WO2008151316A2 - Downhole swaging system and method - Google Patents

Downhole swaging system and method Download PDF

Info

Publication number
WO2008151316A2
WO2008151316A2 PCT/US2008/066141 US2008066141W WO2008151316A2 WO 2008151316 A2 WO2008151316 A2 WO 2008151316A2 US 2008066141 W US2008066141 W US 2008066141W WO 2008151316 A2 WO2008151316 A2 WO 2008151316A2
Authority
WO
WIPO (PCT)
Prior art keywords
swaging
dimension
downhole
swage
tubular
Prior art date
Application number
PCT/US2008/066141
Other languages
French (fr)
Other versions
WO2008151316A3 (en
Inventor
David A. Garcia
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Publication of WO2008151316A2 publication Critical patent/WO2008151316A2/en
Publication of WO2008151316A3 publication Critical patent/WO2008151316A3/en

Links

Classifications

    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
    • E21B23/01—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for anchoring the tools 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
    • E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
    • 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

  • Downhole tools such as hangers and packers include such devices as slips and seals to structurally fix one tubular to another or to seal one tubular to another, for example. Loads applied during the setting of such tools are important to successful setting of the tools. Passing a swaging tool through the hanger or packer is a common method of setting such tools. At times, however, the setting forces from the swaging process are inadequate to reliably set the tool and consequently the set eventually fails. The art, therefore, would be receptive of systems that more reliable set such tools.
  • a downhole swaging system includes, a tubular having an area of strength with a different resistance to swaging as compared to areas of the tubular outside of the area of strength, and a swaging tool.
  • the swaging tool has a first swage, and a second swage with an adjustable swaging dimension, the second swage is in functional communication with the first swage such that the adjustable swaging dimension is adjusted in response to the first swage encountering a change in resistance to swaging.
  • the method includes, positioning an adjustable dimension two staged swaging tool within a tubular, and adjusting at least once a dimension of a second stage of the adjustable dimension two staged swaging tool in response to encountering a change in resistance to swaging of the tubular with a first stage of the adjustable dimension two staged swaging tool.
  • FIG. 1 depicts a partial cross sectional view of the downhole swaging system disclosed herein;
  • FIG. 2 depicts a perspective view of the downhole swaging system of Figure 1;
  • FIG. 3 depicts a partial cross sectional view of a tubular disclosed herein;
  • FIG. 4 depicts a partial cross sectional view of an alternate tubular disclosed herein;
  • FIG. 5 depicts a partial cross sectional view of a tubular after the swaging tool has passed therethrough
  • FIG. 6 depicts a partial cross sectional view of a tubular wall with an alternate area of strength
  • FIG. 7 depicts a partial cross sectional view of a tubular wall with yet another alternate area of strength
  • FIG. 8 depicts a partial cross sectional view of the tubular of FIG. 6 after the swaging tool has passed therethrough.
  • FIG. 1 and 2 an embodiment of the downhole swaging system 10 disclosed herein is illustrated.
  • the swaging system 10 among other things, 284-EXP-43341-US (BAO-0169)
  • the swaging tool 18 includes a swagable tubular 14, depicted herein as a liner made of a rigid material such as steel, for example, and a swaging tool 18.
  • the swaging tool 18 has a first swage 22 that, in this embodiment, has a fixed first swaging dimension 24, and a second swage 26 that has an adjustable second swaging dimension 28. It should be noted that alternate embodiments might have a first swage that is adjustable such that the first swage would have an adjustable swaging dimension that could at times exceed the swaging dimension 24.
  • the tubular 14 has an area of strength 30, depicted in this embodiment as a load ring 34 positioned coaxially with the tubular 14 and radially outwardly of the tubular 14.
  • the area of strength 30 is configured such that the swaging tool 18 encounters an increase in resistance to swaging as the first swage 22 begins to swage the area of strength 30. This increase in resistance to swaging creates a corresponding increase in a force necessary to continue to swage the area of strength 30 with the first swage 22.
  • the swaging tool 18 is configured to increase the second swaging dimension 28, of the second swage 26, in response to an increase in resistance encountered by the first swage 22.
  • the swages 22, 26 of this embodiment are circular such that the swaging performed by the swages 22, 26 increase the dimension of the tubular 14 diametrically. Alternate embodiments, however, may use swages with noncircular shapes such as oval, elliptical or octagonal, for example.
  • the swaging tool 18 is further configured such that the second swaging dimension 28 is reducible in response to a reduction in swaging resistance encountered by the first swage 22.
  • the second swage 26 is dimensionally reduced to allow the second swage 26 to pass through the area of strength 30 without expanding the area of strength 30.
  • An adjustable swaging tool capable of altering a swaging shape in response to encountering obstructions with the tool is known in the industry. Such an adjustable swaging tool is disclosed in U.S. Patent No. 7,128,146 (hereinafter ' 146), to John L. Baugh, the entire contents of which is incorporated herein by reference.
  • the load ring 34 used to create the area of strength 30 can be axially fixed to the tubular 14 by a radially flexible member 38 such as rubber as is shown herein (FIG. 2).
  • the flexibility of the flexible member 38 allows for the expansion of the tubular 14 in the area of strength while maintaining the axial location of both the 284-EXP-43341-US (BAO-0169)
