary embodiment, the teeth 28052 f of the base member 28052 b of the upper cam assembly 28052 and the teeth 28034 j provided on the end face of the tubular spring housing 28034 permit torsional loads to be transmitted between the tubular spring housing and the upper cam assembly.
  • A plurality of circumferentially spaced apart upper expansion segments 28054 are mounted upon and receive the lower tubular mandrel 28006 and each include an external pivot recess 28054 a at one end for mating with and receiving the internal pivot 28050 c of the tubular upper hinge sleeve 28050 and an external tapered expansion surface 28054 b at another end and are pivotally mounted within the tubular upper hinge sleeve and are interleaved with the circumferentially spaced apart cam arms 28052 d of the upper cam assembly 28052. The upper expansion segments 28054 are interleaved among the cam arms 28052 d of the upper cam assembly 28052.
  • A plurality of circumferentially spaced apart lower expansion segments 28058 are mounted upon and receive the lower tubular mandrel 28006, are interleaved among the upper expansion segments 28054, are oriented in the opposite direction to the upper expansion segments 28054, each include an external pivot recess 28058 a at one end and an external tapered expansion surface 28054 b at another end and are positioned in opposing relation to corresponding circumferentially spaced apart cam arms 28052 d of the upper cam assembly 28052.
  • A lower cam assembly 28060 is mounted upon and receives the lower tubular mandrel 28006 that includes a base member 28060 a having an external flange 28060 b, a plurality of circumferentially spaced apart cam arms 28060 d that extend from the base member that each include external cam surfaces 28060 e and define mounting holes 28060 f and 28060 g. The base member 28060 a of the lower cam assembly 28060 further includes a plurality of circumferentially spaced apart teeth 28060 h. The circumferentially spaced apart cam arms 28060 d of the lower cam assembly 28060 are interleaved among the lower expansion segments 28058 and the circumferentially spaced apart cam arms 28052 d of the upper cam assembly 28052 and positioned in opposing relation to corresponding upper expansion segments 28054.
  • Mounting screws, 28062 a, 28062 b, 28062 c, and 28062 e, are mounted within the corresponding mounting holes, 28060 f and 28060 g, of the lower cam assembly 28060 and are received within the external annular recess 28006 g of the lower cam assembly 28060.
  • A tubular lower hinge sleeve 28064 that receives the lower expansion segments 28058 and the lower cam assembly 28060 includes an internal flange 28064 a for engaging the external flange 28060 b of the base member of the lower cam assembly 28060, an internal pivot 28064 b for engaging and receiving the external pivot recess 28058 a of the lower expansion segments 28058 thereby pivotally mounting the lower expansion segments within the tubular lower hinge sleeve, and an internal threaded connection 28064 c.
  • An external threaded connection 28066 a of an end of a tubular sleeve 28066 that defines mounting holes, 28066 b and 28066 c, and includes an internal annular recess 28066 d having a shoulder 28066 e, an internal flange 28066 f, and an internal threaded connection 28066 g at another end is received within and coupled to the internal threaded connection 28064 c of the tubular lower hinge sleeve 28064. An external threaded connection 28068 a of an end of a tubular member 28068 that defines a longitudinal passage 28068 b and mounting holes, 28068 c and 28068 d, and includes an external annular recess 28068 e, and an external threaded connection 28068 f at another end is received within and is coupled to the internal threaded connection 28066 g of the tubular sleeve 28066.
  • Mounting screws, 28070 a and 28070 b, are mounted in and coupled to the mounting holes, 28068 c and 28068 d, respectively, of the tubular member 28068 that also extend into the mounting holes, 28066 b and 28066 c, respectively, of the tubular sleeve 28066. A sealing element 28072 is received within the external annular recess 28068 e of the tubular member 28068 for sealing the interface between the tubular member and the tubular sleeve 28066.
  • An internal threaded connection 28074 a of a tubular retracting piston 28074 that defines a longitudinal passage 28074 b and includes an internal annular recess 28074 c and an external annular recess 28074 d receives and is coupled to the external threaded connection 28006 i of the tubular lower mandrel 28006. A sealing element 28076 is received within the external annular recess 28074 d of the tubular retracting piston 28074 for sealing the interface between the tubular retracting piston and the tubular sleeve 28066. A sealing element 28078 is received within the internal annular recess 28074 c of the tubular retracting piston 28074 for sealing the interface between the tubular retracting piston and the tubular lower mandrel 28006.
  • Locking dogs 28080 mate with and receive the external teeth 28006 h of the tubular lower mandrel 28006. A spacer ring 28082 is positioned between an end face of the locking dogs 28080 and an end face of the lower cam assembly 28060. A release piston 28084 mounted upon the tubular lower mandrel 28006 defines a radial passage 28084 a for mounting a burst disk 28086 includes sealing elements, 28084 b, 28084 c, and 28084 d. The sealing elements, 28084 b and 28084 d, sealing the interface between the release piston 28084 and the tubular lower mandrel 28006. An end face of the release piston 28084 is positioned in opposing relation to an end face of the locking dogs 28080.
  • A release sleeve 28088 that receives and is mounted upon the locking dogs 28080 and the release piston 28084 includes an internal flange 28088 a at one end that sealingly engages the tubular lower mandrel 28006. A bypass sleeve 28090 that receives and is mounted upon the release sleeve 28088 includes an internal flange 28090 a at one end.
  • In an exemplary embodiment, during operation of the adjustable bell section expansion cone assembly 28, the retracting spring 28044 is compressed and thereby applies a biasing spring force in a direction 28092 from the lower tubular mandrel 28006 to the tubular spring housing 28034 that, in the absence of other forces, moves and/or maintains the upper cam assembly 28052 and the upper expansion segments 28054 out of engagement with the lower expansion segments 28058 and the lower cam assembly 28060. In an exemplary embodiment, during operation of the adjustable bell section expansion cone assembly 28, an external threaded connection 26 a of an end of the extension actuator assembly 26 is coupled to the internal threaded connection 28002 d of the upper tubular tool joint 28002 and an internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 is coupled to the external threaded connection 28068 f of the tubular member 28068.
  • The upper cam assembly 28052 and the upper expansion segments 28054 may be brought into engagement with the lower expansion segments 28058 and the lower cam assembly 28060 by pressurizing an annulus 28094 defined between the lower tubular mandrel 28006 and the tubular spring housing 28034. In particular, injection of fluidic materials into the adjustable bell section expansion cone assembly 28 through the longitudinal passage 28006 b of the lower tubular mandrel 28006 and into the radial passage 28006 ba may pressurize the annulus 28094 thereby creating sufficient operating pressure to generate a force in a direction 28096 sufficient to overcome the biasing force of the retracting spring 28044. As a result, the spring housing 28034 may be displaced in the direction 28096 relative to the lower tubular mandrel 28006 thereby displacing the tubular upper hinge sleeve 28050, upper cam assembly 28052, and upper expansion segments 28054 in the direction 28096.
  • In an exemplary embodiment, as illustrated in FIGS. 16P and 16R, the displacement of the upper cam assembly 28052 and upper expansion segments 28054 in the direction 28096 will cause the lower expansion segments 28058 to ride up the cam surfaces 28052 e of the cam arms 28052 d of the upper cam assembly 28052 while also pivoting about the lower tubular hinge segment 28064, and will also cause the upper expansion segments 28054 to ride up the cam surfaces 28060 e of the cam arms 28060 d of the lower cam assembly 28060 while also pivoting about the upper tubular hinge segment 28050. In an exemplary embodiment, when the upper and lower expansion segments, 28054 and 28058, are brought into axial alignment, they define an outer expansion surface that is approximately contiguous in a circumferential direction and which provides an outer expansion surface that at least approximates a conical surface.
  • In an exemplary embodiment, during the operation of the adjustable bell section expansion cone assembly 28, when the upper and lower expansion segments, 28054 and 28058, brought into axial alignment into a radially expanded position, the upper and lower expansion segments, 28054 and 28058, are displaced relative to the expandable wellbore casing 100 to thereby radially expand and plastically deform at least a portion of the expandable wellbore casing. In an exemplary embodiment, during the radial expansion and plastic deformation of the expandable wellbore casing 100, the adjustable bell section expansion cone assembly 28 may then be rotated relative to the expandable wellbore casing to enhance and/or modify the rate at which the expandable wellbore casing is radially expanded and plastically deformed.
  • In an exemplary embodiment, the upper cam assembly 28052 and the upper expansion segments 28054 may be moved out of engagement with the lower expansion segments 28058 and the lower cam assembly 28060 by reducing the operating pressure within the annulus 28094.
  • In an alternative embodiment, as illustrated in FIGS. 16S, 16T, 16U and 16V, during operation of the adjustable bell section expansion cone assembly 28, the upper cam assembly 28052 and the upper expansion segments 28054 may also be moved out of engagement with the lower expansion segments 28058 and the lower cam assembly 28060 by sensing the operating pressure within the longitudinal passage 28006 b of the lower tubular mandrel 28006. In particular, as illustrated in FIG. 16T, if the operating pressure within the longitudinal passage 28006 b and radial passage 28006 bb of the lower tubular mandrel 28006 exceeds a predetermined value, the burst disc 28086 will open the passage 28084 a thereby pressurizing the interior of the tubular release sleeve 28088 thereby displacing the tubular release sleeve 28088 downwardly in a direction 28092 away from engagement with the locking dogs 28080.
  • As a result, as illustrated in FIG. 16U, the locking dogs 28080 are displaced outwardly in the radial directed and thereby released from engagement with the lower tubular mandrel 28006 thereby permitting the lower expansion segments 28058 and the lower cam assembly 28060 to be displaced downwardly relative to the lower tubular mandrel.
  • As a result, as illustrated in FIG. 16V, the operating pressure within the lower tubular mandrel 28066 may then cause the lower tubular mandrel to be displaced downwardly in the direction 28094 relative to the tubular lower mandrel 28006 and the retracting piston 28074. As a result, the lower tubular mandrel 28066, the lower expansion segments 28058, the lower cam assembly 28060, and tubular lower hinge sleeve 28064 are displaced downwardly in the direction 28094 relative to the tubular spring housing 28034 thereby moving the lower expansion segments 28058 and the lower cam assembly 28060 out of engagement with the upper cam assembly 28052 and the upper expansion segments 28054.
  • In an exemplary embodiment, as illustrated in FIGS. 16W, 16X, and 16Y, during operation of the adjustable bell section expansion cone assembly 28, the adjustable bell section expansion cone assembly senses the diameter of the expandable wellbore casing 100 using the upper toggle links, 28022 and 28028, lower toggle links, 28024 and 28030, and triggers, 28026 and 28032, and then prevents the engagement of the upper cam assembly 28052 and the upper expansion segments 28054 with the lower expansion segments 28058 and the lower cam assembly 28060.
  • In particular, as illustrated in FIG. 16W, anytime the upper toggle links, 28022 and 28028, and lower toggle links, 28024 and 28030, are positioned within a portion of the expandable wellbore casing 100 that has been radially expanded and plastically deformed by the system 10, the triggers, 28026 and 28032, will be pivoted by the engagement arms, 28024 d and 28030 d, of the lower toggle links, 28024 and 28030, to a position in which the triggers will no longer engage the internal flange 28034 d of the end of the tubular spring housing 28034 thereby permitting the displacement of the tubular spring housing in the direction 28096. As a result, the upper cam assembly 28052 and the upper expansion segments 28054 can be brought into engagement with the lower expansion segments 28058 and the lower cam assembly 28060. In an exemplary embodiment, the upper toggle links, 28022 and 28028, and the lower toggle links, 28024 and 28030, are spring biased towards the position illustrated in FIG. 16W.
  • Conversely, as illustrated in FIG. 16X, anytime the upper toggle links, 28022 and 28028, and lower toggle links, 28024 and 28030, are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10, the triggers, 28026 and 28032, will be maintained in a position in which the triggers will engage the internal flange 28034 d of the end of the tubular spring housing 28034 thereby preventing the displacement of the tubular spring housing in the direction 28096. As a result, the upper cam assembly 28052 and the upper expansion segments 28054 cannot be brought into engagement with the lower expansion segments 28058 and the lower cam assembly 28060. In an exemplary embodiment, the triggers, 28026 and 28032, are spring biased towards the position illustrated in FIG. 16X.
  • In an exemplary embodiment, as illustrated in FIG. 16Y, the tubular spring housing 28034 may be displaced upwardly in the direction 28098 even if the upper toggle links, 28022 and 28028, and lower toggle links, 28024 and 28030, are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10.
  • In an exemplary embodiment, as illustrated in FIGS. 16Z1 to 16Z4, 16AA1 to 16AA4, 16AB1 to 16AB4, 16AC1 to 16AC4, 16AD, and 16AE, the tubular spring housing 28034 of the adjustable bell section expansion cone assembly 28 defines internal annular recesses 28034 k and 28034 l, spaced apart by an internal flange 28034 m, the tubular toggle bushing 28008 defines an external annular recess 28008 ac, and the adjustable bell section expansion cone assembly further includes pins, 28100 a and 28100 b and 28102 a and 28102 b, mounted in holes 28008 j and 28008 o and 28008 k and 28008 n, respectively, of the tubular toggle bushing, and a one-shot deactivation device 28104 mounted on the tubular toggle bushing between the pins, 28100 a and 28100 b and 28102 a and 28102 b.
  • The one-shot deactivation device 28104 includes a tubular body 28104 a that defines radial holes, 28104 b and 28014 c, and includes an external annular recess 28104 d at one end, a centrally positioned external flange 28104 e, a centrally positioned internal annular recess 28104 f, and an external annular recess 28104 g at another end. An engagement member 28106 that includes a base member 28106 a having a tapered end 28106 b and a key member 28106 c having a tapered end 28106 d is received within a portion of the internal annular recess 28104 f of the tubular body 28104 a and an engagement member 28108 that includes a base member 28108 a having a tapered end 28108 b and a key member 28108 c having a tapered end 28108 d is received within an opposite portion of the internal annular recess 28104 f of the tubular body 28104 a. Spring members, 28110 and 28112, are received within the annular recess 28104 f of the tubular body 28104 a for biasing the base members, base member 28106 a and 28108 a, of the engagement members, 28106 and 28108, respectively, radially inwardly relative to the tubular body 28104 a.
  • In an exemplary embodiment, during operation of the adjustable bell section expansion cone assembly 28, as illustrated in FIGS. 16Z1 to 16Z4, the one-shot deactivation device 28104 are positioned proximate and in intimate contact with the pins, 28102 a and 28102 b, with the tapered ends, 28106 b and 28108 b, of the base members, 28106 a and 28108 a, of the engagement members, 28106 and 28108, received within the external annular recess 28008 ac of the tubular toggle bushing 28008. When the one-shot deactivation device 28104 is positioned as illustrated in FIGS. 16Z1 to 16Z4, the external annular recess 28104 d of the tubular body 28104 a of the one-shot deactivation device is moved out of engagement with the engagement arms, 28026 d and 28032 d, of the triggers, 28026 and 28032, respectively. As a result, the triggers, 28026 and 28032, may operate normally as described above with reference to FIGS. 16W, 16X, and 16Y.
  • Conversely, in an exemplary embodiment, during operation of the adjustable bell section expansion cone assembly 28, as illustrated in FIGS. 16AA1 to 16AA4, the one-shot deactivation device 28104 are positioned proximate and in intimate contact with the pins, 28100 a and 28100 b, with the tapered ends, 28106 b and 28108 b, of the base members, 28106 a and 28108 a, of the engagement members, 28106 and 28108, not received within the external annular recess 28008 ac of the tubular toggle bushing 28008. When the one-shot deactivation device 28104 is positioned as illustrated in FIG. 16AA, the external annular recess 28104 d of the tubular body 28104 a of the one-shot deactivation device is moved into engagement with the engagement arms, 28026 d and 28032 d, of the triggers, 28026 and 28032, respectively. As a result, the triggers, 28026 and 28032, are deactivated and may not operate normally as described above with reference to FIGS. 16W, 16X, and 16Y.
  • In an alternative embodiment, the elements of the adjustable bell section expansion cone assembly 28 that sense the diameter of the expandable wellbore casing 100 may be disabled or omitted or adjusted to sense any pre-selected internal diameter of the expandable wellbore casing.
  • In an exemplary embodiment, the adjustable casing expansion cone assembly 30 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US02/36157, attorney docket number 25791.87.02, filed on Nov. 12, 2002, and/or (2) PCT patent application serial number PCT/US02/36267, attorney docket number 25791.88.02, filed on Nov. 12, 2002, and/or (3) PCT patent application serial number PCT/US03/04837, attorney docket number 25791.95.02, filed on Feb. 29, 2003, and/or (4) PCT patent application serial number PCT/US03/29859, attorney docket no. 25791.102.02, filed on Sep. 22, 2003, and/or (5) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (6) PCT patent application serial number PCT/US03/18530, attorney docket number 25791.108.02, filed on Jun. 11, 2003, and/or (7) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (8) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (9) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (10) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (10) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 17-1 and 17-2, 17A1 to 17A2, 17B1 to 17B2, 17C, 17D, 17E, 17F, 17G, 17H, 17I, 17 j, 17K, 17L, 17M, 17N, 17O, 17P, 17R, 17S, 17T, 17U, 17V, 17W, 17 x, 17Y, 17Z1-17Z4, 17AA1 to 17AA4, 17AB1 to 17AB4, 17AC1 to 17AC4, 17AD, and 17AE, the adjustable casing expansion cone assembly 30 includes an upper tubular tool joint 30002 that defines a longitudinal passage 30002 a and mounting holes, 30002 b and 30002 c, and includes an internal threaded connection 30002 d, an inner annular recess 30002 e, an inner annular recess 30002 f, and an internal threaded connection 30002 g. A tubular torque plate 30004 that defines a longitudinal passage 30004 a and includes circumferentially spaced apart teeth 30004 b is received within, mates with, and is coupled to the internal annular recess 30002 e of the upper tubular tool joint 30002.
  • Circumferentially spaced apart teeth 30006 a of an end of a tubular lower mandrel 30006 that defines a longitudinal passage 30006 b, a radial passage 30006 ba, and a radial passage 30006 bb and includes an external threaded connection 30006 c, an external flange 30006 d, an external annular recess 30006 e having a step 30006 f at one end, an external annular recess 30006 g, external teeth 30006 h, an external threaded connection 30006 i, and an external annular recess 30006 j engage the circumferentially spaced apart teeth 30004 b of the tubular torque plate 30004. An internal threaded connection 30008 a of an end of a tubular toggle bushing 30008 that defines a longitudinal passage 30008 b, an upper longitudinal slot 30008 c, a lower longitudinal slot 30008 d, mounting holes, 30008 e, 30008 f, 30008 g, 30008 h, 30008 i, 30008 j, 30008 k, 30008 l, 30008 m, 30008 n, 30008 o, 30008 p, 30008 q, 30008 r, 30008 s, 30008 t, 30008 u, 30008 v, 30008 w, 30008 x, 30008 xa, and 30008 xb, and includes an external annular recess 30008 y, internal annular recess 30008 z, external annular recess 30008 aa, and an external annular recess 30008 ab receives and is coupled to the external threaded connection 30006 c of the tubular lower mandrel 30006.
  • A sealing element 30010 is received within the external annular recess 30008 y of the tubular toggle bushing 30008 for sealing the interface between the tubular toggle bushing and the upper tubular tool joint 30002. A sealing element 30012 is received within the internal annular recess 30008 z of the tubular toggle bushing 30008 for sealing the interface between the tubular toggle bushing and the tubular lower mandrel 30006.
  • Mounting screws, 30014 a and 30014 b, mounted within and coupled to the mounting holes, 30008 w and 30008 x, respectively, of the tubular toggle bushing 30008 are also received within the mounting holes, 30002 b and 30002 c, of the upper tubular tool joint 30002. Mounting pins, 30016 a, 30016 b, 30016 c, 30016 d, and 30016 e, are mounted within the mounting holes, 30008 e, 30008 f, 30008 g, 30008 h, and 30008 l, respectively. Mounting pins, 30018 a, 30018 b, 30018 c, 30018 d, and 30018 e, are mounted within the mounting holes, 30008 t, 30008 s, 30008 r, 30008 q, and 30008 p, respectively. Mounting screws, 30020 a and 30020 b, are mounted within the mounting holes, 30008 u and 30008 v, respectively.
  • A first upper toggle link 30022 defines mounting holes, 30022 a and 30022 b, for receiving the mounting pins, 30016 a and 30016 b, and includes a mounting pin 30022 c at one end. A first lower toggle link 30024 defines mounting holes, 30024 a, 30024 b, and 30024 c, for receiving the mounting pins, 30022 c, 30016 c, and 30016 d, respectively and includes an engagement arm 30024 d. A first trigger 30026 defines a mounting hole 30026 a for receiving the mounting pin 30016 e and includes an engagement arm 30026 b at one end, an engagement member 30026 c, and an engagement arm 30026 d at another end.
  • A second upper toggle link 30028 defines mounting holes, 30028 a and 30028 b, for receiving the mounting pins, 30018 a and 30018 b, and includes a mounting pin 30028 c at one end. A second lower toggle link 30030 defines mounting holes, 30030 a, 30030 b, and 30030 c, for receiving the mounting pins, 30028 c, 30018 c, and 30018 d, respectively and includes an engagement arm 30030 d. A second trigger 30032 defines a mounting hole 30032 a for receiving the mounting pin 30018 e and includes an engagement arm 30032 b at one end, an engagement member 30032 c, and an engagement arm 30032 d at another end.
  • An end of a tubular spring housing 30034 that defines a longitudinal passage 30034 a, mounting holes, 30034 b and 30034 c, and mounting holes, 30034 ba and 30034 ca, and includes an internal flange 30034 d and an internal annular recess 30034 e at one end, and an internal flange 30034 f, an internal annular recess 30034 g, an internal annular recess 30034 h, and an external threaded connection 30034 i at another end receives and mates with the end of the tubular toggle bushing 30008. Mounting screws, 30035 a and 30035 b, are mounted within and coupled to the mounting holes, 30008 xb and 30008 xa, respectively, of the tubular toggle bushing 30008 and are received within the mounting holes, 30034 ba and 30034 ca, respectively, of the tubular spring housing 30034.
  • A tubular retracting spring ring 30036 that defines mounting holes, 30036 a and 30036 b, receives and mates with a portion of the tubular lower mandrel 30006 and is received within and mates with a portion of the tubular spring housing 30034. Mounting screws, 30038 a and 30038 b, are mounted within and coupled to the mounting holes, 30036 a and 30036 b, respectively, of the tubular retracting spring ring 30036 and extend into the mounting holes, 30034 b and 30034 c, respectively, of the tubular spring housing 30034.
