US20090308588A1 - Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones - Google Patents

Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones Download PDF

Info

Publication number
US20090308588A1
US20090308588A1 US12/139,604 US13960408A US2009308588A1 US 20090308588 A1 US20090308588 A1 US 20090308588A1 US 13960408 A US13960408 A US 13960408A US 2009308588 A1 US2009308588 A1 US 2009308588A1
Authority
US
United States
Prior art keywords
sleeve
plurality
apparatus
disposed
tubing section
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
US12/139,604
Inventor
Matthew Howell
Gregory Vargus
Shawn Webb
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
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 US12/139,604 priority Critical patent/US20090308588A1/en
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: WEBB, SHAWN, VARGUS, GREGORY, HOWELL, MATTHEW
Publication of US20090308588A1 publication Critical patent/US20090308588A1/en
Application status is Abandoned legal-status Critical

Links

Images

Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10Valves arrangements in drilling fluid circulation systems
    • E21B21/103Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
    • E21B23/004Indexing systems for guiding relative movement between telescoping parts of downhole tools
    • E21B23/006"J-slot" systems, i.e. lug and slot indexing mechanisms
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25Methods for stimulating production
    • E21B43/26Methods for stimulating production by forming crevices or fractures

Abstract

A well bore servicing apparatus comprising an first sleeve slidably disposed in a tubing section, an second sleeve slidably disposed in the first sleeve, an indexing slot disposed on one of the outer sleeve and inner sleeve, and a control lug disposed on the other of the outer sleeve and the inner sleeve to communicate with the indexing slot, and an expandable seat disposed in the inner sleeve to receive a plurality of obturating members. A well bore servicing apparatus comprising a work string, a tubing section coupled to the work string, a plurality of sleeve assemblies disposed in the tubing section, and a plurality of seats for receiving an obturating member, one seat disposed in each of the sleeve assemblies, wherein the plurality of seats are substantially the same size.