  • the area of strength 30 can be axially fixed to the tubular 14 by other methods as long as the method retains the axial position of the area of strength 30 after the swaging tool 18 has passed therethrough. Some such methods will be described with reference to Figures 3 and 4 below.
  • the tubular 14, of FIG. 3 includes an area of strength 42 that comprises a wall 46 of the tubular 14 with an increased thickness 50.
  • the increased thickness 50 in this embodiment is on an inner surface 54 of the wall 46.
  • Alternate embodiments could have the increase in thickness on an outer surface, or both an inner and an outer surface, for example.
  • the tubular 14, of FIG. 4 includes an area of strength 56 that comprises a load ring 58 positioned radially inwardly of a wall 62 of the tubular 14.
  • the wall 62 has an inner surface 66 with a perimetrical recess 70 formed therein in which the load ring 58 is positioned.
  • the recess 70 axially locks the load ring 58 to the wall prior to, during and after the swaging tool 18 has passed therethrough.
  • the embodiment of the tubular 14 of FIG. 4 has the perimetrical recess 70 on the inner surface 66 alternate embodiments could position a perimetrical recess on an outer surface to locationally lock a load ring to the outer surface thereof.
  • alternate embodiments of the area of strength 30, 42, 56 could be formed by positioning a downhole tool along an outer surface of the tubular 14. Such a downhole tool would need to dimensionally expand to allow passage of the swaging tool 18 therethrough. In such an embodiment the downhole tool may be designed such that the downhole tool is destroyed as the swaging tool 18 passes thereby.
  • Still other areas of strength may be created with no geometric changes to the tubular 14 or surrounding area thereat.
  • Such an area of strength might use modified material properties of the tubular 14 only in the area of strength to create the area of strength. For example, through heat treating or work hardening, a section of the tubular can be made to have an increased resistance to swaging in the specific heat treated or work hardened section only.
  • a profile 74, of an inner surface 78 of the tubular 14 may be present after the swaging tool 18 has passed therethrough.
  • the profile 74 may have a perimetrical recess 82 in the inner surface 78.
  • the recess 82 can be used to receive a retrieving tool, a hanger or other tool, for example, that needs a recess with which to interface.
  • the profile 74 present on the inner surface 78 may be the same profile regardless of which of the area of strength 30, 42, 56 is employed in the swaging system 10.
  • the increased dimension 28 of the second swage 26 can be used to improve the performance of a tool, such as a hanger or a packer, for example, placed at the location of cladding 90, which is in axial alignment with the location of the second swage dimension 28.
  • a tool such as a hanger or a packer, for example
  • engagement of seals or slips can be improved by the extra dimensional expansion provided by the swaging system 10 as compared to not using the swaging system 10. This improved engagement is due to extra bite of slips or extra compression of seals of the tool permitted by the swaging system 10 disclosed.
  • the second swage 26 might not extend fully to the second swage dimension 28. In such a case, however, an expansion force of the second swage 26 may still increase providing additional biting of slips or seating of seals as described above.
  • a length of the increased dimension swage can be controlled by setting the length of the area of strength 30, 42, 56 as described above.
  • a dimension between the area of strength 30, 42, 56 and the increased dimension 28 can be set as desired by setting of a dimension between the first swage 22 and the second swage 26.
  • Forces of resistance to swaging by the first swage 22 can be set by setting such things as dimensional and material properties of the components used to construct the areas of strength 30, 42, 56 and the dimensional change of the tubular 14 that the first swage 22 will perform, for example.
  • adjustment of the second swage dimension 28 of the second swage 26 can be set to adjust at the resistance forces encountered by the first swage 22 by the teachings disclosed in ' 146. 284-EXP-43341-US (BAO-0169)
  • FIG. 6 includes an area of strength 94 that has a wall 98 of the tubular 14 with an area of decreased thickness 102.
  • the area of decreased thickness 102 results from a recess 104, in this embodiment, in an outer surface 106 of the wall 98.
  • the embodiment of FIG. 7 has an area of strength 108 with an area of decreased thickness 1 10 of wall 114 on an inner surface 118.
  • the area of strength could have changes to a wall thickness on both an inner surface as well as an outer surface simultaneously.
  • the walls 98, 114 are weakened thereby creating a localized decrease in resistance to swaging by the first swage 22.
  • This decrease in resistance to swaging by the first swage 22 can result in a decrease in the second swage dimension 28, thereby leaving a specific feature in the walls 98, 114 that can be interfaced with a tool as will de detailed below.
  • a profile 122, of the inner surface 118 of the tubular 14, may be present after the swaging tool 18 has passed therethrough.
  • the profile 122 may have a perimetrical protrusion 130 in the inner surface 118.
  • the protrusion 130 is similar in length to a length of the area of strength 94 since the area of strength 94 caused the swaging tool 18 to form the protrusion 130.
  • the protrusion 130 can be used to receive a retrieving tool, a hanger or other tool, for example, that needs a protrusion with which to interface.
  • the profile 122, present on the inner surface 1 18, may be the same profile regardless of the areas of strength 94 or 108 employed in the swaging system 10.
  • a perimetrical recess 134 in the outer wall 106 may be formed by the swaging system disclosed herein that can be engaged with a tool that needs the recess 134 in the outer surface 106 to interface with.