  • Casing diameter sensor springs, 30040 a and 30040 b, are positioned within the longitudinal slots, 30008 c and 3008 d, respectively, of the tubular toggle bushing 30008 that engage the engagement members, 30026 c and 30032 c, and engagement arms, 30026 d and 30032 d, of the first and second triggers, 30026 and 30032, respectively. An inner flange 30042 a of an end of a tubular spring washer 30042 mates with and receives a portion of the tubular lower mandrel 30006 and an end face of the inner flange of the tubular spring washer is positioned proximate and end face of the external flange 30006 d of the tubular lower mandrel. The tubular spring washer 30042 is further received within the longitudinal passage 30034 a of the tubular spring housing 30034.
  • An end of a retracting spring 30044 that receives the tubular lower mandrel 30006 is positioned within the tubular spring washer 30042 in contact with the internal flange 30042 a of the tubular spring washer and the other end of the retracting spring is positioned in contact with an end face of the tubular retracting spring ring 30036.
  • A sealing element 30046 is received within the external annular recess 30006 j of the tubular lower mandrel 30006 for sealing the interface between the tubular lower mandrel and the tubular spring housing 30034. A sealing element 30048 is received within the internal annular recess 30034 h of the tubular spring housing 30034 for sealing the interface between the tubular spring housing and the tubular lower mandrel 30006.
  • An internal threaded connection 30050 a of an end of a tubular upper hinge sleeve 30050 that includes an internal flange 30050 b and an internal pivot 30050 c receives and is coupled to the external threaded connection 30034 i of the end of the tubular spring housing 30034.
  • An external flange 30052 a of a base member 30052 b of an upper cam assembly 30052, that is mounted upon and receives the lower tubular mandrel 30006, that includes an internal flange 30052 c that is received within the external annular recess 30006 e of the lower tubular mandrel 30006 and a plurality of circumferentially spaced apart tapered cam arms 30052 d extending from the base member mates with and is received within the tubular upper hinge sleeve 30050. The base member 30052 b of the upper cam assembly 30052 further includes a plurality of circumferentially spaced apart teeth 30052 f that mate with and are received within a plurality of circumferentially spaced apart teeth 30034 j provided on the end face of the tubular spring housing 30034 and an end face of the external flange 30052 a of the base member of the upper cam assembly is positioned in opposing relation to an end face of the internal flange 30050 b of the tubular upper hinge sleeve 30050. Each of the cam arms 30052 d of the upper cam assembly 30052 include external cam surfaces 30052 e. In an exemplary embodiment, the teeth 30052 f of the base member 30052 b of the upper cam assembly 30052 and the teeth 30034 j provided on the end face of the tubular spring housing 30034 permit torsional loads to be transmitted between the tubular spring housing and the upper cam assembly.
  • A plurality of circumferentially spaced apart upper expansion segments 30054 are mounted upon and receive the lower tubular mandrel 30006 and each include an external pivot recess 30054 a at one end for mating with and receiving the internal pivot 30050 c of the tubular upper hinge sleeve 30050 and an external tapered expansion surface 30054 b at another end and are pivotally mounted within the tubular upper hinge sleeve and are interleaved with the circumferentially spaced apart cam arms 30052 d of the upper cam assembly 30052. The upper expansion segments 30054 are interleaved among the cam arms 30052 d of the upper cam assembly 30052.
  • A plurality of circumferentially spaced apart lower expansion segments 30058 are mounted upon and receive the lower tubular mandrel 30006, are interleaved among the upper expansion segments 30054, are oriented in the opposite direction to the upper expansion segments 30054, each include an external pivot recess 30058 a at one end and an external tapered expansion surface 30054 b at another end and are positioned in opposing relation to corresponding circumferentially spaced apart cam arms 30052 d of the upper cam assembly 30052.
  • A lower cam assembly 30060 is mounted upon and receives the lower tubular mandrel 30006 that includes a base member 30060 a having an external flange 30060 b, a plurality of circumferentially spaced apart cam arms 30060 d that extend from the base member that each include external cam surfaces 30060 e and define mounting holes 30060 f and 30060 g. The base member 30060 a of the lower cam assembly 30060 further includes a plurality of circumferentially spaced apart teeth 30060 h. The circumferentially spaced apart cam arms 30060 d of the lower cam assembly 30060 are interleaved among the lower expansion segments 30058 and the circumferentially spaced apart cam arms 30052 d of the upper cam assembly 30052 and positioned in opposing relation to corresponding upper expansion segments 30054.
  • Mounting screws, 30062 a, 30062 b, 30062 c, and 30062 e, are mounted within the corresponding mounting holes, 30060 f and 30060 g, of the lower cam assembly 30060 and are received within the external annular recess 30006 g of the lower cam assembly 30060.
  • A tubular lower hinge sleeve 30064 that receives the lower expansion segments 30058 and the lower cam assembly 30060 includes an internal flange 30064 a for engaging the external flange 30060 b of the base member of the lower cam assembly 30060, an internal pivot 30064 b for engaging and receiving the external pivot recess 30058 a of the lower expansion segments 30058 thereby pivotally mounting the lower expansion segments within the tubular lower hinge sleeve, and an internal threaded connection 30064 c.
  • An external threaded connection 30066 a of an end of a tubular sleeve 30066 that defines mounting holes, 30066 b and 30066 c, and includes an internal annular recess 30066 d having a shoulder 30066 e, an internal flange 30066 f, and an internal threaded connection 30066 g at another end is received within and coupled to the internal threaded connection 30064 c of the tubular lower hinge sleeve 30064. An external threaded connection 30068 a of an end of a tubular member 30068 that defines a longitudinal passage 30068 b and mounting holes, 30068 c and 30068 d, and includes an external annular recess 30068 e, and an external threaded connection 30068 f at another end is received within and is coupled to the internal threaded connection 30066 g of the tubular sleeve 30066.
  • Mounting screws, 30070 a and 30070 b, are mounted in and coupled to the mounting holes, 30068 c and 30068 d, respectively, of the tubular member 30068 that also extend into the mounting holes, 30066 b and 30066 c, respectively, of the tubular sleeve 30066. A sealing element 30072 is received within the external annular recess 30068 e of the tubular member 30068 for sealing the interface between the tubular member and the tubular sleeve 30066.
  • An internal threaded connection 30074 a of a tubular retracting piston 30074 that defines a longitudinal passage 30074 b and includes an internal annular recess 30074 c and an external annular recess 30074 d receives and is coupled to the external threaded connection 30006 i of the tubular lower mandrel 30006. A sealing element 30076 is received within the external annular recess 30074 d of the tubular retracting piston 30074 for sealing the interface between the tubular retracting piston and the tubular sleeve 30066. A sealing element 30078 is received within the internal annular recess 30074 c of the tubular retracting piston 30074 for sealing the interface between the tubular retracting piston and the tubular lower mandrel 30006.
  • Locking dogs 30080 mate with and receive the external teeth 30006 h of the tubular lower mandrel 30006. A spacer ring 30082 is positioned between an end face of the locking dogs 30080 and an end face of the lower cam assembly 30060. A release piston 30084 mounted upon the tubular lower mandrel 30006 defines a radial passage 30084 a for mounting a burst disk 30086 includes sealing elements, 30084 b, 30084 c, and 30084 d. The sealing elements, 30084 b and 30084 d, sealing the interface between the release piston 30084 and the tubular lower mandrel 30006. An end face of the release piston 30084 is positioned in opposing relation to an end face of the locking dogs 30080.
  • A release sleeve 30088 that receives and is mounted upon the locking dogs 30080 and the release piston 30084 includes an internal flange 30088 a at one end that sealingly engages the tubular lower mandrel 30006. A bypass sleeve 30090 that receives and is mounted upon the release sleeve 30088 includes an internal flange 30090 a at one end.
  • In an exemplary embodiment, during operation of the adjustable casing expansion cone assembly 30, the retracting spring 30044 is compressed and thereby applies a biasing spring force in a direction 30092 from the lower tubular mandrel 30006 to the tubular spring housing 30034 that, in the absence of other forces, moves and/or maintains the upper cam assembly 30052 and the upper expansion segments 30054 out of engagement with the lower expansion segments 30058 and the lower cam assembly 30060. In an exemplary embodiment, during operation of the adjustable bell section expansion cone assembly 28, an external threaded connection 20 a of an end of the sealing cup assembly 20 is coupled to the internal threaded connection 30002 d of the upper tubular tool joint 30002 and an internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 is coupled to the external threaded connection 30068 f of the tubular member 30068.
  • The upper cam assembly 30052 and the upper expansion segments 30054 may be brought into engagement with the lower expansion segments 30058 and the lower cam assembly 30060 by pressurizing an annulus 30094 defined between the lower tubular mandrel 30006 and the tubular spring housing 30034. In particular, injection of fluidic materials into the adjustable casing expansion cone assembly 30 through the longitudinal passage 30006 b of the lower tubular mandrel 30006 and into the radial passage 30006 ba may pressurize the annulus 30094 thereby creating sufficient operating pressure to generate a force in a direction 30096 sufficient to overcome the biasing force of the retracting spring 30044. As a result, the spring housing 30034 may be displaced in the direction 30096 relative to the lower tubular mandrel 30006 thereby displacing the tubular upper hinge sleeve 30050, upper cam assembly 30052, and upper expansion segments 30054 in the direction 30096.
  • In an exemplary embodiment, as illustrated in FIGS. 17P, 17Q, and 17R, the displacement of the upper cam assembly 30052 and upper expansion segments 30054 in the direction 30096 will cause the lower expansion segments 30058 to ride up the cam surfaces 30052 e of the cam arms 30052 d of the upper cam assembly 30052 while also pivoting about the lower tubular hinge segment 30064, and will also cause the upper expansion segments 30054 to ride up the cam surfaces 30060 e of the cam arms 30060 d of the lower cam assembly 30060 while also pivoting about the upper tubular hinge segment 30050. In an exemplary embodiment, when the upper and lower expansion segments, 30054 and 30058, are brought into axial alignment, they define an outer expansion surface that is approximately contiguous in a circumferential direction and which provides an outer expansion surface that at least approximates a conical surface.
  • In an exemplary embodiment, during the operation of the adjustable casing expansion cone assembly 30, when the upper and lower expansion segments, 30054 and 30058, brought into axial alignment into a radially expanded position, the upper and lower expansion segments, 30054 and 30058, are displaced relative to the expandable wellbore casing 100 to thereby radially expand and plastically deform at least a portion of the expandable wellbore casing. In an exemplary embodiment, during the radial expansion and plastic deformation of the expandable wellbore casing 100, the adjustable casing expansion cone assembly 30 may then be rotated relative to the expandable wellbore casing to enhance and/or modify the rate at which the expandable wellbore casing is radially expanded and plastically deformed.
  • In an exemplary embodiment, the upper cam assembly 30052 and the upper expansion segments 30054 may be moved out of engagement with the lower expansion segments 30058 and the lower cam assembly 30060 by reducing the operating pressure within the annulus 30094.
  • In an alternative embodiment, as illustrated in FIGS. 17S, 17T, 17U and 17V, during operation of the adjustable casing expansion cone assembly 30, the upper cam assembly 30052 and the upper expansion segments 30054 may also be moved out of engagement with the lower expansion segments 30058 and the lower cam assembly 30060 by sensing the operating pressure within the longitudinal passage 30006 b of the lower tubular mandrel 30006.
  • In particular, as illustrated in FIG. 17T, if the operating pressure within the longitudinal passage 30006 b and radial passage 30006 bb of the lower tubular mandrel 30006 exceeds a predetermined value, the burst disc 30086 will open the passage 30084 a thereby pressurizing the interior of the tubular release sleeve 30088 thereby displacing the tubular release sleeve 30088 downwardly in a direction 30092 away from engagement with the locking dogs 30080.
  • As a result, as illustrated in FIG. 17U, the locking dogs 30080 are displaced outwardly in the radial directed and thereby released from engagement with the lower tubular mandrel 30006 thereby permitting the lower expansion segments 30058 and the lower cam assembly 30060 to be displaced downwardly relative to the lower tubular mandrel.
  • As a result, as illustrated in FIG. 17V, the operating pressure within the lower tubular mandrel 30066 may then cause the lower tubular mandrel to be displaced downwardly in the direction 30094 relative to the tubular lower mandrel 30006 and the retracting piston 30074. As a result, the lower tubular mandrel 30066, the lower expansion segments 30058, the lower cam assembly 30060, and tubular lower hinge sleeve 30064 are displaced downwardly in the direction 30094 relative to the tubular spring housing 30034 thereby moving the lower expansion segments 30058 and the lower cam assembly 30060 out of engagement with the upper cam assembly 30052 and the upper expansion segments 30054.
  • In an exemplary embodiment, as illustrated in FIGS. 17W, 17X, and 17Y, during operation of the adjustable casing expansion cone assembly 30, the adjustable casing expansion cone assembly senses the diameter of the expandable wellbore casing 100 using the upper toggle links, 30022 and 30028, lower toggle links, 30024 and 30030, and triggers, 30026 and 30032, and then prevents the engagement of the upper cam assembly 30052 and the upper expansion segments 30054 with the lower expansion segments 30058 and the lower cam assembly 30060.
  • In particular, as illustrated in FIG. 17W, anytime the upper toggle links, 30022 and 30028, and lower toggle links, 30024 and 30030, are positioned within a portion of the expandable wellbore casing 100 that has been radially expanded and plastically deformed by the system 10, the triggers, 30026 and 30032, will be pivoted by the engagement arms, 30024 d and 30030 d, of the lower toggle links, 30024 and 30030, to a position in which the triggers will no longer engage the internal flange 30034 d of the end of the tubular spring housing 30034 thereby permitting the displacement of the tubular spring housing in the direction 30096. As a result, the upper cam assembly 30052 and the upper expansion segments 30054 can be brought into engagement with the lower expansion segments 30058 and the lower cam assembly 30060. In an exemplary embodiment, the upper toggle links, 30022 and 30028, and the lower toggle links, 30024 and 30030, are spring biased towards the position illustrated in FIG. 17W.
  • Conversely, as illustrated in FIG. 17X, anytime the upper toggle links, 30022 and 30028, and lower toggle links, 30024 and 30030, are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10, the triggers, 30026 and 30032, will be maintained in a position in which the triggers will engage the internal flange 30034 d of the end of the tubular spring housing 30034 thereby preventing the displacement of the tubular spring housing in the direction 30096. As a result, the upper cam assembly 30052 and the upper expansion segments 30054 cannot be brought into engagement with the lower expansion segments 30058 and the lower cam assembly 30060. In an exemplary embodiment, the triggers, 30026 and 30032, are spring biased towards the position illustrated in FIG. 17X.
  • In an exemplary embodiment, as illustrated in FIG. 17Y, the tubular spring housing 30034 may be displaced upwardly in the direction 30098 even if the upper toggle links, 30022 and 30028, and lower toggle links, 30024 and 30030, are positioned within a portion of the expandable wellbore casing 100 that has not been radially expanded and plastically deformed by the system 10.
  • In an exemplary embodiment, as illustrated in FIGS. 17Z1 to 17Z4, 17AA1 to 17AA4, 17AB1 to 17AB4, 17AC1 to 17AC4, 17AD, and 17AE, the tubular spring housing 30034 of the adjustable casing expansion cone assembly 30 defines internal annular recesses 30034 k and 30034, spaced apart by an internal flange 30034 m, the tubular toggle bushing 30008 defines an external annular recess 30008 ac, and the adjustable casing expansion cone assembly further includes pins, 30100 a and 30100 b and 30102 a and 30102 b, mounted in holes 30008 j and 30008 o and 30008 k and 30008 n, respectively, of the tubular toggle bushing, and a one-shot deactivation device 30104 mounted on the tubular toggle bushing between the pins, 30100 a and 30100 b and 30102 a and 30102 b.
  • The one-shot deactivation device 30104 includes a tubular body 30104 a that defines radial holes, 30104 b and 30014 c, and includes an external annular recess 30104 d at one end, a centrally positioned external flange 30104 e, a centrally positioned internal annular recess 30104 f, and an external annular recess 30104 g at another end. An engagement member 30106 that includes a base member 30106 a having a tapered end 30106 b and a key member 30106 c having a tapered end 30106 d is received within a portion of the internal annular recess 30104 f of the tubular body 30104 a and an engagement member 30108 that includes a base member 30108 a having a tapered end 30108 b and a key member 30108 c having a tapered end 30108 d is received within an opposite portion of the internal annular recess 30104 f of the tubular body 30104 a. Spring members, 30110 and 30112, are received within the annular recess 30104 f of the tubular body 30104 a for biasing the base members, base member 30106 a and 30108 a, of the engagement members, 30106 and 30108, respectively, radially inwardly relative to the tubular body 30104 a.
  • In an exemplary embodiment, during operation of the adjustable bell section expansion cone assembly 28, as illustrated in FIG. 17Z, the one-shot deactivation device 30104 are positioned proximate and in intimate contact with the pins, 30102 a and 30102 b, with the tapered ends, 30106 b and 30108 b, of the base members, 30106 a and 30108 a, of the engagement members, 30106 and 30108, received within the external annular recess 30008 ac of the tubular toggle bushing 30008. When the one-shot deactivation device 30104 is positioned as illustrated in FIG. 17Z, the external annular recess 30104 d of the tubular body 30104 a of the one-shot deactivation device is moved out of engagement with the engagement arms, 30026 d and 30032 d, of the triggers, 30026 and 30032, respectively. As a result, the triggers, 30026 and 30032, may operate normally as described above with reference to FIGS. 17W, 17X, and 17Y.
  • Conversely, in an exemplary embodiment, during operation of the adjustable casing expansion cone assembly 30, as illustrated in FIGS. 17AA1 to 17AA4, the one-shot deactivation device 30104 are positioned proximate and in intimate contact with the pins, 30100 a and 30100 b, with the tapered ends, 30106 b and 30108 b, of the base members, 30106 a and 30108 a, of the engagement members, 30106 and 30108, not received within the external annular recess 30008 ac of the tubular toggle bushing 30008. When the one-shot deactivation device 30104 is positioned as illustrated in FIGS. 17AA1 to 17AA4, the external annular recess 30104 d of the tubular body 30104 a of the one-shot deactivation device is moved into engagement with the engagement arms, 30026 d and 30032 d, of the triggers, 30026 and 30032, respectively. As a result, the triggers, 30026 and 30032, are deactivated and may not operate normally as described above with reference to FIGS. 17W, 17X, and 17Y.
  • In an alternative embodiment, the elements of the adjustable casing expansion cone assembly 30 that sense the diameter of the expandable wellbore casing 100 may be disabled or omitted or adjusted to sense any pre-selected internal diameter of the expandable wellbore casing.
  • In an exemplary embodiment, as illustrated in FIGS. 18A to 18C, the packer setting tool assembly 32 includes a tubular adaptor 3202 that defines a longitudinal passage 3202 a, radial external mounting holes, 3202 b and 3202 c, radial passages, 3202 d and 3202 e, and includes an external threaded connection 3202 f at one end and an internal annular recess 3202 g having an internal threaded connection at another end. An external threaded connection 3204 a of an end of a tubular upper mandrel 3204 that defines a longitudinal passage 3204 b, internally threaded external mounting holes, 3204 c and 3204 d, and includes an external annular recess 3204 e, external annular recess 3204 f, external annular recess 3204 g, external flange 3204 h, external splines 3204 i, and an internal threaded connection 3204 j at another end is received within and is coupled to the internally threaded connection of the internal annular recess 3202 g of the other end of the tubular adaptor 3202. Mounting screws, 3205 a and 3205 b, are received within and coupled to the mounting holes, 3204 c and 3204 d, of the tubular upper mandrel 3204 that also extend into the radial passages, 3202 d and 3202 e, of the tubular adaptor 3202.
  • An external threaded connection 3206 a of an end of a mandrel 3206 that defines a longitudinal passage 3206 b and includes an external annular recess 3206 c and an external annular recess 3206 d having an external threaded connection is received within and is coupled to the internal threaded connection 3204 j of the tubular upper mandrel 3204. An internal threaded connection 3208 a of a tubular stinger 3208 that defines a longitudinal passage 3208 b and includes an external annular recess 3208 c, and an external tapered annular recess 3208 d and an engagement shoulder 3208 e at another end receives and is coupled to the external threaded connection of the external annular recess 3206 d of the mandrel 3206. A sealing member 3210 is mounted upon and coupled to the external annular recess 3206 d of the mandrel 3206.
  • An internal flange 3212 a of a tubular key 3212 that includes an external annular recess 3212 b at one end and an internal annular recess 3212 c at another end is movably received within and engages the external annular recess 3204 f of the tubular upper mandrel 3204. A garter spring 3214 is received within and engages the external annular recess 3212 b of the tubular key 3212.
  • An end of a tubular bushing 3216 that defines a longitudinal passage 3216 a for receiving and mating with the upper mandrel 3204, and radial passages, 3216 b and 3216 c, and includes an external threaded connection 3216 d at an intermediate portion, and an external flange 3216 e, an internal annular recess 3216 f, circumferentially spaced apart teeth 3216 g, and external flanges, 3216 h and 3216 i, at another end is received within and mates with the internal annular recess 3212 c of the tubular key 3212. An internal threaded connection 3218 a of a tubular drag block body 3218 that defines a longitudinal passage 3218 b for receiving the tubular bushing 3216, mounting holes, 3218 c and 3218 d, mounting holes, 3218 e and 3218 f, and includes an internal threaded connection 3218 g at one end, a centrally positioned external annular recess 3218 h, and an external threaded connection 3218 i at another end is received within and coupled to the external threaded connection 3216 d of the tubular bushing 3216.
  • A first tubular keeper 3220 that defines mounting holes, 3220 a and 3220 b, is coupled to an end of the tubular drag block body 3218 by mounting screws, 3222 a and 3222 b, that are received within and are coupled to the mounting holes, 3218 c and 3218 d, of the tubular drag block body. A second tubular keeper 3224 that defines mounting holes, 3224 a and 3224 b, is coupled to an end of the tubular drag block body 3218 by mounting screws, 3226 a and 3226 b, that are received within and are coupled to the mounting holes, 3218 e and 3218 f, of the tubular drag block body.
  • Drag blocks, 3228 and 3230, that are received within the external annular recess 3218 h of the tubular drag block body 3218, include ends that mate with and are received within the end of the first tubular keeper 3220, and other ends that mate with and are received within the end of the second tubular keeper 3224. The drag blocks, 3228 and 3230, further include internal annular recesses, 3228 a and 3230 a, respectively, that receive and mate with ends of springs, 3232 and 3234, respectively. The springs, 3232 and 3234, also receive and mate with the external annular recess 3218 h of the tubular drag block body 3218.
  • An external threaded connection 3236 a of an end of a tubular releasing cap extension 3236 that defines a longitudinal passage 3236 b and includes an internal annular recess 3236 c and an internal threaded connection 3236 d at another end is received within and is coupled to the internal threaded connection 3218 g of the tubular drag block body 3218. An external threaded connection 3238 a of an end of a tubular releasing cap 3238 that defines a longitudinal passage 3238 b and includes an internal annular recess 3238 c is received within and coupled to the internal threaded connection 3236 d of the tubular releasing cap extension 3236. A sealing element 3240 is received within the internal annular recess 3238 c of the tubular releasing cap 3238 for fluidicly sealing the interface between the tubular releasing cap and the upper mandrel 3204.