Description

    BACKGROUND
  • Hydrocarbon-producing wells often are stimulated by hydraulic fracturing operations, wherein a fracturing fluid may be introduced into a portion of a subterranean formation penetrated by a well bore at a hydraulic pressure sufficient to create or enhance at least one fracture therein. Stimulating or treating the well in such ways increases hydrocarbon production from the well. The fracturing equipment may be included in a completion assembly used in the overall production process.
  • In some wells, it may be desirable to individually and selectively create multiple fractures along a well bore at a distance apart from each other, creating multiple “pay zones.” The multiple fractures should have adequate conductivity, so that the greatest possible quantity of hydrocarbons in an oil and gas reservoir can be drained/produced into the well bore. When stimulating a formation from a well bore, or completing the well bore, especially those well bores that are highly deviated or horizontal, it may be advantageous to create multiple pay zones with a series of actuatable sleeve assemblies disposed in a downhole tubular. The actuatable sleeve assemblies are also referred to as stimulation sleeves, or casing or tubing windows.
  • A stimulation sleeve may include a section of tubing having holes or apertures pre-formed in the tubing, and a sliding sleeve movable relative to the tubing section. The sliding sleeve also includes apertures alignable with the apertures in the tubing section. Upon actuation of the stimulation sleeve, such as by ball drop or other obturating member interference, the sliding sleeve moves and the sliding sleeve apertures are aligned with the tubing section apertures. This exposes the reservoir to the interior of the tubing string, and vice versa. The flow path created between the reservoir and the tubing string through the stimulation sleeve can be used for fracturing or production operations. The apertures in the tubing section may include jet forming nozzles to provide a fluid jet into the formation, causing tunnels and fractures therein.
  • While the stimulation sleeve just described is one embodiment, other embodiments of actuatable sleeve assemblies may be used in series along a downhole tubular to communicate with multiple pay zones during fracturing or completion operations. To selectively actuate each successive sleeve assembly, differently sized balls or other obturating members are released into the tubing string. Each sleeve assembly includes a ball seat having a different inner diameter. The sleeve assembly having the largest ball seat is disposed furthest uphole, or closest to the surface of the well, while each successive sleeve assembly below the initial assembly includes an incrementally decreasing ball seat diameter. Thus, smaller balls may be released into the tubing string to pass through the larger diameter ball seats and selectively actuate the lower sleeve assemblies. Subsequently, incrementally larger sized balls are released into the tubing string to actuate each successive sleeve assembly in ascending order up the well.
  • Such a tubing assembly with successive diameter sleeves tends to restrict the inner diameter of the flow bore through the tubing string with the lower, smaller diameter sleeves, thereby also restricting the flow rates and treatment pressures that can be achieved with the tubing assembly. Further, a successive diameter system limits the number of sleeve assemblies that can be disposed in the tubing string because the flow bore of the tubing string has a limited number of incremental diameters between the maximum diameter of the flow bore and the minimum diameter that can still achieve treatment pressure flow rates. To achieve desirable results in the aforementioned treatment and production processes, maintaining an inner diameter of the flow bore for flow rates and treatment pressures, and increasing the number of pay zones is needed. The present disclosure includes embodiments for maintaining an increased or substantially uniform inner diameter of a treatment or completion assembly having stimulation sleeves, and for increasing the number of stimulation sleeves included in the treatment or completion assembly.
  • SUMMARY
  • Disclosed herein is a well bore servicing apparatus comprising an first sleeve slidably disposed in a tubing section, an second sleeve slidably disposed in the first sleeve, an indexing slot disposed on one of the outer sleeve and inner sleeve, and a control lug disposed on the other of the outer sleeve and the inner sleeve to communicate with the indexing slot, and an expandable seat disposed in the inner sleeve to receive a plurality of obturating members.
  • Also disclosed herein is a well bore servicing apparatus comprising a work string, a tubing section coupled to the work string, a plurality of sleeve assemblies disposed in the tubing section, and a plurality of seats for receiving an obturating member, one seat disposed in each of the sleeve assemblies, wherein the plurality of seats are substantially the same size.
  • Further disclosed herein is a method of servicing a well bore comprising disposing a tubing section in the well bore, positioning the tubing section adjacent a plurality of formation zones, passing a first obturating member through a first moveable sleeve, catching the first obturating member in a second moveable sleeve to actuate a sleeve assembly adjacent a first formation zone, and catching a second obturating member in the first moveable sleeve to actuate a second sleeve assembly adjacent a second formation zone, wherein the first and second obturating members are substantially the same size.
  • Further disclosed herein is a method of servicing a well bore comprising placing a tubing section in the well bore via a work string, and actuating a plurality of sleeve assemblies in the tubing section with same-size obturating members.
  • Further disclosed herein is a method of servicing a well bore comprising disposing a tubing section having a plurality of actuatable sleeve assemblies in the well bore, providing a series of obturating members having substantially the same size to actuate the sleeve assemblies, and successively actuating the sleeve assemblies with the same-size obturating member to successively treat a plurality of formation zones.
  • BRIEF DESCRIPTION OF THE DRAWINGS
  • For a more detailed description of the embodiments, reference will now be made to the following accompanying drawings:
  • FIG. 1 is a schematic, partial cross-section view of a fluid treatment and completion apparatus in an operating environment;
  • FIGS. 2A and 2B are cross-section views of a stimulation sleeve in a closed position;
  • FIGS. 3A and 3B are cross-section views of the stimulation sleeve of FIGS. 2A and 2B in an open position;
  • FIG. 4A is a partial cross-section view of a hydrojetting casing window assembly;
  • FIG. 4B is a partial cross-section view of the casing window assembly of FIG. 4A in a shifted open position;
  • FIG. 5 is a partial cross-section view of a well completion assembly including embodiments of FIGS. 4A and 4B;
  • FIG. 6A is a partial cross-section view of an indexing assembly;
  • FIG. 6B is a profile view of an indexing slot of the indexing assembly of FIG. 6A;
  • FIG. 7 is a partial cross-section view of an alternative embodiment of an indexing assembly in an initial position;
  • FIG. 8 is a partial cross-section view of the indexing assembly of FIG. 7 receiving a dropped ball;
  • FIG. 9 is a partial cross-section view of the indexing assembly of FIG. 7 in a release position;
  • FIG. 10 is a partial cross-section view of the indexing assembly of FIG. 7 in a return position; and
  • FIG. 11 is a profile view of an indexing slot of the indexing assembly of FIG. 7.
  • DETAILED DESCRIPTION
  • In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present invention is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the invention, and is not intended to limit the invention to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce desired results.
  • Unless otherwise specified, any use of any form of the terms “connect”, “engage”, “couple”, “attach”, or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . ”. Reference to up or down will be made for purposes of description with “up”, “upper”, “upwardly” or “upstream” meaning toward the surface of the well and with “down”, “lower”, “downwardly” or “downstream” meaning toward the terminal end of the well, regardless of the well bore orientation. The term “zone” or “pay zone” as used herein refers to separate parts of the wellbore designated for treatment or production and may refer to an entire hydrocarbon formation or separate portions of a single formation such as horizontally and/or vertically spaced portions of the same formation. The term “seat” as used herein may be referred to as a ball seat, but it is understood that seat may also refer to any type of catching or stopping device for an obturating member or other member sent through a work string fluid passage that comes to rest against a restriction in the passage. The various characteristics mentioned above, as well as other features and characteristics described in more detail below, will be readily apparent to those skilled in the art upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings.
