US20120006562A1 - Method and apparatus for a well employing the use of an activation ball - Google Patents

Method and apparatus for a well employing the use of an activation ball Download PDF

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Publication number
US20120006562A1
US20120006562A1 US13/180,029 US201113180029A US2012006562A1 US 20120006562 A1 US20120006562 A1 US 20120006562A1 US 201113180029 A US201113180029 A US 201113180029A US 2012006562 A1 US2012006562 A1 US 2012006562A1
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United States
Prior art keywords
ball
outer shell
seat
activation ball
activation
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.)
Abandoned
Application number
US13/180,029
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English (en)
Inventor
Tracy Speer
Piro Shkurti
John Chrysostom Wolf
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.)
Schlumberger Technology Corp
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Smith International Inc
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Filing date
Publication date
Application filed by Smith International Inc filed Critical Smith International Inc
Priority to US13/180,029 priority Critical patent/US20120006562A1/en
Assigned to SMITH INTERNATIONAL, INC. reassignment SMITH INTERNATIONAL, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SHKURTI, PIRO, SPEER, TRACY, WOLF, JOHN CHRYSOSTOM
Publication of US20120006562A1 publication Critical patent/US20120006562A1/en
Priority to US14/193,822 priority patent/US9404330B2/en
Assigned to SCHLUMBERGER TECHNOLOGY CORPORATION reassignment SCHLUMBERGER TECHNOLOGY CORPORATION ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SMITH INTERNATIONAL, INC.
Abandoned legal-status Critical Current

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    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E21B47/07—Temperature
    • 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
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons

Definitions

  • the invention generally relates to a method and apparatus for a well employing the use of an activation ball.
  • At least one perforating gun may be deployed into the well via a deployment mechanism, such as a wireline or a coiled tubing string. Shaped charges of the perforating gun(s) may then be fired when the gun(s) are appropriately positioned to form perforating tunnels into the surrounding formation and possibly perforate a casing of the well, if the well is cased. Additional operations may be performed in the well to increase the well's permeability, such as well stimulation operations and operations that involve hydraulic fracturing, acidizing, etc. During these operations, various downhole tools may be used, which require activation and/or deactivation. As non-limiting examples, these tools may include fracturing valves, expandable underreamers and liner hangers.
  • a system in an embodiment, includes a tubular string and an activation ball.
  • the tubular string is adapted to be deployed in the well, and the activation ball is adapted to be deployed in the tubular string to lodge in the seat.
  • the activation ball includes an outer shell that forms a spherical surface. The outer shell forms an enclosed volume therein, and the outer shell is formed from a metallic material.
  • a technique in another embodiment, includes deploying an activation ball in a downhole tubular string in a well.
  • the activation ball includes an outer shell that has an enclosed volume therein.
  • the outer shell includes a metallic material.
  • the technique includes communicating the ball through a passageway of the tubular string until the ball lodges in a seat of the string to form an obstruction (or fluid tight barrier), and the method includes using the obstruction to pressurize a region of the string.
  • FIG. 1 is a schematic diagram of a well according to an embodiment of the invention.
  • FIG. 2 is a flow diagram depicting a technique using an activation ball in a well according to an embodiment of the invention.
  • FIGS. 3A , 3 B and 3 C are cross-sectional views of an exemplary ball-activated tool of FIG. 1 according to an embodiment of the invention.
  • FIG. 4 is a cross-sectional view of an activation ball in accordance with embodiments disclosed herein.
  • FIG. 5 is a cross-sectional view of an activation ball in accordance with embodiments disclosed herein.
  • FIG. 6 is a cross-sectional view of an activation ball in accordance with embodiments disclosed herein.
  • FIG. 7A is a perspective view of an activation ball in accordance with embodiments disclosed herein.
  • FIGS. 7B-7D are cross-sectional views of a portion of an activation ball in accordance with embodiments disclosed herein.
  • FIG. 7E is a perspective view of a portion of an activation ball in accordance with embodiments disclosed herein.
  • FIG. 1 the well 10 includes a wellbore 12 that extends through one or more reservoir formations.
  • the wellbore 12 may be a deviated or horizontal wellbore, in accordance with other embodiments of the invention.
  • a tubular string 20 (a casing string, as a non-limiting example) extends into the wellbore 12 and includes packers 22 , which are radially expanded, or “set,” for purposes of forming corresponding annular seal(s) between the outer surface of the tubular string 20 and the wellbore wall.
  • the packers 22 when set form corresponding isolated zones 30 (zones 30 a , 30 b and 30 c being depicted in FIG. 1 , as non-limiting examples), in which may be performed various completion operations.
  • completion operations may be performed in one zone 30 at a time for purposes of performing such completion operations as fracturing, stimulation, acidizing, etc., depending on the particular implementation.
  • each activation ball 36 is constructed from an outer metallic shell and may be hollow, in accordance with some implementations.
  • the downhole tools are sleeve valves 33 .
  • each sleeve valve 33 is associated with a given zone 30 and includes a sleeve 34 that is operated via a deployed activation ball 36 to selectively open the sleeve 34 .
  • the sleeve valves 33 are all initially configured to be closed when installed in the well as part of the string 20 . Referring to FIG. 3A in conjunction with FIG.
  • the sleeve 34 when closed (as depicted in zones 30 b and 30 c ), the sleeve 34 covers radial ports 32 (formed in a housing 35 of the sleeve valve 33 , which is concentric with the tubular string 30 ) to block fluid communication between a central passageway 21 of the tubular string 20 and the annulus of the associated zone 30 .
  • the sleeve valve 33 has associated seals (o-rings, for example) for purposes of sealing off fluid communication through the radial ports 32 .
  • the sleeve valve 33 may be opened by deployment of a given activation ball 36 , as depicted in zone 30 a of FIG. 1 .
  • the activation ball 36 is deployed from the surface of the well and travels downhole (in the direction of arrow “A”) through the central passageway 21 to eventually lodge in a seat 38 of the sleeve 34 .
  • FIG. 3C in conjunction with FIG.
  • an obstruction or fluid tight barrier
  • fluid pressure to be increased (by operating fluid pumps at the surface of the well, for example) to exert a downward force on the sleeve 34 due to the pressure differential (i.e., a high pressure “P high ” above the ball 36 and a low pressure “P low ” below the ball 36 ) to cause the sleeve valve 33 to open and thereby allow fluid communication through the associated radial ports 32 .
  • the seats 38 of the sleeve valves 33 are graduated such that the inner diameters of the seats 38 become progressively smaller from the surface of the well toward the end, or toe, of the wellbore 12 . Due to the graduated openings, a series of varying diameter hollow activation balls 36 may be used to select and activate a given sleeve valve. In this manner, for the exemplary arrangement described herein, the smallest outer diameter activation ball 36 is first deployed into the central passageway 21 of the tubular string 20 for purposes of activating the lowest sleeve valve. For the example depicted in FIG.
