WO2019152039A1 - Joint d'étanchéité pliable - Google Patents

Joint d'étanchéité pliable Download PDF

Info

Publication number
WO2019152039A1
WO2019152039A1 PCT/US2018/016458 US2018016458W WO2019152039A1 WO 2019152039 A1 WO2019152039 A1 WO 2019152039A1 US 2018016458 W US2018016458 W US 2018016458W WO 2019152039 A1 WO2019152039 A1 WO 2019152039A1
Authority
WO
WIPO (PCT)
Prior art keywords
elastomeric element
inner bore
base
isolation device
fluid flow
Prior art date
Application number
PCT/US2018/016458
Other languages
English (en)
Inventor
Michael James Jurgensmeier
Rene HINOJOSA
Zachary William Walton
Daniel Lee SCHMIDT
Original Assignee
Halliburton Energy Services, Inc.
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 Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to PCT/US2018/016458 priority Critical patent/WO2019152039A1/fr
Publication of WO2019152039A1 publication Critical patent/WO2019152039A1/fr

Links

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
    • E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
    • E21B33/1295—Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure
    • E21B33/12955—Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure using drag blocks frictionally engaging the inner wall of the well
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole

Definitions

  • the present application is directed to a collapsible seal. More specifically, this application is directed to a collapsible seal implemented with a wellbore isolate device.
  • FIG. 1 is a diagrammatic view of a tool string having a wellbore isolation device disposed within a wellbore according to the present disclosure
  • FIG. 2 is an isometric view of a wellbore isolation device in an uncollapsed state according to the present disclosure
  • FIG. 3 is an isometric cross-section view of a wellbore isolation device in an uncollapsed state according to the present disclosure
  • FIG. 4 is an isometric view of a wellbore isolation device in a collapsed state according to the present disclosure
  • FIG. 5 is an elevation view of a wellbore isolation device in a collapsed state according to the present disclosure
  • FIG. 6 is an isometric view of a wellbore isolation device having sealing inserts in an uncollapsed state according to the present disclosure
  • FIG. 7 is an isometric view of a wellbore isolation device having sealing inserts in a collapsed state according to the present disclosure.
  • FIG. 8 is an elevational view of a an elastomeric element having sealing inserts in a collapsed state according to the present disclosure.
  • substantially is defined to be essentially conforming to the particular dimension, shape or other word that substantially modifies, such that the component need not be exact.
  • substantially tubular means that the object resembles a tube, but can have one or more deviations from a true cylinder.
  • the present disclosure provides an isolation device.
  • the isolation device can be for use within a subterranean wellbore environment, or in any other environment where restriction of fluid flow through an inner bore is desirable.
  • the isolation device can include a base having an inner bore formed therein.
  • the inner bore can have an inner diameter and extend along a longitudinal axis of the base and an outer surface of the base can have one or more engagement surfaces disposed thereon.
  • An elastomeric element can be coupled with the base.
  • the elastomeric element has an inner bore formed therein substantially the same as the inner diameter of the inner bore of the base. A fluid flow passing through the inner bore of the elastomeric element and the inner bore of the base at a predetermined flow rate can collapse the inner diameter of the elastomeric element, thereby blocking flow therethrough.
  • sealing mechanism While the present disclosure is described specifically with respect to a wellbore isolation device, it is within the scope of this disclosure for the sealing mechanism to be implemented in other environments. Further, while generally described for use with an isolation specific device the present disclosure can also be implemented with other devices, including in wellbore applications, as a sealing mechanism.
  • FIG. 1 shows an environmental view of an isolation device.
  • a system 10 for wellbore isolation can include a rig 12 extending over and around a wellbore 14.
  • the wellbore 14 is drilled within an earth formation 16 and has a casing 18 lining the wellbore 14, the casing 18 is held into place by cement 20.
  • a isolation device 100 can include a plurality of discrete components.
  • the wellbore isolation assembly 100 can be moved down the wellbore 14 via a conveyance 22 to a desired location.
  • a conveyance can be, for example, tubing-conveyed, coiled tubing, joint tubing, or other tubulars, wireline, slickline, work string, or any other suitable means for conveying tools into a wellbore.
  • a setting tool assembly 24 may be actuated to secure the wellbore isolation assembly into place.
  • FIG. 1 generally depicts a land- based operation
  • those skilled in the art would readily recognize that the principles described herein are equally applicable to operations that employ floating or sea-based platforms and rigs, without departing from the scope of the disclosure.
  • FIG. 1 depicts a vertical wellbore
  • the present disclosure is equally well-suited for use in wellbores having other orientations, including horizontal wellbores, slanted wellbores, multilateral wellbores or the like.
  • the isolation device 100 can be transitioned from a configuration allowing fluidic communication above and below the isolation device 100 to a configuration preventing fluidic communication below the isolation device 100.
