WO2014004433A2 - Mécanisme de verrouillage pour outils de fond - Google Patents

Mécanisme de verrouillage pour outils de fond Download PDF

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Publication number
WO2014004433A2
WO2014004433A2 PCT/US2013/047491 US2013047491W WO2014004433A2 WO 2014004433 A2 WO2014004433 A2 WO 2014004433A2 US 2013047491 W US2013047491 W US 2013047491W WO 2014004433 A2 WO2014004433 A2 WO 2014004433A2
Authority
WO
WIPO (PCT)
Prior art keywords
cone
teeth
mandrel
downhole tool
slip
Prior art date
Application number
PCT/US2013/047491
Other languages
English (en)
Other versions
WO2014004433A3 (fr
Inventor
William M. Roberts
Original Assignee
Team Oil Tools, Lp
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 Team Oil Tools, Lp filed Critical Team Oil Tools, Lp
Publication of WO2014004433A2 publication Critical patent/WO2014004433A2/fr
Publication of WO2014004433A3 publication Critical patent/WO2014004433A3/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
    • 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
    • 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
    • E21B33/1216—Anti-extrusion means, e.g. means to prevent cold flow of rubber packing
    • 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

Definitions

  • Embodiments disclosed herein relate to apparatuses and methods used in locking do vnhole tools. More specifically, embodiments disclosed herein relate to apparatuses and methods used in locking packers, bridge plugs, and frac plugs. More specifically still, embodiments disclosed herein relate to apparatuses and methods used in locking packers, bridge plugs, and frac plugs to decrease the loss of energy during pack-off.
  • downhoie tools are used to isolate sections of weflbores.
  • examples of such tools include packers, bridge plugs, and frac plugs.
  • a packer, bridge plug, or frac plug is lowered into the wellbore to a predetermined depth.
  • the downhoie tool reaches the predetermined depth, the tool is actuated, which causes one or more sealing elements to radially expand within the wellbore, thereby isolating a portion of the well below the downhoie tool from a portion of the well above the downhoie tool.
  • lock rings designed to retain pack-off energy in the downhoie tool.
  • the lock ring has a double set of threads, where one is a fine pitch and the second is a coarse pitch.
  • the lock ring is pushed into engagement with the mating fine pitch thread, one of several scenarios may occur that results in a loss of pack-off energy.
  • the fine tooth of the female part may not completely pass the fine tooth of the male part, and thus will not bite properly.
  • the female part may then slip back one pitch, or a portion of a pitch, before biting into the male thread.
  • This longitudinal stroke is referred to in the industry as "bounce' '' and translates to a loss of pack-off energy stored in the element.
  • multiple lock rings have been used in the same housing in an attempt to decrease the loss of pack-off energy.
  • the fine thread of one lock ring will not be at the same place as the fine thread of a second lock ring, thereby effectively splitting the thread and decreasing bounce.
  • the presently claimed subject matter is directed to a downhoie tool comprising: a mandrel; a sealing element disposed around the mandrel; a cone disposed below the sealing element, the cone having a plurality of teeth on the inner diameter of the cone; a slip disposed below the cone; and a bottom sub disposed below the slip.
  • the presentl claimed subject matter is directed to a method of locking a downhoie tool, the method comprising; moving a cone of the downhoie tool; collapsing the cone under a slip of the downhoie tool; engaging a plurality of teeth on an inner diameter of the cone with an outer diameter of the mandrel; and expanding radially a sealing element.
  • the presently claimed subject matter is directed to a method of locking a dow'nhole tool, the method comprising: moving a cone of the downhoie tool; collapsing the cone under a slip of the downhoie tool; engaging a plurality of teeth on an inner diameter of the cone with a second plurality of teeth on an outer diameter of the mandrel; and expanding radially a sealing element.
  • Figure 1 is a cross-sectional side view of a downhole tool according to embodiments of the present disclosure
  • Figure 2 is a cross-sectional side view of a downhole tool in an embodiment alternative to that of Figure 1 ,
  • Figure 3 - Figure 4 are a plan side and cross-sectional view, respectively, of a mandrel according to the embodiment shown in Figure I.
  • Figure 5 is a cross-sectional view of a mandrel according to embodiments of the present di closure.
  • Figure 6- Figure 7 are cross-sectional views of cones according to embodiments of the present disclosure as may be used in implementing, for example, the downhole tools of Figure 1 - Figure 2.
  • Figure 8- Figure 9 are cross-sectional views of a lock ring retainer and a lock ring, respectively, as may be used to implement the downhole tools in embodiments shown in Figure 1 .