Abstract

Disclosed herein is a downhole swaging system. The system includes, a tubular having an area of strength with a different resistance to swaging as compared to areas of the tubular outside of the area of strength, and a swaging tool. The swaging tool has a first swage, and a second swage with an adjustable swaging dimension, the second swage is in functional communication with the first swage such that the adjustable swaging dimension is adjusted in response to the first swage encountering a change in resistance to swaging.

Description

284-EXP-43341-US (BAO-0169)
DOWNHOLE SWAGING SYSTEM AND METHOD
BACKGROUND OF THE INVENTION
[0001] Downhole tools such as hangers and packers include such devices as slips and seals to structurally fix one tubular to another or to seal one tubular to another, for example. Loads applied during the setting of such tools are important to successful setting of the tools. Passing a swaging tool through the hanger or packer is a common method of setting such tools. At times, however, the setting forces from the swaging process are inadequate to reliably set the tool and consequently the set eventually fails. The art, therefore, would be receptive of systems that more reliable set such tools.
BRIEF DESCRIPTION OF THE INVENTION
[0002] Disclosed herein is a downhole swaging system. The system includes, a tubular having an area of strength with a different resistance to swaging as compared to areas of the tubular outside of the area of strength, and a swaging tool. The swaging tool has a first swage, and a second swage with an adjustable swaging dimension, the second swage is in functional communication with the first swage such that the adjustable swaging dimension is adjusted in response to the first swage encountering a change in resistance to swaging.
[0003] Further disclosed herein is a method of swaging a tubular. The method includes, positioning an adjustable dimension two staged swaging tool within a tubular, and adjusting at least once a dimension of a second stage of the adjustable dimension two staged swaging tool in response to encountering a change in resistance to swaging of the tubular with a first stage of the adjustable dimension two staged swaging tool.
BRIEF DESCRIPTION OF THE DRAWINGS 284-EXP-43341-US (BAO-0169)
[0004] The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
[0005] FIG. 1 depicts a partial cross sectional view of the downhole swaging system disclosed herein;
[0006] FIG. 2 depicts a perspective view of the downhole swaging system of Figure 1;
[0007] FIG. 3 depicts a partial cross sectional view of a tubular disclosed herein;
[0008] FIG. 4 depicts a partial cross sectional view of an alternate tubular disclosed herein;
[0009] FIG. 5 depicts a partial cross sectional view of a tubular after the swaging tool has passed therethrough; and
[0010] FIG. 6 depicts a partial cross sectional view of a tubular wall with an alternate area of strength;
[0011] FIG. 7 depicts a partial cross sectional view of a tubular wall with yet another alternate area of strength; and
[0012] FIG. 8 depicts a partial cross sectional view of the tubular of FIG. 6 after the swaging tool has passed therethrough.
DETAILED DESCRIPTION OF THE INVENTION
[0013] A detailed description of several embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
[0014] Referring to Figures 1 and 2, an embodiment of the downhole swaging system 10 disclosed herein is illustrated. The swaging system 10, among other things, 284-EXP-43341-US (BAO-0169)
includes a swagable tubular 14, depicted herein as a liner made of a rigid material such as steel, for example, and a swaging tool 18. The swaging tool 18 has a first swage 22 that, in this embodiment, has a fixed first swaging dimension 24, and a second swage 26 that has an adjustable second swaging dimension 28. It should be noted that alternate embodiments might have a first swage that is adjustable such that the first swage would have an adjustable swaging dimension that could at times exceed the swaging dimension 24. The tubular 14 has an area of strength 30, depicted in this embodiment as a load ring 34 positioned coaxially with the tubular 14 and radially outwardly of the tubular 14. The area of strength 30 is configured such that the swaging tool 18 encounters an increase in resistance to swaging as the first swage 22 begins to swage the area of strength 30. This increase in resistance to swaging creates a corresponding increase in a force necessary to continue to swage the area of strength 30 with the first swage 22. The swaging tool 18 is configured to increase the second swaging dimension 28, of the second swage 26, in response to an increase in resistance encountered by the first swage 22. The swages 22, 26 of this embodiment are circular such that the swaging performed by the swages 22, 26 increase the dimension of the tubular 14 diametrically. Alternate embodiments, however, may use swages with noncircular shapes such as oval, elliptical or octagonal, for example.
