EP3094813B1 - Élément d'étanchéité pour un outil de fond de trou - Google Patents

Élément d'étanchéité pour un outil de fond de trou Download PDF

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Publication number
EP3094813B1
EP3094813B1 EP14888977.7A EP14888977A EP3094813B1 EP 3094813 B1 EP3094813 B1 EP 3094813B1 EP 14888977 A EP14888977 A EP 14888977A EP 3094813 B1 EP3094813 B1 EP 3094813B1
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EP
European Patent Office
Prior art keywords
sealing member
sealing
wall
wedge
downhole tool
Prior art date
Legal status (The legal status 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 status listed.)
Active
Application number
EP14888977.7A
Other languages
German (de)
English (en)
Other versions
EP3094813A4 (fr
EP3094813A1 (fr
Inventor
David Allen Dockweiler
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
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Publication date
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Publication of EP3094813A1 publication Critical patent/EP3094813A1/fr
Publication of EP3094813A4 publication Critical patent/EP3094813A4/fr
Application granted granted Critical
Publication of EP3094813B1 publication Critical patent/EP3094813B1/fr
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 boreholes or wells
    • E21B23/01—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 boreholes or wells
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • E21B33/1293—Packers; Plugs with mechanical slips for hooking into the casing with means for anchoring against downward and upward movement