  • An internal threaded connection 3242 a of an end of a tubular setting sleeve 3242 that defines a longitudinal passage 3242 b, radial passage 3242 c, radial passages, 3242 d and 3242 e, radial passage 3242 f, and includes an internal flange 3242 g at another end receives the external threaded connection 3218 i of the tubular drag block body 3218. An internal flange 3244 a of a tubular coupling ring 3244 that defines a longitudinal passage 3244 b and radial passages, 3244 c and 3244 d, receives and mates with the external flange 3216 h of the tubular bushing 3216 and an end face of the internal flange of the tubular coupling ring is positioned proximate and in opposing relation to an end face of the external flange 3216 i of the tubular bushing.
  • An internal flange 3246 a of a tubular retaining collet 3246 that includes a plurality of axially extending collet fingers 3246 b, each having internal flanges 3246 c at an end of each collet finger, for engaging and receiving the tubular coupling ring 3244 receives and mates with external flange 3216 e of the tubular bushing 3216 and an end face of the internal flange of the tubular retaining collet is positioned proximate and in opposing relation to an end face of the external flange 3216 h of the tubular bushing.
  • In an exemplary embodiment, the packer assembly 36 operates and is provided substantially, at least in part, as disclosed in one or more of the following: (1) PCT patent application serial number PCT/US03/14153, attorney docket number 25791.104.02, filed on Nov. 13, 2003, and/or (2) PCT patent application serial number PCT/US03/29460, attorney docket number 25791.114.02, filed on Sep. 23, 2003, and/or (3) PCT patent application serial number PCT/US04/07711, attorney docket number 25791.253.02, filed on Mar. 11, 2004, and/or (4) PCT patent application serial number PCT/US04/009434, attorney docket number 25791.260.02, filed on Mar. 26, 2004, and/or (5) PCT patent application serial number PCT/US04/010317, attorney docket number 25791.270.02, filed on Apr. 2, 2004, and/or (6) PCT patent application serial number PCT/US04/010712, attorney docket number 25791.272.02, filed on Apr. 7, 2004, and/or (7) PCT patent application serial number PCT/US04/010762, attorney docket number 25791.273.02, filed on Apr. 6, 2004, and/or PCT application serial number PCT/US04/011973, attorney docket number 25791.277.02, filed on Apr. 15, 2004, the disclosures of which are incorporated herein by reference.
  • In an exemplary embodiment, as illustrated in FIGS. 19-1 to 19-5, the packer assembly 36 includes a tubular upper adaptor 3602 that defines a longitudinal passage 3602 a having a tapered opening 3602 b and mounting holes, 3602 c and 3602 d, that includes a plurality of circumferentially spaced apart teeth 3602 e at one end, an external flange 3602 f, and an internal threaded connection 3602 g at another end. In an exemplary embodiment, the tubular upper adaptor 3602 is fabricated from aluminum. An external threaded connection 3604 a of an end of a tubular upper mandrel 3604 that defines a longitudinal passage 3604 b, mounting holes, 3604 c and 3604 d, mounting holes, 3604 e and 3604 f, and mounting holes, 3604 g and 3604 h, and includes an external flange 3604 i, an internal annular recess 3604 j, and an internal threaded connection 3604 k at another end is received within and coupled to the internal threaded connection 3602 g of the tubular upper adaptor 3602. In an exemplary embodiment, the tubular upper mandrel 3604 is fabricated from aluminum.
  • An upper tubular spacer ring 3606 that defines mounting holes, 3606 a and 3606 b, receives and mates with the end of the tubular upper mandrel 3604 and includes an angled end face 3606 c and another end face that is positioned proximate to an end face of the tubular upper adaptor 3602 is coupled to the tubular upper mandrel by shear pins, 3608 a and 3608 b, that are mounted within and coupled to the mounting holes, 3604 c and 3606 a, and, 3604 d and 3606 b, respectively, of the tubular upper mandrel and upper tubular spacer ring, respectively. A lower tubular spacer ring 3610 that includes an angled end face 3610 a receives, mates, and is coupled to the other end of the tubular upper mandrel 3604 and includes another end face that is positioned proximate to an end face of the external flange 3604 i of the tubular upper mandrel 3604. In an exemplary embodiment, the upper and tubular spacer rings, 3606 and 3610, are fabricated from a composite material.
  • A sealing element or upper tubular slip 3612 that receives and is movably mounted upon the tubular upper mandrel 3604 defines a longitudinal passage 3612 a having a tapered opening 3612 b and includes external annular recesses, 3612 c, 3612 d, 3612 e, 3612 f, and 3612 g, and an angled end face 3612 h that mates with and is positioned proximate the angled end face 3606 c of the upper tubular spacer ring 3606. Slip retaining bands, 3614 a, 3614 b, 3614 c, 3614 d, and 3614 e, are received within and coupled to the external annular recesses, 3612 c, 3612 d, 3612 e, 3612 f, and 3612 g, of the upper tubular slip 3612. A sealing element or lower tubular slip 3616 that receives and is movably mounted upon the tubular upper mandrel 3604 defines a longitudinal passage 3616 a having a tapered opening 3616 b and includes external annular recesses, 3616 c, 3616 d, 3616 e, 3616 f, and 3616 g, and an angled end face 3616 h that mates with and is positioned proximate the angled end face 3610 a of the lower tubular spacer ring 3610. Slip retaining bands, 3618 a, 3618 b, 3618 c, 3618 d, and 3618 e, are received within and coupled to the external annular recesses, 3616 c, 3616 d, 3616 e, 3616 f, and 3616 g, of the lower tubular slip 3616. In an exemplary embodiment, the upper and lower tubular slips, 3612 and 3616, are fabricated from composite materials, and at least some of the slip retaining bands, 3614 a, 3614 b, 3614 c, 3614 d, 3614 e, 3618 a, 3618 b, 3618 c, 3618 d, and 3618 e are fabricated from carbide insert materials. In an exemplary embodiment, one or more of the slip retaining bands, 3614 a, 3614 b, 3614 c, 3614 d, and 3614 e, and one or more of the respective external annular recesses, 3612 c, 3612 d, 3612 e, 3612 f, and 3612 g, of the upper tubular slip 3612 may be removed from the packer assembly 36. In an exemplary embodiment, one or more of the slip retaining bands, 3618 a, 3618 b, 3618 c, 3618 d, and 3618 e, and one or more of the respective external annular recesses, 3616 c, 3616 d, 3616 e, 3616 f, and 3616 g, of the lower tubular slip 3616 may be removed from the packer assembly 36.
  • An upper tubular wedge 3620 that defines an longitudinal passage 3620 a for receiving the tubular upper mandrel 3604 and mounting holes, 3620 b and 3620 c, and includes an angled end face 3620 d at one end that is received within and mates with the tapered opening 3612 b of the upper tubular slip 3612, and an angled end face 3620 e at another end is coupled to the tubular upper mandrel by shear pins, 3622 a and 3622 b, mounted within and coupled to the mounting holes, 3604 e and 3620 b, and, 3604 f and 3620 c, respectively, of the tubular upper mandrel and upper tubular wedge, respectively. A lower tubular wedge 3624 that defines an longitudinal passage 3624 a for receiving the tubular upper mandrel 3604 and mounting holes, 3624 b and 3624 c, and includes an angled end face 3624 d at one end that is received within and mates with the tapered opening 3616 b of the lower tubular slip 3616, and an angled end face 3624 e at another end is coupled to the tubular upper mandrel by shear pins, 3626 a and 3626 b, mounted within and coupled to the mounting holes, 3604 g and 3624 b, and, 3604 h and 3624 c, respectively, of the tubular upper mandrel and lower tubular wedge, respectively. In an exemplary embodiment, the upper and lower tubular wedges, 3620 and 3624, are fabricated from composite materials.
  • An upper tubular extrusion limiter 3628 that defines a longitudinal passage 3628 a for receiving the tubular upper mandrel 3604 includes an angled end face 3628 b at one end that mates with the angled end face 3620 e of the upper tubular wedge 3620, an angled end face 3628 c at another end having recesses 3628 d, and external annular recesses, 3628 e, 3628 f and 3628 g. Retaining bands, 3630 a, 3630 b, and 3630 c, are mounted within and coupled to the external annular recesses, 3628 e, 3628 f and 3628 g, respectively, of the upper tubular extrusion limiter 3628. Circular disc-shaped extrusion preventers 3632 are coupled and mounted within the recesses 3628 d. A lower tubular extrusion limiter 3634 that defines a longitudinal passage 3634 a for receiving the tubular upper mandrel 3604 includes an angled end face 3634 b at one end that mates with the angled end face 3624 e of the lower tubular wedge 3624, an angled end face 3634 c at another end having recesses 3634 d, and external annular recesses, 3634 e, 3634 f and 3634 g. Retaining bands, 3636 a, 3636 b, and 3636 c, are mounted within and coupled to the external annular recesses, 3634 e, 3634 f and 3634 g, respectively, of the lower tubular extrusion limiter 3634. Circular disc-shaped extrusion preventers 3638 are coupled and mounted within the recesses 3634 d. In an exemplary embodiment, the upper and lower extrusion limiters, 3628 and 3634, are fabricated from composite materials. In an exemplary embodiment, one or more of the retaining bands, 3630 a, 3630 b, and 3630 c, and one or more of the respective external annular recesses, 3628 e, 3628 f and 3628 g of the upper tubular extrusion limiter 3628 may be removed from the packer assembly 36. In an exemplary embodiment, one or more of the retaining bands, 3636 a, 3636 b, and 3636 c, and one or more of the respective external annular recesses, 3634 e, 3634 f and 3634 g of the lower tubular extrusion limiter 3634 may be removed from the packer assembly 36.
  • A sealing element or upper tubular elastomeric packer element 3640 that defines a longitudinal passage 3640 a for receiving the tubular upper mandrel 3604 includes an angled end face 3640 b at one end that mates with and is positioned proximate the angled end face 3628 c of the upper tubular extrusion limiter 3628 and an curved end face 3640 c at another end. A lower tubular elastomeric packer element 3642 that defines a longitudinal passage 3642 a for receiving the tubular upper mandrel 3604 includes an angled end face 3642 b at one end that mates with and is positioned proximate the angled end face 3634 c of the lower tubular extrusion limiter 3634 and an curved end face 3642 c at another end.
  • A central tubular elastomeric packer element 3644 that defines a longitudinal passage 3644 a for receiving the tubular upper mandrel 3604 includes a curved outer surface 3644 b for mating with and engaging the curved end faces, 3640 c and 3642 c, of the upper and lower tubular elastomeric packer elements, 3640 and 3642, respectively.
  • An external threaded connection 3646 a of a tubular lower mandrel 3646 that defines a longitudinal passage 3646 b having throat passages, 3646 c and 3646 d, and flow ports, 3646 e and 3646 f, and a mounting hole 3646 g, and includes an internal annular recess 3646 h at one end, and an external flange 3646 i, internal annular recess 3646 j, and internal threaded connection 3646 k at another end. In an exemplary embodiment, the tubular lower mandrel 3646 is fabricated from aluminum. A sealing element 3648 is received within the inner annular recess 3604 j of the other end of the tubular upper mandrel 3604 for sealing an interface between the tubular upper mandrel and the tubular lower mandrel 3646.
  • A tubular sliding sleeve valve 3650 that defines a longitudinal passage 3650 a and radial flow ports, 3650 b and 3650 c, and includes collet fingers 3650 d at one end for engaging the internal annular recess 3646 h of the lower tubular mandrel 3646, an external annular recess 3650 e, an external annular recess 3650 f, an external annular recess 3650 g, and circumferentially spaced apart teeth 3650 h at another end is received within and is slidably coupled to the longitudinal passage 3646 b of the tubular lower mandrel 3646. In an exemplary embodiment, the tubular sliding sleeve valve 3650 is fabricated from aluminum. A set screw 3652 is mounted within and coupled to the mounting hole 3646 g of the tubular lower mandrel 3646 that is received within the external annular recess 3650 e of the tubular sliding sleeve 3650. Sealing elements, 3654 and 3656, are mounted within the external annular recesses, 3650 f and 3650 g, respectively, of the tubular sliding sleeve valve 3650 for sealing an interface between the tubular sliding sleeve valve and the tubular lower mandrel 3646.
  • An end of a tubular outer sleeve 3658 that defines a longitudinal passage 3658 a, radial passages, 3658 b and 3658 c, upper flow ports, 3658 d and 3658 e, lower flow ports, 3658 f and 3658 g, and radial passages, 3658 h and 3658 i, receives, mates with, and is coupled to the other end of the tubular upper mandrel 3604 and an end face of the end of the tubular outer sleeve is positioned proximate and end face of the lower tubular spacer ring 3610. The other end of the tubular outer sleeve 3658 receives, mates with, and is coupled to the other end of the tubular lower mandrel 3646.
  • An external threaded connection 3660 a of an end of a tubular bypass mandrel 3660 that defines a longitudinal passage 3660 b, upper flow ports, 3660 c and 3660 d, lower flow ports, 3660 e and 3660 f, and a mounting hole 3660 g and includes an internal annular recess 3660 h and an external threaded connection 3660 i at another end is received within and coupled to the internal threaded connection 3646 k of the tubular lower mandrel 3646. A sealing element 3662 is received within the internal annular recess 3646 j of the tubular lower mandrel 3646 for sealing an interface between the tubular lower mandrel and the tubular bypass mandrel 3660.
  • A tubular plug seat 3664 that defines a longitudinal passage 3664 a having a tapered opening 3664 b at one end, and flow ports, 3664 c and 3664 d, and includes an external annular recess 3664 e, an external annular recess 3664 f, an external annular recess 3664 g, an external annular recess 3664 h, and an external annular recess 3664 i having an external threaded connection at another end is received within and is movably coupled to the longitudinal passage 3660 b of the tubular bypass mandrel 3660. A tubular nose 3666 is threadably coupled to and mounted upon the external annular recess 3664 i of the tubular plug seat 3664. In an exemplary embodiment, the tubular plug seat 3664 is fabricated from aluminum. Sealing elements, 3668, 3670, and 3672, are received within the external annular recesses, 3664 e, 3664 g, and 3664 h, respectively, of the tubular plug seat 3664 for sealing an interface between the tubular plug seat and the tubular bypass mandrel 3660. A set screw 3674 is mounted within and coupled to the mounting hole 3660 g of the tubular bypass mandrel 3660 that is received within the external annular recess 3664 f of the tubular plug seat 3664.
  • An end of a tubular bypass sleeve 3676 that defines a longitudinal passage 3676 a and includes an internal annular recess 3676 b at one end and an internal threaded connection 3676 c at another end is coupled to the other end of the tubular outer sleeve 3658 and mates with and receives the tubular bypass mandrel 3660. In an exemplary embodiment, the tubular bypass sleeve 3676 is fabricated from aluminum.
  • An external threaded connection 3678 a of a tubular valve seat 3678 that defines a longitudinal passage 3678 b including a valve seat 3678 c and up-jet flow ports, 3678 d and 3678 e, and includes a spring retainer 3678 f and an external annular recess 3678 g is received within and is coupled to the internal threaded connection 3676 c of the tubular bypass sleeve 3676. In an exemplary embodiment, the tubular valve seat 3678 is fabricated from aluminum. A sealing element 3680 is received within the external annular recess 3678 g of the tubular valve seat 3678 for fluidicly sealing an interface between the tubular valve seat and the tubular bypass sleeve 3676.
  • A poppet valve 3682 mates with and is positioned within the valve seat 3678 c of the tubular valve seat 3678. An end of the poppet valve 3682 is coupled to an end of a stem bolt 3684 that is slidingly supported for longitudinal displacement by the spring retainer 3678 f A valve spring 3686 that surrounds a portion of the stem bolt 3684 is positioned in opposing relation to the head of the stem bolt and a support 3678 fa of the spring retainer 3678 f for biasing the poppet valve 3682 into engagement with the valve seat 3678 c of the tubular valve seat 3678.
  • An end of a composite nose 3688 that defines a longitudinal passage 3688 a and mounting holes, 3688 b and 3688 c, and includes an internal threaded connection 3688 d at another end receives, mates with, and is coupled to the other end of the tubular valve seat 3678. A tubular nose sleeve 3690 that defines mounting holes, 3690 a and 3690 b, is coupled to the composite nose 3688 by shear pins, 3692 a and 3692 b, that are mounted in and coupled to the mounting holes, 3688 b and 3690 a, and, 3688 c and 3690 b, respectively, of the composite nose and tubular nose sleeve, respectively.
  • An external threaded connection 3694 a of a baffle nose 3694 that defines longitudinal passages, 3694 b and 3694 c, is received within and is coupled to the internal threaded connection internal threaded connection 3688 d of the composite nose 3688.
  • In an exemplary embodiment, as illustrated in FIGS. 19A1 to 19A5, during the operation of the packer setting tool assembly 32 and packer assembly 36, the packer setting tool and packer assembly are coupled to one another by inserting the end of the tubular upper adaptor 3602 into the other end of the tubular coupling ring 3244, bringing the circumferentially spaced teeth 3216 g of the other end of the tubular bushing 3216 into engagement with the circumferentially spaced teeth 3602 e of the end of the tubular upper adaptor, and mounting shear pins, 36100 a and 36100 b, within the mounting holes, 3244 c and 3602 c, and, 3244 d and 3602 d, respectively, of the tubular coupling ring and tubular upper adaptor, respectively. As a result, the tubular mandrel 3206 and tubular stinger 3208 of the packer setting tool assembly 32 are thereby positioned within the longitudinal passage 3604 a of the tubular upper mandrel 3604 with the 3208 e of the tubular stinger positioned within the longitudinal passage 3646 b of the tubular lower mandrel 3646 proximate the collet fingers 3650 d of the tubular sliding sleeve valve 3650.
  • Furthermore, in an exemplary embodiment, during the operation of the packer setting tool 32 and packer assembly 36, as illustrated in FIGS. 20A1 to 20A5, the packer setting tool and packer assembly are positioned within the expandable wellbore casing 100 and an internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 receives and is coupled to the external threaded connection 3202 f of the end of the tubular adaptor 3202 of the packer setting tool assembly. Furthermore, shear pins, 36102 a and 36102 b, mounted within the mounting holes, 3658 b and 3658 c, of the tubular outer sleeve 3658 couple the tubular outer sleeve to the expandable wellbore casing. As a result, torsion loads may transferred between the tubular outer sleeve 3658 and the expandable wellbore casing 100.
  • In an exemplary embodiment, as illustrated in FIGS. 20B1 to 20B5, a conventional plug 36104 is then injected into the setting tool assembly 32 and packer assembly 36 by injecting a fluidic material 36106 into the setting tool assembly and packer assembly through the longitudinal passages, 3202 a, 3204 b, 3206 b, 3208 b, 3650 a, 3646 a, 3660 b, and 3664 a of the tubular adaptor 3202, tubular upper mandrel 3204, tubular mandrel 3206, tubular stinger 3208, tubular sliding sleeve valve 3650, tubular lower mandrel 3646, tubular bypass mandrel 3660, and tubular plug seat 3664, respectively. The plug 36104 is thereby positioned within the longitudinal passage 3664 a of the tubular plug seat 3664. Continued injection of the fluidic material 36106 following the seating of the plug 1606 within the longitudinal passage 3664 a of the tubular plug seat 3664 causes the plug and the tubular plug seat to be displaced downwardly in a direction 36108 until further movement of the tubular plug seat is prevented by interaction of the set screw 3674 with the external annular recess 3664 f of the tubular plug seat. As a result, the flow ports, 3664 c and 3664 d, of the tubular plug seat 3664 are moved out of alignment with the upper flow ports, 3660 c and 3660 d, of the tubular bypass mandrel 3660.
  • In an exemplary embodiment, as illustrated in FIGS. 20C1 to 20C5, after the expandable wellbore casing 100 has been radially expanded and plastically deformed to form at least the bell section 112 of the expandable wellbore casing 100 thereby shearing the shear pins, 36102 a and 36102 b, the setting tool assembly 32 and packer assembly 36 are then moved upwardly to a position within the expandable wellbore casing 100 above the bell section. The tubular adaptor 3202 is then rotated, by rotating the tool string of the system 10 above the setting tool assembly 32, to displace and position the drag blocks, 3228 and 3230, into engagement with the interior surface of the expandable wellbore casing 100.
  • As a result of the engagement of the drag blocks, 3228 and 3230, with the interior surface of the expandable wellbore casing 100, further rotation of the drag blocks relative to the wellbore casing is prevented. Consequently, due to the operation and interaction of the threaded connections, 3216 d and 3218 a, of the tubular bushing 3216 and tubular drag block body 3218, respectively, further rotation of the tubular adaptor 3202 causes the tubular drag block body and setting sleeve 3242 to be displaced downwardly in a direction 36112 relative to the remaining elements of the setting tool assembly 32 and packer assembly 36. As a result, the setting sleeve 3242 engages and displaces the upper tubular spacer ring 3606 thereby shearing the shear pins, 3622 a and 3622 b, and driving the upper tubular slip 3612 onto and up the angled end face 3620 d of the upper tubular wedge 3620 and into engagement with the interior surface of the expandable wellbore casing 100. As a result, longitudinal displacement of the upper tubular slip 3612 relative to the expandable wellbore casing 100 is prevented. Furthermore, as a result, the 3246 b collet fingers of the tubular retaining collet 3246 are disengaged from the tubular upper adaptor 3602.
  • In an alternative embodiment, after the drag blocks, 3228 and 3230, engage the interior surface of the expandable wellbore casing 100, an upward tensile force is applied to the tubular support member 12, and the ball gripper assembly 16 is then operate to engage the interior surface of the expandable wellbore casing. The tension actuator assembly 18 is then operated to apply an upward tensile force to the tubular adaptor 3202 thereby pulling the upper tubular spacer ring 3606, lower tubular spacer ring 3610, upper tubular slip 3612, lower tubular slip 3616, upper tubular wedge 3620, lower tubular wedge 3624, upper tubular extrusion limiter 3628, lower tubular extrusion limiter 3634, and central tubular elastomeric element 3644 upwardly into contact with the 3242 thereby compressing the upper tubular spacer ring, lower tubular spacer ring, upper tubular slip, lower tubular slip, upper tubular wedge, lower tubular wedge, upper tubular extrusion limiter, lower tubular extrusion limiter, and central tubular elastomeric element. As a result, the upper tubular slip 3612, lower tubular slip 3616, and central tubular elastomeric element 3644 engage the interior surface of the expandable wellbore casing 100.
  • In an exemplary embodiment, as illustrated in FIGS. 20D1 to 20D5, an upward tensile force is then applied to the tubular adaptor 3202 thereby compressing the lower tubular slip 3616, lower tubular wedge 3624, central elastomeric packer element 3644, upper tubular extrusion limiter 3628, and upper tubular wedge 3620 between the lower tubular spacer ring 3610 and the stationary upper tubular slip 3612. As a result, the lower tubular slip 3616 is driven onto and up the angled end face 3624 d of the lower tubular wedge 3624 and into engagement with the interior surface of the expandable wellbore casing 100, and the central elastomeric packer element 3644 is compressed radially outwardly into engagement with the interior surface of the expandable tubular member. As a result, further longitudinal displacement of the upper tubular slip 3612, lower tubular slip 3616, and central elastomeric packer element 3644 relative to the expandable wellbore casing 100 is prevented.