[0015] The swaging tool 18 is further configured such that the second swaging dimension 28 is reducible in response to a reduction in swaging resistance encountered by the first swage 22. Thus, as the first swage passes beyond the area of strength 30 the second swage 26 is dimensionally reduced to allow the second swage 26 to pass through the area of strength 30 without expanding the area of strength 30. An adjustable swaging tool capable of altering a swaging shape in response to encountering obstructions with the tool is known in the industry. Such an adjustable swaging tool is disclosed in U.S. Patent No. 7,128,146 (hereinafter ' 146), to John L. Baugh, the entire contents of which is incorporated herein by reference.
[0016] The load ring 34 used to create the area of strength 30 can be axially fixed to the tubular 14 by a radially flexible member 38 such as rubber as is shown herein (FIG. 2). The flexibility of the flexible member 38 allows for the expansion of the tubular 14 in the area of strength while maintaining the axial location of both the 284-EXP-43341-US (BAO-0169)
flexible member 38 and the load ring 34. The area of strength 30 can be axially fixed to the tubular 14 by other methods as long as the method retains the axial position of the area of strength 30 after the swaging tool 18 has passed therethrough. Some such methods will be described with reference to Figures 3 and 4 below.
[0017] Referring to Figures 3 and 4, alternate embodiments of the tubular 14 are disclosed. The tubular 14, of FIG. 3, includes an area of strength 42 that comprises a wall 46 of the tubular 14 with an increased thickness 50. The increased thickness 50 in this embodiment is on an inner surface 54 of the wall 46. Alternate embodiments could have the increase in thickness on an outer surface, or both an inner and an outer surface, for example. The tubular 14, of FIG. 4, includes an area of strength 56 that comprises a load ring 58 positioned radially inwardly of a wall 62 of the tubular 14. The wall 62 has an inner surface 66 with a perimetrical recess 70 formed therein in which the load ring 58 is positioned. The recess 70 axially locks the load ring 58 to the wall prior to, during and after the swaging tool 18 has passed therethrough. Although the embodiment of the tubular 14 of FIG. 4 has the perimetrical recess 70 on the inner surface 66 alternate embodiments could position a perimetrical recess on an outer surface to locationally lock a load ring to the outer surface thereof. Additionally, alternate embodiments of the area of strength 30, 42, 56 could be formed by positioning a downhole tool along an outer surface of the tubular 14. Such a downhole tool would need to dimensionally expand to allow passage of the swaging tool 18 therethrough. In such an embodiment the downhole tool may be designed such that the downhole tool is destroyed as the swaging tool 18 passes thereby. Still other areas of strength may be created with no geometric changes to the tubular 14 or surrounding area thereat. Such an area of strength might use modified material properties of the tubular 14 only in the area of strength to create the area of strength. For example, through heat treating or work hardening, a section of the tubular can be made to have an increased resistance to swaging in the specific heat treated or work hardened section only.
[0018] Referring to FIG. 5, a profile 74, of an inner surface 78 of the tubular 14 may be present after the swaging tool 18 has passed therethrough. The profile 74 may have a perimetrical recess 82 in the inner surface 78. A length of the recess 82 284-EXP-43341-US (BAO-0169)
may be similar to a length of the area of strength 30, 42, 56 since the area of strength 30, 42, 56 caused the swaging tool 18 to form the recess 82. The recess 82 can be used to receive a retrieving tool, a hanger or other tool, for example, that needs a recess with which to interface. The profile 74 present on the inner surface 78 may be the same profile regardless of which of the area of strength 30, 42, 56 is employed in the swaging system 10.