Definitions

  • This invention relates to tools used in oil and gas wellbores. More specifically, the disclosure relates to expansion sealing elements used to prevent fluid flow through an annulus formed by a tubing within the well and the wall of the wellbore or casing.
  • Downhole tools such as packers, bridge plugs and frac plugs are often used to seal the annulus formed by a tubing within the well and the wall of the wellbore or casing.
  • Downhole tools such as packers, bridge plugs and frac plugs are often used to seal the annulus formed by a tubing within the well and the wall of the wellbore or casing.
  • the seal for the annulus is generally established by a deformable element such as rubber or an elastomer.
  • a compressive force is generally applied to the deformable element, causing it to extrude radially outward.
  • the element extends from the outer portion of the mandrel of the downhole tool to the wellbore wall or casing and seals between those structures.
  • Sealing element 10 is illustrated in its first position or unset position.
  • Sealing element 10 is shown as being within a wall 42, which can be a casing wall or wellbore wall.
  • Sealing element 10 comprises a first sealing member 12 and a second sealing member 14.
  • each sealing member is made from a deformable element such as rubber or an elastomeric compound, but can be made of thermoplastic or other various soft deformable materials.
  • First sealing member 12 and second sealing member 14 are each disposed about a mandrel 16 of a downhole tool.
  • the sealing element 10 is set between a first packer shoe 18 and second packer shoe 20, or between two other barriers at least one of which is moveable so that compression or longitudinal pressure can be applied to the sealing element 10.
  • First packer shoe 18 and second packer shoe 20 are also disposed about mandrel 16
  • first sealing member 12 is a generally cylindrical sealing element having an outer surface 22, an inner surface 24, a first end 26 and a second end 28. First end 26 abuts first packer shoe 18. Inner surface 24 has an inclined inner wall 30 at second end 28.
  • Second sealing member 14 has an outer surface 32, an inner surface 34, a first end 36 and a second end 38. Second sealing member 14 is at least partially wedged or truncated conical in shape so that outer surface 32 has an inclined outer wall 40. Inclined outer wall 40 is at first end 26 of second sealing member 14 and adjacent second end 28 of first sealing member 12 when sealing element 10 is in its unset position. Thus, first sealing member 12 is longitudinally separated from second sealing member 14. By “longitudinally separated” it is meant that the sealing members are spaced longitudinally along mandrel 16 such that there is only a minor portion of overlap or no overlap of the sealing members, that is there is no overlap that creates any significant radial expansion and, preferably, no radial expansion of either sealing member. As shown in FIG.
  • second end 38 of second sealing member 14 can be wedged or truncated conical in shape, as shown, or can be another suitable shape such as cylindrical.
  • inner surface 24 and inner surface 34 are in contact with mandrel 16 when sealing element 10 is in its unset position.
  • outer surface 22 and outer surface 32 are exposed to but spaced away from the wall 42 of the wellbore, which may be a casing wall if the wellbore is lined. Accordingly, neither outer surface 22 nor outer surface 32 are in contact with wall 42.
  • sealing element 10 is illustrated in transition from its unset position to its second or set position ( FIG. 3 ) and is illustrated in its set position ( FIG. 4 ).
  • first sealing member 12 moves in relation to each other.
  • inclined inner wall 30 slides over inclined outer wall 40 causing first sealing member 12 to stretch over second sealing member 14 and come into sealing engagement with wall 42.
  • first sealing member 12 moves from being longitudinally spaced from second sealing member 14 to being radially outward from the second sealing member such that outer surface 22 is in sealing engagement with wall 42.
  • inner surface 24 of first sealing member 12 is in sealing engagement with outer surface 32 of second sealing member 14, and inner surface 34 of second sealing member 14 is in sealing engagement with mandrel 16.
  • Sealing element 10 represents a more versatile sealing element than prior conventional sealing elements. Although designed for a specific casing diameter ("design size") such as that shown in FIGS. 1-4 , sealing element 10 advantageously can also be utilized in smaller diameter casings. As shown in FIG. 5 , when sealing element 10 is used in smaller diameter casing it achieves sealing without the complete overlap of sealing member 12 and sealing member 14. Thus, the amount that first sealing member 12 stretches over second sealing member 14 will be determined by the casing size. As illustrated in FIG.
  • first sealing member 12 when used in a casing having a diameter below the design size, first sealing member 12 stretches over second sealing member 14 so that only a first portion 44 of first sealing member 12 is radially outward from second sealing member 14 with the remaining portion or second portion 46 of first sealing member 12 being longitudinally spaced from second sealing member 14.