  • Figure 10 is a side view of a slip according to embodiments of the present disclosure
  • Figure 11 is a cross-sectional view of a slip according to embodiments of the present disclosure.
  • FIG. 1 is a cross-sectional view of a downhole tool 100.
  • downhole tool 100 is a frac plug, which is a tool designed to provide isolation between sections of a wellbore during multistage stimulation treatments.
  • Downhole tool 100 includes a mandrel 105.
  • Mandrel 105 may be formed from various metals, such as aluminum, stainless steel, other metal alloys, or in certain embodiments, from various composites, such as fiberglass with epoxy resins.
  • Mandrel 105 has a central flow bore 1 10, through which fluids may flow after treatment.
  • a lock ring retainer 1 15 is disposed around the upper end 120 of mandrel 1 05.
  • the lock ring retainer 1 15 is configured to retain lock ring 125, which is disposed between lock ring retainer 1 15 and mandrel 105. Lock ring retainer 1 15 is threaded along the inner diameter to engage corresponding threads of lock ring 125.
  • Downhole tool 100 further includes a sealing element 130, which is disposed axially below lock ring 125 on mandrel 105, Sealing element 130 is configured to radially expand, thereby isolating two areas of a well.
  • the sealing element may be formed from various high- pressure/high-temperature elastomerie materials.
  • a sealing element retainer 135 is disposed on mandrel between lock ring 1.25 and sealing element 130. The sealing element retainer 135 is configured to hold sealing element 130 in place on mandrel 105,
  • Downhole tool 100 also includes a cone 140 disposed on mandrel 105 axially below sealing element 130.
  • Cone 140 includes a plurality of teeth 145 machined along the inner diameter of the cone.
  • the plurality of teeth 145 may include a fine pitch buttress thread form.
  • the thread pitch may be approximately l /16 Lii of an inch. In such a fine pitch buttress thread form, approximately 16 threads may be machined per inch.
  • the plurality of teeth 145 of cone 140 are configured to engage a second plurality of teeth 150 machined onto the outer diameter of mandrel 105.
  • the second plurality of teeth 150 of mandrel 105 may also include a fine pitch buttress thread forms, such as a thread as described above.
  • Axially above cone 140 and belo sealing element 130, a triangle ring 136 and a backup ring 137 may be disposed,
  • Triangle ring 136 may be formed from bakeiite and include one or more grooves 138, into which sealing element 130 m ⁇ ' he disposed.
  • the sealing element 130 and the triangle ring are bonded together.
  • triangle ring 136 is configured to collapse, thereby preventing extrusion of the sealing element 130.
  • a backup ring 137 is disposed axially below triangle ring 136.
  • Backup ring 137 may also be formed from bakelite, Backup ring 137 may include a plurality of notches (not shown) or castellations that are configured to engage a corresponding plurality of notches (not shown) or castellations of the triangle ring 136. Backup ring 137 may further include a second plurality of notches (not shown) or castellations that are configured to engage cone 140. During actuation, the backup ring 137 expands and locks into cone 140. The engagement of sealing element 130, triangle ring 136, backup ring 137, and cone 140 after actuation may enhance drill out operations of downhole tool 100.
  • Downhole tool 100 further includes one or more slips 155 disposed around mandrel 105 axially below cone 140.
  • slip or sltps 155 may include a cylindrical unibody slip.
  • slip 155 includes a tapered upper portion 160 that extends partially over cone 140.
  • the cone 140 slides under tapered portion 160.
  • the tapered portion 160 of slip 155 forces cone 140 into contact with mandrel 105,
  • the plurality of teeth 145 of cone 140 engage the second plurality of teeth 150 of mandrel 105.
  • the tapered portion 160 of slip 155 pushes cone 140 into contact with mandrel 105 and the cone 140 collapses inwardly. Because cone 140 collapses into contact with mandrel 105, and the plurality of teeth 150 of the cone 140 engage the second plurality of teeth 150 of mandrel 105, the driliabiiity of downhole tool 100 may be enhanced. Because the components are effectively locked together, the individual components will not slide down until a mill drills out the components.
  • a bottom sub 1 5 is disposed axially below slip 155.
  • Bottom sub 165 holds slip 155 in place and includes a threadable connection for attaching downhole tool 100 to other downhole tools, drill pipe, etc.
  • downhole tool 100 may further include a ball 170 located in central flow bore 1 10. Ball 170 may be used to seal the top of mandrel 105, while floating off mandrel 105, thereby not blocking central flow bore 1 10 when pressure from below is applied.
  • second plurality of teeth 150 may not be machined onto mandrel 105.
  • the plurality of teeth 145 of cone 140 may engage and btte into the mandrel 105, which is formed from a softer material.