  • the isolation device 100 can be implemented in any wellbore operations including, but not limited to, fracking, diverting, well treatment, or etching. In at least one instance, the isolation device 100 can be implemented for use during fracking (or hydraulic fracturing) operations to isolate, or separate, one portion of the wellbore 10 from any other portion of the wellbore 10.
  • FIG. 2 shows an isolation device according to the present disclosure.
  • the wellbore isolation device 100 having a base 102 and an elastomeric element 104.
  • Elastomeric element 104 may be made up of or include a deformable viscoelastic material such as a viscoelastic polymer.
  • the base 102 has an inner bore 106 formed therein and extending along a longitudinal axis 150.
  • the inner bore 106 has an inner diameter 108 sufficient to allow a fluid flow through the inner bore 106 and the isolation device 100.
  • the base 102 is shown as a portion of a well isolation device 100 or plug as depicted in FIG. 1,.
  • the base 102 can alternatively be at least a portion of a component disposed within a wellbore or other substantially tubular extending fluid flow path.
  • the base 102 can provide a coupling element for receivably coupling with the elastomeric element 104.
  • the base 102 can be a tool or component disposed within a work string and configured to couple with the elastomeric element 104.
  • the base 102 can have a distal (downhole) end 110 and a proximal (uphole) end 112.
  • the inner bore 106 formed along the longitudinal axis 150 can extend between the distal end 110 and the proximal end 112.
  • An outer surface 114 of the base 102 can have one or more engagement surfaces 116 disposed thereon.
  • the one or more engagement surfaces 116 can be arranged on the outer surface 114 in a predetermined pattern or randomly placed. In at least one instance, the engagement surfaces 116 can be configured to engage with an subterranean wellbore and/or wellbore casing, thereby securing the isolation device 100 in place.
  • the one or more engagement surfaces 116 vary in shape and arrangement depending on the desired implementation. In at least one instance, the engagement surfaces 116 are wedge shaped to secure the isolation device. In some instances, the engagement surfaces 116 can be recessed within the outer surface 114 to allow positioning of the isolation device 100 and then be deployable such that the engagement surfaces 116 extend beyond the outer surface 114.
  • FIG. 3 shows an isolation device in an uncollapsed state according to the present disclosure.
  • the elastomeric element 104 can couple with the proximal end 112 of the base 102.
  • the elastomeric element 104 can include an inner bore 118 formed along the longitudinal axis 150 and having an inner diameter 120 substantially the same as the inner diameter 108 of the inner bore 106 of the base 102.
  • the inner bore 118 can further substantially align with the inner bore 106 of the base, thus forming a fluid flow path through the isolation device 100.
  • FIG. 4 shows an isolation device 100 in a collapsed state.
  • the elastomeric element 104 can be transitioned from an uncollapsed state (shown in FIGS. 2 and 3) to a collapsed state.
  • the inner diameter 120 of the elastomeric element 104 is restricted (reduced) as compared to the uncollapsed state, thereby impeding the fluid flow path through the isolation device.
  • the elastomeric element 104 may deform, changing shape, thereby physically reducing the inner diameter 120.
  • the elastomeric element 104 in a collapsed state, can allow the collection of fluid and/or increase fluid pressure uphole by preventing fluid flow to the base 102.
  • the isolation device 100 can be a wellbore isolation device configured to restrict fluid flow within a subterranean wellbore to isolate a particular portion of the wellbore.
  • the narrowing of inner diameter 120 can completely restrict fluid flow therethrough. In other instances, the inner diameter 120 is reduced to substantially restrict fluid flow therethrough, but may allow minimal fluid flow to pass to the base 102 while still allowing fluid pressure to build uphole.
  • the elastomeric element 104 can be transitioned from an uncollapsed state to a collapsed state by a fluid flow through the inner bore 118 at a predetermined flow rate.
  • the fluid flow at the predetermined flow rate can induce a pressure differential (i.e. pressure drop) within the inner bore 118, thereby causing the elastomeric element 104 to collapse.
  • the pressure differential can be induced by friction within the pipe, elevational differences, length of pipe, pipe diameter, fluid density, and/or flow velocity.
  • the predetermined flow rate can be varied depending on the desire application and environment.
  • the elastomeric element 104 can be formed from any deformable polymer or elastomer, and thus the internal pipe friction can be varied by adjusting the size of the inner diameter to accommodate different predetermined flow rates at which the elastomeric element 104 transitions from the collapsed state to the uncollapsed state.
  • Fluid flow through the isolation element 100 can be controlled below the predetermined flow rate to allow fluid communication uphole and downhole of the isolation device 100.
  • the predetermine flow rate is between 10 gallons per minute (gpm) and 50 gpm.
  • FIG. 5 shows an elevational proximal end view of an isolation device.
  • the elastomeric element 104 of the isolation device 100 can be collapsed after exposure to a fluid flow at a predetermined volumetric flow rate.
  • the collapsed elastomeric element 104 has an inner bore 118 restricted so as to prevent fluid flow through the isolation device 100.