  • outer surface 22 of at least the first portion 44 of first sealing member 14 is in sealing engagement with wall 42 and, depending on the size of the casing, a majority or even all of outer surface 22 can be in sealing engagement with wall 42.
  • the inner surface 24 of a second portion 46 of first sealing member 12 is in sealing engagement with mandrel 16 and inner surface 24 of first portion 44 is in sealing engagement with outer surface 32 of second sealing member 14.
  • Inner surface 34 of second sealing member 14 is in sealing engagement with mandrel 16.
  • FIGS. 6 and 7 the use of an embodiment of the sealing element 10 in a downhole tool 100 is shown. While the embodiment of FIGS. 5 and 6 illustrate downhole tool 100 as a packer tool, it should be understood that the invention is not limited to use in packer-type tools but is useful for any downhole tool for use in a wellbore requiring a fluid tight seal and is especially useful where there is a change in wellbore diameter such that the tool and expansion device must pass through a wellbore of smaller radius before being received into the wellbore where it will be placed in the set position. The latter wellbore having a greater radius than the wellbore of smaller radius.
  • downhole tool 100 is shown in well comprising first wellbore or first casing 102 having a diameter D1 and a second wellbore or second casing 104 having a diameter D2.
  • D1 is less than D2.
  • Downhole tool 100 can be lowered into a well on tubing or can be lowered on a wire line or other means known in the art (not shown).
  • FIG. 5 shows the downhole tool 100 in its unset position and
  • FIG. 6 shows downhole tool 100 in its set position.
  • Downhole tool 100 comprises a mandrel 106 with an outer surface 108 and inner surface 110.
  • Mandrel 106 will typically be a drillable material such as a polymeric composite.
  • Mandrel 106 has a bore 112 defined by inner surface 110.
  • Mandrel 106 has upper or top end 116 and lower or bottom end 118. Bore 112 defines a central flow passage therethrough.
  • An end section 120 may comprise a mule shoe 120.
  • Mule shoe 120 is shown as integrally formed with the mandrel 106 but can be a separate piece that is connected with pins to mandrel 106.
  • Mule shoe 120 defines an upward facing shoulder 122 thereon.
  • Mandrel 106 has first or upper outer diameter 130, a second or first-intermediate outer diameter 132, which is a threaded outer diameter 132, a third or second-intermediate outer diameter 134 and a fourth or lower outer diameter 136. Shoulder 122 is defined by and extends between third and fourth outer diameters 134 and 136, respectively. Threads 138 are defined on threaded outer diameter 132. A head or head portion 140 is threadedly connected to mandrel 112 and, thus, has mating buttress threads 142 thereon.
  • Head portion 140 has an upper end 144 that may comprise a plug or ball seat 146. Head 140 has lower end 148 and has first, second and third inner diameters 150, 152 and 154, respectively. Buttress threads 142 are defined on third inner diameter 154. Second inner diameter 152 has a magnitude greater than first inner diameter 150 and third inner diameter 154 has a magnitude greater than second inner diameter 152. A shoulder 156 is defined by and extends between first and second inner diameters 150 and 152. Shoulder 156 and upper end 120 of mandrel 106 define an annular space 158 therebetween. In the embodiment illustrated, a spacer sleeve 160 is disposed in annular space 158.
  • Spacer sleeve 160 has an open bore 162 so that fluid may pass unobstructed therethrough into and through longitudinal central flow passage 124. Head portion 140 may be disconnected by unthreading from mandrel 106 so that instead of spacer sleeve 160, a plug may be utilized. The plug will prevent flow in either direction and, as such, the tool will act as a bridge plug.
  • a spacer ring 164 is disposed about mandrel 106 and abuts lower end 148 of head portion 140 so that it is axially restrained on mandrel 106.
  • Downhole tool 100 further comprises a set of expansion apparatuses 166 as described in co-pending US Patent Application Serial Number 14/848,323, filed January 31, 2013 .
  • Expansion apparatuses 166 comprise first and second or upper and lower expansion apparatuses 167 and 168.
  • Upper and lower expansion apparatuses 167 and 168 are generally identical in configuration but their orientation is reversed on mandrel 106.
  • Expansion apparatuses 167 and 168 have slip rings 170.
  • Slip rings 170 are segmented slip rings and are shown as having buttons 172 secured to the outer surface thereof. When downhole tool 100 is moved to the set position, as shown in FIG. 6 , buttons 172 will grippingly engage second casing 104 to secure downhole tool 100 in the wellbore.
  • Buttons 172 comprise a material of sufficient hardness to partially penetrate second casing 104 and may be comprised of metallic-ceramic composite or other material of sufficient strength.