  • the cone 140 moves into contact with upper portion 1 60 of slip 155, the cone 140 deflects or collapses inwardly, thereby mechanically securing the cone 140 to the mandrel 105, preventing loss of energy.
  • Such an embodiment may be used when no threads are cut into the mandrel 1 05, such as is common when non-metallic mandrels 105 are used.
  • additional slips could be used to further the pressure holding ability of the tool 100.
  • downhoie tool 200 is a bridge plug, which is a tool designed to provide isolation between sections of a wellbore during multistage stimulation treatments or to permanently seal a portion of a wellbore from production.
  • Downhoie tool 200 includes a mandrel 205.
  • Mandrel 205 may be formed from various metal alloys, such as stainless steel, or in certain embodiments, from various composites.
  • downhoie tool 200 has a first slip 210 disposed on an upper end 215 of mandrel 205, Slip 210 has a tapered portion 220 that is configured to extend over a first cone 225. Cone 225 is disposed axially below slip 210. Downhoie tooi 200 further includes a sealing element 230, disposed axially below cone 225. As described above with respect to downhoie tool 100, cone 225 includes a plurality of teeth 235 machined along the inner diameter of the cone. The plurality of teeth 235 may include a fine pitch buttress thread form. Such as the fine pitch buttress thread form described above.
  • the plurality of teeth 235 of cone 225 are configured to engage a second plurality of teeth 240 machined onto the outer diameter of mandrel 205.
  • the second plurality of teeth 240 of mandrel 205 may also include a fine pitch buttress thread form, such as that disclosed above.
  • the tapered portion 220 of slip 210 presses down on cone 225, thereby causing the plurality of teeth 235 of cone 225 to engage and bite into the second plurality of teeth 240 of mandrel 205.
  • the cone 225 is mechanically secured to the mandrel 205, thereby lessening the loss of pack-off energy due to bounce.
  • a sealing element 230 is disposed around mandrel 205.
  • the sealing element 230 may be formed from various high-pressure/liigh-temperat re materials, such as eiastomeric materials, and is configured to radially expand.
  • a second cone 250 is disposed on mandrel 205 axially below sealing element 230.
  • downhoie tooi 200 further includes a second slip 255 disposed axially below second cone 250.
  • Second cone 250 includes a plurality of teeth 260 machined along the inner diameter of the second cone 250.
  • the plurality of teeth 260 may include a line pitch buttress thread form, plurality of teeth 260 of second cone 250 are configured to engage a second plurality of teeth 265 machined onto the outer diameter of mandrel 205.
  • the second plurality of teeth 265 of mandrel 205 may also include a fine pitch buttress thread form, such as those described above.
  • a tapered portion 270 of second slip 255 presses down on second cone 250, thereby causing the plurality of teeth 260 of second cone 250 to engage and bite into the second plurality of teeth 265 of mandrel 205.
  • the second cone 250 is mechanically secured to the mandrel 205, thereby making the tool 100 more stable during drill up. Additionally, as the second cone 250 is secured to the mandrel 205, the mandrel may be prevented from falling out during the drill out process.
  • downhole tool 200 may also include one or more triangle rings 236 and 238 and/or backup rings 237 and 239.
  • a first triangle ring 236 may be disposed axially above sealing element 230 and a first backup ring 237 may be disposed axially above first triangle ring 236.
  • a second triangle ring 238 may be disposed axially below sealing element 230, with a second backup ring 239 disposed axially below second triangle ring 238.
  • the tnangle rings 236 and 238, as well as the backup rings 237 and 239 of downhole tool 200 may operate substantially the same as the triangle and backup rings discussed with respect to downhole tool 100 of Figure 1 .
  • a bottom sub 275 is disposed axially belo second slip 255.
  • Bottom sub 275 holds slip 255 in place and includes a threadable connection for attaching downhole tool 200 to other downhoie tools, such as, for example, additional bridge plugs and/or frac plugs.
  • mandrel 205 may not have teeth configured to engage cone 225 or second cone 250.
  • the plurality of teeth 235, 265 of cone 225 and second cone 250 may engage or bite directly into mandrel 205.
  • Such an embodiment may be used when no threads are cut into the mandrel 205, such as is common when non- metailic/composite mandrels 205 are used.
  • additional slips could be used to farther improve the pressure holding capability of the tool 200.
  • Mandrel 305 includes an upper end 310 that has a threadable connection 315, such as a pin, which is commonly used in downhole tools in the oilfield industry.
  • Mandrel 305 includes a central flow bore 320 having a restricted portion 325.