  • In an exemplary embodiment, as illustrated in FIGS. 20E1 to 20E6, continued application of the upward tensile force to tubular adaptor 3202 will then shear the shear pins, 1602 a and 1602 b, thereby disengaging the setting tool assembly 32 from the packer assembly 36.
  • In an exemplary embodiment, as illustrated in FIGS. 20F1 to 20F6, with the drag blocks, 3228 and 3230, in engagement with the interior surface of the expandable wellbore casing 100, the tubular adaptor 102 is further rotated thereby causing the tubular drag block body 3218 and setting sleeve 3242 to be displaced further downwardly in the direction 36113 until the tubular drag block body and setting sleeve are disengaged from the tubular stinger 3208. As a result, the tubular stinger 3208 of the setting tool assembly 32 may then be displaced downwardly into complete engagement with the tubular sliding sleeve valve 3650.
  • In an exemplary embodiment, as illustrated in FIGS. 20G1 to 20G6, a fluidic material 36114 is then injected into the setting tool assembly 32 and the packer assembly 36 through the longitudinal passages 3202 a, 3204 b, 3206 b, 3208 b, 3604 b, 3650 a, and 3646 b of the tubular adaptor 3202, tubular upper mandrel 3204, tubular mandrel 3206, tubular stinger 3208, tubular upper mandrel 3604, tubular sliding sleeve valve 3650, and tubular lower mandrel 3646, respectively. Because, the plug 36104 is seated within and blocks the longitudinal passage 3664 a of the tubular plug seat 3664, the longitudinal passages 3604 b, 3650 a, and 3646 b of the tubular upper mandrel 3604, tubular sliding sleeve valve 3650, and tubular lower mandrel 3646 are pressurized thereby displacing the tubular upper adaptor 3602 and tubular upper mandrel 3604 downwardly until the end face of the tubular upper mandrel impacts the end face of the upper tubular spacer ring 3606.
  • In an exemplary embodiment, as illustrated in FIGS. 20H1 to 20H5, the setting tool assembly 32 is brought back into engagement with the packer assembly 36 until the engagement shoulder 3208 e of the other end of the tubular stinger 3208 engages the collet fingers 3650 d of the end of the tubular sliding sleeve valve 3650. As a result, further downward displacement of the tubular stinger 3208 displaces the tubular sliding sleeve valve 3650 downwardly until the radial flow ports, 3650 b and 3650 c, of the tubular sliding sleeve valve are aligned with the flow ports, 3646 e and 3646 f, of the tubular lower mandrel 3646. A hardenable fluidic sealing material 36116 may then be injected into the setting tool assembly 32 and the packer assembly 36 through the longitudinal passages 3202 a, 3204 b, 3206 b, 3208 b, and 3650 a of the tubular adaptor 3202, tubular upper mandrel 3204, tubular mandrel 3206, tubular stinger 3208, and tubular sliding sleeve valve 3650, respectively. The hardenable fluidic sealing material may then flow out of the packer assembly 36 through the upper flow ports, 3658 d and 3658 e, into the annulus between the expandable wellbore casing 100 and the wellbore 102.
  • The tubular sliding sleeve valve 3650 may then be returned to its original position, with the radial flow ports, 3650 b and 3650 c, of the tubular sliding sleeve valve out of alignment with the flow ports, 3646 e and 3646 f, of the tubular lower mandrel 3646. The hardenable fluidic sealing material 36116 may then be allowed to cure before, during, or after the continued operation of the system 10 to further radially expand and plastically deform the expandable wellbore casing.
  • In an alternative embodiment, as illustrated in FIGS. 21 and 21A to 21AX, the packer assembly 36 includes an upper tubular spacer ring 36200 receives and mates with the end of the tubular upper mandrel 3604 and includes an angled end face 36200 a that includes a plurality of spaced apart radial grooves 36200 b and another end face that is positioned proximate to an end face of the tubular upper adaptor 3602 is coupled to the tubular upper mandrel by shear pins, 36202 a, 36202 b, 36202 c, and 36202 d. A lower tubular spacer ring 36204 that includes an angled end face 36204 a that includes a plurality of spaced apart radial grooves 36204 b receives, mates, and is coupled to the other end of the tubular upper mandrel 3604 and includes another end face that is positioned proximate to an end face of the external flange 3604 i of the tubular upper mandrel 3604. In an exemplary embodiment, the upper and tubular spacer rings, 3606 and 3610, are fabricated from a composite material.
  • An upper tubular slip assembly 36206 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical slip elements 36206 a that each include an exterior arcuate cylindrical surface 36206 aa including mounting holes, 36206 ab, 36206 ac, 36206 ad, 36206 ae, 36206 af, 36206 ag, 36206 ah, 36206 ai, and 36206 aj, and grooves, 36206 aj and 36206 ak, a front end face 36206 al, a rear end face 36206 am including a mounting hole 36206 an, side faces, 36206 ao and 36206 ap, an interior arcuate cylindrical surface 36206 aq that mates with the exterior surface of the tubular upper mandrel 3604, and an interior tapered surface 36206 ar including a mounting hole 36206 as. Mounting pins 36206 at are received within and coupled to the mounting holes 36206 an and are received within corresponding radial grooves 36200 b of the angled end face 36200 a of the upper tubular spacer ring 36200. Retaining pins 36206 au are mounted within and coupled to the mounting holes 36206 as that include heads 36206 av. Slip retaining bands, 36206 aw and 36206 ax, are received within and coupled to grooves, 36206 aj and 36206 ak, respectively, of the slip elements 36206 a. Slip gripping elements, 36206 ay, 36206 az, 36206 aaa, 36206 aab, 36206 aac, 36206 aad, 36206 aae, 36206 aaf, and 36206 aag, are mounted within, coupled to, and extend out of the mounting holes, 36206 ab, 36206 ac, 36206 ad, 36206 ae, 36206 af, 36206 ag, 36206 ah, 36206 ai, and 36206 aj, respectively. In an exemplary embodiment, the adjacent exterior arcuate cylindrical surfaces 36206 aa of the identical slip elements 36206 a of the upper tubular slip assembly 36206 together define a substantially contiguous cylindrical surface.
  • A lower tubular slip assembly 36208 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical slip elements 36208 a that each include an exterior arcuate cylindrical surface 36208 aa including mounting holes, 36208 ab, 36208 ac, 36208 ad, 36208 ae, 36208 af, 36208 ag, 36208 ah, 36208 ai, and 36208 aj, and grooves, 36208 aj and 36208 ak, a front end face 36208 al, a rear end face 36208 am including a mounting hole 36208 an, side faces, 36208 ao and 36208 ap, an interior arcuate cylindrical surface 36208 aq that mates with the exterior surface of the tubular upper mandrel 3604, and an interior tapered surface 36208 ar including a mounting hole 36208 as. Mounting pins 36208 at are received within and coupled to the mounting holes 36208 an and are received within corresponding radial grooves 36204 b of the angled end face 36204 a of the lower tubular spacer ring 36204. Retaining pins 36208 au are mounted within and coupled to the mounting holes 36208 as that include heads 36208 av. Slip retaining bands, 36208 aw and 36208 ax, are received within and coupled to grooves, 36208 aj and 36208 ak, respectively, of the slip elements 36208 a. Slip gripping elements, 36208 ay, 36208 az, 36208 aaa, 36208 aab, 36208 aac, 36208 aad, 36208 aae, 36208 aaf, and 36208 aag, are mounted within, coupled to, and extend out of the mounting holes, 36208 ab, 36208 ac, 36208 ad, 36208 ae, 36208 af, 36208 ag, 36208 ah, 36208 ai, and 36208 aj, respectively. In an exemplary embodiment, the adjacent exterior arcuate cylindrical surfaces 36208 aa of the identical slip elements 36208 a of the upper tubular slip assembly 36208 together define a substantially contiguous cylindrical surface.
  • An upper tubular wedge 36210 that receives the tubular upper mandrel 3604 includes an angled front end face 36210 a including spaced apart radial grooves 36210 b, a rear end face 36210 c, an exterior cylindrical surface 36210 d, a plurality of spaced apart faceted tapered exterior surface segments 36210 e that mate with corresponding tapered internal surfaces 36206 ar of corresponding slip elements 36206 a of the upper tubular slip assembly 36206, and T-shaped exterior grooves 36210 f aligned with the midline of corresponding faceted tapered exterior surface segments that extend from the angled end face to the rear end face that receive and mate with corresponding retaining pins 36206 au of corresponding slip elements of the upper tubular slip assembly. The upper tubular wedge 36210 is releasably coupled to the tubular upper mandrel 3604 by shear pins 36211.
  • A lower tubular wedge 36212 that receives the tubular upper mandrel 3604 includes an angled front end face 36212 a including spaced apart radial grooves 36212 b, a rear end face 36212 c, an exterior cylindrical surface 36212 d, a plurality of spaced apart faceted tapered exterior surface segments 36212 e that mate with corresponding tapered internal surfaces 36208 ar of corresponding slip elements 36208 a of the upper tubular slip assembly 36208, and T-shaped exterior grooves 36212 f aligned with the midline of corresponding faceted tapered exterior surface segments that extend from the angled end face to the rear end face that receive and mate with corresponding retaining pins 36208 au of corresponding slip elements of the lower tubular slip assembly. The lower tubular wedge 36212 is releasably coupled to the tubular upper mandrel 3604 by shear pins 36213.
  • An upper tubular extrusion limiter assembly 36214 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical extrusion limiter elements 36214 a that each include an angled front end face 36214 aa having a recessed portion 36214 ab, an angled rear end face 36214 ac that defines a mounting hole 36214 ad, an interior arcuate cylindrical surface 36214 ae that mates with the tubular upper mandrel, and an exterior arcuate cylindrical surface 36214 af including grooves, 36214 ag, 36214 ah, and 36214 ai. Disk extrusion preventers 36214 aj are mounted within and coupled to the recessed portions 36214 ab of adjacent extrusion limiter elements 36214 a, and mounting pins 36214 ak are mounted within and coupled to mounting holes 36214 ad of corresponding extrusion limiter elements 36214 a that are received within corresponding radial grooves 36210 b of the front end face 36210 a of the upper tubular wedge 36210. Retaining bands, 36214 al, 36214 am, and 36214 an, are positioned within and coupled to the grooves, 36214 ai, 36214 ah, and 36214 ag, respectively, of the extrusion limiter elements 36214 a.
  • A lower tubular extrusion limiter assembly 36216 that receives and is movably mounted upon the tubular upper mandrel 3604 includes a plurality of substantially identical extrusion limiter elements 36216 a that each include an angled front end face 36216 aa having a recessed portion 36216 ab, an angled rear end face 36216 ac that defines a mounting hole 36216 ad, an interior arcuate cylindrical surface 36216 ae that mates with the tubular upper mandrel, and an exterior arcuate cylindrical surface 36216 af including grooves, 36216 ag, 36216 ah, and 36216 ai. Disk extrusion preventers 36216 aj are mounted within and coupled to the recessed portions 36216 ab of adjacent extrusion limiter elements 36216 a, and mounting pins 36216 ak are mounted within and coupled to mounting holes 36216 ad of corresponding extrusion limiter elements 36216 a that are received within corresponding radial grooves 36212 b of the front end face 36212 a of the lower tubular wedge 36212. Retaining bands, 36216 al, 36216 am, and 36216 an, are positioned within and coupled to the grooves, 36216 ag, 36216 ah, and 36216 ai, of the extrusion limiter elements 36216 a.
  • The angled end face 3640 b of the upper tubular elastomeric packer element 3640 mates with and is positioned proximate the angled end faces 36214 aa and disk extrusion preventers 36214 aj of the extrusion limiter elements 36214 a of the upper tubular extrusion limiter assembly 36214, and the angled end face 3642 b of the lower tubular elastomeric packer element 3642 mates with and is positioned proximate the angled end faces 36216 aa and disk extrusion preventers 36216 aj of the extrusion limiter elements 36216 a of the lower tubular extrusion limiter assembly 36216.
  • During operation of the alternative embodiment of the packer assembly 36 described above with reference to FIGS. 21 and 21A to 21AX, the first step in setting the packer assembly 36 includes pushing the slip elements, 36206 a and 36208 a, of the upper and lower slip assemblies, 36206 and 36208, respectively, up the upper and lower tubular wedges, 36210 and 36212, respectively, which breaks the retaining rings, 36206 aw and 36206 ax, and 36208 aw and 36208 ax, respectively, and moves the slip elements outwardly against the interior surface of the expandable wellbore casing 100. In an exemplary embodiment, during the radial displacement of the slip elements, 36206 a and 36208 a, the retaining pins, 36206 au and 36208 au, respectively, and the mounting pins, 36206 at and 36208 at, respectively, maintain the slip elements in an evenly spaced apart configuration. In an exemplary embodiment, during the operation of the packer assembly 36, the mounting pins, 36214 ak and 36216 ak, maintain the extrusion limiter elements, 36214 a and 36216 a, of the upper and lower tubular extrusion limiter assemblies, 36214 and 36216, respectively, in an evenly spaced apart configuration. The operation of the alternative embodiment of the packer assembly 36 described above with reference to FIGS. 21 and 21A to 21AX is otherwise substantially identical to the operation of the packer assembly described above with reference to FIGS. 20A1 to 20A5, 20B1 to 20B5, 20C1 to 20C5, 20D1 to 20D5, 20E1 to 20E6, 20F1 to 20F6, 20G1 to 20G6, and 20H1 to 20H5.
  • In an exemplary embodiment, as illustrated in FIGS. 22A to 22D, a packer setting tool assembly 38 includes a tubular adapter 3802 that defines a longitudinal passage 3802 a, radial external mounting holes, 3802 b and 3802 c, radial passages, 3802 d and 3802 e, and includes an external threaded connection 3802 f at one end and an internal annular recess 3802 g having an internal threaded connection at the other end.
  • An external threaded connection 3804 a of an end of a tubular support or tubular upper mandrel 3804 that defines a longitudinal passage 3804 b, external mounting holes, 3804 c and 3804 d, and includes an external annular recess 3804 e, an external annular recess 3804 f, external splines 3804 g, an external flange 3804 h, external splines 3804 i, and an internal threaded connection 3804 j at another end is received within and is coupled to the internally threaded connection of the internal annular recess 3802 g of the other end of the tubular adaptor 3802. The tubular upper mandrel 3804 further includes external mounting holes, 3804 k and 3804 l, radial passages, 3804 m and 3804 n, and external mounting holes, 3804 o and 3804 p.
  • Torque pins, 3805 a and 3805 b, are received within and coupled to the mounting holes, 3804 c and 3804 d, respectively, of the tubular upper mandrel 3804 and also extend into the radial passages, 3802 d and 3802 e, respectively, of the tubular adaptor 3802.
  • An external threaded connection 3806 a of an end of a tubular support or tubular mandrel 3806 that defines a longitudinal passage 3806 b and includes an external annular recess 3806 c and an external annular recess 3806 d having an external threaded connection is received within and is coupled to the internal threaded connection 3804 j of the tubular upper mandrel 3804.
  • An internal threaded connection 3808 a of a tubular stinger 3808 that defines a longitudinal passage 3808 b and includes an external annular recess 3808 c, and an external tapered annular recess 3808 d and an engagement shoulder 3808 e at another end receives and is coupled to the external threaded connection of the external annular recess 3806 d of the mandrel 3806. A sealing member 3810 is mounted upon and coupled to the external annular recess 3806 d of the mandrel 3806.
  • Internal splines 3812 aa of a key 3812 a that includes an internal annular recess 3812 ab at one end are movably received within and engage the external splines 3804 g of the tubular upper mandrel 3804. Similarly, internal splines 3812 ba of a key 3812 b that includes an internal annular recess 3812 bb at one end are movably received within and engage the external splines 3804 g of the tubular upper mandrel 3804.
  • An end of a tubular support or tubular bushing 3816 that defines a longitudinal passage 3816 a for receiving and mating with the upper mandrel 3804, and radial passages, 3816 b and 3816 c, and includes an external flange 3816 d, an internal annular recess 3816 e, circumferentially spaced apart teeth 3816 f, and external flanges, 3816 g and 3816 h, at another end mates with the other ends of the keys, 3812 a and 3812 b. The external flange 3804 h of the upper mandrel 3804 extends within the internal annular recess 3816 e of the tubular bushing 3816 so that the tubular bushing 3816 is retained between the keys, 3812 a and 3812 b, and the external flange 3804 h of the upper mandrel 3804. The tubular bushing 3816 further includes radial holes, 3816 i and 3816 j, through which the keys, 3812 a and 3812 b, respectively, radially extend so that the keys, 3812 a and 3812 b, lock the bushing 3816 to the upper mandrel 3804. The tubular bushing 3816 further includes an external annular recess 3816 k.
  • A tubular support or tubular spacer 3818 defines a longitudinal passage 3818 a for receiving the upper mandrel 3804, includes an annular portion 3818 b at one end that is near or adjacent the other end of the tubular adaptor 3802, further defines radial passages, 3818 c and 3818 d, and further includes an external annular recess 3818 e, an external annular recess 3818 f, an internal annular recess 3818 g, and counterbores, 3818 h and 3818 i, that are axially aligned with the holes, 3804 k and 3804 l, respectively, of the upper mandrel 3804. The external annular recesses, 3818 e and 3818 f, define an annular protrusion 3818 j. Screws 3820 a and 3820 b are threadably engaged with the counterbores, 3818 h and 3818 i, respectively, of the tubular spacer 3818, and extend into the holes 3804 m and 3804 l, respectively, of the upper mandrel 3804, thereby coupling the tubular spacer 3818 to the upper mandrel 3804.
  • An end of a tubular packer cup sleeve 3822 that defines a longitudinal passage 3822 a for receiving the upper mandrel 3804 and includes an external annular recess 3822 b and an internal annular recess 3822 c, extends into the internal annular recess 3818 g of the tubular spacer 3818. A retaining ring 3824 is disposed in the external annular recess 3804 e of the upper mandrel 3804 and extends into the internal annular recess 3822 c of the packer cup sleeve 3822, retaining the end of the packer cup sleeve 3822 in the internal annular recess 3818 g of the tubular spacer 3818, thereby coupling the packer cup sleeve 3822 to the upper mandrel 3804.
  • A packer cup 3824 is disposed in the external annular recess 3822 b of the packer cup sleeve 3822, and a packer ring 3825 is disposed in the external annular recess 3822 b of the packer cup sleeve 3822 and is axially positioned between the packer cup 3824 and the tubular spacer 3818.
  • An end of a tubular support or tubular upper sleeve 3826 that defines a longitudinal passage 3826 a and includes an internal annular recess 3826 b, an internal annular recess 3826 c, an internal annular recess 3826 d, an internal annular recess 3826 e, an internal annular recess 3826 f, and an internal threaded connection 3826 g, is positioned near or adjacent the annular portion 3818 b of the tubular spacer 3818 so that the annular portion 3818 b of the tubular spacer 3818 is axially positioned between the tubular adaptor 3802 and the upper sleeve 3826. Radial holes, 3826 h and 3826 i, extend through the internal annular recess 3826 b, and radial holes, 3826 j and 3286 k, extend through the internal annular recess 3826 d. The packer cup 3824 sealingly engages the internal annular recess 3826 c of the upper sleeve 3826.
  • Upper retaining dogs, 3828 a and 3828 b, including internal annular recesses 3828 aa and 3828 ba, respectively, extend through the radial holes 3826 h and 3826 i, respectively, and are coupled to the tubular upper sleeve 3826. The upper retaining dogs, 3828 a and 3828 b, are adapted to further extend into the external annular recess 3818 e to releasably engage the tubular spacer 3818, as shown in FIG. 22A and under conditions to be described.
  • A retaining ring 3829 extends into the external annular recess 3804 f of the upper mandrel 3804 and extends into an internal annular recess 3830 a of a lower dog retainer 3830. The lower dog retainer 3830 further includes an internal annular recess 3830 b, an external annular recess 3830 c, counterbores, 3830 d and 3830 e, that are axially aligned with the external mounting holes, 3804 o and 3804 p, respectively, of the upper mandrel 3804, and radial holes 3830 f and 3830 g. Screws, 3832 a and 3832 b, are threadably engaged with the counterbores, 3830 d and 3830 e, respectively, of the lower dog retainer 3830, and extend into the external mounting holes, 3804 o and 3804 p, respectively, of the upper mandrel 3804, which, along with the retaining ring 3829, couple the lower dog retainer 3830 to the upper mandrel 3804.
  • A tubular support or tubular retaining sleeve 3834 includes an external annular recess 3834 a and an external annular recess 3834 b, and mates with the exterior surface of the upper mandrel 3804 and with the interior surface of the upper sleeve 3826. Lower retaining dogs, 3836 a and 3836 b, including respective internal annular recesses, 3836 aa and 3836 ab, engage the internal annular recess 3826 d and extend through the radial holes, 3830 f and 3830 g, respectively, to mate with the retaining sleeve 3834. It is understood that the retaining sleeve 3834 retains the lower retaining dogs, 3836 a and 3836 b, so that any relative movement between the lower retaining dogs, 3836 a and 3836 b, and the upper mandrel 3804 is substantially prevented. Rupture discs, 3838 a and 3838 b, are received and mounted within the radial passages, 3804 m and 3804 n.
  • An external threaded connection 3840 a of an external annular recess 3840 b of a tubular support or spring mandrel 3840 is received within the internal annular recess 3826 f of the upper sleeve 3826 and is coupled to the internal threaded connection 3826 g of the upper sleeve 3826. The spring mandrel 3840 further includes an external annular recess 3840 c, an external annular recess 3840 d, an external annular recess 3840 e, an external threaded connection 3840 f, an internal annular recess 3840 g and an internal annular recess 3840 h. A locking dog 3841 is received within the internal annular recess 3840 h of the spring mandrel 3840 and engages the exterior surface of the bushing 3816.
  • An internal threaded connection 3842 a of a tubular support or tubular spring retainer 3842 is coupled to the external threaded connection 3840 f of the spring mandrel 3840, and includes a external flange 3842 b. A tubular spring sleeve 3844 engages the external flange 3842 b of the spring retainer 3842 and includes an internal annular recess 3844 a, radial passages, 3844 b and 3844 c, an external annular recess 3844 d and an external threaded connection 3844 e. A compressible element such as a spring 3846 is retained and extends within an annular region 3848 defined by the internal annular recess 3844 a of the spring sleeve 3844, the exterior of the spring retainer 3842 and at least an end of the spring mandrel 3840, thereby circumferentially extending about the tubular upper mandrel 3804.