  • Disclosed herein are several embodiments of a well bore servicing apparatus including multiple sleeve assemblies disposed in a work string that are selectively actuatable to expose different formation zones to an inner fluid passage of the work string at different times. The sleeve assemblies may be sequentially actuated to expose the inner fluid passage to the formation zones such that they are treated at different times in a certain order. The sleeve assemblies may also include an inner indexing assembly allowing the sleeve assemblies to be actuated without loss of the inner diameter of the fluid passage in the work string, and without using multiple sizes of dropped balls. The indexing assembly may include an inner sleeve that is moveable and lockable relative to the moveable sleeve of the sleeve assemblies. The indexing assembly can be manipulated to allow a pre-determined number of obturating members to pass through a seat in the indexing assembly before a selected obturating members is caught in the seat and the indexing assembly is moved to actuate the sleeve assembly. In essence, the indexing assembly is configured to count the number of passing obturating members before actuation. The number of counted obturating members can be adjusted. The counting can be achieved with a J-slot or indexing slot communicating between the inner sleeve of the indexing assembly and the moveable or outer sleeve of the sleeve assembly, and an expandable seat for the obturating member.
  • Referring to FIG. 1, a schematic representation of an exemplary operating environment for a fluid treatment or completion apparatus 100 is shown. The apparatus 100 is an exemplary embodiment, and various other embodiments of the apparatus 100 consistent with the teachings herein are included. As depicted, a drilling rig 110 is positioned on the earth's surface 105 and extends over and around a well bore 120 that penetrates a subterranean formation F for the purpose of recovering hydrocarbons. The well bore 120 may be drilled into the subterranean formation F using conventional (or future) drilling techniques. The well bore 120 may extend substantially vertically away from the surface 105 over a vertical portion 122, or may deviate at any angle from the surface 105 over a deviated or horizontal portion 124. In some instances, all or portions of the well bore 120 may be vertical, deviated, horizontal, and/or curved.
  • At least a portion of the vertical well bore 122 may be lined with casing 125 that may be cemented 127 into position against the formation F in a conventional manner. Alternatively, the horizontal portion 124 may be cased and cemented also, or the operating environment for the apparatus 100 includes an uncased well bore 120. The drilling rig 110 includes a derrick 112 with a rig floor 114 through which a tubing or work string 118 extends downwardly from the drilling rig 110 into the well bore 120. The tubing string 118 suspends a representative downhole apparatus 100 to a predetermined depth within the well bore 120 to perform a specific operation, such as perforating a casing, expanding a fluid path therethrough, fracturing the formation F, producing the formation F, or other completion operation. The tubing string 18 may also be known as the entire conveyance above and coupled to the apparatus 100. The drilling rig 110 is conventional and therefore includes a motor driven winch and other associated equipment for extending the tubing string 118 into the well bore 120 to position the apparatus 100 at the desired depth.
  • While the exemplary operating environment depicted in FIG. 1 refers to a stationary drilling rig 110 for lowering and setting the apparatus 100 within a land-based well bore 120, one of ordinary skill in the art will readily appreciate that mobile workover rigs, well servicing units, such as coiled tubing units, and the like, could also be used to lower the apparatus 100 into the well bore 120. It should be understood that the apparatus 100 may also be used in other operational environments, such as within an offshore well bore.
  • In one embodiment, the apparatus 100 comprises an upper end having a liner hanger 132 such as, for example, a Halliburton VersaFlex® liner hanger, a lower end 136, and a tubing section 134 extending therebetween. The lower end 136 may have a float shoe 138 and a float collar 140 of a type known in the art connected therein, and other tubing conveyed devices 142, 144 connected therein. The horizontal well bore 124 and the tubing section 134 define an annulus 146 therebetween. The tubing section 134 includes an interior 148 that defines a flow passage 150 therethrough. In the embodiment shown, an inner string 152 is disposed in tubing section 134 and extends therethrough so that a lower end 154 thereof extends into and is received in a polished bore receptacle 144. The inner string 152 may be used to carry cement if the completion operation requires cement. Alternatively, cement may not be needed and the tubing section 134 may be without the inner string 152 such that the flow passage 150 is the main flowbore through the apparatus 100. A plurality of actuatable sleeve assemblies or stimulation sleeves 158 are connected in the tubing section 134. The stimulation sleeves 158 may be, for example, ball drop activated, Delta Stim® Sleeves available from Halliburton Energy Services, Inc.
  • Referring now to FIGS. 2A and 2B, the stimulation sleeve 158 comprises an outer housing 160 with an opening sleeve 162 detachably connected therein. The opening sleeve 162 has a lower end 163. After becoming detached from the housing 160, the opening sleeve 162 is slidable or movable in the housing 160 as explained in more detail hereinbelow. The outer housing 160 has an upper end 164 and a lower end 166, both of which are adapted to be directly connected or threaded into a tubing section such that the outer housing 160 makes up a part of the tubing section 134. The opening sleeve 162 is initially connected to the outer housing 160 with a snap ring 168 which extends into a groove 170 defined on an inner surface 172 of the outer housing 160. In addition, shear pins extending through the outer housing 160 and into the sleeve 162 may be utilized to detachably connect the sleeve 162 to the outer housing 160. Guide pins 176 may be threaded or otherwise attached to the sleeve 162 and may be received in axial grooves or axial slots 178 in the housing 160. The guide pins 176 are slidable in the axial slots 178, which will prevent relative rotation between the sleeve 162 and the outer housing 160. The sleeve 162 has a plurality of sleeve or door ports 180 therethrough. The outer housing 160 has a plurality of housing ports 182 defined therein. In the position shown in FIGS. 2A and 2B, the sleeve ports 180 are misaligned from the housing ports 182 such that the stimulation sleeve 158 is in a closed position. The sleeve 162 has a seat ring 184 operably associated therewith and is connected therein at or near the lower end 163. The seat ring 184 has a central opening 186 defining a diameter 188 therethrough, and has a seat surface 190 for engaging an obturating member to be dropped through the tubing string.
  • To move the opening sleeve 162 from the closed position to an open position, an obturating member 194, such as a closing ball shown in FIG. 3B, is dropped through the tubing string 118 so that it will engage the seat 190 on the seat ring 184. Although shown as a closing ball, the obturating member 194 may be other closing devices such as plugs and darts that will engage the seat 190 and prevent flow therethrough. Pressure is increased to overcome the holding force applied by the snap ring 168 and the shear pins, thereby moving the opening sleeve 162 to the position shown in FIGS. 3A and 3B in which the sleeve ports 180 and the casing ports 182 are aligned to allow for the passage of fluids therethrough.
  • Referring now to FIGS. 4A and 4B, an exemplary casing window assembly 300 is shown and can be adapted for use as an alternative embodiment of the stimulation sleeve 158. As used herein, the term “casing window” refers to a section of casing configured to enable selective access to one or more specified zones of an adjacent subterranean formation. A casing window has a window that may be selectively opened and closed by an operator, for example, movable sleeve member 304. The casing window assembly 300 can have numerous configurations and can employ a variety of mechanisms to selectively access one or more specified zones of an adjacent subterranean formation.
  • The casing window 300 includes a substantially cylindrical outer casing 302 that receives a movable sleeve member 304. The outer casing 302 includes one or more apertures 306 to allow the communication of a fluid from the interior of the outer casing 302 into an adjacent subterranean formation. The apertures 306 are configured such that fluid jet forming nozzles 308 may be coupled thereto. In some embodiments, the fluid jet forming nozzles 308 may be threadably inserted into the apertures 306. The fluid jet forming nozzles 308 may be isolated from the annulus 310 (formed between the outer casing 302 and the movable sleeve member 304) by coupling seals or pressure barriers 312 to the outer casing 302.
  • The movable sleeve member 304 includes one or more apertures 314 configured such that, as shown in FIG. 4A, the apertures 314 may be selectively misaligned with the apertures 306 so as to prevent the communication of a fluid from the interior of the movable sleeve member 304 into an adjacent subterranean formation. The movable sleeve member 304 may be shifted axially, rotatably, or by a combination thereof such that, as shown in FIG. 4B, the apertures 314 selectively align with the apertures 306 so as to allow the communication of a fluid from the interior of the movable sleeve member 304 into an adjacent subterranean formation. The movable sleeve member 304 may be shifted via the use of a ball drop mechanism.
  • Referring now to FIG. 5, an exemplary well completion assembly 400 includes open casing window 402 and closed casing window 404 formed in a tubing section or conduit 406. Alternatively, the well completion assembly 400 may be selectively configured such that the casing window 404 is open and the casing window 402 is closed, such that the casing windows 402 and 404 are both open, or such the that casing windows 402 and 404 are both closed.