  • the activation ball 36 that is used to activate the sleeve valve 33 for the zone 30 a is thereby smaller than the corresponding hollow activation ball 36 (not shown) that is used to activate the sleeve valve 33 for the zone 30 b .
  • an activation ball 36 (not shown) that is of a yet larger outer diameter may be used activate the sleeve valve 33 for the zone 30 c , and so forth.
  • FIG. 1 depicts a system of varying, fixed diameter seats 38
  • a tubular string may contain valve seats that are selectively placed in “object catching states” by hydraulic control lines, for example.
  • a tubular string includes at least one downhole tool that is activated by an activation ball, which is deployed through a passageway of the string.
  • Removing a given activation ball 36 from its seat 38 may be used to relieve the pressure differential resulting from the obstruction of the passageway 37 (see FIG. 3C ) through the sleeve valve 33 .
  • a seated actuation ball 36 may be removed from the seat 38 in a number of different ways.
  • the activation ball 36 may be made of a drillable material so that activation ball 36 may be milled to allow fluid flow through the central passageway 21 .
  • the valve seat 38 , the sleeve 34 or the activation ball 36 may be constructed from a deformable material, such that the activation ball 36 may be extruded through the seat 38 at a higher pressure, thereby opening the central passageway 21 .
  • the flow of fluid through the central passageway 21 may be reversed so that the activation ball 36 may be pushed upwardly through the central passageway 21 toward the surface of the well.
  • a reverse circulation flow may be established between the central passageway 21 and the annulus to retrieve the ball 36 to the surface of the well.
  • the activation ball 36 is non-destructably removed from the well so that both the activation ball 36 and the corresponding sleeve valve may be reused.
  • deformation of the activation ball 36 under impact loads, high pressure for high temperatures may conceivably prevent the activation ball 36 from properly sealing against the seat 38 , thereby preventing the effective buildup of a pressure differential.
  • the deformation of the activation ball 36 may cause the activation ball 36 to slide through the seat 38 and to become lodged in the sleeve 34 , such that it may be relatively challenging to remove the activation ball 36 .
  • the activation ball 36 may have the following specific physical properties. Specifically, the activation ball 36 may have a particular specific gravity so that the upward flowing fluid can remove the activation ball 36 from the seat 38 and carry it upward through central passageway 21 . While the specific gravity of the activation ball 36 may be a relatively important constraint, the activation ball 36 may also be able to withstand the impact of seating in the downhole tool, the building of a pressure differential across the activation ball 36 , and the high temperatures of a downhole environment. Failure of the activation ball 36 to maintain its shape and structure during use may lead to failure of the downhole tool.
  • deformation of the activation ball 36 under impact loads, high pressures, or high temperatures may prevent activation ball 36 from properly sealing against seat 38 , thereby preventing the effective build up of a pressure differential.
  • deformation of the activation ball 36 may cause the activation ball 36 to slide through the seat 38 and to become lodged in the sleeve 34 , such that conventional means of removing activation ball 112 may be ineffective.
  • traditional activation balls may be solid spheres, which are constructed from plastics, such as for example, polyetheretherketone, or fiber-reinforced plastics, such as, for example, fiber-reinforced phenolic. While a traditional activation ball may meet specific gravity requirements, inconsistency in material properties between batches may present challenges such that the activation balls may be overdesigned so that their strength ratings, pressure ratings and temperature ratings are conservative.
  • the activation ball 36 is constructed out of a metallic shell and as such, may be a hollow ball or sphere, which permits the activation ball 36 to have desired strength properties while being light enough to allow removal of the ball 36 from the well.
  • a technique 50 includes deploying (block 52 ) a shell-based activation ball, such as a hollow activation ball, into a tubular string in a well and allowing (block 54 ) the ball to lodge in a seat of the string.
  • the technique 50 includes using (block 56 ) an obstruction created by the activation ball lodging in the seat to increase fluid pressure in the tubular string and using (block 58 ) the increased fluid pressure to activate a downhole tool.
  • Hollow activation ball 200 includes an outer shell 202 having an enclosed hollow volume 204 .
  • Outer shell 202 may be formed from a first portion 206 and a second portion 208 which may be joined together using joining methods such as, for example, welding, friction stir welding, threading, adhering, pressure fitting, and/or mechanical fastening.
  • first and second portions 206 , 208 of outer shell 202 are joined using a weld 210 ; however, those of ordinary skill in the art will appreciate that any known method of joining two parts may be used.
  • outer shell 202 may be formed from a metallic material.
  • the metallic material may include a metallic alloy such as, for example, aluminum alloy and/or magnesium alloy. Aluminum alloys from the 6000 series and 7000 series may be used such as, for example, 6061 aluminum alloy or 7075 aluminum alloy.
  • a hollow activation ball 200 in accordance with the present disclosure may have a specific gravity less than 2.0.