  • A tubular locking dog retainer 3843 is received within the internal annular recess 3826 f of the upper sleeve 3826 and includes an internal flange 3843 a that engages the keys, 3812 a and 3812 b, and is received within the internal annular recess 3840 g of the spring mandrel 3840.
  • An internal threaded connection 3850 a of an end of a tubular setting sleeve 3850 that defines a longitudinal passage 3850 b, radial passages, 3850 c and 3850 d, radial passages, 3850 e and 3850 f, and includes an internal flange 3850 g at another end, engages the external threaded connection 3844 e of the spring retainer 3842.
  • An internal flange 3852 a of a tubular coupling ring 3852 that defines a longitudinal passage 3852 b and radial passages, 3852 c and 3852 d, and includes an external annular recess 3852 e, receives and mates with the external flange 3816 h of the bushing 3816. An internal flange 3854 a of a tubular retaining collet 3854 that includes a plurality of axially extending collet fingers 3854 b, each finger 3854 b having internal flanges 3854 c at an end of each collet finger, receives the tubular coupling ring 3852 and engages the external annular recess 3852 e of the tubular coupling ring 3852.
  • In an exemplary embodiment, as illustrated in FIGS. 23A to 23E, during the operation of the packer setting tool assembly 38 and the packer assembly 36, the packer setting tool assembly 38 and the packer assembly 36 are coupled to one another by inserting the end of the tubular upper adaptor 3602 into the other end of the tubular coupling ring 3852, bringing the circumferentially spaced teeth 3816 f of the other end of the tubular bushing 3816 into engagement with the circumferentially spaced teeth 3602 e of the end of the tubular upper adaptor 3602, and mounting shear pins, 36100 a and 36100 b, within the radial passages, 3852 c and 3852 d, respectively, of the tubular coupling ring 3852 and within the mounting holes, 3602 c and 3602 d, respectively, of the tubular upper adaptor 3602. As a result, the tubular mandrel 3806 and the tubular stinger 3808 of the packer setting tool assembly 38 are thereby positioned within the longitudinal passage 3604 b of the tubular upper mandrel 3604 with the engagement shoulder 3808 e of the tubular stinger 3808 positioned within the longitudinal passage 3646 b of the tubular lower mandrel 3646 proximate the collet fingers 3650 d of the tubular sliding sleeve valve 3650.
  • In an exemplary embodiment, the packer setting tool assembly 38 and the packer assembly 36 are positioned within the expandable wellbore casing 100, and the internal threaded connection 30 a of an end of the adjustable casing expansion cone assembly 30 receives and is coupled to the external threaded connection 3802 f of the tubular adaptor 3802 of the packer setting tool assembly 38. The upper retaining dogs, 3828 a and 3828 b, and/or the outer diameter of the tubular upper sleeve 3826, are sized so that the upper retaining dogs, 3828 a and 3828 b, and/or at least a portion of the exterior surface of the tubular upper sleeve 3826, engage the wellbore casing 100, and the tubular upper sleeve 3826 is radially inwardly biased so that the upper retaining dogs, 3828 a and 3828 b, extend into the external annular recess 3818 e and are forced to mate with the tubular spacer 3818, thereby releasably engaging the tubular spacer 3818, including releasably engaging the annular protrusion 3818 j. Furthermore, in an exemplary embodiment, torque pins, 3676 d and 3676 e, may be mounted within mounting holes, 3676 f and 3676 g, respectively, of the tubular bypass sleeve 3676 to couple the tubular bypass sleeve 3676 to the expandable wellbore casing 100. As a result, torsion loads may be transferred between the tubular bypass sleeve 3676 and the expandable wellbore casing 100.
  • In an exemplary embodiment, as illustrated in FIGS. 24A to 24E, the plug 36104 is then injected into the setting tool assembly 38 and the packer assembly 36 by injecting the fluidic material 36106 into the setting tool assembly 38 and the packer assembly 36 through the longitudinal passages, 3802 a, 3804 b, 3806 b, 3808 b, 3650 a, 3646 b and 3664 a of the tubular adaptor 3802, tubular upper mandrel 3804, tubular mandrel 3806, tubular stinger 3808, tubular sliding sleeve valve 3650, tubular lower mandrel 3646, and tubular plug seat 3664, respectively. The plug 36104 is thereby positioned within the longitudinal passage 3664 a of the tubular plug seat 3664. The flow ports, 3664 c and 3664 d, of the tubular plug seat 3664 are aligned with the upper flow ports, 3660 c and 3660 d, respectively, of the tubular bypass mandrel 3660.
  • In an exemplary embodiment, as illustrated in FIGS. 25A to 25E, continued injection of the fluidic material 36106 following the seating of the plug 36104 within the longitudinal passage 3664 a of the tubular plug seat 3664 causes the plug and the tubular plug seat to be displaced downwardly in the direction 36108 until further movement of the tubular plug seat is prevented by the interaction of the circumferentially-spaced set screws 3674 and 3675 with the external annular recess 3664 f of the tubular plug seat. As a result, the flow ports, 3664 c and 3664 d, of the tubular plug seat 3664 are moved out of alignment with the upper flow ports, 3660 c and 3660 d, respectively, of the tubular bypass mandrel 3660.
  • In an exemplary embodiment, as illustrated in FIGS. 26A to 26E, continued injection of the fluidic material 36106 following the prevention of further movement of the tubular plug seat 3664 actuates the extension actuator assembly 26 in a manner substantially similar to that described above so that the extension actuator assembly 26 pushes the adjustable bell section expansion cone assembly 28, the adjustable casing expansion cone assembly 30, the packer setting tool assembly 38 and the packer assembly 36 out of the wellbore casing 100. Since the packer setting tool assembly 38 extends outside of the wellbore casing 100, the upper retaining dogs, 3828 a and 3828 b, and the tubular upper sleeve 3826 no longer engage the wellbore casing 100 and thus the tubular upper sleeve 3826 is no longer radially inwardly biased. As a result, the upper retaining dogs, 3828 a and 3828 b, are released from mating with the tubular spacer 3818 and engaging the annular protrusion 3818 j.
  • In an exemplary embodiment, it is understood that if it is desired to cease further operation of the packer assembly 36 when the packer setting tool assembly 38 and the packer assembly 36 extend outside of the wellbore casing 100, the upper sleeve 3826 is displaced in a direction toward the packer assembly 36 in a manner to be described below, thereby causing the spring sleeve 3844, the setting sleeve 3850 and the upper tubular spacing ring 3606 of the packer assembly 36 to move in a direction towards the upper tubular wedge 3620 in a manner described below. As a result, the upper tubular slip 3612 is forced to move along the upper tubular wedge 3620 until the upper tubular slip 3612 is pushed off of the packer assembly 36, thereby permitting the packer setting tool assembly 38 and the packer assembly 36 to be retrieved.
  • In an exemplary embodiment, it is understood that if the packer setting tool assembly 38 and the packer assembly 36 are not able to be extended outside of the wellbore casing 100, the upper retaining dogs, 3828 a and 3828 b, continue to mate with the tubular spacer 3818 and to engage the annular protrusion 3818 j, thereby preventing the upper sleeve 3826 from moving in a direction towards the packer assembly 36 in a manner, and for reasons, to be described below, and permitting the packer setting tool assembly 38 and the packer assembly 36 to be retrieved.
  • In an exemplary embodiment, the wellbore casing 100 is radially expanded and plastically deformed using the ball gripper assembly 16, the tension actuator assembly 18, the casing lock assembly 24, the extension actuator assembly 26 and the expansion cone assemblies, 28 and 30, in a manner of operation substantially similar to any one of the manners of operation described and/or referenced above, and/or any combination thereof.
  • In an exemplary embodiment, as illustrated in FIGS. 27A to 27E, after the expandable wellbore casing 100 has been radially expanded and plastically deformed to form at least the bell section 112 of the expandable wellbore casing 100, thereby shearing the torque pins, 3676 d and 3676 e, the packer setting tool assembly 38 and the packer assembly 36 are then moved upwardly to a position within the expandable wellbore casing 100 above the bell section 112.
  • Continued injection of the fluidic material 36106, with any further movement of the tubular plug seat 3664 still being prevented, increases the operating pressure of the fluidic material 36106 above a predetermined level sufficient to rupture the rupture discs, 3838 a and 3838 b. As a result, the fluidic material 36106 enters an annulus 3856 defined by the tubular upper mandrel 3804 and the tubular upper sleeve 3826. As a result, the retaining sleeve 3834 is displaced downwardly in the direction 36108, and engages the internal annular recess 3830 b of the lower dog retainer 3830. As a result, the lower retaining dogs, 3836 a and 386 b, no longer engage the internal annular recess 3826 d of the upper sleeve 3826, but instead move radially inward to engage the external annular recesses, 3834 a and 3834 b, of the tubular retaining sleeve 3834. Thus, it is understood that the lower retaining dogs, 3836 a and 3836 b, are released from the upper sleeve 3826.
  • In an exemplary embodiment, as illustrated in FIGS. 28A to 28E, the operating pressure of the fluidic material 36106 in the annulus 3856 causes the upper sleeve 3826, the spring mandrel 3840, the spring sleeve 3844 and the setting sleeve 3850 to be displaced in the downward direction 36108 until the setting sleeve 3850 engages the upper tubular spacer ring 3606 of the packer assembly 36, which is mated with the upper tubular slip 3612 of the packer assembly 36.
  • The operating pressure of the fluidic material 36106 in the annulus 3856 continues to cause the upper sleeve 3826, the spring mandrel 3840 and the spring sleeve 3844 to be displaced in the downward direction 36108, relative to the setting sleeve 3850. As a result, the external annular recess 3840 d of the spring mandrel 3840 compresses the spring 3846 against an end face 3844 aa defined by the internal annular recess 3844 a of the spring sleeve 3844.
  • When the spring 3846 is fully compressed, the operating pressure of the fluidic material 36106 in the annulus 3856 causes the upper sleeve 3826 to force the upper tubular slip 3612 of the packer assembly 36, via force transmission across the spring mandrel 3840, the compressed spring 3846, the spring sleeve 3844, the setting sleeve 3850 and the upper tubular spacer ring 3606, to move along the upper tubular wedge 3620 of the packer assembly 36. In an exemplary embodiment, it is understood that the shear pins, 3608 a and 3608 b, may be broken to enable the upper tubular slip 3612 to move along the upper tubular wedge 3620. In an exemplary embodiment, it is further understood that one or more of the slip retaining bands, 3612 c, 3612 d, 3612 e, 3612 f, 3612 g, 3614 a, 3614 b, 3614 c, 3614 d, and 3614 e, if present, may be broken to enable the upper tubular slip 3612 to move along the upper tubular wedge 3620.
  • The upper sleeve 3826 continues to force the upper tubular slip 3612 to move along the upper tubular wedge 3620 until the spring mandrel 3840 engages the external flange 3816 d of the tubular bushing 3816, the end of which, in turn, is engaged with the external flange 3804 h of the upper mandrel 3804. Thus, any further displacement of the upper sleeve 3826 in the downward direction 36108 is substantially prevented.
  • As a result of the displacement of the upper sleeve 3826 in the downward direction 36108, the keys, 3812 a and 3812 b, are released from their engagement with the internal flange 3843 a of the locking dog retainer 3843. As another result of the displacement of the upper sleeve 3826 in the downward direction 36108, the locking dog 3841 is displaced in the downward direction 36018 so that the locking dog 3841 is received within the external annular recess 3816 k of the bushing 3816.
  • In an exemplary embodiment, it is understood that the keys, 3812 a and 3812 b, lock the bushing 3816 to the upper mandrel 3804, and allow torque and load top to be transmitted from the upper mandrel 3804 to the tubular bushing 3816, and to the packer assembly 36 via the above-described coupling between the packer setting tool assembly 38 and the packer assembly 36. In an exemplary embodiment, it is understood that the keys, 3812 a and 3812 b, prevent the stinger 3808 from engaging and displacing the sliding sleeve valve 3650, thereby preventing the radial flow ports, 3650 b and 3650 c, of the sliding sleeve valve 3650 from being axially aligned with the flow ports, 3646 e and 3646 f, of the tubular lower mandrel 3646 of the packer assembly 36.
  • In an exemplary embodiment, as illustrated in FIGS. 29A through 29E, although any further displacement of the upper sleeve 3826 in the downward direction 36108 is prevented, the fully compressed spring 3846 begins to uncompress, and extends to force the spring sleeve 3844, the setting sleeve 3850 and the upper tubular spacing ring 3606 of the packer assembly 36 in the downward direction 36108, thereby causing the upper tubular slip 3612 to further move along the upper tubular wedge 3620 and against the interior surface of the wellbore casing 100, until the upper tubular slip 3612 is set against the wellbore casing 100. As a result, further longitudinal displacement of the upper tubular slip 3612 relative to the wellbore casing 100 is prevented.
  • In an exemplary embodiment, it is understood that, by preventing any further displacement of the upper sleeve 3826 in the downward direction and by permitting the compressed spring 3846 to uncompress and force the upper tubular slip 3612 to set against the wellbore casing 100, the upper tubular slip 3612 is substantially prevented from applying an impact load against the interior surface of the wellbore casing 100.
  • In an exemplary embodiment, as illustrated in FIGS. 30A through 30E, after the upper tubular slip 3612 is set against the wellbore casing 100, an upward tensile force is applied to the tubular support member 12, and the ball gripper assembly 16 is then operated to engage the interior surface of the wellbore casing 100 in a manner of operation substantially similar to any one of the manners of operation described and/or referenced above, and/or any combination thereof. The tension actuator assembly 18 is then operated to apply a tensile force to the tubular adaptor 3802 in an upward direction 3860, in any one of the manners of operation described and/or referenced above, and/or any combination thereof, thereby compressing the lower tubular slip 3616, the lower tubular wedge 3624, the lower tubular extrusion limiter 3634, the central elastomeric packer element 3644, the upper tubular extrusion limiter 3628 and the upper tubular wedge 3620 between the lower tubular spacer ring 3610 and the stationary upper tubular slip 3612. As a result, the lower tubular slip 3616 moves along the lower tubular wedge 3624 and into engagement with the interior surface of the wellbore casing 100, forcing the lower tubular slip 3616 to set against the interior surface of the wellbore casing 100. As another result, the elastomeric packer element 3644 is compressed radially outwardly into engagement with the interior surface of the wellbore casing 100, forcing the packer element 3644 to set against the interior surface of the wellbore casing 100. As a result, further longitudinal displacement of the upper tubular slip 3612, the lower tubular slip 3616 and the packer element 3644, relative to the wellbore casing 100, is prevented.
  • Continued application of the upward tensile force to the tubular adaptor 3802 will then shear the shear pins, 36100 a and 36100 b, thereby disengaging and releasing the packer setting tool assembly 38 from the packer assembly 36.
  • In an exemplary embodiment, the packer setting tool assembly 38 continues to move away from the packer assembly 36, in the direction 3860, at least until at least a portion of the stinger 3808 no longer extends within the longitudinal passage 3602 a of the tubular upper adaptor 3602 of the packer assembly 36, and the adjustable expansion cone assembly 30 engages and mates with at least a portion of the interior surface of the unexpanded portion of the wellbore casing 100.
  • In an exemplary embodiment, as illustrated in FIGS. 31A through 31E, continued injection of the fluidic material 36106 causes the packer setting tool assembly 38 to move in the direction 36108 until the tubular spacer ring 3606 engages the stationary upper tubular slip 3612. The continued injection of the fluidic material 36106 also causes the packer assembly 36, including the tubular upper mandrel 3604, to move in the direction 36108 so that the lower tubular spacer ring 3610 moves away from the stationary lower tubular slip 3616. As a result of the continued injection of the fluidic material 36106, the portion of the interior of the wellbore casing 100 within which at least a portion of the packer assembly 36 extends is pressurized, thereby testing the ability of the engagement between the wellbore casing 100 and one or more of the upper tubular slip 3612, the upper tubular extrusion limiter 3628, the elastomeric packer element 3644, the lower tubular extrusion limiter 3634 and the lower tubular slip 3616 to maintain a pressure seal against the interior surface of the wellbore casing 100.
  • In an exemplary embodiment, as illustrated in FIGS. 32A through 32E, the continued injection of the fluidic material 36106 is stopped, and the operating pressure within the longitudinal passages, 3802 a, 3804 b, 3806 b, 3808 b, 3650 a, 3646 b and 3664 a of the tubular adaptor 3802, tubular upper mandrel 3804, tubular mandrel 3806, tubular stinger 3808, tubular sliding sleeve valve 3650, tubular lower mandrel 3646, and tubular plug seat 3664, respectively, is released. The packer setting tool assembly 38 is brought back into engagement with the packer assembly 36 until the engagement shoulder 3808 e of the other end of the tubular stinger 3808 engages the collet fingers 3650 d of the end of the tubular sliding sleeve valve 3650. As a result, further downward displacement of the tubular stinger 3808 displaces the tubular sliding sleeve valve 3650 downwardly until the radial flow ports, 3650 b and 3650 c, of the tubular sliding sleeve valve 3650 are aligned with the radial flow ports, 3646 e and 3646 f, of the tubular lower mandrel 3646. During the downward displacement of the tubular stinger 3808, the locking dog 3841 engages the external annular recess 3816 k of the bushing 3816 and the internal annular recess 3840 h of the spring mandrel 3840 to further separate the bushing 3816, the coupling ring 3852 and the retaining collet 3854 from the packer assembly 36.
  • In an exemplary embodiment, as illustrated in FIGS. 33A through 33E, a hardenable fluidic sealing material 36116 may then be injected into the packer setting tool assembly 38 and the packer assembly 36 through the longitudinal passages 3802 a, 3804 b, 3806 b, 3808 b and 3650 a of the tubular adaptor 3802, tubular upper mandrel 3804, tubular mandrel 3806, tubular stinger 3808 and the tubular sliding sleeve valve 3650, respectively. The hardenable fluidic sealing material 3116 may then flow out of the longitudinal passage 3650 a, through the radial ports, 3650 b and 3650 c, of the tubular sliding sleeve valve 3650, through the radial ports, 3646 e and 3646 f, of the tubular lower mandrel 3646, and into an annulus 36118 defined by the exterior surface of the tubular lower mandrel 3646 and the interior surface of the tubular outer sleeve 3658. The hardenable sealing material 3116 may then flow out of the annulus 36118, through the upper flow ports, 3658 d and 3658 e, and the lower flow ports, 3658 f and 3658 g, and into the annulus between the wellbore casing 100 and the wellbore 102. In an exemplary embodiment, in addition to, or instead of the injection of the hardenable fluidic sealing material 36116, it is understood that other well fluids may be injected into the packer setting tool assembly 38 and the packer assembly 36 in a manner similar to the injection of the hardenable fluidic sealing material 36116.
  • The tubular sliding sleeve valve 3650 may then be returned to its original position, with the radial flow ports, 3650 b and 3650 c, of the tubular sliding sleeve valve out of alignment with the flow ports, 3646 e and 3646 f, of the tubular lower mandrel 3646. The hardenable fluidic sealing material 36116 may then be allowed to cure before, during, or after the continued operation of the system 10 to further radially expand and plastically deform the expandable wellbore casing 100.