  • A fluid 408 may be pumped down the conduit 406 and communicated through the fluid jet forming nozzles 410 of the open casing window 402 against the surface of the well bore 120 in the zone 414 of the subterranean formation F. The fluid 408 would not be communicated through the fluid jet forming nozzles 418 of the closed casing window 404, thereby isolating the zone 420 of the subterranean formation F from any well completion operations being conducted through the open casing window 402 involving the zone 414. The fluid 408 may include any of the embodiments disclosed elsewhere herein.
  • In one embodiment, the fluid 408 is pumped through the fluid jet forming nozzles 410 at a velocity sufficient for fluid jets 422 to form perforation tunnels 424. In one embodiment, after the perforation tunnels 424 are formed, the fluid 408 is pumped into the conduit 406 and through the fluid jet forming nozzles 410 at a pressure sufficient to form cracks or fractures 426 along the perforation tunnels 424.
  • Referring back to FIG. 1, a plurality of the sleeve assemblies 158 are included in the tubing section 134 of the treatment and completion apparatus 100. The sleeve assemblies 158 are positioned adjacent the selected zones to be treated, such as the plurality of selected zones 80, 82, 84, 86, 88 and 90 that may be treated and produced with the methods and apparatus described herein. After work string 118 having apparatus 100 is lowered into well bore 120, and the apparatus 100 is appropriately set, a first ball or other obturating member may be dropped into the work string 118. The ball seats in the lowermost sleeve assembly 158 to actuate, as described herein, the sleeve assembly and establish a fluid path to the formation zone 90. Then, a treatment fluid, such as an acidizing fluid or a fracturing fluid, may be flowed through the work string 118, the tubing section 134, the fluid path in the sleeve assembly, and toward the zone 90. In some embodiments, a high pressure fluid is communicated through the sleeve assembly fluid path to provide a hydrojet stream to the zone 90. As used herein, high pressure, for example, is generally greater than about 1,000 p.s.i., alternatively greater than about 3,500 p.s.i., alternatively greater than about 10,000 p.s.i., and alternatively greater than about 15,000 p.s.i. Once the selected zone 90 has been treated, a second ball is dropped to engage the sleeve seat in the next sleeve assembly 158 in ascending order, adjacent the zone 88. When the ball is seated, fluid flow is blocked to the lower sleeve assembly and fluid pressure will increase to actuate the new sleeve assembly. The zone 88 can then be treated. This procedure may be followed to selectively and successively actuate the sleeve assemblies 158 in ascending order, and service any and/or all of the zones 80, 82, 84, 86, 88, 90. Typically, the center opening 186 (FIGS. 2B and 3B) in each of the sleeve assemblies 158 is of a diameter 188 such that the balls 194 may pass therethrough to engage the seat sleeves 184 in sleeve assemblies therebelow. Therefore, the seat sleeve diameter 188 will be gradually and incrementally larger from the lowermost seat sleeve through the final seat sleeve in the uppermost sleeve assembly.
  • Referring now to FIG. 6A, an assembly is shown that is adaptable to be used with the various sleeve assembly embodiments described herein. A sliding sleeve sub or indexing assembly 500 includes an outer sleeve 502 and an inner sleeve member 504 disposed therein. For reference purposes, the outer sleeve 502 is analogous to the opening sleeve 162 of FIGS. 2A-3B. The inner sleeve member 504 includes an upper end 506, a lower end 508 and a flow bore 505 therethrough. The upper end 506 includes an increased diameter portion 510 having an indexing slot or J-slot pattern 512 that receives a control lug 514 disposed on an inner surface of the outer sleeve 502. The interaction between the lug 514 and the indexing slot 512, as will be described in more detail hereinbelow, is the primary mode of communication between the outer sleeve 502 and the inner sleeve member 504. The lower end 508 includes a projection 522 and a series of collet fingers 524. Disposed between an outer sleeve shoulder 520 and an inner sleeve shoulder 518 is a biasing spring 516. The inner surface of the outer sleeve 502 also includes a recessed portion 526.
  • Referring next to FIG. 6B, the indexing slot 512 is shown in an unwrapped or flattened profile view. The indexing slot 512 may also be referred to as a continuous J-slot or a control groove. The indexing slot 512 includes a plurality of biased, reset or stop positions 530, 532, 534 and a plurality of release positions 536, 538 for the lug 514. The slot 512 also includes a final engagement or actuation position 540. The indexing slot 512 is disposed about the upper portion of the tube forming the inner sleeve 504. The indexing slot 512, in some embodiments, may be a solid member, such as a metal sheet, having a slot or groove formed therein. The indexing slot may be shaped to extend around a cylindrical member, as is shown in FIG. 6A. In some embodiments described, the lug 514 includes a circular shape from a top view of the lug. The lug may include other shapes, such as an oval or elliptical shape. Furthermore, other control slot operating members may interact with the indexing slot 512 to provide the relationships described herein.
  • In operation, the indexing assembly 500 is assembled as shown in FIG. 6A, with the inner sleeve 504 biased upward by the spring 516 such that the collet fingers 524 and the projection 526 are above the recess 526. The control lug 514 is initially disposed in one of the stop positions 530, 532, 534 and limits the upward movement of the inner sleeve 504. Preferably, the initial position of the lug 514 is the furthest from the final position 540 to allow the most number of cycles through the indexing slot, though the initial position can be selected to pre-determine the number of cycles through the indexing slot and thus the number of balls that pass through the inner sleeve 504. A first ball, such as that shown in FIG. 8, passes through the flow bore 505 and arrives at a seat 542 in the lower end 508. A pressure buildup above the ball causes the inner sleeve to overcome the biasing force of the spring 516 and move downward, as similarly depicted in FIG. 9. As the inner sleeve 504 moves downward, the projection 526 slides into the recess 526 and the collet fingers expand into the recess, as shown in FIG. 9. Simultaneously, the inner sleeve 504 and the indexing slot 512 are guided about the lug 514, which is stationary on the outer sleeve 502, such that the lug moves from initial slot 530 to the release position 536. The ball is then allowed to pass into the flow bore 544 below the inner sleeve 504. After the ball passes, the pressure on the inner sleeve 504 is relieved the biasing spring moves the inner sleeve 504 upward. At the same time, the inner sleeve 504 and the indexing slot 512 are guided about the lug 514 such that the lug is now placed in the stop position 532.
  • The lug 514 is guided through any number of sets of stop and release positions until the lug 514 reaches the final position 540. In the final position 540, vertical movement of the inner sleeve 504 is restricted such that the pressure buildup in the inner sleeve 504 is transferred to the outer sleeve 502 and the overall sleeve assembly is actuated as described herein. For example, when the lug 514 is in the final position 540, the ball seat 542 acts analogously to the ball seat 190 in the seat ring 184 of FIGS. 2B and 3B. The outer sleeve 502 then moves similarly to the sleeve 162 of the sleeve assembly 158. Thus, the indexing assembly 500 can replace the seat ring 184 arrangement of the sleeve assembly 158 while providing increased flexibility for inner sleeve 504 movement and ball pass-through while the overall sleeve assembly remains unactuated.
  • The indexing assembly 500 can be pre-set to count any number of ball pass-throughs. For example, if an indexing assembly 500 is placed in the second lowermost position, wherein another assembly is below it, and it is known that one ball must pass through the indexing assembly 500, then the assembly is adjusted accordingly. In one embodiment, the indexing slot 512 is simply manufactured to have the initial position 532, the release position 538, the reset position 534 and the final position 540. Therefore, one cycle from position 532 to position 538 to position 534 allows one ball to pass through the indexing assembly 500 before the final position 540 is reached and the sleeve assembly is actuated. In another embodiment, the indexing slot 512 is manufactured to have any number of stop and release positions, and the indexing assembly 500 is assembled such that the initial position of the lug 514 is in the second to last stop position, or position 532.