[0019] Referring again to Figures 1 and 2, the increased dimension 28 of the second swage 26 can be used to improve the performance of a tool, such as a hanger or a packer, for example, placed at the location of cladding 90, which is in axial alignment with the location of the second swage dimension 28. By positioning the tool, at the location of the cladding 90, engagement of seals or slips can be improved by the extra dimensional expansion provided by the swaging system 10 as compared to not using the swaging system 10. This improved engagement is due to extra bite of slips or extra compression of seals of the tool permitted by the swaging system 10 disclosed. It should be noted that based on the dimensional limitations created by the tool in the area where the second swage 26 is attempting to increase dimensionally, the second swage 26 might not extend fully to the second swage dimension 28. In such a case, however, an expansion force of the second swage 26 may still increase providing additional biting of slips or seating of seals as described above.
[0020] It should be noted that several parameters regarding the swaging system 10 might be set to meet desired characteristics. For example, a length of the increased dimension swage can be controlled by setting the length of the area of strength 30, 42, 56 as described above. A dimension between the area of strength 30, 42, 56 and the increased dimension 28 can be set as desired by setting of a dimension between the first swage 22 and the second swage 26. Forces of resistance to swaging by the first swage 22 can be set by setting such things as dimensional and material properties of the components used to construct the areas of strength 30, 42, 56 and the dimensional change of the tubular 14 that the first swage 22 will perform, for example. Additionally, adjustment of the second swage dimension 28 of the second swage 26 can be set to adjust at the resistance forces encountered by the first swage 22 by the teachings disclosed in ' 146. 284-EXP-43341-US (BAO-0169)
[0021] Referring to Figures 6 and 7, alternate embodiments of the tubular 14 are disclosed. Unlike earlier embodiments that had an area of strength with an increase resistance to swaging, the embodiments of Figures 6 and 7 have area of strength with a decrease in resistance to swaging. The tubular 14, of FIG. 6, includes an area of strength 94 that has a wall 98 of the tubular 14 with an area of decreased thickness 102. The area of decreased thickness 102 results from a recess 104, in this embodiment, in an outer surface 106 of the wall 98. Alternately, the embodiment of FIG. 7 has an area of strength 108 with an area of decreased thickness 1 10 of wall 114 on an inner surface 118. In still other embodiments the area of strength could have changes to a wall thickness on both an inner surface as well as an outer surface simultaneously. In either of the areas of strength 94, 108, the walls 98, 114 are weakened thereby creating a localized decrease in resistance to swaging by the first swage 22. This decrease in resistance to swaging by the first swage 22 can result in a decrease in the second swage dimension 28, thereby leaving a specific feature in the walls 98, 114 that can be interfaced with a tool as will de detailed below.
[0022] Referring to FIG. 8, a profile 122, of the inner surface 118 of the tubular 14, may be present after the swaging tool 18 has passed therethrough. The profile 122 may have a perimetrical protrusion 130 in the inner surface 118. The protrusion 130 is similar in length to a length of the area of strength 94 since the area of strength 94 caused the swaging tool 18 to form the protrusion 130. The protrusion 130 can be used to receive a retrieving tool, a hanger or other tool, for example, that needs a protrusion with which to interface. The profile 122, present on the inner surface 1 18, may be the same profile regardless of the areas of strength 94 or 108 employed in the swaging system 10. Additionally, a perimetrical recess 134 in the outer wall 106 may be formed by the swaging system disclosed herein that can be engaged with a tool that needs the recess 134 in the outer surface 106 to interface with.
[0023] While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications 284-EXP-43341-US (BAO-0169)
may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims.