  • In an exemplary embodiment, it is understood that if it is desired to retrieve the packer setting tool assembly 38 when the packer assembly 36 is in the bell section 112 of the wellbore casing 100, the packer setting tool assembly 38 and the packer assembly 36 are operated in the above-described manner so that the upper tubular slip 3612, the lower tubular slip 3616 and the packer element 3644 engage and set against the interior surface of the bell section 112 of the wellbore casing 100, thereby permitting the packer setting tool assembly 38 to be retrieved, that is, to be moved in a direction away from the upper tubular slip 3612, the lower tubular slip 3614 and the packer element 3644.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member has been described that includes a support member, a cutting device for cutting the tubular member coupled to the support member, and an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member. In an exemplary embodiment, the apparatus further includes a gripping device for gripping the tubular member coupled to the support member. In an exemplary embodiment, the gripping device comprises a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member. In an exemplary embodiment, if the tubular member is displaced in a first axial direction, the gripping device grips the tubular member; and, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position. In an exemplary embodiment, the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator. In an exemplary embodiment, the apparatus further includes a sealing device for sealing an interface with the tubular member coupled to the support member. In an exemplary embodiment, the sealing device seals an annulus defines between the support member and the tubular member. In an exemplary embodiment, the apparatus further includes a locking device for locking the position of the tubular member relative to the support member. In an exemplary embodiment, the apparatus further includes a packer assembly coupled to the support member. In an exemplary embodiment, the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member. In an exemplary embodiment, the packer includes: a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member. In an exemplary embodiment, the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device includes: a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve. In an exemplary embodiment, the apparatus further includes an actuator for displacing the expansion device relative to the support member. In an exemplary embodiment, the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device. In an exemplary embodiment, the actuator includes means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the first and second actuators include means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the actuator includes a plurality of pistons positioned within corresponding piston chambers. In an exemplary embodiment, the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements includes a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements. In an exemplary embodiment, the expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements. In an exemplary embodiment, the expansion device includes an adjustable expansion device. In an exemplary embodiment, the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices includes an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member has been described that includes a support member, an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member, and an actuator coupled to the support member for displacing the expansion device relative to the support member. In an exemplary embodiment, the apparatus further includes a cutting device coupled to the support member for cutting the tubular member. In an exemplary embodiment, the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements. In an exemplary embodiment, the apparatus further includes a gripping device for gripping the tubular member coupled to the support member. In an exemplary embodiment, the gripping device includes a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member. In an exemplary embodiment, if the tubular member is displaced in a first axial direction, the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position. In an exemplary embodiment, the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator. In an exemplary embodiment, the apparatus further includes a sealing device for sealing an interface with the tubular member coupled to the support member. In an exemplary embodiment, the sealing device seals an annulus defines between the support member and the tubular member. In an exemplary embodiment, the apparatus further includes a locking device for locking the position of the tubular member relative to the support member. In an exemplary embodiment, the apparatus further includes a packer assembly coupled to the support member. In an exemplary embodiment, the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member. In an exemplary embodiment, the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device comprises: a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve. In an exemplary embodiment, the expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, the in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements. In an exemplary embodiment, the expansion device includes an adjustable expansion device. In an exemplary embodiment, the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices includes an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member has been described that includes a support member; an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a sealing assembly for sealing an annulus defined between the support member and the tubular member. In an exemplary embodiment, the apparatus further includes a gripping device for gripping the tubular member coupled to the support member. In an exemplary embodiment, the gripping device includes a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member. In an exemplary embodiment, the if the tubular member is displaced in a first axial direction, the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position. In an exemplary embodiment, the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator. In an exemplary embodiment, the apparatus further includes a locking device for locking the position of the tubular member relative to the support member. In an exemplary embodiment, the apparatus further includes a packer assembly coupled to the support member. In an exemplary embodiment, the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member. In an exemplary embodiment, the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve. In an exemplary embodiment, the apparatus further includes an actuator for displacing the expansion device relative to the support member. In an exemplary embodiment, the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device. In an exemplary embodiment, the actuator includes means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the first and second actuators comprise means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the actuator includes a plurality of pistons positioned within corresponding piston chambers. In an exemplary embodiment, the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements. In an exemplary embodiment, the expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements includes a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements. In an exemplary embodiment, the expansion device includes an adjustable expansion device. In an exemplary embodiment, the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices includes an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member has been described that includes a support member; a first expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a second expansion device for radially expanding and plastically deforming the tubular member coupled to the support member. In an exemplary embodiment, the apparatus further includes a gripping device for gripping the tubular member coupled to the support member. In an exemplary embodiment, the gripping device includes a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member. In an exemplary embodiment, if the tubular member is displaced in a first axial direction, the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position. In an exemplary embodiment, the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator. In an exemplary embodiment, the apparatus further includes a sealing device for sealing an interface with the tubular member coupled to the support member. In an exemplary embodiment, the sealing device seals an annulus defines between the support member and the tubular member. In an exemplary embodiment, the apparatus further includes a locking device for locking the position of the tubular member relative to the support member. In an exemplary embodiment, the apparatus further includes a packer assembly coupled to the support member. In an exemplary embodiment, the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member. In an exemplary embodiment, the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device comprises: a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve. In an exemplary embodiment, the apparatus further includes an actuator for displacing the expansion device relative to the support member. In an exemplary embodiment, the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device. In an exemplary embodiment, the actuator includes means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the first and second actuators include means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the actuator includes a plurality of pistons positioned within corresponding piston chambers. In an exemplary embodiment, the apparatus further includes a cutting device for cutting the tubular member coupled to the support member. In an exemplary embodiment, the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements. In an exemplary embodiment, at least one of the first second expansion devices include a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements. In an exemplary embodiment, at least one of the first and second expansion devices comprise a plurality of expansion devices. In an exemplary embodiment, at least one of the first and second expansion device comprise an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member has been described that includes a support member; an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; and a packer coupled to the support member. In an exemplary embodiment, the apparatus further includes a gripping device for gripping the tubular member coupled to the support member. In an exemplary embodiment, the gripping device comprises a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member. In an exemplary embodiment, if the tubular member is displaced in a first axial direction, the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position. In an exemplary embodiment, the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator. In an exemplary embodiment, the apparatus further includes a sealing device for sealing an interface with the tubular member coupled to the support member. In an exemplary embodiment, the sealing device seals an annulus defines between the support member and the tubular member. In an exemplary embodiment, the apparatus further includes a locking device for locking the position of the tubular member relative to the support member. In an exemplary embodiment, the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member. In an exemplary embodiment, the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve. In an exemplary embodiment, the apparatus further includes an actuator for displacing the expansion device relative to the support member. In an exemplary embodiment, the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device. In an exemplary embodiment, the actuator includes means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the first and second actuators include means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the actuator includes a plurality of pistons positioned within corresponding piston chambers. In an exemplary embodiment, the apparatus further includes a cutting device coupled to the support member for cutting the tubular member. In an exemplary embodiment, the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements. In an exemplary embodiment, the expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements. In an exemplary embodiment, the expansion device includes an adjustable expansion device. In an exemplary embodiment, the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices comprises an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device includes a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for radially expanding and plastically deforming an expandable tubular member has been described that includes a support member; a cutting device for cutting the tubular member coupled to the support member; a gripping device for gripping the tubular member coupled to the support member; a sealing device for sealing an interface with the tubular member coupled to the support member; a locking device for locking the position of the tubular member relative to the support member; a first adjustable expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; a second adjustable expansion device for radially expanding and plastically deforming the tubular member coupled to the support member; a packer coupled to the support member; and an actuator for displacing one or more of the sealing assembly, first and second adjustable expansion devices, and packer relative to the support member. In an exemplary embodiment, the gripping device includes a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction relative to the support member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction relative to the support member. In an exemplary embodiment, if the tubular member is displaced in a first axial direction, the gripping device grips the tubular member; and wherein, if the tubular member is displaced in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, the gripping elements are biased to remain in the first position. In an exemplary embodiment, the gripping device further includes an actuator for moving the gripping elements from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein the actuator is a fluid powered actuator. In an exemplary embodiment, the sealing device seals an annulus defines between the support member and the tubular member. In an exemplary embodiment, the packer assembly includes a packer; and a packer control device for controlling the operation of the packer coupled to the support member. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member. In an exemplary embodiment, the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the packer. In an exemplary embodiment, the packer includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; and wherein the packer control device includes a support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the support member for engaging the sliding sleeve valve. In an exemplary embodiment, the actuator includes a first actuator for pulling the expansion device; and a second actuator for pushing the expansion device. In an exemplary embodiment, the actuator includes means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the first and second actuators include means for transferring torsional loads between the support member and the expansion device. In an exemplary embodiment, the actuator includes a plurality of pistons positioned within corresponding piston chambers. In an exemplary embodiment, the cutting device includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements. In an exemplary embodiment, at least one of the adjustable expansion devices include a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements. In an exemplary embodiment, at least one of the adjustable expansion devices comprise a plurality of expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices include a support member; and a plurality of movable expansion elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the expansion elements between a first position and a second position; wherein in the first position, the expansion elements do not engage the tubular member; and wherein in the second position, the expansion elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the expansion elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the expansion elements include a first set of expansion elements; and a second set of expansion elements; wherein the first set of expansion elements are interleaved with the second set of expansion elements. In an exemplary embodiment, in the first position, the first set of expansion elements are not axially aligned with the second set of expansion elements. In an exemplary embodiment, in the second position, the first set of expansion elements are axially aligned with the second set of expansion elements.
  • An apparatus for cutting a tubular member has been described that includes a support member; and a plurality of movable cutting elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the cutting elements between a first position and a second position; wherein in the first position, the cutting elements do not engage the tubular member; and wherein in the second position, the cutting elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the cutting elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the cutting elements include a first set of cutting elements; and a second set of cutting elements; wherein the first set of cutting elements are interleaved with the second set of cutting elements. In an exemplary embodiment, in the first position, the first set of cutting elements are not axially aligned with the second set of cutting elements. In an exemplary embodiment, in the second position, the first set of cutting elements are axially aligned with the second set of cutting elements.
  • An apparatus for engaging a tubular member has been described that includes a support member; and a plurality of movable elements coupled to the support member. In an exemplary embodiment, the apparatus further includes an actuator coupled to the support member for moving the elements between a first position and a second position; wherein in the first position, the elements do not engage the tubular member; and wherein in the second position, the elements engage the tubular member. In an exemplary embodiment, the apparatus further includes a sensor coupled to the support member for sensing the internal diameter of the tubular member. In an exemplary embodiment, the sensor prevents the elements from being moved to the second position if the internal diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, the elements include a first set of elements; and a second set of elements; wherein the first set of elements are interleaved with the second set of elements. In an exemplary embodiment, in the first position, the first set of elements are not axially aligned with the second set of elements. In an exemplary embodiment, in the second position, the first set of elements are axially aligned with the second set of elements.
  • An apparatus for gripping a tubular member has been described that includes a plurality of movable gripping elements. In an exemplary embodiment, the gripping elements are moveable in a radial direction. In an exemplary embodiment, the gripping elements are moveable in an axial direction. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial and an axial direction. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in a radial direction. In an exemplary embodiment, the gripping elements are moveable from a first position to a second position; wherein in the first position, the gripping elements do not engage the tubular member; wherein in the second position, the gripping elements do engage the tubular member; and wherein, during the movement from the first position to the second position, the gripping elements move in an axial direction. In an exemplary embodiment, in a first axial direction, the gripping device grips the tubular member; and wherein, in a second axial direction, the gripping device does not grip the tubular member. In an exemplary embodiment, the apparatus further includes an actuator for moving the gripping elements. In an exemplary embodiment, the gripping elements include a plurality of separate and distinct gripping elements.
  • An actuator has been described that includes a tubular housing; a tubular piston rod movably coupled to and at least partially positioned within the housing; a plurality of annular piston chambers defined by the tubular housing and the tubular piston rod; and a plurality of tubular pistons coupled to the tubular piston rod, each tubular piston movably positioned within a corresponding annular piston chamber. In an exemplary embodiment, the actuator further includes means for transmitting torsional loads between the tubular housing and the tubular piston rod.
  • An apparatus for controlling a packer has been described that includes a tubular support member; one or more drag blocks releasably coupled to the tubular support member; and a tubular stinger coupled to the tubular support member for engaging the packer. In an exemplary embodiment, the apparatus further includes a tubular sleeve coupled to the drag blocks. In an exemplary embodiment, the tubular support member includes one or more axially aligned teeth for engaging the packer.
  • A packer has been described that includes a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more compressible packer elements movably coupled to the support member; and a sliding sleeve valve movably positioned within the passage of the support member.
  • A method of radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing has been described that includes positioning the tubular member within the borehole in overlapping relation to the wellbore casing; radially expanding and plastically deforming a portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section. In an exemplary embodiment, radially expanding and plastically deforming a portion of the tubular member to form a bell section includes positioning an adjustable expansion device within the expandable tubular member; supporting the expandable tubular member and the adjustable expansion device within the borehole; lowering the adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member, wherein n is greater than or equal to 1.
  • A method for forming a mono diameter wellbore casing has been described that includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; positioning the adjustable expansion device within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole.
  • A method for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes positioning an adjustable expansion device within the expandable tubular member; supporting the expandable tubular member and the adjustable expansion device within the borehole; lowering the adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • A method for forming a mono diameter wellbore casing has been described that includes positioning an adjustable expansion device within a first expandable tubular member; supporting the first expandable tubular member and the adjustable expansion device within a borehole; lowering the adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; positioning the adjustable expansion mandrel within a second expandable tubular member; supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; lowering the adjustable expansion mandrel out of the second expandable tubular member; increasing the outside dimension of the adjustable expansion mandrel; displacing the adjustable expansion mandrel upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole; and pressurizing an interior region of the second expandable tubular member above the adjustable expansion mandrel during the radial expansion and plastic deformation of the second expandable tubular member within the borehole.
  • A method for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A method for forming a mono diameter wellbore casing has been described that includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; positioning first and second adjustable expansion devices within a second expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; lowering the first adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; and displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A method for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes positioning first and second adjustable expansion devices within the expandable tubular member; supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; lowering the first adjustable expansion device out of the expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; and pressurizing an interior region of the expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the expandable tubular member above the lower portion of the expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A method for forming a mono diameter wellbore casing has been described that includes positioning first and second adjustable expansion devices within a first expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; lowering the first adjustable expansion device out of the first expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; pressurizing an interior region of the first expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the first expandable tubular member above the lower portion of the first expandable tubular member by the second adjustable expansion device; positioning first and second adjustable expansion devices within a second expandable tubular member; supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; lowering the first adjustable expansion device out of the second expandable tubular member; increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; pressurizing an interior region of the second expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the second expandable tubular member by the first adjustable expansion device; displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; and pressurizing an interior region of the second expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the second expandable tubular member above the lower portion of the second expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A method for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; and displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member. In an exemplary embodiment, the method further includes reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed. In an exemplary embodiment, the method further includes fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device. In an exemplary embodiment, the method further includes permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member. In an exemplary embodiment, the method further includes injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and a preexisting structure after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the method further includes increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the method further includes displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform another portion of the expandable tubular member. In an exemplary embodiment, the method further includes if the end of the other portion of the expandable tubular member overlaps with a preexisting structure, then not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the other portion of the expandable tubular member that overlaps with the preexisting structure.
  • A method for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing has been described that includes supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; increasing the size of the adjustable expansion device; displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member. In an exemplary embodiment, the method further includes reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed. In an exemplary embodiment, the method further includes fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device. In an exemplary embodiment, the method further includes permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member. In an exemplary embodiment, the method further includes injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the borehole after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the method further includes increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the method further includes displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member. In an exemplary embodiment, the method further includes not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the remaining portion of the expandable tubular member that overlaps with the preexisting wellbore casing after not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • A method of radially expanding and plastically deforming a tubular member has been described that includes positioning the tubular member within a preexisting structure; radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and radially expanding and plastically deforming a portion of the tubular member above the bell section. In an exemplary embodiment, positioning the tubular member within a preexisting structure includes locking the tubular member to an expansion device. In an exemplary embodiment, the outside diameter of the expansion device is less than the inside diameter of the tubular member. In an exemplary embodiment, the expansion device is positioned within the tubular member. In an exemplary embodiment, the expansion device includes an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices includes an adjustable expansion device. In an exemplary embodiment, at least one of the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, radially expanding and plastically deforming a lower portion of the tubular member to form a bell section includes lowering an expansion device out of an end of the tubular member; and pulling the expansion device through the end of the tubular member. In an exemplary embodiment, lowering an expansion device out of an end of the tubular member includes lowering the expansion device out of the end of the tubular member; and adjusting the size of the expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes gripping the tubular member; and pulling an expansion device through an end of the tubular member. In an exemplary embodiment, gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using an actuator. In an exemplary embodiment, radially expanding and plastically deforming a portion of the tubular member above the bell section includes lowering an expansion device out of an end of the tubular member; and pulling the expansion device through the end of the tubular member. In an exemplary embodiment, lowering an expansion device out of an end of the tubular member includes lowering the expansion device out of the end of the tubular member; and adjusting the size of the expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes gripping the tubular member; and pulling an expansion device through an end of the tubular member. In an exemplary embodiment, gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using an actuator. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using fluid pressure. In an exemplary embodiment, pulling the expansion device through the end of the tubular member using fluid pressure includes pressurizing an annulus within the tubular member above the expansion device. In an exemplary embodiment, radially expanding and plastically deforming a portion of the tubular member above the bell section includes fluidicly sealing an end of the tubular member; and pulling the expansion device through the tubular member. In an exemplary embodiment, the expansion device is adjustable. In an exemplary embodiment, the expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device comprises a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes gripping the tubular member; and pulling an expansion device through an end of the tubular member. In an exemplary embodiment, gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using an actuator. In an exemplary embodiment, pulling the expansion device through the end of the tubular member includes pulling the expansion device through the end of the tubular member using fluid pressure. In an exemplary embodiment, pulling the expansion device through the end of the tubular member using fluid pressure includes pressurizing an annulus within the tubular member above the expansion device. In an exemplary embodiment, radially expanding and plastically deforming a portion of the tubular member above the bell section includes overlapping the portion of the tubular member above the bell section with an end of a preexisting tubular member; and pulling an expansion device through the overlapping portions of the tubular member and the preexisting tubular member. In an exemplary embodiment, the expansion device is adjustable. In an exemplary embodiment, the expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes gripping the tubular member; and pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member. In an exemplary embodiment, gripping the tubular member includes permitting axial displacement of the tubular member in a first direction; and not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using an actuator. In an exemplary embodiment, pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using fluid pressure. In an exemplary embodiment, pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using fluid pressure includes pressurizing an annulus within the tubular member above the expansion device. In an exemplary embodiment, the method further includes cutting an end of the portion of the tubular member that overlaps with the preexisting tubular member. In an exemplary embodiment, the method further includes removing the cut off end of the expandable tubular member from the preexisting structure. In an exemplary embodiment, the method further includes injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the preexisting structure. In an exemplary embodiment, the method further includes cutting off an end of the expandable tubular member. In an exemplary embodiment, the method further includes removing the cut off end of the expandable tubular member from the preexisting structure.
  • A method of radially expanding and plastically deforming a tubular member has been described that includes applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another.
  • A system for radially expanding and plastically deforming an expandable tubular member within a borehole having a preexisting wellbore casing has been described that includes means for positioning the tubular member within the borehole in overlapping relation to the wellbore casing; means for radially expanding and plastically deforming a portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section comprising a portion of the tubular member that overlaps with the wellbore casing; wherein the inside diameter of the bell section is greater than the inside diameter of the radially expanded and plastically deformed portion of the tubular member above the bell section. In an exemplary embodiment, means for radially expanding and plastically deforming a portion of the tubular member to form a bell section includes means for positioning an adjustable expansion device within the expandable tubular member; means for supporting the expandable tubular member and the adjustable expansion device within the borehole; means for lowering the adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member, wherein n is greater than or equal to 1.
  • A system for forming a mono diameter wellbore casing has been described that includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for positioning the adjustable expansion device within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion device within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole.
  • A system for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes means for positioning an adjustable expansion device within the expandable tubular member; means for supporting the expandable tubular member and the adjustable expansion device within the borehole; means for lowering the adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion mandrel upwardly relative to the expandable tubular member n times to radially expand and plastically deform n portions of the expandable tubular member within the borehole; and means for pressurizing an interior region of the expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the expandable tubular member within the borehole.
  • A system for forming a mono diameter wellbore casing has been described that includes means for positioning an adjustable expansion device within a first expandable tubular member; means for supporting the first expandable tubular member and the adjustable expansion device within a borehole; means for lowering the adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the first expandable tubular member m times to radially expand and plastically deform m portions of the first expandable tubular member within the borehole; means for pressurizing an interior region of the first expandable tubular member above the adjustable expansion device during the radial expansion and plastic deformation of the first expandable tubular member within the borehole; means for positioning the adjustable expansion mandrel within a second expandable tubular member; means for supporting the second expandable tubular member and the adjustable expansion mandrel within the borehole in overlapping relation to the first expandable tubular member; means for lowering the adjustable expansion mandrel out of the second expandable tubular member; means for increasing the outside dimension of the adjustable expansion mandrel; means for displacing the adjustable expansion mandrel upwardly relative to the second expandable tubular member n times to radially expand and plastically deform n portions of the second expandable tubular member within the borehole; and means for pressurizing an interior region of the second expandable tubular member above the adjustable expansion mandrel during the radial expansion and plastic deformation of the second expandable tubular member within the borehole.
  • A system for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A system for forming a mono diameter wellbore casing has been described that includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; means for positioning first and second adjustable expansion devices within a second expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; means for lowering the first adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; and means for displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A system for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes means for positioning first and second adjustable expansion devices within the expandable tubular member; means for supporting the expandable tubular member and the first and second adjustable expansion devices within the borehole; means for lowering the first adjustable expansion device out of the expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform a lower portion of the expandable tubular member; means for pressurizing an interior region of the expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform portions of the expandable tubular member above the lower portion of the expandable tubular member; and means for pressurizing an interior region of the expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the expandable tubular member above the lower portion of the expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A system for forming a mono diameter wellbore casing has been described that includes means for positioning first and second adjustable expansion devices within a first expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within a borehole; means for lowering the first adjustable expansion device out of the first expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform a lower portion of the first expandable tubular member; means for pressurizing an interior region of the first expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the first expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the first expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the first expandable tubular member to radially expand and plastically deform portions of the first expandable tubular member above the lower portion of the expandable tubular member; means for pressurizing an interior region of the first expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the first expandable tubular member above the lower portion of the first expandable tubular member by the second adjustable expansion device; means for positioning first and second adjustable expansion devices within a second expandable tubular member; means for supporting the first expandable tubular member and the first and second adjustable expansion devices within the borehole in overlapping relation to the first expandable tubular member; means for lowering the first adjustable expansion device out of the second expandable tubular member; means for increasing the outside dimension of the first adjustable expansion device; means for displacing the first adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform a lower portion of the second expandable tubular member; means for pressurizing an interior region of the second expandable tubular member above the first adjustable expansion device during the radial expansion of the lower portion of the second expandable tubular member by the first adjustable expansion device; means for displacing the first adjustable expansion device and the second adjustable expansion device downwardly relative to the second expandable tubular member; means for decreasing the outside dimension of the first adjustable expansion device and increasing the outside dimension of the second adjustable expansion device; means for displacing the second adjustable expansion device upwardly relative to the second expandable tubular member to radially expand and plastically deform portions of the second expandable tubular member above the lower portion of the second expandable tubular member; and means for pressurizing an interior region of the second expandable tubular member above the second adjustable expansion device during the radial expansion of the portions of the second expandable tubular member above the lower portion of the second expandable tubular member by the second adjustable expansion device; wherein the outside dimension of the first adjustable expansion device is greater than the outside dimension of the second adjustable expansion device.
  • A system for radially expanding and plastically deforming an expandable tubular member within a borehole has been described that includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member. In an exemplary embodiment, the system further includes means for reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed. In an exemplary embodiment, the system further includes means for fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device. In an exemplary embodiment, the system further includes means for permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member. In an exemplary embodiment, the system further includes means for injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and a preexisting structure after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the system further includes means for increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, system further includes means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform another portion of the expandable tubular member. In an exemplary embodiment, the system further includes if the end of the other portion of the expandable tubular member overlaps with a preexisting structure, then means for not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the other portion of the expandable tubular member that overlaps with the preexisting structure.
  • A system for forming a mono diameter wellbore casing within a borehole that includes a preexisting wellbore casing has been described that includes means for supporting the expandable tubular member, an hydraulic actuator, and an adjustable expansion device within the borehole; means for increasing the size of the adjustable expansion device; means for displacing the adjustable expansion device upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform a portion of the expandable tubular member; and means for displacing the adjustable expansion device upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member and a portion of the preexisting wellbore casing that overlaps with an end of the remaining portion of the expandable tubular member. In an exemplary embodiment, the system further includes means for reducing the size of the adjustable expansion device after the portion of the expandable tubular member has been radially expanded and plastically deformed. In an exemplary embodiment, the system further includes means for fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member after reducing the size of the adjustable expansion device. In an exemplary embodiment, the system further includes means for permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator after fluidicly sealing the radially expanded and plastically deformed end of the expandable tubular member. In an exemplary embodiment, the system further includes means for injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the borehole after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the system further includes means for increasing the size of the adjustable expansion device after permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator. In an exemplary embodiment, the system further includes means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member to radially expand and plastically deform the remaining portion of the expandable tubular member. In an exemplary embodiment, the system further includes means for not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator; and means for displacing the adjustable expansion cone upwardly relative to the expandable tubular member using the hydraulic actuator to radially expand and plastically deform the end of the remaining portion of the expandable tubular member that overlaps with the preexisting wellbore casing after not permitting the position of the expandable tubular member to float relative to the position of the hydraulic actuator.