  • A plurality of indexing assemblies 500 may be disposed in a tubing section in series, such as in the series of stimulation sleeves 158 shown in FIG. 1. The series of indexing assemblies 500 will include ball seats 542 all having the same unexpanded diameter to receive the same size balls. For example, the diameter of unexpanded ball seat 542 in FIG. 6A may be 2.75 inches, while the balls may be 3 inches in diameter. Each assembly 500 can be pre-set to catch and release a different number of 3-inch balls such that the series of assemblies will actuate a series of sleeve assemblies 158 or 300 to successively expose the work and tubing strings to different zones of interest 80, 82, 84, 86, 88, 90 while passing the same size ball through the plurality of indexing and sleeve assemblies. In alternative embodiments, a first series of indexing and sleeve assemblies is adapted to receive a first size ball while a second series of indexing and sleeve assemblies is adapted to receive a second size ball, thereby further expanding the total number of sleeve assemblies that can be actuated in the well. Alternatively, a third series may be added and so on. For example, a bottom series of four indexing and sleeve assemblies may be adapted to successively actuate upon receiving a series of four 2-inch balls. A next series of four indexing and sleeve assemblies may be adapted to successively actuate upon receiving a series of four 2.25-inch balls. A third series disposed uphole of the second series may be adapted to successively actuate upon receiving a series of four 2.5-inch balls. In this embodiment, a total of twelve indexing and sleeve assemblies can be actuated to expose zones of interest. Further added series will add indexing and sleeve assemblies in increments of four, or however many balls the indexing assembly is designed to catch and release as designed herein.
  • In some embodiments, the collet fingers 524 are dipped in stiffening or hardening agents for added strength or resistance. In one embodiment, the collet fingers 524 are at rest in the contracted position shown in FIG. 6A, and the force of the ball passing through the collet fingers causes them to expand into the recess 526. These collet fingers 524 may also be referred to as “normally closed” or “normally contracted.” In another embodiment, the collet fingers are formed and strengthened to normally be in the expanded position shown in FIG. 9, such that the collet fingers are forced together as shown in FIG. 6A and allowed to spread automatically when placed in the position of FIG. 9. These collet fingers 524 may also be referred to as “normally open” or “normally expanded.” In other embodiments, the collet fingers 524 are dipped in an elastomer or other compressible material such that when the collet fingers are contracted as shown in FIG. 6A, the elastomer coating on one finger will compress against the elastomer coating on an adjacent finger to close the spaces between the fingers and provide a sealed ball seat 542.
  • In an alternative embodiment, the control lug 514 is disposed on the outer surface of the inner sleeve 504 and the indexing slot 512 is disposed on the inner surface of the outer sleeve 502, i.e., they are switched. In this embodiment, the profile view of FIG. 6B would be flipped such that the stop positions would be on top and the release positions on bottom, and the final position would be on top.
  • With reference to FIG. 7-11, a further embodiment includes an indexing assembly 600 having similar components as the assembly 500, such as an outer sleeve 602 and an inner sleeve 604. However, assembly 600 further includes an upper recessed portion 627. In operation, a ball 670 enters the flow bore 605 and arrives at the seat 642 as shown in FIG. 8. The pressure buildup above the ball 670 overcomes the biasing force provided by the spring 616 and moves the inner sleeve 604 downward. As shown in FIG. 9, the collet fingers 624 expand into the recess 626, either by the force provided by the ball 670 or by the normally open disposition of the fingers, and the ball 670 passes through the fingers 624 and the seat 642 to travel downward 650 through the flow bore 644. The biasing force of the spring 616 then returns the inner sleeve 604 to the middle position shown in FIG. 8, readying the indexing assembly 600 to receive another ball 670. During this process, the lug 614 and indexing slot 612 operate as previously described.
  • However, at some point, it may be desirable to return a ball or balls to the surface of the well. A ball may be forced upward along a return path 660 in the flow bore 644 by fluid pressure or other means, and the indexing assembly 600 is adapted to work in reverse wherein the upper recess 627 receives the expanding collet fingers 624 as shown in FIG. 10. As shown in FIG. 11, a reserve position 648 is provided in the indexing slot 612 to accommodate the upward movement of the inner sleeve 604 as shown in FIG. 10. For example, the indexing assembly 600 may be assembled such that the lug 614 is given an initial position 630. Ball engagement on the seat 642 causes the inner sleeve 604 to move downward, and thus the lug 614 moves upward in the indexing slot 612 to the first release position 636. The ball 670 passes through the collet fingers 624, thereby relieving the pressure in the inner sleeve 604. The biasing spring 616 returns the inner sleeve 604 and the indexing slot 612 to a position placing the lug 614 in a first reset position 632. Another ball 670 may be cycled through the inner sleeve 604, placing the lug 614 in a second release position 638, then in a second reset position 634 which is also the catch position. Position 634 is a catch position because the lug 614 is not allowed to move upward to a position similar to positions 636, 638, thereby preventing downward movement of the inner sleeve 604 and release of the ball 670. The pressure buildup above the ball 670 is transferred to the outer sleeve 602, which is the slidable sleeve of a larger sleeve assembly as described herein. However, unlike indexing slot 512, the slot 612 provides an additional position 648 that allows upward movement of the inner sleeve 604 to accommodate the return of the ball 670 shown in FIG. 10. Once the balls have been returned as described, the well can be produced unobstructed and without intervention to drill out the ball-engaged indexing and sleeve assemblies. In other embodiments, the balls or other obturating members are breakable or dissolvable to remove them from the inner flow bores.
  • In other embodiments, the total number of reset and release positions is adjusted to increase or decrease the number of balls the indexing assemblies are designed to catch and release. For example, the indexing slots 512, 612 are designed to release two balls before catching the third ball. However, additional sets of reset and release positions can be added to increase the number of balls that are released before the final ball is caught.
  • The number of zones, indexing assemblies and sleeve assemblies shown herein is not intended to be limiting and is shown only for exemplary purposes. Any desired number of zones may be treated or produced. The plurality of zones will be treated sequentially upwardly. For example, when a sleeve assembly is moved to align openings, dissolving fluid and then treatment fluid may be flowed into the zone to be treated, and the next zone desired to be treated is done so in the manner described. Once the selected zones have been treated, the balls can be flowed back to the surface, as previously described, or drilled out and the well can be produced through each of the selected zones in a manner known in the art.
  • In alternative embodiments, the mechanical assemblies 500, 600 may be similar with the exception of the indexing slots 512, 612. The indexing slots 512, 612 act as counter mechanisms to count the number of balls that pass through the assemblies. While the other elements and components of the assemblies remain similar, the indexing slots 512, 612 can be replaced by alternative counting mechanisms. The electro-mechanical sliding sleeve assemblies or subs may incorporate electronics, and the counter or reader in the sleeve assembly could be actuated by magnets, RFID tags or other “smarts” in the balls. For example, the sliding sleeve sub can be placed in the open or release position as the normal position. An electronic reader in the inner sleeve electronically counts the magnets or tags in the balls as they pass through the expandable seat, and upon counting a pre-determined number of balls, the sleeve is actuated to move to the closed position. The inner sleeve can be moved to the closed position by a motor or other drive means known in the art. Thus, while the sliding inner sleeve and collet finger arrangement provides the same uniformity of flow bore diameter and ball size, the counting of the balls is accomplished by electronic or electrical means rather than mechanical means, and the inner sleeve is driven not by fluid pressure but by a drive means such as an electro-mechanical actuator. In alternative embodiments, the electro-mechanical actuator can be replaced by pressurized chambers adjacent the inner sliding sleeve. An unpressurized chamber is adjacent and communicates with the inner sleeve, and is separate from a pressurized chamber by a burst disc. Upon an actuation command from the electronic counter, the disc can be burst to expose the unpressurized chamber and thus the inner sliding sleeve to fluid pressure to move the sleeve to its closed position as described herein.
  • In addition to servicing, treatment and completion systems, the embodiments of the indexing or sliding sleeve assemblies can be used in other systems. For example, a system including a series open-hole packer can incorporate the indexing or sliding sleeve assemblies for successive actuation of the packers.
  • While specific embodiments have been shown and described, modifications can be made by one skilled in the art without departing from the spirit or teaching of this invention. The embodiments as described are exemplary only and are not limiting. Many variations and modifications are possible and are within the scope of the invention. Accordingly, the scope of protection is not limited to the embodiments described, but is only limited by the claims that follow, the scope of which shall include all equivalents of the subject matter of the claims.