  • Expansion apparatuses 167 and 168 further have expansion wedges 174, which are segmented wedges. Expansion wedges 174 are likewise disposed about mandrel 106. Further, expansion apparatuses 167 and 168 have wedges 176, which are disposed about mandrel 106. Wedges 176 are in contact with expansion wedges 174.
  • Sealing element 10 which is an expandable sealing element, as described above, is disposed about mandrel 106 and has first and second sealing members 12 and 14.
  • the embodiment illustrates a single sealing element; however, a multiple piece packer configuration can be used.
  • First and second sealing members 12 and 14 abut the ends of wedges 176 of upper and lower expansion apparatuses 167 and 168, respectively.
  • the downhole tool 100 in FIG. 6 in run-in configuration or unset position, is lowered into (run-in) the well by means of a work string of tubing sections or coupled tubing attached to the upper end 144 of head portion 140.
  • a setting tool can be part of the work string.
  • the downhole tool 100 in its unset position, fits through first casing 102, which has the smaller diameter of the two casings 102 and 104. Downhole tool 100 is then positioned in second casing 104.
  • the setting tool is actuated and it drives spacer ring 164 from its run-in configuration to the set position shown in FIG. 7 .
  • Spacer ring 164 as well as other components, such as wedge 176 of upper expansion apparatus 167, can be held in place during run-in by shear pins.
  • the axial pressure provided by the setting tool is sufficient to shear the shear pins to allow the components held by the shear pins to move to their set position.
  • each expansion apparatus 166 is longitudinally compressed, as is sealing element 10. With sufficient compression and sufficient resultant relative movement among the components of the expansion apparatuses 166 (wedges 176, expansion wedges 174 and slip rings 170) the connections between the wedge segments of expansion wedge 174 are sheared and the connections between the slip segments of slip ring 170 are sheared thus separating the wedge segments from each other and the slip segments from each other.
  • FIG. 7 shows the downhole tool 100 in its set position with expansion apparatuses 166 in its expanded configuration and with sealing element 10 sealed against casing 104.
  • a sealing element for a downhole tool comprising a first sealing member and a second sealing member.
  • the first sealing member engages the second sealing member such that the sealing element has a first position and a second position. In the second position, the first sealing member stretches over the second sealing member.
  • the first sealing member can be radially outward from the second sealing member when the sealing element is in the second position.
  • the sealing element moves from the first position to the second position under compression or tension.
  • the first sealing member can have an inner surface with an inclined inner wall and the second sealing member can have an outer surface with inclined outer wall. The inclined inner wall matches the inclined outer wall so as to facilitate the stretching of the first sealing member.
  • the sealing element when the sealing element is in the second position, the outer surface of the first sealing member is in sealing engagement with a wall of a wellbore; the inner surface of the first sealing member is in sealing engagement with the outer surface of the second sealing member; and the inner surface of the second member is in sealing engagement with a mandrel of the downhole tool.
  • a downhole tool for use in a wellbore comprising a mandrel, a first sealing member and a second sealing member.
  • the first sealing member is disposed about the mandrel.
  • the second sealing member is disposed about the mandrel.
  • the first sealing member is longitudinally separated from the second sealing member when the downhole tool is in the unset position, and the first sealing member is radially outward from the second sealing member when the downhole tool is in the second position.
  • the first sealing member stretches over the second sealing member when the downhole tool moves from the unset position to the set position.
  • the first sealing member can have an inner surface with an inclined inner wall and the second sealing member can have an outer surface with inclined outer wall.
  • the inclined inner wall matches the inclined outer wall so as to facilitate the stretching of the first sealing member.
  • a servicing tool in a wellbore comprising:
  • the first sealing member moves from being longitudinally separated from the second sealing member to being radially outward from the second sealing member. Also, after the first sealing member stretches over the second sealing member, the first sealing member sealingly engages the second sealing member.
  • the first sealing member has an inner surface with an inclined inner wall and the second sealing member has an outer surface with an inclined outer wall. The inclined inner wall matches the inclined outer wall so that the first sealing member stretches over the second sealing member by the inclined inner wall moving along the inclined outer wall.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Underground Structures, Protecting, Testing And Restoring Foundations (AREA)
  • Gasket Seals (AREA)