  • Restricted portion 325 may be used as a ball seat, In certain embodiments, a ball (not, shown) may be disposed on restricted portion 325 to control the flo of fluids through the central flow bore 320.
  • a ball (not, shown) may be disposed on restricted portion 325 to control the flo of fluids through the central flow bore 320.
  • restricted portion 325 may vary based on the requirements of the operation, thus, restricted portions 325 of varying size and geometry may be used.
  • Mandrel 305 further includes a plurality of teeth 330 machined along the outer diameter of the mandrel 305.
  • the plurality of teeth 330 may include a fine pitch buttress thread form, such as those discussed above.
  • the plurality of teeth 330 may be configured to engage one or more components of downhole tool 300, such as lock rings, which are described above in detail with respect to Figure 1 .
  • Mandrel 305 further includes a second plurality of teeth 335 machined along the outer diameter of mandrel 305 axially below the first plurality of teeth 330.
  • the second plurality of teeth 335 may include a fine pitch buttress thread form, such as those described above.
  • the second plurality of teeth 335 may be configured to engage a cone of a downhole tool 300 during actuation as described above with respect to Figure 1 and Figure 2.
  • a second plurality of teeth 335 may not be machined on the outer diameter of mandrel 305, in such an embodiment, a cone of a downhole tool 300 may bite directly into the mandrel 305.
  • mandrel 305 may be formed from various materials including metal alloys, such as stainless steel, or composite materials.
  • Mandrel 505 includes an upper end 510 that has a threadable connection 515, such as a pin, which is commonly used in downhole tools in the oilfield industry.
  • Mandrel 505 further includes a plurality of teeth 530 machined along the outer diameter of the mandrel 505,
  • the plurality of teeth 530 may include a fine pitch buttress thread form, such as those described above.
  • the plurality of teeth 530 may be configured to engage one or more components of downhole tool 500, such as an upper cone, described above with respect to Figure 2.
  • Mandrel 505 further includes a second plurality of teeth 535 machined along the outer diameter of mandrel 505 axiaily below the first plurality of teeth 530.
  • the second plurality of teeth 535 may include a fine pitch buttress thread form, such as those described above.
  • the second plurality of teeth 535 may be configured to engage a lower cone of a downhole tool 500 during actuation as described above with respect to Figure 2.
  • the first and second plurality of teeth 530, 535 may not be machined on the outer diameter of mandrel 505.
  • one or more cones of a downhole tool 500 may bite directly into the mandrel 505.
  • mandrel 505 may be formed from various materials including metal alloys, such as stainless steel, or composite materials.
  • cone 600 is the type of cone that may be used in a frae plug, as described with respect to Figure 1 , or as the lower cone in a downhole tool such as a bridge plug, as described with respect to Figure 2.
  • Cone 700 is representative of the type of cone that may be used as an upper cone in, for example, a bridge plug.
  • a bridge plug a downhole tool
  • cones may be used in various downhole applications in addition to frae plugs and bridge plugs.
  • either type of cone may be used in packers as well.
  • cone 600 includes a plurality of teeth 605 machined along the inner diameter of the cone 600,
  • the plurality of teeth 605 may include a fine pitch buttress thread form, such as those described above.
  • cone 600 may include a plurality of ramps 610, rather than constitute a single conical surface.
  • a plurality of teeth 605 may be machined along the inner diameter of each ramp 610,
  • the pluralit of teeth 605 may be machined to correspond to a plurality of teeth that are machined along an outer diame ter of mandrel of a downhole tool, as described above.
  • the plurality of teeth 605 may be machined along the inner diameter of cone 600 to engage directly with a mandrel of a downhole tool.
  • cone 700 also includes a plurality of teeth 705 machined along the inner diameter of the cone 700,
  • the plurality of teeth 705 may include a fine pitch buttress thread form, such as those described above.
  • cone 700 may include a plurality of ramps 710, rather than constitute a single conical surface.
  • a plurality of teeth 705 may be machined along the inner diameter of each ramp 710,
  • the plurality of teeth 705 may be machined to correspond to a plurality of teet that are machined along an outer diameter of a mandrel of a downhoie tool, as described above.
  • the plurality of teeth 705 may be machined along the inner diameter of cone 700 to engage directly with a mandrel of a downhoie tool
  • cones 600 the materials used to form cones 600,
  • cones 600, 700 may vary.
  • cones 600, 700 may be formed from metals and metal alloys, such as aluminum or stainless steel.