Claims (26)

1. A well bore servicing apparatus comprising:
an first sleeve slidably disposed in a tubing section;
an second sleeve slidably disposed in the first sleeve;
an indexing slot disposed on one of the outer sleeve and inner sleeve, and a control lug disposed on the other of the outer sleeve and the inner sleeve to communicate with the indexing slot; and
an expandable seat disposed in the inner sleeve to receive a plurality of obturating members.
2. The apparatus of claim 1 wherein the lug is disposed within the indexing slot to guide relative movement between the first sleeve and the second sleeve.
3. The apparatus of claim 1 wherein the plurality of obturating members are the same size.
4. The apparatus of claim 2 wherein the indexing slot includes a plurality of stop positions and a plurality of release positions for the lug.
5. The apparatus of claim 4 wherein the plurality of stop positions correspond to a contracted position of the expandable seat and the plurality of release positions correspond to an expanded position of the expandable seat for passing through the plurality of obturating members.
6. The apparatus of claim 1 wherein the expandable seat includes a plurality of collet fingers.
7. The apparatus of claim 6 wherein the collet fingers are normally open.
8. The apparatus of claim 6 wherein the collet fingers are normally closed.
9. The apparatus of claim 6 wherein the collet fingers are dipped or coated.
10. A well bore servicing apparatus comprising:
a work string;
a tubing section coupled to the work string;
a plurality of sleeve assemblies disposed in the tubing section; and
a plurality of seats for receiving an obturating member, one seat disposed in each of the sleeve assemblies;
wherein the plurality of seats are substantially the same size.
11. The apparatus of claim 10 wherein the seats are operable to receive a series of obturating members having substantially the same size.
12. The apparatus of claim 11 wherein the series of obturating members are operable to successively actuate the plurality of sleeve assemblies adjacent multiple formation zones.
13. The apparatus of claim 10 wherein the tubing section having the plurality of sleeve assemblies includes a substantially uniform minimum flow bore diameter over its axial length.
14. The apparatus of claim 10 wherein all sleeve assemblies disposed in the tubing section are actuatable by the same size obturating member.
15. The apparatus of claim 10 further comprising an indexing slot and a corresponding control lug disposed in each of the sleeve assemblies.
16. The apparatus of claim 15 wherein the control lugs communicate with positions in the indexing slot to count the number of obturating members that pass through an inner sleeve assembly.
17. The apparatus of claim 10 further including an electronic counter operable to detect the obturating member.
18. The apparatus of claim 10 further including a drive means coupled to an indexing assembly in each of the sleeve assemblies.
19. The apparatus of claim 11 further comprising an electronic tag in each of the obturating members, an electronic counter in each of an inner sleeve assembly disposed in each of the sleeve assemblies, and an electro-mechanical actuator coupled to the inner sleeves.
20. A method of servicing a well bore comprising:
disposing a tubing section in the well bore;
positioning the tubing section adjacent a plurality of formation zones;
passing a first obturating member through a first moveable sleeve;
catching the first obturating member in a second moveable sleeve to actuate a sleeve assembly adjacent a first formation zone; and
catching a second obturating member in the first moveable sleeve to actuate a second sleeve assembly adjacent a second formation zone;
wherein the first and second obturating members are substantially the same size.
21. The method of claim 20 further comprising passing a plurality of same-size obturating members through the first moveable sleeve and actuating a plurality of sleeve assemblies below the first moveable sleeve with the same-size obturating members.
22. A method of servicing a well bore comprising:
placing a tubing section in the well bore via a work string; and
actuating a plurality of sleeve assemblies in the tubing section with same-size obturating members.
23. The method of claim 22 further comprising pumping a treatment fluid through a flow bore in the tubing section having a substantially uniform inner diameter.
24. The method of claim 22 further comprising maintaining constant flow rates over the axial length of the tubing section having the plurality of sleeve assemblies.
25. The method of claim 22 further comprising maintaining constant treatment pressures over the axial length of the tubing section having the plurality of sleeve assemblies.
26. A method of servicing a well bore comprising:
disposing a tubing section having a plurality of actuatable sleeve assemblies in the well bore;
providing a series of obturating members having substantially the same size to actuate the sleeve assemblies; and
successively actuating the sleeve assemblies with the same-size obturating member to successively treat a plurality of formation zones.
US12/139,604 2008-06-16 2008-06-16 Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones Abandoned US20090308588A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US12/139,604 US20090308588A1 (en) 2008-06-16 2008-06-16 Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US12/139,604 US20090308588A1 (en) 2008-06-16 2008-06-16 Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones
CA 2668129 CA2668129A1 (en) 2008-06-16 2009-06-03 Method and apparatus for exposing a servicing apparatus to multiple formation zones