Claims

284-EXP-43341-US (BAO-0169)What is claimed is:
1. A downhole swaging system, comprising;
a tubular having an area of strength, the area of strength having a different resistance to swaging as compared to areas of the tubular outside of the area of strength; and
a swaging tool comprising;
a first swage; and
a second swage having an adjustable swaging dimension, the second swage being in functional communication with the first swage such that the adjustable swaging dimension is adjusted in response to the first swage encountering a change in resistance to swaging thereby.
2. The downhole swaging system of claim 1, wherein the adjustable swaging dimension is increased when the different resistance to swaging is an increase in the resistance to swaging.
3. The downhole swaging system of claim 1, wherein the adjustable swaging dimension is decreased when the different resistance to swaging is a decrease in the resistance to swaging.
4. The downhole swaging system of claim 1, wherein the area of strength includes a load ring positioned coaxial with the tubular.
5. The downhole swaging system of claim 4, wherein the load ring is positioned radially outwardly of the tubular.
6. The downhole swaging system of claim 1, wherein the area of strength includes a change in wall thickness of the tubular.
7. The downhole swaging system of claim 6, wherein the change in wall thickness includes a thickening of the wall in a radially inwardly direction. 284-EXP-43341-US (BAO-0169)
8. The downhole swaging system of claim 1, wherein the area of strength includes a change in material properties of the tubular.
9. The downhole swaging system of claim 1, wherein the second swage is positioned behind the first swage in the direction of motion of the swage tool while swaging.
10. The downhole swaging system of claim 1, wherein the area of strength is located near a downhole tool such that the adjustment of the dimension of the second swage occurs at the downhole tool.
11. The downhole swaging system of claim 10, wherein the downhole tool is a packer.
12. The downhole swaging system of claim 11, wherein the packer includes slips the engagement force of which to a downhole structure is increased by the adjusted dimension of the second swage.
13. The downhole swaging system of claim 11 , wherein the packer includes seals the engagement force of which to a downhole structure is increased by the adjusted dimension of the second swage.
14. The downhole swaging system of claim 1, wherein the first swage has a fixed swaging dimension.
15. The downhole swaging system of claim 1, wherein the adjustable dimension is circular.
16. A method of swaging a tubular, comprising:
positioning an adjustable dimension two staged swaging tool within a tubular; and
adjusting at least once a dimension of a second stage of the adjustable dimension two staged swaging tool in response to encountering a change in resistance 284-EXP-43341-US (BAO-0169)
to swaging of the tubular with a first stage of the adjustable dimension two staged swaging tool.
17. The method of swaging a tubular of claim 16, wherein the adjusting the dimension of the second stage includes increasing the adjustable dimension.
18. The method of swaging a tubular of claim 16, wherein the change in resistance to swaging includes increasing the resistance.
19. The method of swaging a tubular of claim 16, wherein the adjusting at least once is adjusting twice and one adjustment to the dimension is an increase in the dimension and the other adjustment to the dimension is a decrease in the dimension.
20. The method of swaging a tubular of claim 19, wherein the first adjustment to the dimension is in response to an increase in a swaging resistance encountered by the first stage and the second adjustment to the dimension is in response to a decrease in the swaging resistance encountered by the first stage.
PCT/US2008/066141 2007-06-05 2008-06-06 Downhole swaging system and method WO2008151316A2 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US94201807P 2007-06-05 2007-06-05
US60/942,018 2007-06-05

Publications (2)

Publication Number Publication Date
WO2008151316A2 true WO2008151316A2 (en) 2008-12-11
WO2008151316A3 WO2008151316A3 (en) 2010-03-25

Family

ID=40094428

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2008/066141 WO2008151316A2 (en) 2007-06-05 2008-06-06 Downhole swaging system and method

Country Status (2)

Country Link
US (1) US7878240B2 (en)
WO (1) WO2008151316A2 (en)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2934634A1 (en) * 2009-11-09 2010-02-05 Saltel Ind Tubular expandable sleeve i.e. metallic patch, positioning device for e.g. petrol production field, has control element that is not passed at interior of patch, when patch is incorrectly expanded, such that advancement of tool is blocked