  • Figure 8 and Figure 9 are cross-sectional views of a lock ring retainer 800 and a lock ring 900, respectively, such as may be used to implement the downhoie tools disclosed above.
  • Figure 8 illustrates a lock ring retainer 800, which is configured to hold a lock ring 900 in place.
  • Lock ring retainer 800 includes a plurality of teeth 805 along the inner diameter of the lock ring retainer 800.
  • the plurality of teeth 805 is configured to engage a plurality of teeth 905 along the outer diameter of the lock ring 900.
  • the lock ring 900 is screwed into lock ring retainer 800, and the assembly is slid into place along a mandrel of a downhoie tool, as described in detail above.
  • lock ring 900 further includes a plurality of teeth 910 along the inner diameter of the lock ring 900.
  • the plurality of teeth 910 along the inner diameter of the lock ring 900 may include a fine pitch buttress thread form, such as those described above.
  • the plurality of teeth along the inner diameter of the lock ring 900 is configured to engage a corresponding set of teeth disposed along the outer diameter of a mandrel of a downhoie tool.
  • Lock ring retainer 800 and lock ring 900 may be formed from various metals and metal alloys, such as, for example, cast iron or stainless steel. Those of ordinary skill in the art will appreciate that the specific materials used to form lock ring retainer 800 and lock ring 900 may vary according to operational considerations.
  • slip 1000 such as may be used to implement the downhoie tools disclosed above.
  • slip 1000 includes a tapered portion 1005 that is configured to contact a cone of a downhoie tool, as described above.
  • the angle of tapered portion 1005 may vary depending on the specific requirements of an operation. For example taper angles that range between 10° and 45°, or in a particular embodiment a taper angle of about 15°, may be used.
  • Slip 1000 may be fonned from various materials such as metals and metal alloys, for example, aluminum or stainless steel.
  • the outer diameter of the slip 1000 may include a non-slip surface that may be coated in, for example, a carbide material.
  • Downhole tools according to the disclosure provided above may be actuated in a variety of ways. For example, hydraulic and mechanical actuators such as are known in the art may be used in order to set, or radially expand, the sealing elements of frae plugs, bridge plugs, packers, and the like. While the specific actuation mechanisms are known in the art, methods for setting and holding downhole tools in place, according to embodiments of the present di closure, are described in detail below.
  • the cone of the downhole tool is moved downward.
  • the cone may then collapse under a slip, which causes the plurality of teeth on the cone to engage and bite into the outer diameter of the mandrel.
  • a sealmg element radially expands.
  • the teeth of the cone may then secure the sealing element in an expanded condition, thereby isolating sections of a wellbore.
  • a second cone having a second plurality of teeth may also collapse under a slip, The teeth of the second cone may also engage or bite into the mandrel, thereby securing the sealing element in an expanded condition from both sides of the sealing element.
  • a downhole tool having a cone including a plurality of teeth that are configured to engage a set of corresponding teeth on the outer diameter of a mandrel is rim in hole.
  • the cone is then moved, causing the cone to collapse under a slip.
  • the plurality of teeth of the cone engages the plurality of teeth on the outer diameter of the mandrel.
  • the sealing element radially expands and the teeth of the cone engaging the teeth of the mandrel hold the sealing element in an expanded condition.
  • the engagement between the plurality of teeth and the cone may further hold the mandrel in place during drill out, thereby preventing the mandrel from falling downhole.
  • a second cone having a second plurality of teeth may also collapse under a slip.
  • the teeth of the second cone may also engage or bite into a second set of teeth disposed on the outer diameter of the mandrel, thereby securing the sealing element in an expanded condition from both sides of the sealing element.
  • Various embodiments of the present disclosure may provide frac plugs, bridge plugs, packers, and the like, which increase a tools pressure-holding capability across a sealing element.
  • Conventional downhole tools employ the interaction of one coarse and one fine threaded component, which results in bounce and a loss in pack-off energy, as described above.
  • Embodiments of the present disclosure collapse the cone under a slip, thereby causing the cone to engage or bite onto corresponding mandrel threads or directly onto the mandrel surface. By collapsing the cone to engage the mandrel, pack-off energy loss due to bounce is reduced.
  • fine pitch threads instead of course threads as are typically used, the lateral movement caused by slack between the coarse threads is decreased, thereby increasing the pack-off energy.