Publications (1)

Publication Number Publication Date
US20090308588A1 true US20090308588A1 (en) 2009-12-17

Family

ID=41413704

Family Applications (1)

Application Number Title Priority Date Filing Date
US12/139,604 Abandoned US20090308588A1 (en) 2008-06-16 2008-06-16 Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones

Country Status (2)

Country Link
US (1) US20090308588A1 (en)
CA (1) CA2668129A1 (en)

Cited By (144)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100044041A1 (en) * 2008-08-22 2010-02-25 Halliburton Energy Services, Inc. High rate stimulation method for deep, large bore completions
US20100212886A1 (en) * 2009-02-24 2010-08-26 Hall David R Downhole Tool Actuation having a Seat with a Fluid By-Pass
WO2010148494A1 (en) * 2009-06-22 2010-12-29 Trican Well Service Ltd. Apparatus and method for stimulating subterranean formations
US20110067888A1 (en) * 2009-09-22 2011-03-24 Baker Hughes Incorporated Plug counter and method
US20110174484A1 (en) * 2010-01-15 2011-07-21 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US20110180270A1 (en) * 2010-01-27 2011-07-28 Schlumberger Technology Corporation Position retention mechanism for maintaining a counter mechanism in an activated position
US20110192607A1 (en) * 2010-02-08 2011-08-11 Raymond Hofman Downhole Tool With Expandable Seat
US20110198100A1 (en) * 2010-02-12 2011-08-18 I-Tec As Expandable Ball Seat
US20110198096A1 (en) * 2010-02-15 2011-08-18 Tejas Research And Engineering, Lp Unlimited Downhole Fracture Zone System
CN102182438A (en) * 2011-06-03 2011-09-14 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 Layered fracturing technology for variable-length graded sliding sleeve
US20110232915A1 (en) * 2010-03-23 2011-09-29 Baker Hughes Incorporated System, assembly and method for port control
US20110240301A1 (en) * 2010-04-02 2011-10-06 Robison Clark E Indexing Sleeve for Single-Trip, Multi-Stage Fracing
US20110240311A1 (en) * 2010-04-02 2011-10-06 Weatherford/Lamb, Inc. Indexing Sleeve for Single-Trip, Multi-Stage Fracing
US20120031615A1 (en) * 2010-08-03 2012-02-09 Thru Tubing Solutions, Inc. Abrasive perforator with fluid bypass
US20120048556A1 (en) * 2010-08-24 2012-03-01 Baker Hughes Incorporated Plug counter, fracing system and method
WO2011117602A3 (en) * 2010-03-26 2012-06-21 Petrowell Limited Mechanical counter
WO2011117601A3 (en) * 2010-03-26 2012-06-21 Petrowell Limited Downhole actuating apparatus
US20120199353A1 (en) * 2011-02-07 2012-08-09 Brent Daniel Fermaniuk Wellbore injection system
US20120205121A1 (en) * 2011-02-10 2012-08-16 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US8251154B2 (en) 2009-08-04 2012-08-28 Baker Hughes Incorporated Tubular system with selectively engagable sleeves and method
WO2012118889A2 (en) * 2011-03-02 2012-09-07 Team Oil Tools, Lp Multi-actuating seat and drop element
US8261761B2 (en) 2009-05-07 2012-09-11 Baker Hughes Incorporated Selectively movable seat arrangement and method
US20120227973A1 (en) * 2010-06-29 2012-09-13 Baker Hughes Incorporated Tool with Multisize Segmented Ring Seat
US8272443B2 (en) 2009-11-12 2012-09-25 Halliburton Energy Services Inc. Downhole progressive pressurization actuated tool and method of using the same
US8272445B2 (en) 2009-07-15 2012-09-25 Baker Hughes Incorporated Tubular valve system and method
US8291980B2 (en) 2009-08-13 2012-10-23 Baker Hughes Incorporated Tubular valving system and method
US8291988B2 (en) 2009-08-10 2012-10-23 Baker Hughes Incorporated Tubular actuator, system and method
US20120266994A1 (en) * 2011-04-19 2012-10-25 Baker Hughes Incorporated Tubular actuating system and method
US8316951B2 (en) 2009-09-25 2012-11-27 Baker Hughes Incorporated Tubular actuator and method
US8327931B2 (en) 2009-12-08 2012-12-11 Baker Hughes Incorporated Multi-component disappearing tripping ball and method for making the same
US20130025876A1 (en) * 2011-07-28 2013-01-31 Baker Hughes Incorporated Selective hydraulic fracturing tool and method thereof
US20130048290A1 (en) * 2011-08-29 2013-02-28 Halliburton Energy Services, Inc. Injection of fluid into selected ones of multiple zones with well tools selectively responsive to magnetic patterns
US8397823B2 (en) 2009-08-10 2013-03-19 Baker Hughes Incorporated Tubular actuator, system and method
CN102979495A (en) * 2012-12-28 2013-03-20 中国石油集团渤海钻探工程有限公司 Multi-cluster current limiting fracturing string of open hole horizontal well and fracturing method thereof
US8418769B2 (en) 2009-09-25 2013-04-16 Baker Hughes Incorporated Tubular actuator and method
US8424610B2 (en) 2010-03-05 2013-04-23 Baker Hughes Incorporated Flow control arrangement and method
US8425651B2 (en) 2010-07-30 2013-04-23 Baker Hughes Incorporated Nanomatrix metal composite
US8439116B2 (en) 2009-07-24 2013-05-14 Halliburton Energy Services, Inc. Method for inducing fracture complexity in hydraulically fractured horizontal well completions
WO2013109394A1 (en) * 2012-01-19 2013-07-25 Baker Hughes Incorporated Counter device for selectively catching plugs
US20130248201A1 (en) * 2012-03-20 2013-09-26 Team Oil Tools, Lp Method and apparatus for actuating a downhole tool
US8573295B2 (en) 2010-11-16 2013-11-05 Baker Hughes Incorporated Plug and method of unplugging a seat
US20130299199A1 (en) * 2012-05-09 2013-11-14 Utex Industries, Inc. Seat assembly with counter for isolating fracture zones in a well
AU2012200380B2 (en) * 2010-04-02 2013-11-21 Weatherford Technology Holdings, Llc Indexing sleeve for single-trip, multi-stage fracing
CN103477026A (en) * 2011-02-07 2013-12-25 克雷麦克控股有限公司 Wellbore injection system
WO2013054099A3 (en) * 2011-10-14 2013-12-27 Nov Downhole Eurasia Limited Downhole tool actuator
US8631876B2 (en) 2011-04-28 2014-01-21 Baker Hughes Incorporated Method of making and using a functionally gradient composite tool
US8631872B2 (en) 2009-09-24 2014-01-21 Halliburton Energy Services, Inc. Complex fracturing using a straddle packer in a horizontal wellbore
WO2014020335A2 (en) * 2012-07-31 2014-02-06 Petrowell Limited Downhole apparatus and method
US8646531B2 (en) 2009-10-29 2014-02-11 Baker Hughes Incorporated Tubular actuator, system and method
US8662178B2 (en) 2011-09-29 2014-03-04 Halliburton Energy Services, Inc. Responsively activated wellbore stimulation assemblies and methods of using the same
US8662162B2 (en) 2011-02-03 2014-03-04 Baker Hughes Incorporated Segmented collapsible ball seat allowing ball recovery
US8668016B2 (en) 2009-08-11 2014-03-11 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US8695710B2 (en) 2011-02-10 2014-04-15 Halliburton Energy Services, Inc. Method for individually servicing a plurality of zones of a subterranean formation
US20140102797A1 (en) * 2012-10-12 2014-04-17 Smith International, Inc. Selective deployment of underreamers and stabilizers
US8757265B1 (en) 2013-03-12 2014-06-24 EirCan Downhole Technologies, LLC Frac valve
US8757274B2 (en) 2011-07-01 2014-06-24 Halliburton Energy Services, Inc. Well tool actuator and isolation valve for use in drilling operations
US8776884B2 (en) 2010-08-09 2014-07-15 Baker Hughes Incorporated Formation treatment system and method
US8863853B1 (en) 2013-06-28 2014-10-21 Team Oil Tools Lp Linearly indexing well bore tool
US20140318815A1 (en) * 2013-04-30 2014-10-30 Halliburton Energy Services, Inc. Actuator ball retriever and valve actuation tool