  • A system for radially expanding and plastically deforming a tubular member has been described that includes means for positioning the tubular member within a preexisting structure; means for radially expanding and plastically deforming a lower portion of the tubular member to form a bell section; and means for radially expanding and plastically deforming a portion of the tubular member above the bell section. In an exemplary embodiment, positioning the tubular member within a preexisting structure includes means for locking the tubular member to an expansion device. In an exemplary embodiment, the outside diameter of the expansion device is less than the inside diameter of the tubular member. In an exemplary embodiment, the expansion device is positioned within the tubular member. In an exemplary embodiment, the expansion device includes an adjustable expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of expansion devices. In an exemplary embodiment, at least one of the expansion devices includes an adjustable expansion device. In an exemplary embodiment, at least one of the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, means for radially expanding and plastically deforming a lower portion of the tubular member to form a bell section includes means for lowering an expansion device out of an end of the tubular member; and means for pulling the expansion device through the end of the tubular member. In an exemplary embodiment, means for lowering an expansion device out of an end of the tubular member includes means for lowering the expansion device out of the end of the tubular member; and means for adjusting the size of the expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for gripping the tubular member; and means for pulling an expansion device through an end of the tubular member. In an exemplary embodiment, means for gripping the tubular member includes means for permitting axial displacement of the tubular member in a first direction; and means for not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for pulling the expansion device through the end of the tubular member using an actuator. In an exemplary embodiment, means for radially expanding and plastically deforming a portion of the tubular member above the bell section includes means for lowering an expansion device out of an end of the tubular member; and means for pulling the expansion device through the end of the tubular member. In an exemplary embodiment, means for lowering an expansion device out of an end of the tubular member includes means for lowering the expansion device out of the end of the tubular member; and means for adjusting the size of the expansion device. In an exemplary embodiment, the adjustable expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device comprises a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for gripping the tubular member; and means for pulling an expansion device through an end of the tubular member. In an exemplary embodiment, means for gripping the tubular member includes means for permitting axial displacement of the tubular member in a first direction; and means for not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for pulling the expansion device through the end of the tubular member using an actuator. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for pulling the expansion device through the end of the tubular member using fluid pressure. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member using fluid pressure includes means for pressurizing an annulus within the tubular member above the expansion device. In an exemplary embodiment, means for radially expanding and plastically deforming a portion of the tubular member above the bell section includes means for fluidicly sealing an end of the tubular member; and means for pulling the expansion device through the tubular member. In an exemplary embodiment, the expansion device is adjustable. In an exemplary embodiment, the expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for gripping the tubular member; and means for pulling an expansion device through an end of the tubular member. In an exemplary embodiment, means for gripping the tubular member includes means for permitting axial displacement of the tubular member in a first direction; and means for not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for pulling the expansion device through the end of the tubular member using an actuator. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member includes means for pulling the expansion device through the end of the tubular member using fluid pressure. In an exemplary embodiment, means for pulling the expansion device through the end of the tubular member using fluid pressure includes means for pressurizing an annulus within the tubular member above the expansion device. In an exemplary embodiment, means for radially expanding and plastically deforming a portion of the tubular member above the bell section includes means for overlapping the portion of the tubular member above the bell section with an end of a preexisting tubular member; and means for pulling an expansion device through the overlapping portions of the tubular member and the preexisting tubular member. In an exemplary embodiment, the expansion device is adjustable. In an exemplary embodiment, the expansion device is adjustable to a plurality of sizes. In an exemplary embodiment, the expansion device includes a plurality of adjustable expansion devices. In an exemplary embodiment, at least one of the adjustable expansion devices is adjustable to a plurality of sizes. In an exemplary embodiment, means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes means for gripping the tubular member; and means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member. In an exemplary embodiment, means for gripping the tubular member includes means for permitting axial displacement of the tubular member in a first direction; and means for not permitting axial displacement of the tubular member in a second direction. In an exemplary embodiment, means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using an actuator. In an exemplary embodiment, means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member includes means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using fluid pressure. In an exemplary embodiment, means for pulling the expansion device through the overlapping portions of the tubular member and the preexisting tubular member using fluid pressure includes means for pressurizing an annulus within the tubular member above the expansion device. In an exemplary embodiment, the system further includes means for cutting an end of the portion of the tubular member that overlaps with the preexisting tubular member. In an exemplary embodiment, the system further includes means for removing the cut off end of the expandable tubular member from the preexisting structure. In an exemplary embodiment, the system further includes means for injecting a hardenable fluidic sealing material into an annulus between the expandable tubular member and the preexisting structure. In an exemplary embodiment, the system further includes means for cutting off an end of the expandable tubular member. In an exemplary embodiment, the system further includes means for removing the cut off end of the expandable tubular member from the preexisting structure.
  • A system of radially expanding and plastically deforming a tubular member has been described that includes a support member; and means for applying internal pressure to the inside surface of the tubular member at a plurality of discrete location separated from one another coupled to the support member.
  • A method of cutting a tubular member has been described that includes positioning a plurality of cutting elements within the tubular member; and bringing the cutting elements into engagement with the tubular member. In an exemplary embodiment, the cutting elements include a first group of cutting elements; and a second group of cutting elements; wherein the first group of cutting elements are interleaved with the second group of cutting elements. In an exemplary embodiment, bringing the cutting elements into engagement with the tubular member includes bringing the cutting elements into axial alignment. In an exemplary embodiment, bringing the cutting elements into engagement with the tubular member further includes pivoting the cutting elements. In an exemplary embodiment, bringing the cutting elements into engagement with the tubular member further includes translating the cutting elements. In an exemplary embodiment, bringing the cutting elements into engagement with the tubular member further includes pivoting the cutting elements; and translating the cutting elements. In an exemplary embodiment, bringing the cutting elements into engagement with the tubular member includes rotating the cutting elements about a common axis. In an exemplary embodiment, bringing the cutting elements into engagement with the tubular member includes pivoting the cutting elements about corresponding axes; translating the cutting elements; and rotating the cutting elements about a common axis. In an exemplary embodiment, the method further includes preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes sensing the inside diameter of the tubular member.
  • A method of gripping a tubular member has been described that includes positioning a plurality of gripping elements within the tubular member; bringing the gripping elements into engagement with the tubular member. In an exemplary embodiment, bringing the gripping elements into engagement with the tubular member includes displacing the gripping elements in an axial direction; and displacing the gripping elements in a radial direction. In an exemplary embodiment, the method further includes biasing the gripping elements against engagement with the tubular member.
  • A method of operating an actuator has been described that includes pressurizing a plurality of pressure chamber. In an exemplary embodiment, the method further includes transmitting torsional loads.
  • A method of injecting a hardenable fluidic sealing material into an annulus between a tubular member and a preexisting structure has been described that includes positioning the tubular member into the preexisting structure; sealing off an end of the tubular member; operating a valve within the end of the tubular member; and injecting a hardenable fluidic sealing material through the valve into the annulus between the tubular member and the preexisting structure.
  • A system for cutting a tubular member has been described that includes means for positioning a plurality of cutting elements within the tubular member; and means for bringing the cutting elements into engagement with the tubular member. In an exemplary embodiment, the cutting elements include a first group of cutting elements; and a second group of cutting elements; wherein the first group of cutting elements are interleaved with the second group of cutting elements. In an exemplary embodiment, means for bringing the cutting elements into engagement with the tubular member includes means for bringing the cutting elements into axial alignment. In an exemplary embodiment, means for bringing the cutting elements into engagement with the tubular member further includes means for pivoting the cutting elements. In an exemplary embodiment, means for bringing the cutting elements into engagement with the tubular member further includes means for translating the cutting elements. In an exemplary embodiment, means for bringing the cutting elements into engagement with the tubular member further includes means for pivoting the cutting elements; and means for translating the cutting elements. In an exemplary embodiment, means for bringing the cutting elements into engagement with the tubular member includes means for rotating the cutting elements about a common axis. In an exemplary embodiment, means for bringing the cutting elements into engagement with the tubular member includes means for pivoting the cutting elements about corresponding axes; means for translating the cutting elements; and means for rotating the cutting elements about a common axis. In an exemplary embodiment, the system further includes means for preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, means for preventing the cutting elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes means for sensing the inside diameter of the tubular member.
  • A system for gripping a tubular member has been described that includes means for positioning a plurality of gripping elements within the tubular member; and means for bringing the gripping elements into engagement with the tubular member. In an exemplary embodiment, means for bringing the gripping elements into engagement with the tubular member includes means for displacing the gripping elements in an axial direction; and means for displacing the gripping elements in a radial direction. In an exemplary embodiment, the system further includes means for biasing the gripping elements against engagement with the tubular member.
  • An actuator system has been described that includes a support member; and means for pressurizing a plurality of pressure chambers coupled to the support member. In an exemplary embodiment, the system further includes means for transmitting torsional loads.
  • A system for injecting a hardenable fluidic sealing material into an annulus between a tubular member and a preexisting structure has been described that includes means for positioning the tubular member into the preexisting structure; means for sealing off an end of the tubular member; means for operating a valve within the end of the tubular member; and means for injecting a hardenable fluidic sealing material through the valve into the annulus between the tubular member and the preexisting structure.
  • A method of engaging a tubular member has been described that includes positioning a plurality of elements within the tubular member; and bringing the elements into engagement with the tubular member. In an exemplary embodiment, the elements include a first group of elements; and a second group of elements; wherein the first group of elements are interleaved with the second group of elements. In an exemplary embodiment, bringing the elements into engagement with the tubular member includes bringing the elements into axial alignment. In an exemplary embodiment, bringing the elements into engagement with the tubular member further includes pivoting the elements. In an exemplary embodiment, bringing the elements into engagement with the tubular member further includes translating the elements. In an exemplary embodiment, bringing the elements into engagement with the tubular member further includes pivoting the elements; and translating the elements. In an exemplary embodiment, bringing the elements into engagement with the tubular member includes rotating the elements about a common axis. In an exemplary embodiment, bringing the elements into engagement with the tubular member includes pivoting the elements about corresponding axes; translating the elements; and rotating the elements about a common axis. In an exemplary embodiment, the method further includes preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes sensing the inside diameter of the tubular member.
  • A system for engaging a tubular member has been described that includes means for positioning a plurality of elements within the tubular member; and means for bringing the elements into engagement with the tubular member. In an exemplary embodiment, the elements include a first group of elements; and a second group of elements; wherein the first group of elements are interleaved with the second group of elements. In an exemplary embodiment, means for bringing the elements into engagement with the tubular member includes means for bringing the elements into axial alignment. In an exemplary embodiment, means for bringing the elements into engagement with the tubular member further includes means for pivoting the elements. In an exemplary embodiment, means for bringing the elements into engagement with the tubular member further includes means for translating the elements. In an exemplary embodiment, means for bringing the elements into engagement with the tubular member further includes means for pivoting the elements; and means for translating the elements. In an exemplary embodiment, means for bringing the elements into engagement with the tubular member includes means for rotating the elements about a common axis. In an exemplary embodiment, means for bringing the elements into engagement with the tubular member includes means for pivoting the elements about corresponding axes; means for translating the elements; and means for rotating the elements about a common axis. In an exemplary embodiment, the system further includes means for preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value. In an exemplary embodiment, means for preventing the elements from coming into engagement with the tubular member if the inside diameter of the tubular member is less than a predetermined value includes means for sensing the inside diameter of the tubular member.
  • A locking device for locking a tubular member to a support member has been described that includes a plurality of circumferentially spaced apart locking elements coupled to the support member for engaging an interior surface of the tubular member; a plurality of spring elements coupled to the support member for biasing corresponding locking elements out of engagement with the interior surface of the tubular member; a releasable retaining element releasably coupled to the support member for releasably retaining the locking elements in engagement with the interior surface of the tubular member; an actuator coupled to the support member for controllably displacing the retaining element relative to the locking elements; and a sensor coupled to the support member for sensing an operating condition within the tubular member for controllably displacing the retaining element relative to the locking elements.
  • A method of locking a tubular member to a support member has been described that includes engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • A system for locking a tubular member to a support member has been described that includes means for engaging the interior surface of the tubular member at a plurality of circumferentially spaced apart locations using one or more engagement members; and means for disengaging the engagement members from the interior surface of the tubular member if an operating condition within the tubular member exceeds a predetermined amount; wherein the engagement members are biased out of engagement with the tubular member.
  • A method has been described that includes positioning a packer assembly comprising a sealing element within a tubular member; setting the sealing element against an interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member. In an exemplary embodiment, setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member. In an exemplary embodiment, preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member comprises preventing further application of the first force against the sealing element. In an exemplary embodiment, the method comprises coupling a packer control device to the packer assembly. In an exemplary embodiment, the tubular member extends within a wellbore; and the method further comprises positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore. In an exemplary embodiment, the method comprises radially expanding and plastically deforming at least a portion of the tubular member. In an exemplary embodiment, the method comprises moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member. In an exemplary embodiment, the packer assembly further comprises at least one other sealing element; and the method further comprises setting the at least one other sealing element against the interior surface of the tubular member. In an exemplary embodiment, the method comprises decoupling the packer control device from the packer assembly. In an exemplary embodiment, the method comprises testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • A system has been described that includes means for positioning a packer assembly comprising a sealing element within a tubular member; means for setting the sealing element against an interior surface of the tubular member; and means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member. In an exemplary embodiment, the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member. In an exemplary embodiment, the means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member comprises means for preventing further application of the first force against the sealing element. In an exemplary embodiment, the system comprises means for coupling a packer control device to the packer assembly. In an exemplary embodiment, the tubular member extends within a wellbore; and the system further comprises means for positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore. In an exemplary embodiment, the system comprises means for radially expanding and plastically deforming at least a portion of the tubular member. In an exemplary embodiment, the system comprises means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member. In an exemplary embodiment, the packer assembly comprises at least one other sealing element; and the system further comprises means for setting the at least one other sealing element against the interior surface of the tubular member. In an exemplary embodiment, the system comprises means for decoupling the packer control device from the packer assembly. In an exemplary embodiment, the system comprises means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • A method has been described that includes positioning a packer assembly comprising a sealing element within a tubular member; applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member. In an exemplary embodiment, the method comprises preventing further application of the first force against the sealing element. In an exemplary embodiment, the method comprises preventing further application of the first force against the sealing element. In an exemplary embodiment, preventing further application of the first force against the sealing element prevents the application of an impact load against the interior surface of the tubular member. In an exemplary embodiment, the method comprises coupling a packer control device to the packer assembly. In an exemplary embodiment, the tubular member extends within a wellbore; and the method further comprises positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore. In an exemplary embodiment, the method comprises radially expanding and plastically deforming at least a portion of the tubular member. In an exemplary embodiment, the method comprises moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member. In an exemplary embodiment, the packer assembly further comprises at least one other sealing element; and the method further comprises setting the at least one other sealing element against the interior surface of the tubular member. In an exemplary embodiment, the method comprises decoupling the packer control device from the packer assembly. In an exemplary embodiment, the method comprises testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • A system has been described that includes means for positioning a packer assembly comprising a sealing element within a tubular member; means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member. In an exemplary embodiment, the system comprises means for preventing further application of the first force against the sealing element. In an exemplary embodiment, preventing further application of the first force against the sealing element prevents the application of an impact load against the interior surface of the tubular member. In an exemplary embodiment, the system comprises means for coupling a packer control device to the packer assembly. In an exemplary embodiment, the tubular member extends within a wellbore; and the system comprises means for positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore. In an exemplary embodiment, the system comprises means for radially expanding and plastically deforming at least a portion of the tubular member. In an exemplary embodiment, the system comprises means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member. In an exemplary embodiment, the packer assembly comprises at least one other sealing element; and the system comprises means for setting the at least one other sealing element against the interior surface of the tubular member. In an exemplary embodiment, the system comprises means for decoupling the packer control device from the packer assembly. In an exemplary embodiment, the system comprises means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • A method has been described that includes coupling a packer control device to a packer assembly comprising a sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; radially expanding and plastically deforming at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • A system has been described that includes means for coupling a packer control device to a packer assembly comprising a sealing element; means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; means for radially expanding and plastically deforming at least a portion of the tubular member; means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
  • A method has been described that includes coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore; radially expanding and plastically deforming at least a portion of the tubular member; moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises applying a first force against the sealing element to move the sealing element relative to the tubular member; and applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element; setting the at least one other sealing element against the interior surface of the tubular member; decoupling the packer control device from the packer assembly; and testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • A system has been described that includes means for coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element; means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore; means for positioning the packer control device and the packer outside of the tubular member and in the wellbore; means for radially expanding and plastically deforming at least a portion of the tubular member; means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member; means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element; means for setting the at least one other sealing element against the interior surface of the tubular member; means for decoupling the packer control device from the packer assembly; and means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; and a stinger coupled to the second tubular support for releasably engaging the packer assembly. In an exemplary embodiment, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support. In an exemplary embodiment, the apparatus comprises one or more second retaining dogs releasably engaged with the first tubular support. In an exemplary embodiment, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support. In an exemplary embodiment, the apparatus comprises a third tubular support coupled to the second tubular support and the stinger. In an exemplary embodiment, the apparatus comprises a compressible element at least partially circumferentially extending about the third tubular support. In an exemplary embodiment, the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed. In an exemplary embodiment, when the one or more first retaining dogs are released from the second tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration. In an exemplary embodiment, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly. In an exemplary embodiment, the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration. In an exemplary embodiment, the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly. In an exemplary embodiment, the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element. In an exemplary embodiment, the compressible element comprises a spring. In an exemplary embodiment, the apparatus comprises a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support; a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration. In an exemplary embodiment, the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support. In an exemplary embodiment, the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support. In an exemplary embodiment, the apparatus comprises one or more rupture discs coupled to the third tubular support; wherein an exterior surface of the third tubular support and an interior surface of the first tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the annular region. In an exemplary embodiment, the apparatus comprises the packer assembly. In an exemplary embodiment, the apparatus comprises a tubular member within which the packer assembly at least partially extends. In an exemplary embodiment, the packer assembly comprises a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more sealing elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; and one or more second retaining dogs releasably engaged with the first tubular support; wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; a second configuration in which the compressible element is at least partially compressed; wherein, when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration; wherein, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; and wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element. In an exemplary embodiment, the compressible element comprises a spring. In an exemplary embodiment, the apparatus comprises a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support; a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration. In an exemplary embodiment, the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support. In an exemplary embodiment, the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support. In an exemplary embodiment, the apparatus comprises one or more rupture discs coupled to the third tubular support; wherein an exterior surface of the third tubular support and the interior surface of the first tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the annular region. In an exemplary embodiment, the apparatus comprises the packer assembly. In an exemplary embodiment, the apparatus comprises a tubular member within which the packer assembly at least partially extends. In an exemplary embodiment, the packer assembly comprises a support member to which the at least one sealing element is movably coupled, the support member defining a passage; and a shoe comprising a float valve coupled to an end of the support member. In an exemplary embodiment, the packer assembly further comprises a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a second tubular support at least partially extending within the first tubular support; one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; a stinger coupled to the second tubular support for releasably engaging the packer assembly; one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support; a third tubular support coupled to the second tubular support and the stinger; a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; wherein, when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration; wherein, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; and wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element; wherein the compressible element comprises a spring; wherein the apparatus further comprises a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support; a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining a first annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the first annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration; wherein the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and wherein movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support; wherein the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; wherein the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an s of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support; one or more rupture discs coupled to the third tubular support; and the packer assembly; wherein an exterior surface of the third tubular support and the interior surface of the first tubular support define a second annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the second annular region; wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the second annular region; and wherein the packer assembly comprises a support member to which the at least one sealing element is movably coupled, the support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; and a compressible element at least partially circumferentially extending about the first tubular support; wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed. In an exemplary embodiment, the apparatus comprises a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly. In an exemplary embodiment, the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration. In an exemplary embodiment, the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly. In an exemplary embodiment, the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element. In an exemplary embodiment, the apparatus comprises one or more first retaining dogs coupled to the third tubular support for releasably engaging the second tubular support. In an exemplary embodiment, the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support. In an exemplary embodiment, the apparatus comprises one or more second retaining dogs releasably engaged with the third tubular support. In an exemplary embodiment, the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the third tubular support. In an exemplary embodiment, the compressible element comprises a spring. In an exemplary embodiment, the apparatus comprises a fourth tubular support coupled to the first tubular support and through which the first tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the first tubular support; a spring mandrel coupled to the third tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration. In an exemplary embodiment, the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the third tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the first tubular support. In an exemplary embodiment, the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support. In an exemplary embodiment, the apparatus comprises one or more rupture discs coupled to the first tubular support; wherein an exterior surface of the first tubular support and an interior surface of the third tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the third tubular support in response to the flow of the fluidic material into the annular region. In an exemplary embodiment, the apparatus comprises the packer assembly. In an exemplary embodiment, the apparatus comprises a tubular member within which the packer assembly at least partially extends. In an exemplary embodiment, the packer assembly comprises a support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; one or more sealing elements movably coupled to the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
  • An apparatus for controlling the operation of a packer assembly has been described that includes a first tubular support; a stinger coupled to the first tubular support for releasably engaging the packer assembly; a compressible element at least partially circumferentially extending about the first tubular support, wherein the compressible element comprises a first configuration in which the compressible element is uncompressed; and a second configuration in which the compressible element is at least partially compressed; a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and a third tubular support within which the second tubular support at least partially extends; wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly; wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration; wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element; and wherein the apparatus further comprises one or more first retaining dogs coupled to the third tubular support for releasably engaging the second tubular support; and one or more second retaining dogs releasably engaged with the third tubular support; wherein the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the third tubular support. In an exemplary embodiment, the compressible element comprises a spring. In an exemplary embodiment, the apparatus comprises a fourth tubular support coupled to the first tubular support and through which the first tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the first tubular support; a spring mandrel coupled to the third tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region; wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration. In an exemplary embodiment, the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and movement of the third tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the first tubular support. In an exemplary embodiment, the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support. In an exemplary embodiment, the apparatus comprises one or more rupture discs coupled to the first tubular support; wherein an exterior surface of the first tubular support and an interior surface of the third tubular support define an annular region; wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and wherein the one or more second retaining dogs are released from the third tubular support in response to the flow of the fluidic material into the annular region. In an exemplary embodiment, the apparatus comprises the packer assembly. In an exemplary embodiment, the apparatus comprises a tubular member within which the packer assembly at least partially extends. In an exemplary embodiment, the packer assembly comprises a support member to which the at least one sealing element is movably coupled, the support member defining a passage; a shoe comprising a float valve coupled to an end of the support member; and a sliding sleeve valve positioned within the passage of the support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus has been described that includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer. In an exemplary embodiment, the apparatus comprises the packer comprising a second support member defining a passage; a shoe comprising a float valve coupled to an end of the second support member; one or more compressible packer elements movably coupled to the second support member; and a sliding sleeve valve positioned within the passage of the second support member; wherein the stinger engages the sliding sleeve valve.
  • An apparatus has been described that includes a packer control device for controlling the operation of a packer, the packer control device comprising a first support member; one or more drag blocks releasably coupled to the support member; and a stinger coupled to the first support member for engaging the packer; and the packer comprising a second support member defining a passage; a shoe comprising a float valve coupled to an end of the second support member; one or more compressible packer elements movably coupled to the second support member; and a sliding sleeve valve positioned within the passage of the second support member; wherein the stinger engages the sliding sleeve valve.