  • the specific gravity of hollow activation ball 200 in accordance with embodiments disclosed herein is between about 1.00 and about 1.85.
  • hollow activation ball 300 Similar to hollow activation ball 200 ( FIG. 4 ), hollow activation ball 300 includes an outer shell 302 having an enclosed volume 304 . Outer shell 302 may be formed from a first portion 306 and a second portion 308 , joined together using threads 320 . One of ordinary skill in the art will appreciate that other joining or coupling methods may be used such as, for example, welding. Hollow activation ball 300 may further include a coating 322 disposed over an outer surface of outer shell 302 .
  • Coating 322 may be a corrosion resistant material such as, for example, polytetrafluoroethylene, perfluoroalkoxy copolymer resin, fluorinated ethylene propylene resin, ethylene tetrafluoroethylene, polyvinylidene fluoride, ceramic material, and/or an epoxy-based coating material.
  • coating 322 may include Fluorolon® 610-E, available from Southwest Impreglon of Houston, Tex.
  • Coating 322 may be between 0.001 and 0.005 inches thick, and may be applied by dipping outer shell 302 in the coating material, by spraying the coating material onto outer shell 302 , by rolling outer shell 302 through the coating material, or by any other known coating application method.
  • coating 322 may include a plating, an anodized layer, and/or a laser cladding.
  • the coating material and the thickness of coating 322 may be selected such that activation ball 300 has an overall specific gravity between about 1.00 and about 1.85.
  • the coating material may be chosen to provide activation ball 300 with improved properties such as, for example, improved corrosion resistance and/or improved abrasion resistance.
  • the coating material may be selected to prevent a reaction between the metallic material of outer shell 302 and downhole fluids such as drilling mud or produced fluid.
  • Hollow activation ball 400 includes an outer shell 402 having an enclosed volume 404 .
  • Outer shell 402 may include a first portion 406 and a second portion 408 joined using an interference fit 424 ; however, other joining methods such as welding, adhering, and threading may be used.
  • Enclosed volume 404 may include a fill material 426 to provide additional support to shell 402 under high impact loads, pressures, and temperatures.
  • fill material 426 may include at least one of a plastic, a thermoplastic, a foam, and a fiber reinforced phenolic.
  • Fill material 426 may be selected such that the overall specific gravity of activation ball 400 is between about 1.00 and about 1.85. Although activation ball 400 is not shown including a coating, a coating may be added similar to coating 322 shown on activation ball 300 ( FIG. 5 ).
  • hollow volume 404 may be filled with a gas such as, for example, nitrogen.
  • the gas may be pressurized to provide support within outer shell 402 which may allow activation ball 400 to maintain its spherical shape under high impact loads, pressures, and temperatures.
  • Hollow volume 404 may be filled with gas using an opening or port (not shown) disposed in outer shell 402 . After a desired amount of gas is pumped into hollow volume 404 and a desired internal pressure is reached, the port (not shown) may be sealed or capped to prevent gas from leaking out of activation ball 400 .
  • FIG. 7A a perspective view of a joined outer shell 502 including a first portion 506 and a second portion 508 in accordance with embodiments disclosed herein is shown.
  • FIG. 7B a side cross-sectional view of second portion 508 of outer shell 502 is shown. Only second portion 508 of outer shell 502 is shown for simplicity, and those of ordinary skill in the art will appreciate that the corresponding first portion 506 may be substantially the same as second portion 508 .
  • Outer shell 502 includes a hollow volume 504 , an inner surface 528 , and a support structure 530 disposed on the inner surface 528 .
  • Support structure 530 may include a reinforcing ring 532 as shown which may be coupled to inner surface 528 of second portion 508 of outer shell 502 . Although only one reinforcing ring 532 is shown, those of ordinary skill in the art will appreciate that multiple reinforcing rings may be used having any desired thickness, t, and any desired maximum width, w.
  • inner face 534 of reinforcing ring 532 is shown parallel to a central axis 536 of second portion 508 , inner face 534 may alternatively be angled relative to central axis 536 , or may be arced to correspond with the curve of inner surface 528 .
  • a side cross-sectional view of second portion 508 of outer shell 502 is shown having a second type of support structure 530 disposed therein.
  • Ribs 538 are shown disposed on inner surface 528 of second portion 508 .
  • Ribs 538 may take any shape or size, and may extend along inner surface 528 in any desired direction.
  • ribs 538 a , 538 b , and 538 c intersect each other at junction 540 ; however, a plurality of ribs 538 may be positioned within second portion 508 such that no contact between ribs 538 occurs.
  • spindles 542 may be used to help support outer shell 502 , thereby maintaining the shape of outer shell 502 under high pressures, impact loads, and temperatures.
  • a plurality of spindles 542 may extend radially outwardly from a center point 446 of an assembled activation ball 500 , and may contact inner surface 528 of second portion 508 at an intersection 544 . While specific examples of support structure configurations have been described, one of ordinary skill in the art will appreciate that other support structure configurations may be used without departing from the scope of embodiments disclosed herein.