Families Citing this family (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8443881B2 (en) * 2008-10-13 2013-05-21 Weatherford/Lamb, Inc. Expandable liner hanger and method of use
US7980302B2 (en) * 2008-10-13 2011-07-19 Weatherford/Lamb, Inc. Compliant expansion swage
US8973667B2 (en) * 2012-01-18 2015-03-10 Baker Hughes Incorporated Packing element with full mechanical circumferential support
BR112016017226B1 (en) 2014-01-28 2022-01-25 Shell Internationale Research Maatschappij B.V. PROCESS TO PRODUCE LIQUID HYDROCARBIDE PRODUCTS
CA2956239C (en) 2014-08-13 2022-07-19 David Paul Brisco Assembly and method for creating an expanded tubular element in a borehole
EP3353263A1 (en) 2015-09-25 2018-08-01 Shell International Research Maatschappij B.V. Conversion of biomass into methane
US11156052B2 (en) * 2019-12-30 2021-10-26 Saudi Arabian Oil Company Wellbore tool assembly to open collapsed tubing
US11448026B1 (en) 2021-05-03 2022-09-20 Saudi Arabian Oil Company Cable head for a wireline tool
US11859815B2 (en) 2021-05-18 2024-01-02 Saudi Arabian Oil Company Flare control at well sites
US11905791B2 (en) 2021-08-18 2024-02-20 Saudi Arabian Oil Company Float valve for drilling and workover operations
US11913298B2 (en) 2021-10-25 2024-02-27 Saudi Arabian Oil Company Downhole milling system

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3191680A (en) * 1962-03-14 1965-06-29 Pan American Petroleum Corp Method of setting metallic liners in wells
US20050127673A1 (en) * 1998-12-22 2005-06-16 Simpson Neil Andrew A. Tubing seal
EP1719874A1 (en) * 2005-04-11 2006-11-08 Halliburton Energy Services, Inc. Variable diameter expansion tool and expansion method
US20060266514A1 (en) * 2005-05-26 2006-11-30 Abarca John R Expandable tool with enhanced expansion capability
WO2007017355A1 (en) * 2005-08-05 2007-02-15 Shell Internationale Research Maatschappij B.V. Pipe expander

Family Cites Families (30)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4311194A (en) 1979-08-20 1982-01-19 Otis Engineering Corporation Liner hanger and running and setting tool
CA2529480C (en) 1996-03-11 2006-12-12 Schlumberger Canada Limited Method and apparatus for establishing branch wells at a node of a parent well
US6547006B1 (en) 1996-05-02 2003-04-15 Weatherford/Lamb, Inc. Wellbore liner system
GB2348908B (en) 1998-01-30 2002-09-11 Dresser Ind Method and apparatus for running two tubing strings into a well
US7357188B1 (en) * 1998-12-07 2008-04-15 Shell Oil Company Mono-diameter wellbore casing
US6823937B1 (en) 1998-12-07 2004-11-30 Shell Oil Company Wellhead
US7195064B2 (en) 1998-12-07 2007-03-27 Enventure Global Technology Mono-diameter wellbore casing
CA2297595A1 (en) 1999-01-29 2000-07-29 Baker Hughes Incorporated Flexible swage
AU782084B2 (en) 2000-08-15 2005-06-30 Baker Hughes Incorporated Self lubricating swage
AU9269501A (en) 2000-09-18 2002-03-26 Shell Oil Co Liner hanger with sliding sleeve valve
US6450261B1 (en) 2000-10-10 2002-09-17 Baker Hughes Incorporated Flexible swedge
US6655456B1 (en) 2001-05-18 2003-12-02 Dril-Quip, Inc. Liner hanger system
US6648075B2 (en) 2001-07-13 2003-11-18 Weatherford/Lamb, Inc. Method and apparatus for expandable liner hanger with bypass
US6691789B2 (en) * 2001-09-10 2004-02-17 Weatherford/Lamb, Inc. Expandable hanger and packer
BR0213060A (en) * 2001-10-01 2004-09-28 Baker Hughes Inc Tubular expansion apparatus and method
CA2463610A1 (en) * 2001-10-23 2003-05-01 Shell Canada Limited Device for performing a downhole operation
BR0214432A (en) * 2001-11-28 2004-11-03 Shell Int Research Expandable tubular element for use in a wellbore formed in a terrestrial formation
US7661470B2 (en) * 2001-12-20 2010-02-16 Baker Hughes Incorporated Expandable packer with anchoring feature
US7114559B2 (en) 2002-02-11 2006-10-03 Baker Hughes Incorporated Method of repair of collapsed or damaged tubulars downhole
US6866100B2 (en) 2002-08-23 2005-03-15 Weatherford/Lamb, Inc. Mechanically opened ball seat and expandable ball seat
US6899186B2 (en) 2002-12-13 2005-05-31 Weatherford/Lamb, Inc. Apparatus and method of drilling with casing
WO2004079157A1 (en) * 2003-02-28 2004-09-16 Baker Hughes Incorporated Compliant swage
US7441606B2 (en) 2003-05-01 2008-10-28 Weatherford/Lamb, Inc. Expandable fluted liner hanger and packer system
US6920927B2 (en) * 2003-05-02 2005-07-26 Weatherford/Lamb, Inc. Method and apparatus for anchoring downhole tools in a wellbore
US7159661B2 (en) 2003-12-01 2007-01-09 Halliburton Energy Services, Inc. Multilateral completion system utilizing an alternate passage
US7225880B2 (en) 2004-05-27 2007-06-05 Tiw Corporation Expandable liner hanger system and method
GB2423321B (en) 2005-02-22 2010-05-12 Weatherford Lamb Expandable tubulars for use in a wellbore
US7360592B2 (en) 2005-04-20 2008-04-22 Baker Hughes Incorporated Compliant cladding seal/hanger
US7549469B2 (en) * 2006-06-06 2009-06-23 Baker Hughes Incorporated Adjustable swage
US7607476B2 (en) * 2006-07-07 2009-10-27 Baker Hughes Incorporated Expandable slip ring