  • It is understood that variations may be made in the foregoing without departing from the scope of the invention. For example, the teachings of the present illustrative embodiments may be used to provide a wellbore casing, a pipeline, or a structural support. Furthermore, the elements and teachings of the various illustrative embodiments may be combined in whole or in part in some or all of the illustrative embodiments. In addition, one or more of the elements and teachings of the various illustrative embodiments may be omitted, at least in part, and/or combined, at least in part, with one or more of the other elements and teachings of the various illustrative embodiments.
  • Although illustrative embodiments of the invention have been shown and described, a wide range of modification, changes and substitution is contemplated in the foregoing disclosure. In some instances, some features of the present invention may be employed without a corresponding use of the other features. Accordingly, it is appropriate that the appended claims be construed broadly and in a manner consistent with the scope of the invention. In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.

Claims (88)

1. A method comprising:
positioning a packer assembly comprising a sealing element within a tubular member;
setting the sealing element against an interior surface of the tubular member; and
preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
2. The method of claim 1 wherein setting the sealing element against the interior surface of the tubular member comprises:
applying a first force against the sealing element to move the sealing element relative to the tubular member; and
applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member.
3. The method of claim 2 wherein preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member comprises:
preventing further application of the first force against the sealing element.
4. The method of claim 1 further comprising:
coupling a packer control device to the packer assembly.
5. The method of claim 4 wherein the tubular member extends within a wellbore; and
wherein the method further comprises:
positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore.
6. The method of claim 5 further comprising:
radially expanding and plastically deforming at least a portion of the tubular member.
7. The method of claim 6 further comprising:
moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member.
8. The method of claim 7 wherein the packer assembly further comprises at least one other sealing element; and
wherein the method further comprises:
setting the at least one other sealing element against the interior surface of the tubular member.
9. The method of claim 8 further comprising:
decoupling the packer control device from the packer assembly.
10. The method of claim 9 further comprising:
testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
11. A method comprising:
positioning a packer assembly comprising a sealing element within a tubular member;
applying a first force against the sealing element to move the sealing element relative to the tubular member; and
applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
12. The method of claim 11 further comprising:
preventing further application of the first force against the sealing element.
13. The method of claim 12 wherein preventing further application of the first force against the sealing element prevents the application of an impact load against the interior surface of the tubular member.
14. The method of claim 11 further comprising:
coupling a packer control device to the packer assembly;
15. The method of claim 14 wherein the tubular member extends within a wellbore; and
wherein the method further comprises:
positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore.
16. The method of claim 15 further comprising:
radially expanding and plastically deforming at least a portion of the tubular member.
17. The method of claim 16 further comprising:
moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member.
18. The method of claim 17 wherein the packer assembly further comprises at least one other sealing element; and
wherein the method further comprises:
setting the at least one other sealing element against the interior surface of the tubular member.
19. The method of claim 18 further comprising:
decoupling the packer control device from the packer assembly.
20. The method of claim 19 further comprising:
testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
21. A method comprising:
coupling a packer control device to a packer assembly comprising a sealing element;
positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore;
radially expanding and plastically deforming at least a portion of the tubular member;
setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises:
applying a first force against the sealing element to move the sealing element relative to the tubular member; and
applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and
preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
22. An apparatus for controlling the operation of a packer assembly, comprising:
a first tubular support;
a second tubular support at least partially extending within the first tubular support;
one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support; and
a stinger coupled to the second tubular support for releasably engaging the packer assembly.
23. The apparatus of claim 22 wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support.
24. The apparatus of claim 22 further comprising:
one or more second retaining dogs releasably engaged with the first tubular support.
25. The apparatus of claim 24 wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support.
26. The apparatus of claim 22 further comprising:
a third tubular support coupled to the second tubular support and the stinger.
27. The apparatus of claim 26 further comprising:
a compressible element at least partially circumferentially extending about the third tubular support.
28. The apparatus of claim 27 wherein the compressible element comprises:
a first configuration in which the compressible element is uncompressed; and
a second configuration in which the compressible element is at least partially compressed.
29. The apparatus of claim 28 wherein, when the one or more first retaining dogs are released from the second tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration.
30. The apparatus of claim 29 wherein, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly.
31. The apparatus of claim 30 wherein the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration.
32. The apparatus of claim 31 wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly.
33. The apparatus of claim 32 wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
34. The apparatus of claim 33 wherein the compressible element comprises a spring.
35. The apparatus of claim 34 further comprising:
a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support;
a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and
a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region;
wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration.
36. The apparatus of claim 35 wherein the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and
wherein movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support.
37. The apparatus of claim 36 wherein the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and
wherein the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising:
a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and
a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support.
38. The apparatus of claim 26 further comprising:
one or more rupture discs coupled to the third tubular support;
wherein an exterior surface of the third tubular support and an interior surface of the first tubular support define an annular region;
wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and
wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the annular region.
39. The apparatus of claim 22 further comprising the packer assembly.
40. The apparatus of claim 39 further comprising a tubular member within which the packer assembly at least partially extends.
41. The apparatus of claim 39 wherein the packer assembly comprises:
a support member defining a passage;
a shoe comprising a float valve coupled to an end of the support member;
one or more sealing elements movably coupled to the support member; and
a sliding sleeve valve positioned within the passage of the support member;
wherein the stinger engages the sliding sleeve valve.
42. An apparatus for controlling the operation of a packer assembly, comprising:
a first tubular support;
a stinger coupled to the first tubular support for releasably engaging the packer assembly; and
a compressible element at least partially circumferentially extending about the first tubular support;
wherein the compressible element comprises:
a first configuration in which the compressible element is uncompressed; and
a second configuration in which the compressible element is at least partially compressed.
43. The apparatus of claim 42 further comprising:
a second tubular support coupled to the first tubular support and within which the first tubular support at least partially extends; and
a third tubular support within which the second tubular support at least partially extends;
wherein, when the compressible element is in the second configuration, the third tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly.
44. The apparatus of claim 43 wherein the first tubular support comprises an external flange for preventing further movement of the third tubular support in the direction when the compressible element is in the second configuration.
45. The apparatus of claim 44 wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly.
46. The apparatus of claim 45 wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element.
47. The apparatus of claim 46 further comprising:
one or more first retaining dogs coupled to the third tubular support for releasably engaging the second tubular support.
48. The apparatus of claim 47 wherein the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support.
49. The apparatus of claim 47 further comprising:
one or more second retaining dogs releasably engaged with the third tubular support.
50. The apparatus of claim 49 wherein the one or more first retaining dogs and the third tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the third tubular support.
51. The apparatus of claim 50 wherein the compressible element comprises a spring.
52. The apparatus of claim 51 further comprising:
a fourth tubular support coupled to the first tubular support and through which the first tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the first tubular support;
a spring mandrel coupled to the third tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining an annular region in which the spring extends; and
a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the annular region;
wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration.
53. The apparatus of claim 52 wherein the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and
wherein movement of the third tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the first tubular support.
54. The apparatus of claim 53 wherein the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess; and
wherein the apparatus further comprises a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising:
a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and
a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support.
55. The apparatus of claim 50 further comprising:
one or more rupture discs coupled to the first tubular support;
wherein an exterior surface of the first tubular support and an interior surface of the third tubular support define an annular region;
wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the annular region; and
wherein the one or more second retaining dogs are released from the third tubular support in response to the flow of the fluidic material into the annular region.
56. The apparatus of claim 42 further comprising the packer assembly.
57. The apparatus of claim 56 further comprising a tubular member within which the packer assembly at least partially extends.
58. The apparatus of claim 56 wherein the packer assembly comprises:
a support member defining a passage;
a shoe comprising a float valve coupled to an end of the support member;
one or more sealing elements movably coupled to the support member; and
a sliding sleeve valve positioned within the passage of the support member;
wherein the stinger engages the sliding sleeve valve.
59. An apparatus comprising:
a packer control device for controlling the operation of a packer, the packer control device comprising:
a first support member;
one or more drag blocks releasably coupled to the support member; and
a stinger coupled to the first support member for engaging the packer.
60. The apparatus of claim 59 further comprising:
the packer comprising:
a second support member defining a passage;
a shoe comprising a float valve coupled to an end of the second support member;
one or more compressible packer elements movably coupled to the second support member; and
a sliding sleeve valve positioned within the passage of the second support member;
wherein the stinger engages the sliding sleeve valve.
61. An apparatus comprising:
a packer control device for controlling the operation of a packer, the packer control device comprising:
a first support member;
one or more drag blocks releasably coupled to the support member; and
a stinger coupled to the first support member for engaging the packer; and
the packer comprising:
a second support member defining a passage;
a shoe comprising a float valve coupled to an end of the second support member;
one or more compressible packer elements movably coupled to the second support member; and
a sliding sleeve valve positioned within the passage of the second support member;
wherein the stinger engages the sliding sleeve valve.
62. An apparatus for radially expanding and plastically deforming an expandable tubular member, comprising:
a support member;
a cutting device for cutting the tubular member coupled to the support member;
an expansion device for radially expanding and plastically deforming the tubular member coupled to the support member;
a gripping device for gripping the tubular member coupled to the support member;
a sealing device for sealing an interface with the tubular member coupled to the support member;
a locking device for locking the position of the tubular member relative to the support member;
an actuator for displacing the expansion device relative to the support member;
a packer assembly coupled to the support member; and
a device for controlling the operation of the packer assembly, the device comprising:
a tubular support;
a stinger coupled to the tubular support for releasably engaging the packer assembly; and
a compressible element at least partially circumferentially extending about the first tubular support;
wherein the compressible element comprises:
a first configuration in which the compressible element is uncompressed; and
a second configuration in which the compressible element is at least partially compressed.
63. A method of radially expanding and plastically deforming a tubular member, comprising:
positioning the tubular member within a preexisting structure, comprising:
locking the tubular member to an expansion device;
radially expanding and plastically deforming a lower portion of the tubular member to form a bell section, comprising:
lowering an expansion device out of an end of the tubular member; and
pulling the expansion device through the end of the tubular member, comprising:
gripping the tubular member; and
pulling the expansion device through the end of the tubular member;
radially expanding and plastically deforming a portion of the tubular member above the bell section;
positioning a packer assembly comprising a sealing element within the tubular member;
setting the sealing element against an interior surface of the tubular member; and
preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
64. A system comprising:
means for positioning a packer assembly comprising a sealing element within a tubular member;
means for setting the sealing element against an interior surface of the tubular member; and
means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
65. The system of claim 64 wherein the means for setting the sealing element against the interior surface of the tubular member comprises:
means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and
means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member.
66. The system of claim 65 wherein the means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member comprises:
means for preventing further application of the first force against the sealing element.
67. The system of claim 64 further comprising:
means for coupling a packer control device to the packer assembly;
68. The system of claim 67 wherein the tubular member extends within a wellbore; and
wherein the system further comprises:
means for positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore.
69. The system of claim 68 further comprising:
means for radially expanding and plastically deforming at least a portion of the tubular member.
70. The system of claim 69 further comprising:
means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member.
71. The system of claim 70 wherein the packer assembly further comprises at least one other sealing element; and
wherein the system further comprises:
means for setting the at least one other sealing element against the interior surface of the tubular member.
72. The system of claim 71 further comprising:
means for decoupling the packer control device from the packer assembly.
73. The system of claim 72 further comprising:
means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
74. A system comprising:
means for coupling a packer control device to a packer assembly comprising a sealing element;
means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore;
means for radially expanding and plastically deforming at least a portion of the tubular member;
means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises:
means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and
means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member; and
means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element.
75. A system comprising:
means for positioning a packer assembly comprising a sealing element within a tubular member;
means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and
means for applying a second force against the sealing element to set the sealing element against an interior surface of the tubular member.
76. The system of claim 75 further comprising:
means for preventing further application of the first force against the sealing element.
77. The system of claim 76 wherein preventing further application of the first force against the sealing element prevents the application of an impact load against the interior surface of the tubular member.
78. The system of claim 75 further comprising:
means for coupling a packer control device to the packer assembly;
79. The system of claim 78 wherein the tubular member extends within a wellbore; and
wherein the system further comprises:
means for positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore.
80. The system of claim 79 further comprising:
means for radially expanding and plastically deforming at least a portion of the tubular member.
81. The system of claim 80 further comprising:
means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member.
82. The system of claim 81 wherein the packer assembly further comprises at least one other sealing element; and
wherein the system further comprises:
means for setting the at least one other sealing element against the interior surface of the tubular member.
83. The system of claim 82 further comprising:
means for decoupling the packer control device from the packer assembly.
84. The system of claim 83 further comprising:
means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
85. A system for radially expanding and plastically deforming a tubular member, comprising:
means for positioning the tubular member within a preexisting structure, comprising:
means for locking the tubular member to an expansion device;
means for radially expanding and plastically deforming a lower portion of the tubular member to form a bell section, comprising:
means for lowering an expansion device out of an end of the tubular member; and
means for pulling the expansion device through the end of the tubular member, comprising:
means for gripping the tubular member; and
means for pulling the expansion device through the end of the tubular member;
means for radially expanding and plastically deforming a portion of the tubular member above the bell section;
means for positioning a packer assembly comprising a sealing element within the tubular member;
means for setting the sealing element against an interior surface of the tubular member; and
means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member.
86. An apparatus for controlling the operation of a packer assembly, comprising:
a first tubular support;
a second tubular support at least partially extending within the first tubular support;
one or more first retaining dogs coupled to the first tubular support for releasably engaging the second tubular support;
a stinger coupled to the second tubular support for releasably engaging the packer assembly;
one or more second retaining dogs releasably engaged with the first tubular support, wherein the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support;
a third tubular support coupled to the second tubular support and the stinger;
a compressible element at least partially circumferentially extending about the third tubular support, wherein the compressible element comprises:
a first configuration in which the compressible element is uncompressed; and
a second configuration in which the compressible element is at least partially compressed;
wherein, when the one or more first retaining dogs are released from the second tubular support and the one or more second retaining dogs are released from the first tubular support, the one or more first retaining dogs and the first tubular support are movable relative to the second tubular support to place the compressible element in the second configuration;
wherein, when the compressible element is in the second configuration, the first tubular support is movable in a direction relative to the second tubular support to cause a first force to be applied against at least one sealing element of the packer assembly;
wherein the third tubular support comprises an external flange for preventing further movement of the first tubular support in the direction when the compressible element is in the second configuration;
wherein the compressible element further comprises a third configuration in which the compressible element is permitted to uncompress to cause a second force to be applied against the at least one sealing element of the packer assembly; and
wherein the at least one sealing element is adapted to be set against an interior surface of a tubular member in response to the second force applied against the at least one sealing element;
wherein the compressible element comprises a spring;
wherein the apparatus further comprises:
a fourth tubular support coupled to the third tubular support and through which the third tubular support extends, the fourth tubular support comprising an external flange and engaging the external flange of the third tubular support;
a spring mandrel coupled to the first tubular support and through which the fourth tubular support extends, the spring mandrel at least partially defining a first annular region in which the spring extends; and
a spring sleeve at least partially circumferentially extending about the spring for retaining the spring within the first annular region;
wherein the spring mandrel is movable in the direction relative to the spring sleeve to place the spring in the second configuration;
wherein the spring mandrel is adapted to engage the external flange of the fourth tubular support when the spring is in the second configuration; and
wherein movement of the first tubular support and the spring mandrel in the direction is prevented in response to the engagement of the spring mandrel with the external flange of the fourth tubular support and the engagement of the fourth tubular support with the external flange of the third tubular support;
wherein the spring mandrel comprises an internal annular recess and the fourth tubular support comprises an external annular recess;
wherein the apparatus further comprises:
a locking dog received within the internal annular recess of the spring mandrel, the locking dog comprising:
a first configuration in which the locking dog engages an exterior surface of the fourth tubular support; and
a second configuration in which the locking dog is received within the external annular recess of the fourth tubular support to limit movement of the spring mandrel relative to the fourth tubular support;
one or more rupture discs coupled to the third tubular support; and
the packer assembly;
wherein an exterior surface of the third tubular support and the interior surface of the first tubular support define a second annular region;
wherein, when the one or more rupture discs rupture, fluidic material is permitted to flow into the second annular region;
wherein the one or more second retaining dogs are released from the first tubular support in response to the flow of the fluidic material into the second annular region; and
wherein the packer assembly comprises:
a support member to which the at least one sealing element is movably coupled, the support member defining a passage;
a shoe comprising a float valve coupled to an end of the support member; and
a sliding sleeve valve positioned within the passage of the support member;
wherein the stinger engages the sliding sleeve valve.
87. A method comprising:
coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element;
positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore;
positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore;
radially expanding and plastically deforming at least a portion of the tubular member;
moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member;
setting the sealing element against an interior surface of the tubular member, wherein setting the sealing element against the interior surface of the tubular member comprises:
applying a first force against the sealing element to move the sealing element relative to the tubular member; and
applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member;
preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element;
setting the at least one other sealing element against the interior surface of the tubular member;
decoupling the packer control device from the packer assembly; and
testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
88. A system comprising:
means for coupling a packer control device to a packer assembly comprising a sealing element and at least one other sealing element;
means for positioning the packer control device and the packer assembly within a tubular member that extends within a wellbore;
means for positioning the packer control device and the packer assembly outside of the tubular member and in the wellbore;
means for radially expanding and plastically deforming at least a portion of the tubular member;
means for moving the packer control device and the packer assembly so that the packer control device and the packer assembly extend within the at least a portion of the tubular member;
means for setting the sealing element against an interior surface of the tubular member, wherein the means for setting the sealing element against the interior surface of the tubular member comprises:
means for applying a first force against the sealing element to move the sealing element relative to the tubular member; and
means for applying a second force against the sealing element to set the sealing element against the interior surface of the tubular member;
means for preventing the application of an impact load against the interior surface of the tubular member during setting the sealing element against the interior surface of the tubular member by preventing further application of the first force against the sealing element;
means for setting the at least one other sealing element against the interior surface of the tubular member;
means for decoupling the packer control device from the packer assembly; and
means for testing the ability of at least one of the sealing element and the at least one other sealing element to maintain a pressure seal against the interior surface of the tubular member.
US11/531,041 2002-11-12 2006-09-12 Apparatus for radially expanding and plastically deforming a tubular member Abandoned US20070227730A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US11/531,041 US20070227730A1 (en) 2005-09-15 2006-09-12 Apparatus for radially expanding and plastically deforming a tubular member
US11/838,782 US20080142213A1 (en) 2002-11-12 2007-08-14 Radial expansion of a wellbore casing against a formation

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US71739105P 2005-09-15 2005-09-15
US11/531,041 US20070227730A1 (en) 2005-09-15 2006-09-12 Apparatus for radially expanding and plastically deforming a tubular member

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US7793721B2 (en) 2003-03-11 2010-09-14 Eventure Global Technology, Llc Apparatus for radially expanding and plastically deforming a tubular member
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CN104612614A (en) * 2013-11-05 2015-05-13 天津大港油田钻采技术开发公司 Arc-shaped reducing expansion device for expansion pipe
US20170130569A1 (en) * 2015-11-10 2017-05-11 Michael Sequino System for forming a horizontal well for environmental remediation and method of operation
WO2018148480A1 (en) * 2017-02-09 2018-08-16 Enventure Global Technology, Inc. Liner hanger for use with an expansion tool having an adjustable cone
US10309189B1 (en) * 2016-03-24 2019-06-04 Christopher A. Branton Downhole bridge plugs reinforcing rings and reinforcing ring fabrication methods
US10316627B2 (en) * 2014-08-13 2019-06-11 Shell Oil Company Assembly and method for creating an expanded tubular element in a borehole
CN112302602A (en) * 2019-07-29 2021-02-02 中国石油化工股份有限公司 Sliding sleeve opening device
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EP2201211A1 (en) * 2007-10-24 2010-06-30 Halliburton Energy Services, Inc. Setting tool for expandable liner hanger and associated methods
EP2201211A4 (en) * 2007-10-24 2014-03-19 Halliburton Energy Serv Inc Setting tool for expandable liner hanger and associated methods
US20090200041A1 (en) * 2008-02-07 2009-08-13 Halliburton Energy Services, Inc. Expansion Cone for Expandable Liner Hanger
US7779910B2 (en) 2008-02-07 2010-08-24 Halliburton Energy Services, Inc. Expansion cone for expandable liner hanger
US20090294118A1 (en) * 2008-05-29 2009-12-03 Halliburton Energy Services, Inc. Method and apparatus for use in a wellbore
US7779924B2 (en) 2008-05-29 2010-08-24 Halliburton Energy Services, Inc. Method and apparatus for use in a wellbore
US8261842B2 (en) 2009-12-08 2012-09-11 Halliburton Energy Services, Inc. Expandable wellbore liner system
US20110220356A1 (en) * 2010-03-11 2011-09-15 Halliburton Energy Services, Inc. Multiple stage cementing tool with expandable sealing element
US8230926B2 (en) 2010-03-11 2012-07-31 Halliburton Energy Services Inc. Multiple stage cementing tool with expandable sealing element
CN104612614A (en) * 2013-11-05 2015-05-13 天津大港油田钻采技术开发公司 Arc-shaped reducing expansion device for expansion pipe
US10316627B2 (en) * 2014-08-13 2019-06-11 Shell Oil Company Assembly and method for creating an expanded tubular element in a borehole
US20170130569A1 (en) * 2015-11-10 2017-05-11 Michael Sequino System for forming a horizontal well for environmental remediation and method of operation
US10309189B1 (en) * 2016-03-24 2019-06-04 Christopher A. Branton Downhole bridge plugs reinforcing rings and reinforcing ring fabrication methods
WO2018148480A1 (en) * 2017-02-09 2018-08-16 Enventure Global Technology, Inc. Liner hanger for use with an expansion tool having an adjustable cone
GB2571862A (en) * 2017-02-09 2019-09-11 Enventure Global Tech Inc Liner hanger for use with an expansion tool having an adjustable cone
GB2571862B (en) * 2017-02-09 2022-02-16 Enventure Global Tech Inc Liner hanger for use with an expansion tool having an adjustable cone
US11352858B2 (en) 2017-02-09 2022-06-07 Enventure Global Technology Inc. Liner hanger for use with an expansion tool having an adjustable cone
US11713655B2 (en) 2017-02-09 2023-08-01 Enventure Global Technology Inc. Liner hanger for use with an expansion tool having an adjustable cone
CN112302602A (en) * 2019-07-29 2021-02-02 中国石油化工股份有限公司 Sliding sleeve opening device
CN113404463A (en) * 2020-03-16 2021-09-17 中国石油天然气股份有限公司 Expansion pipe column

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GB2431179A (en) 2007-04-18
NO20064139L (en) 2007-03-16
GB0618076D0 (en) 2006-10-25

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Owner name: ENVENTURE GLOBAL TECHNOLOGY, L.L.C., TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:BRISCO, DAVID PAUL;WATSON, BROCK WAYNE;TREECE, HAROLD OTIS;REEL/FRAME:018589/0069;SIGNING DATES FROM 20061020 TO 20061130

STCB Information on status: application discontinuation

Free format text: EXPRESSLY ABANDONED -- DURING EXAMINATION