  • the collapsed elastomeric element 104 can prevent any fluid from flowing to the base 102. In other instances, the collapsed elastomeric element 104 substantially reduces fluid flow to the base 102. The substantial reduction in fluid flow allow minor leakage of fluid through the collapsed elastomeric element 104, while still substantially prevent fluid flow through the isolation device 100.
  • the elastomeric element 104 can be dissolved by exposure to a second fluid flow.
  • the second fluid flow can be any fluid configured to dissolve the elastomeric element 104, such as acid.
  • the second fluid flow can be provided at any volumetric flow rate, but be capable of dissolving the elastomeric element 104 and thereby allowing fluid flow through inner bore
  • impediment caused by the elastomeric element 104 can be removed by drilling through the elastomeric element, or any other intervention process.
  • FIG. 6 details an isolation device having an elastomeric element, in an uncollapsed state, shown as transparent for illustration purposes.
  • the isolation device 200 can have a base 202 and an elastomeric element 204.
  • the base 202 can have an inner bore 206 formed therein and extending along a longitudinal axis 250.
  • the inner bore 206 can have an inner diameter 208 sufficient to allow a fluid flow through the inner bore 206 and the isolation device 200.
  • the base 202 can have a distal (downhole) end 210 and a proximal (uphole) end 212.
  • the inner bore 206 formed along the longitudinal axis 250 can extend between the distal end 210 and the proximal end 212.
  • An outer surface 214 of the base 202 can have one or more engagement surfaces 216 disposed thereon.
  • the engagement surfaces 216 may be placed to prevent slippage and fix the isolation device 200 in a wellbore environment. They may be made up of a strong material and may be for instance ceramic, metallic and/or metallic-ceramic composite.
  • the one or more engagement surfaces 216 can be arranged on the outer surface 214 in a predetermined pattern or randomly placed. In at least one instance, the engagement surfaces 216 can be configured to engage with an subterranean wellbore and/or wellbore casing, thereby securing the isolation device 200 in place.
  • the one or more engagement surfaces 216 can vary in shape and arrangement depending on the desired implementation. In at least one instance, the engagement surfaces 216 are wedge shaped to secure the isolation device. In one instances, the engagement surfaces 216 can be recessed within the outer surface 214 to allow positioning of the isolation device 200 and then be deployable such that the engagement surfaces 216 extend beyond the outer surface 214.
  • the elastomeric element 204 can couple with the proximal end 212 of the base 202.
  • the elastomeric element 204 can include an inner bore 218 formed along the longitudinal axis 250 and having an inner diameter 220 substantially the same as the inner diameter 208 of the inner bore 206 of the base 202.
  • the inner bore 218 can further substantially align with the inner bore 206 of the base, thus forming a fluid flow path through the isolation device 200.
  • the elastomeric element 204 can also include a plurality of inserts 222 circumferentially disposed around an inner surface 224.
  • the plurality of inserts 222 can assist in sealing the inner bore 218 and impeding the fluid flow path of the isolation device 200 when the isolation device 200 is in a collapsed state. In the uncollapsed state, the plurality of inserts 222 can be substantially parallel to the longitudinal axis 250, thereby permitting fluid through the inner bore 218 and the fluid flow path of the isolation device 200.
  • FIG. 7 details an isolation device having an elastomeric element, in a collapsed state, shown as transparent for illustration purposes.
  • the inner bore 218 of the elastomeric element 204 provides a portion of the fluid flow path of the isolation device 200.
  • the elastomeric element 204 transitions from an uncollapsed state (shown in FIGS. 4 and 6) to a collapsed state.
  • the elastomeric element 204 substantially restricts and impedes the inner bore 218, thereby blocking and/or sealing in whole or in part the fluid flow path of the isolation device 200.
  • the plurality of inserts 222 can transition along with the elastomeric element 204 from being substantially parallel to the longitudinal axis 250 to being substantially perpendicular to the longitudinal axis 250.
  • the plurality of inserts 222 can be sized and shaped such that the circumferentially arrangement blocks or substantially blocks the inner bore 218 in the collapsed state.
  • the elastomeric element 204 and the plurality of inserts 222 can each individually, and collectively, block the inner bore 218 of the elastomeric element 204, thereby impeding the fluid flow path of the isolation device 200.
  • FIG. 8 is a proximal end view of an isolation device in a collapsed state.
  • each of the plurality of inserts 222 can overlap and adjacent insert 222.
  • the plurality of inserts 222 can have elastomeric, or other flexible, materials disposed around an edge or overlapping portion of the insert 222 to further assist in sealing the inner bore 218 and the fluid flow path of the isolation device.
  • the plurality of inserts 222 can be of any size and shape configured to substantially cover the inner bore 218 of the elastomeric element 204.
  • the plurality of inserts 222 can be coupled together, or can be individual elements. In at least one instance, the plurality of inserts 222 operate as an iris, similar to that of a camera aperture.