  • Support structures 530 such as, for example, reinforcing rings 532 , ribs 538 , and spindles 542 , shown in FIGS. 7B-7D , may be formed from a plastic, metal, ceramic, and/or composite material. Specifically, metal support structures may be formed from cast iron or low grade steel. In certain embodiments, support structures 530 may be formed integrally with first or second portions 506 , 508 of outer shell 502 . Alternatively, support structures 530 may be formed separately and may be assembled within outer shell 502 using welding, brazing, adhering, mechanical fastening, and/or interference fitting. Those of ordinary skill in the art will appreciate that materials, designs, and dimensions of support structures 530 may be selected to provide increased strength to outer shell 502 while maintaining an overall specific gravity of activation ball 500 between about 1.00 and about 1.85.
  • FIG. 7E a perspective view of a first portion 506 of outer shell 502 of activation ball 500 is shown.
  • Support structure 530 is shown disposed in hollow volume 504 of first portion 506 .
  • the support structure 530 is an assembly of reinforcing rings 532 , ribs 538 , and a spindle 542 .
  • Those of ordinary skill in the art will appreciate that various configurations of reinforcing rings 532 , ribs 538 , and spindles 542 may be used to create a support structure 530 .
  • a support structure 530 as discussed above may be used in combination with a fill material injected into enclosed volume 504 .
  • enclosed volume 504 may also be used to house equipment such as, for example, sensors. Sensors configured to measure pressure, temperature, and/or depth may be disposed within enclosed volume 504 . Data collected by the sensors may be stored in a storage device enclosed within volume 504 , or the data may be relayed to the surface of the wellbore.
  • equipment such as, for example, receivers, transmitters, transceivers, and transponders, may be disposed within enclosed volume 504 and may send and/or receive signals to interact with downhole tools.
  • RFID radio frequency identification
  • equipment such as, for example, receivers, transmitters, transceivers, and transponders, may be disposed within enclosed volume 504 and may send and/or receive signals to interact with downhole tools.
  • RFID tags may be used as activation devices for triggering an electrical device in another downhole tool.
  • the RFID tags may activate a timer linked to the electrical device, which may lead to the performance of a desired task.
  • a frac valve may be opened by initiating a corresponding timer using RFID tags and/or magnets housed within an activation ball.
  • a magnet disposed within enclosed volume 504 may also be used to trigger and/or actuate downhole tools.
  • An activation ball in accordance with some embodiments may be manufactured by forming an outer shell out of a metallic material, wherein the outer shell includes an enclosed volume therein.
  • the outer shell may be formed from a magnesium alloy, an aluminum alloy, a steel alloy, or nickel-cobalt base alloy.
  • an aluminum alloy may be selected from 6000 series aluminum alloys or 7000 series aluminum alloys
  • a steel alloy may be selected from 4000 series steel alloys.
  • 4140 steel may be used.
  • a nickel-cobalt base alloy such as, for example MP35N® may also be used.
  • manufacturing the activation ball may further include filling the enclosed volume within the outer shell with a fill material such as, for example, plastic, thermoplastic, polyether ether ketone, fiber reinforced phenolic, foam, liquid, or gas.
  • a fill material such as, for example, plastic, thermoplastic, polyether ether ketone, fiber reinforced phenolic, foam, liquid, or gas.
  • the outer shell enclosed volume may be filled such that a pressure inside of the outer shell is greater than atmospheric pressure, thereby providing the activation ball with increased strength against impact loads and high pressures.
  • a rigid support structure may be provided within the enclosed volume of the outer shell.
  • reinforcing rings, ribs, and spindles may be used separately or in combination to form the support structure.
  • the support structure may be formed integrally with the outer shell by machining, casting, or sintering the outer shell.
  • the support structure may be formed as a separate component and may be later installed within the outer shell.
  • the support structure may be installed using welding, brazing, adhering, mechanical fastening, and/or pressure fitting.
  • the support structure may be designed such that, when assembled within the activation ball, pressure applied by the support structure to the inner surface of the outer shell is greater than atmospheric pressure.
  • embodiments disclosed herein provide for an activation ball having increased strength under impact loads, high pressures, and high temperatures, while having an overall specific gravity between about 1.00 and about 1.85.
  • Activation balls in accordance with the present disclosure may also have greater durability than activation balls formed from composite materials which degrade over time.
  • activation balls having a metal shell as disclosed herein may be more reliable due to the consistency of mechanical properties between different batches of metallic materials. Because of the consistency of mechanical properties of metallic materials, and because of their high strength, activation balls in accordance with the present invention can be designed to have less contact area between the activation ball and a corresponding bearing area. As such, activation balls disclosed herein may allow for an increased number of ball activated downhole tools to be used on a single drill string.
  • approximately twelve fracturing valves (such as the sleeve valves 33 ) may be used during a multi-stage fracturing process, whereas approximately eight fracturing valves may be used with traditional activation balls.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Earth Drilling (AREA)
  • Pens And Brushes (AREA)
  • Seats For Vehicles (AREA)
  • Taps Or Cocks (AREA)
  • Pivots And Pivotal Connections (AREA)
  • Pressure Welding/Diffusion-Bonding (AREA)
US13/180,029 2010-07-12 2011-07-11 Method and apparatus for a well employing the use of an activation ball Abandoned US20120006562A1 (en)