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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)

Abstract

L'invention concerne des procédés et des appareils servant à verrouiller des outils de fond comme le verrouillage de garnitures d'étanchéité, de bouchons provisoires, et de bouchons de fracturation permettant de réduire la perte d'énergie au cours de l'opération d'étanchéification.
PCT/US2013/047491 2012-06-25 2013-06-25 Mécanisme de verrouillage pour outils de fond WO2014004433A2 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US201261663737P 2012-06-25 2012-06-25
US61/663,737 2012-06-25
US13/585,654 2012-08-14
US13/585,654 US20130341049A1 (en) 2012-06-25 2012-08-14 Lock mechanism for downhole tools

Publications (2)

Publication Number Publication Date
WO2014004433A2 true WO2014004433A2 (fr) 2014-01-03
WO2014004433A3 WO2014004433A3 (fr) 2015-07-09

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Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9771768B2 (en) * 2014-04-15 2017-09-26 Baker Hughes Incorporated Slip release assembly with cone undermining feature
US9677373B2 (en) 2014-10-31 2017-06-13 Team Oil Tools, Lp Downhole tool with anti-extrusion device
WO2019023413A1 (fr) * 2017-07-26 2019-01-31 Schlumberger Technology Corporation Déflecteur de fracturation
WO2019071024A1 (fr) * 2017-10-06 2019-04-11 G&H Diversified Manufacturing Lp Systèmes et des procédés d'étanchéisation d'un puits de forage
WO2022093756A1 (fr) * 2020-10-30 2022-05-05 Vertice Oil Tools Procédés et systèmes pour bouchon de fracturation
WO2024107417A1 (fr) * 2022-11-15 2024-05-23 Schlumberger Technology Corporation Système d'appui extensible pour bouchons de fracturation composites

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2598340A (en) * 1946-07-20 1952-05-27 Baker Oil Tools Inc Well packer lock device
US4397351A (en) * 1979-05-02 1983-08-09 The Dow Chemical Company Packer tool for use in a wellbore
US5163598A (en) * 1990-07-23 1992-11-17 Rudolph Peters Sternum stapling apparatus

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WO2014004433A3 (fr) 2015-07-09
US20130341049A1 (en) 2013-12-26

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