Claims (13)

  1. Outil de fond de trou (100) destiné à être utilisé dans un puits comportant un tubage (102), l'outil de fond de trou (100) comprenant :
    un mandrin (16, 106) ;
    une bague de glissement (170) disposée autour dudit mandrin (16, 106), dans lequel ladite bague de glissement (170) présente une position non réglée dans laquelle la bague de glissement (170) ne met pas en prise le tubage (102) et une position réglée dans laquelle ladite bague de glissement (170) met en prise par saisie le tubage (102) ;
    un premier coin (176) disposé autour dudit mandrin (16, 106), dans lequel ledit premier coin (176) est disposé de sorte qu'un déplacement longitudinal relatif dudit premier coin (176) vers ladite bague de glissement (170) entraîne ladite bague de glissement (170) radialement vers l'extérieur jusqu'à la position réglée ;
    un second coin (176) ; et
    un élément d'étanchéité (10) disposé entre le premier coin (176) et le second coin (176), l'élément d'étanchéité (10) comprenant un premier élément d'étanchéité (12) et un second élément d'étanchéité (14) ; caractérisé en ce que
    le premier élément d'étanchéité (12) vient en butée contre l'un du premier coin (176) et du second coin (176) ;
    le second élément d'étanchéité (14) vient en butée contre l'autre du premier coin (176) et du second coin (176) ; dans lequel ledit premier élément d'étanchéité (12) vient en prise avec ledit second élément d'étanchéité (14) de sorte que ledit élément d'étanchéité (10) présente une première position et une seconde position, et dans lequel ledit premier élément d'étanchéité (12) s'étend sur ledit second élément d'étanchéité (14) lorsque ledit élément d'étanchéité (10) est dans ladite seconde position de sorte que ledit étirement place le premier élément d'étanchéité (12) en prise étanche avec ledit tubage (102), et dans lequel ledit premier élément d'étanchéité (12) et ledit second élément d'étanchéité (14) sont en relation de fonctionnement avec ledit premier coin (176) et ledit second coin (176) de sorte qu'une pression longitudinale peut être appliquée sur l'élément d'étanchéité (10) afin de déplacer l'élément d'étanchéité (10) de ladite première position à ladite seconde position.
  2. Outil de fond de trou selon la revendication 1, dans lequel ledit premier élément d'étanchéité (12) est dirigé radialement vers l'extérieur depuis ledit second élément d'étanchéité (14) lorsque ledit élément d'étanchéité (10) est dans ladite seconde position.
  3. Outil de fond de trou selon la revendication 1, dans lequel ledit élément d'étanchéité (10) se déplace de ladite première position à ladite seconde position sous compression ou tension.
  4. Outil de fond de trou selon la revendication 3, dans lequel ledit premier élément d'étanchéité (12) présente une surface interne (24) avec une paroi interne inclinée (30) et ledit second élément d'étanchéité (14) présente une surface externe (32) avec une paroi externe inclinée (40), et dans lequel ladite paroi interne inclinée (30) correspond à ladite paroi externe inclinée (40) de manière à faciliter ledit étirement dudit premier élément d'étanchéité (12).
  5. Outil de fond de trou selon la revendication 4, dans lequel soit
    (i) lorsque ledit élément d'étanchéité (10) est dans ladite seconde position :
    ladite surface externe (22) dudit premier élément d'étanchéité (12) est en prise étanche avec une paroi d'un puits de forage :
    ladite surface interne (24) dudit premier élément d'étanchéité (12) est en prise étanche avec ladite surface externe (32) dudit second élément d'étanchéité (14) ; et
    ladite surface interne (34) dudit second élément (14) est en prise étanche avec un mandrin (16, 106) dudit outil de fond de trou (100) ;
    soit
    (ii) ledit premier élément d'étanchéité (12) est dirigé radialement vers l'extérieur depuis ledit second élément d'étanchéité (14).
  6. Outil de fond de trou selon la revendication 1, dans lequel ledit premier élément d'étanchéité (12) : soit (a) est séparé longitudinalement dudit second élément d'étanchéité (14) lorsque ledit élément d'étanchéité (10) est dans ladite première position et dans lequel ledit premier élément d'étanchéité (12) est dirigé radialement vers l'extérieur depuis ledit second élément d'étanchéité (14) lorsque ledit élément d'étanchéité (10) est dans ladite seconde position ; soit (b) s'étend sur ledit second élément d'étanchéité (14) lorsque ledit élément d'étanchéité (10) se déplace de ladite première position à ladite seconde position.
  7. Outil de fond de trou selon la revendication 6, dans lequel ledit premier élément d'étanchéité (12) présente une surface interne (24) avec une paroi interne inclinée (30) et ledit second élément d'étanchéité (14) présente une surface externe (32) avec une paroi externe inclinée (40), et dans lequel ladite paroi interne inclinée (30) correspond à ladite paroi externe inclinée (40) de manière à faciliter ledit étirement dudit premier élément d'étanchéité (12).
  8. Outil de fond de trou selon la revendication 7, dans lequel, lorsque ledit élément d'étanchéité (10) se déplace de ladite première position à ladite seconde position, des forces de compression sont appliquées sur ledit premier élément d'étanchéité (12) et sur ledit second élément d'étanchéité (14), déplaçant ainsi ledit premier élément d'étanchéité (12) d'une position de séparation longitudinale dudit second élément d'étanchéité (14) à une position dirigée radialement vers l'extérieur depuis ledit second élément d'étanchéité (14), éventuellement dans lequel, lorsque ledit élément d'étanchéité (10) se déplace d'une première position à une seconde position, ledit premier élément d'étanchéité (12) vient en prise de manière étanche avec ledit second élément d'étanchéité (14), et ledit second élément d'étanchéité vient en prise de manière étanche avec ledit mandrin (16, 106).
  9. Outil de fond de trou selon la revendication 1, dans lequel un coin de dilatation présentant des segments de coin est disposé autour dudit mandrin, lesdits segments de coin étant extensibles radialement vers l'extérieur par interaction avec le coin.
  10. Outil de fond de trou selon une quelconque revendication précédente, dans lequel
    le premier élément d'étanchéité (12) est disposé autour dudit mandrin (16, 106) ;
    le second élément d'étanchéité (14) est disposé autour dudit mandrin (16, 106) ; et
    dans lequel, pendant le déplacement de l'élément d'étanchéité (10) de la première position à la seconde position, ledit premier élément d'étanchéité (12) se déplace par rapport audit second élément d'étanchéité (14) de sorte que ledit premier élément d'étanchéité (12) glisse sur ledit second élément d'étanchéité (14).
  11. Procédé de fonctionnement d'un outil d'entretien dans un puits de forage comprenant :
    la compression longitudinale d'un élément d'étanchéité (10) le long d'un axe central, dans lequel ledit élément d'étanchéité (10) est tel que décrit à la revendication 10, et présente un premier élément d'étanchéité (12) et un second élément d'étanchéité (12) et ladite compression donne lieu à un déplacement axial relatif dudit premier élément d'étanchéité (12) et dudit second élément d'étanchéité (14) ;
    lors d'une compression suffisante, la dilatation dudit premier élément d'étanchéité (12) de sorte qu'il s'étend sur ledit second élément d'étanchéité (14) et vient en prise de manière étanche avec ledit puits de forage.
  12. Procédé selon la revendication 11, dans lequel, pendant ledit déplacement axial relatif, ledit premier élément d'étanchéité (12) se déplace d'une position longitudinalement séparée dudit second élément d'étanchéité (14) à une position dirigée radialement vers l'extérieur dudit second élément d'étanchéité (14).
  13. Procédé selon la revendication 11, dans lequel, après que ledit premier élément d'étanchéité (12) s'étend sur ledit second élément d'étanchéité (14), ledit premier élément d'étanchéité (12) vient en prise de manière étanche avec ledit second élément d'étanchéité (14) ; et éventuellement dans lequel ledit premier élément d'étanchéité (12) présente une surface interne (24) avec une paroi interne inclinée (30) et ledit second élément d'étanchéité (14) présente une surface externe (34) avec une paroi externe inclinée (40), et dans lequel ladite paroi interne inclinée (30) correspond à ladite paroi externe inclinée (40) de sorte que ledit premier élément d'étanchéité (12) s'étend sur ledit second élément d'étanchéité (14) par le déplacement de ladite paroi interne inclinée (30) le long de ladite paroi externe inclinée (40).
EP14888977.7A 2014-04-09 2014-04-09 Élément d'étanchéité pour un outil de fond de trou Active EP3094813B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2014/033508 WO2015156796A1 (fr) 2014-04-09 2014-04-09 Élément d'étanchéité pour un outil de fond de trou