Priority Applications (2)

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US13/180,029 US20120006562A1 (en) 2010-07-12 2011-07-11 Method and apparatus for a well employing the use of an activation ball
US14/193,822 US9404330B2 (en) 2010-07-12 2014-02-28 Method and apparatus for a well employing the use of an activation ball

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US36354710P 2010-07-12 2010-07-12
US36426710P 2010-07-14 2010-07-14
US13/180,029 US20120006562A1 (en) 2010-07-12 2011-07-11 Method and apparatus for a well employing the use of an activation ball

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US14/193,822 Expired - Fee Related US9404330B2 (en) 2010-07-12 2014-02-28 Method and apparatus for a well employing the use of an activation ball

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CN (1) CN103080465A (zh)
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RU181716U1 (ru) * 2017-12-27 2018-07-26 Акционерное общество "ОКБ Зенит" АО "ОКБ Зенит" Муфта гидроразрыва пласта с растворимым седлом
US10472927B2 (en) 2015-12-21 2019-11-12 Vanguard Completions Ltd. Downhole drop plugs, downhole valves, frac tools, and related methods of use
US10738561B2 (en) 2015-12-25 2020-08-11 Kureha Corporation Stock shape for downhole tool component, downhole tool component, and downhole tool
US11015414B1 (en) * 2019-11-04 2021-05-25 Reservoir Group Inc Shearable tool activation device
US11702904B1 (en) 2022-09-19 2023-07-18 Lonestar Completion Tools, LLC Toe valve having integral valve body sub and sleeve

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US10907440B2 (en) * 2016-04-25 2021-02-02 Schlumberger Technology Corporation Wound composite core for molded components
US10479929B2 (en) * 2016-06-06 2019-11-19 Baker Hughes, A Ge Company, Llc Spherical high temperature high closure tolerant cashew nut shell liquid based proppant, methods of manufacture, and uses thereof
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US20140174728A1 (en) 2014-06-26
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CA2804868A1 (en) 2012-01-19
CN103080465A (zh) 2013-05-01
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WO2012009310A2 (en) 2012-01-19
WO2012009310A3 (en) 2012-05-03

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