  • An isolation device comprising a base having an inner bore formed therein, the inner bore having an inner diameter and extending along a longitudinal axis of the base, an outer surface of the base having one or more engagement surfaces disposed thereon, and an elastomeric element coupled with the base, the elastomeric element having an inner bore formed therein, the elastomeric element inner bore having an inner diameter substantially the same as the inner diameter of the inner bore of the base, wherein, a fluid flow passing through the inner bore of the elastomeric element and the inner bore of the base at a predetermined flow rate collapses the inner bore of the elastomeric element reducing the inner diameter of the elastomeric element, thereby blocking flow therethrough.
  • Statement 2 The isolation device of Statement 1, wherein the one or more engagement surfaces are deployable between an unengaged position and an engaged position.
  • Statement 3 The isolation device of Statement 1 or Statement 2, wherein the elastomeric element is dissolvable upon introduction of a second fluid flow.
  • Statement 4 The isolation device of any one of Statements 1-3, wherein the collapsed elastomeric element prevents fluid flow to the inner bore of the base.
  • Statement 5 The isolation device of any one of Statements 1-4, wherein the collapsed elastomeric element substantially prevents fluid flow to the inner bore of the base.
  • Statement 6 The isolation device of any one of Statements 1-5, further comprising a plurality of inserts disposed around an inner circumference of the inner bore of the elastomeric element, the plurality of inserts substantially parallel to a longitudinal axis of the inner bore in an uncollapsed state and substantially perpendicular to the longitudinal axis of the inner bore in a collapsed state.
  • Statement 7 The isolation device of any one of Statements 1-6, wherein in a collapsed state the plurality of inserts are triangular shaped and at least partially overlap adjacent inserts to seal the inner bore of the elastomeric element.
  • a wellbore isolation device system comprising a work string comprising one or more downhole tools, the work string configured to be disposed within a wellbore formed in a subterranean formation; and at least of one the one or more downhole tools being a well isolation device, the well isolation device comprising a base having an inner bore formed therein, the inner bore having an inner diameter and extending along a longitudinal axis of the base, an outer surface of the base having one or more engagement surfaces disposed thereon, and an elastomeric element coupled with the base, the elastomeric element having an inner bore formed therein, the elastomeric element inner bore having an inner diameter substantially the same as the inner diameter of the inner bore of the base, wherein, a fluid flow passing through the inner bore of the elastomeric element and the inner bore of the base at a predetermined flow rate collapses the inner bore of the elastomeric element reducing the inner diameter of the elastomeric element, thereby blocking flow therethrough.
  • Statement 9 The system of Statement 8, wherein the one or more engagement surfaces are deployable between an unengaged position and an engaged position.
  • Statement 10 The system of Statement 8 or Statement 9, wherein the elastomeric element is dissolvable upon introduction of a second fluid flow.
  • Statement 11 The system of any one of Statements 8-10, wherein the collapsed elastomeric element prevents fluid flow into the inner bore of the base.
  • Statement 12 The system of any one of Statements 8-11, wherein the collapsed elastomeric element substantially prevents fluid flow into the inner bore of the base.
  • Statement 13 The system of any one of Statements 8-12, further comprising a plurality of inserts disposed around an inner circumference of the inner bore of the elastomeric element, the plurality of inserts substantially parallel to a longitudinal axis of the inner bore in an uncollapsed state and substantially perpendicular to the longitudinal axis of the inner bore in a collapsed state.
  • Statement 14 A method of wellbore isolation, the method comprising placing an isolation device within a wellbore formed in a subterranean formation, the isolation device having one or more engagement surfaces engaging at at least one location within the wellbore, providing a fluid flow through the wellbore and a fluid flow path formed by an inner bore of a base and an inner bore of an elastomeric element of the isolation device, and collapsing, at a predetermined volumetric flow rate through the inner bore of the elastomeric element, the inner bore of the elastomeric element reducing the inner diameter of the elastomeric element, wherein the predetermined volumetric flowrate causes a pressure drop within the inner bore of the elastomeric element.
  • Statement 15 The method of Statement 14, further comprising deploying the one or more engagement surfaces of the isolation device.
  • Statement 16 The method of Statement 14 or Statement 15, further comprising dissolving the collapsed elastomeric element by introduction of a second fluid flow.
  • Statement 17 The method of any one of Statements 14-16, wherein dissolving the collapsed elastomeric element provides restores the fluid flow path through the isolation device.
  • Statement 18 The method of any one of Statements 14-17, wherein the collapsed elastomeric element prevents fluid flow into the base.
  • Statement 19 The method of any one of Statements 14-18, wherein the collapsed elastomeric element substantially prevents fluid flow into the base.
  • Statement 20 The method of any one of Statements 14-19, wherein the isolation device further comprises a plurality of inserts disposed around an inner circumference of the inner bore of the elastomeric element, the plurality of inserts substantially parallel to a longitudinal axis of the inner bore in an uncollapsed state and substantially perpendicular to the longitudinal axis of the inner bore in a collapsed state.