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3191680A (en) * 1962-03-14 1965-06-29 Pan American Petroleum Corp Method of setting metallic liners in wells
US20050127673A1 (en) * 1998-12-22 2005-06-16 Simpson Neil Andrew A. Tubing seal
EP1719874A1 (en) * 2005-04-11 2006-11-08 Halliburton Energy Services, Inc. Variable diameter expansion tool and expansion method
US20060266514A1 (en) * 2005-05-26 2006-11-30 Abarca John R Expandable tool with enhanced expansion capability
WO2007017355A1 (en) * 2005-08-05 2007-02-15 Shell Internationale Research Maatschappij B.V. Pipe expander

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2934634A1 (en) * 2009-11-09 2010-02-05 Saltel Ind Tubular expandable sleeve i.e. metallic patch, positioning device for e.g. petrol production field, has control element that is not passed at interior of patch, when patch is incorrectly expanded, such that advancement of tool is blocked
WO2011054687A1 (en) * 2009-11-09 2011-05-12 Saltel Industries Device for applying an expandable skirt having application diameter control upon advance
CN102713134A (en) * 2009-11-09 2012-10-03 索泰尔实业公司 Device for applying an expandable skirt having application diameter control upon advance
EA020831B1 (en) * 2009-11-09 2015-02-27 Сальтель Индюстри Device for applying an expandable skirt having application diameter control upon advance
US9163487B2 (en) 2009-11-09 2015-10-20 Saltel Industries Device for applying an expandable skirt having application diameter control upon advance

Also Published As

Publication number Publication date
US20090139732A1 (en) 2009-06-04
US7878240B2 (en) 2011-02-01
WO2008151316A3 (en) 2010-03-25

Similar Documents

Publication Publication Date Title
US7878240B2 (en) Downhole swaging system and method
US7367404B2 (en) Tubing seal
US7367390B2 (en) Slip energized by longitudinal shrinkage
EP1428974B1 (en) Expandable wellbore junction
EP2013445B1 (en) Expandable liner hanger
CA2663723C (en) Monobore construction with dual expanders
EP2255063B1 (en) Expandable packer
US7350588B2 (en) Method and apparatus for supporting a tubular in a bore
EP1517001B1 (en) Downhole expander device
US11021921B2 (en) Morphable anchor
WO2013112259A1 (en) Treatment plug and method of anchoring and sealing the same to a structure
US9982496B2 (en) Rolled tubular centralizer
US20020175474A1 (en) Tubing seal
WO2003023179A2 (en) System for lining a wellbore casing
US10012053B2 (en) Treatment plug, method of anchoring and sealing the same to a structure and method of treating a formation
EP3027333B1 (en) Rolled tubular centralizer
AU2014390013B2 (en) Sealing element for downhole tool
WO2022164621A1 (en) Slip system for use in downhole applications
EP3230555A1 (en) Anchor system and method for use in a wellbore
AU2015359407B2 (en) Expanding a tubular element in a wellbore
US20130146307A1 (en) Treatment plug and method of anchoring a treatment plug and then removing a portion thereof
WO2010040790A2 (en) Apparatus and method for deforming the shape of a tubular element

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 08770356

Country of ref document: EP

Kind code of ref document: A2

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 08770356

Country of ref document: EP

Kind code of ref document: A2