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EP3094813A1 EP3094813A1 (fr) 2016-11-23
EP3094813A4 EP3094813A4 (fr) 2017-08-16
EP3094813B1 true EP3094813B1 (fr) 2019-12-04

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US (1) US20160265303A1 (fr)
EP (1) EP3094813B1 (fr)
AU (1) AU2014390013B2 (fr)
CA (1) CA2939070C (fr)
MX (1) MX2016011592A (fr)
WO (1) WO2015156796A1 (fr)

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US9835003B2 (en) * 2015-04-18 2017-12-05 Tercel Oilfield Products Usa Llc Frac plug
US20200048981A1 (en) * 2018-08-07 2020-02-13 Petroquip Energy Services, Llp Frac Plug with Sealing Element Compression Mechanism
WO2019194813A1 (fr) 2018-04-05 2019-10-10 Halliburton Energy Services, Inc. Dispositif d'isolation de puits de forage
WO2019209336A1 (fr) * 2018-04-27 2019-10-31 Halliburton Energy Services, Inc. Bouchon provisoire à éléments d'étanchéité multiples

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AU2014390013A1 (en) 2016-08-04
CA2939070A1 (fr) 2015-10-15
MX2016011592A (es) 2016-11-29
US20160265303A1 (en) 2016-09-15
AU2014390013B2 (en) 2018-02-01
WO2015156796A1 (fr) 2015-10-15
CA2939070C (fr) 2018-01-23
EP3094813A4 (fr) 2017-08-16
EP3094813A1 (fr) 2016-11-23

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