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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)
  • Physical Or Chemical Processes And Apparatus (AREA)

Abstract

Cette invention concerne un dispositif d'Isolation comprenant une base dans laquelle est formé un alésage interne. L'alésage interne a un diamètre interne et s'étend le long d'un axe longitudinal de la base et une surface externe de la base a une ou plusieurs surfaces de mise en prise disposées sur celle-ci. Un élément élastomère est couplé à la base et a un alésage interne formé à l'intérieur de celui-ci. L'alésage interne de l'élément élastomère a un diamètre interne sensiblement identique au diamètre interne de l'alésage interne de la base. Un écoulement de fluide traversant l'alésage interne de l'élément élastomère et l'alésage interne de la base à un débit prédéfini tasse l'alésage interne de l'élément élastomère de sorte à réduire le diamètre interne de l'élément élastomère, bloquant ainsi l'écoulement à travers celui-ci.
PCT/US2018/016458 2018-02-01 2018-02-01 Joint d'étanchéité pliable WO2019152039A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/US2018/016458 WO2019152039A1 (fr) 2018-02-01 2018-02-01 Joint d'étanchéité pliable

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2018/016458 WO2019152039A1 (fr) 2018-02-01 2018-02-01 Joint d'étanchéité pliable

Publications (1)

Publication Number Publication Date
WO2019152039A1 true WO2019152039A1 (fr) 2019-08-08

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Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040007829A1 (en) * 2001-09-07 2004-01-15 Ross Colby M. Downhole seal assembly and method for use of same
US20060219415A1 (en) * 2005-03-30 2006-10-05 Xu Zheng R Packer cups for use inside a wellbore
US20160376869A1 (en) * 2015-06-23 2016-12-29 Weatherford Technology Holdings, Llc Self-Removing Plug for Pressure Isolation in Tubing of Well
US20170260825A1 (en) * 2015-09-22 2017-09-14 Halliburton Energy Services, Inc. Wellbore isolation device with slip assembly
WO2017190255A1 (fr) * 2016-05-06 2017-11-09 Steelhaus Technologies Inc. Bouchon de fracturation hydraulique

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040007829A1 (en) * 2001-09-07 2004-01-15 Ross Colby M. Downhole seal assembly and method for use of same
US20060219415A1 (en) * 2005-03-30 2006-10-05 Xu Zheng R Packer cups for use inside a wellbore
US20160376869A1 (en) * 2015-06-23 2016-12-29 Weatherford Technology Holdings, Llc Self-Removing Plug for Pressure Isolation in Tubing of Well
US20170260825A1 (en) * 2015-09-22 2017-09-14 Halliburton Energy Services, Inc. Wellbore isolation device with slip assembly
WO2017190255A1 (fr) * 2016-05-06 2017-11-09 Steelhaus Technologies Inc. Bouchon de fracturation hydraulique

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