US8887803B2 (en) 2012-04-09 2014-11-18 Halliburton Energy Services, Inc. Multi-interval wellbore treatment method
US8893811B2 (en) 2011-06-08 2014-11-25 Halliburton Energy Services, Inc. Responsively activated wellbore stimulation assemblies and methods of using the same
US8899334B2 (en) 2011-08-23 2014-12-02 Halliburton Energy Services, Inc. System and method for servicing a wellbore
WO2014087153A3 (en) * 2012-12-04 2014-12-24 Petrowell Limited Downhole apparatus and method
CN104234683A (en) * 2014-09-12 2014-12-24 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 Reducing mechanism
WO2014140605A3 (en) * 2013-03-15 2015-01-08 Petrowell Limited Downhole catching apparatus
WO2015026340A1 (en) * 2013-08-21 2015-02-26 Halliburton Energy Services, Inc. Wellbore steam injector
US8973657B2 (en) 2010-12-07 2015-03-10 Halliburton Energy Services, Inc. Gas generator for pressurizing downhole samples
US8978765B2 (en) 2010-12-13 2015-03-17 I-Tec As System and method for operating multiple valves
US8991509B2 (en) 2012-04-30 2015-03-31 Halliburton Energy Services, Inc. Delayed activation activatable stimulation assembly
US9016376B2 (en) 2012-08-06 2015-04-28 Halliburton Energy Services, Inc. Method and wellbore servicing apparatus for production completion of an oil and gas well
US9022107B2 (en) 2009-12-08 2015-05-05 Baker Hughes Incorporated Dissolvable tool
US9033055B2 (en) 2011-08-17 2015-05-19 Baker Hughes Incorporated Selectively degradable passage restriction and method
US20150144358A1 (en) * 2013-11-22 2015-05-28 Weatherford Technology Holdings, Llc Downhole release tool
US9051810B1 (en) 2013-03-12 2015-06-09 EirCan Downhole Technologies, LLC Frac valve with ported sleeve
US9057242B2 (en) 2011-08-05 2015-06-16 Baker Hughes Incorporated Method of controlling corrosion rate in downhole article, and downhole article having controlled corrosion rate
US9068428B2 (en) 2012-02-13 2015-06-30 Baker Hughes Incorporated Selectively corrodible downhole article and method of use
US9080098B2 (en) 2011-04-28 2015-07-14 Baker Hughes Incorporated Functionally gradient composite article
US9079246B2 (en) 2009-12-08 2015-07-14 Baker Hughes Incorporated Method of making a nanomatrix powder metal compact
US9090956B2 (en) 2011-08-30 2015-07-28 Baker Hughes Incorporated Aluminum alloy powder metal compact
US9090955B2 (en) 2010-10-27 2015-07-28 Baker Hughes Incorporated Nanomatrix powder metal composite
US9101978B2 (en) 2002-12-08 2015-08-11 Baker Hughes Incorporated Nanomatrix powder metal compact
US9109429B2 (en) 2002-12-08 2015-08-18 Baker Hughes Incorporated Engineered powder compact composite material
US9109269B2 (en) 2011-08-30 2015-08-18 Baker Hughes Incorporated Magnesium alloy powder metal compact
US9127515B2 (en) 2010-10-27 2015-09-08 Baker Hughes Incorporated Nanomatrix carbon composite
US9133695B2 (en) 2011-09-03 2015-09-15 Baker Hughes Incorporated Degradable shaped charge and perforating gun system
US9139928B2 (en) 2011-06-17 2015-09-22 Baker Hughes Incorporated Corrodible downhole article and method of removing the article from downhole environment
US9151138B2 (en) 2011-08-29 2015-10-06 Halliburton Energy Services, Inc. Injection of fluid into selected ones of multiple zones with well tools selectively responsive to magnetic patterns
US9169705B2 (en) 2012-10-25 2015-10-27 Halliburton Energy Services, Inc. Pressure relief-assisted packer
US9187990B2 (en) 2011-09-03 2015-11-17 Baker Hughes Incorporated Method of using a degradable shaped charge and perforating gun system
US20150369003A1 (en) * 2012-12-19 2015-12-24 Schlumberger Technology Corporation Downhole Valve Utilizing Degradable Material
US9228422B2 (en) 2012-01-30 2016-01-05 Thru Tubing Solutions, Inc. Limited depth abrasive jet cutter
US9227243B2 (en) 2009-12-08 2016-01-05 Baker Hughes Incorporated Method of making a powder metal compact
US9243475B2 (en) 2009-12-08 2016-01-26 Baker Hughes Incorporated Extruded powder metal compact
US9260940B2 (en) 2013-01-22 2016-02-16 Halliburton Energy Services, Inc. Pressure testing valve and method of using the same
US9260930B2 (en) 2012-08-30 2016-02-16 Halliburton Energy Services, Inc. Pressure testing valve and method of using the same
US9267347B2 (en) 2009-12-08 2016-02-23 Baker Huges Incorporated Dissolvable tool
US9279310B2 (en) 2013-01-22 2016-03-08 Halliburton Energy Services, Inc. Pressure testing valve and method of using the same
US9284812B2 (en) 2011-11-21 2016-03-15 Baker Hughes Incorporated System for increasing swelling efficiency
US9284817B2 (en) 2013-03-14 2016-03-15 Halliburton Energy Services, Inc. Dual magnetic sensor actuation assembly
US9334710B2 (en) 2013-01-16 2016-05-10 Halliburton Energy Services, Inc. Interruptible pressure testing valve
WO2016074078A1 (en) * 2014-11-11 2016-05-19 Rapid Design Group Inc. Wellbore tool with pressure actuated indexing mechanism and method
US9347119B2 (en) 2011-09-03 2016-05-24 Baker Hughes Incorporated Degradable high shock impedance material
US9366134B2 (en) 2013-03-12 2016-06-14 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9404330B2 (en) * 2010-07-12 2016-08-02 Schlumberger Technology Corporation Method and apparatus for a well employing the use of an activation ball
US9441467B2 (en) 2013-06-28 2016-09-13 Team Oil Tools, Lp Indexing well bore tool and method for using indexed well bore tools
NO338704B1 (en) * 2010-02-11 2016-10-03 I Tec As Drop ball Activated apparatus and method for enabling a plurality of such devices
US9458698B2 (en) 2013-06-28 2016-10-04 Team Oil Tools Lp Linearly indexing well bore simulation valve
US9482072B2 (en) 2013-07-23 2016-11-01 Halliburton Energy Services, Inc. Selective electrical activation of downhole tools
US9506324B2 (en) 2012-04-05 2016-11-29 Halliburton Energy Services, Inc. Well tools selectively responsive to magnetic patterns
WO2016200819A1 (en) * 2015-06-10 2016-12-15 Weatherford Technology Holdings, LLC. Sliding sleeve having indexing mechanism and expandable sleeve
US9534691B2 (en) 2008-01-02 2017-01-03 Utex Industries, Inc. Packing assembly for a pump
US9546537B2 (en) * 2013-01-25 2017-01-17 Halliburton Energy Services, Inc. Multi-positioning flow control apparatus using selective sleeves
US9556704B2 (en) 2012-09-06 2017-01-31 Utex Industries, Inc. Expandable fracture plug seat apparatus
RU2611083C2 (en) * 2013-12-04 2017-02-21 Везерфорд/Лэм, Инк. Rupturing coupling and positive indication of coupling opening for hydraulic fracturing
US9574414B2 (en) 2011-07-29 2017-02-21 Packers Plus Energy Services Inc. Wellbore tool with indexing mechanism and method
US9587486B2 (en) 2013-02-28 2017-03-07 Halliburton Energy Services, Inc. Method and apparatus for magnetic pulse signature actuation
US9605508B2 (en) 2012-05-08 2017-03-28 Baker Hughes Incorporated Disintegrable and conformable metallic seal, and method of making the same
US9611719B2 (en) 2011-05-02 2017-04-04 Peak Completion Technologies, Inc. Downhole tool
US9643250B2 (en) 2011-07-29 2017-05-09 Baker Hughes Incorporated Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle
US9643144B2 (en) 2011-09-02 2017-05-09 Baker Hughes Incorporated Method to generate and disperse nanostructures in a composite material
US9682425B2 (en) 2009-12-08 2017-06-20 Baker Hughes Incorporated Coated metallic powder and method of making the same
US9707739B2 (en) 2011-07-22 2017-07-18 Baker Hughes Incorporated Intermetallic metallic composite, method of manufacture thereof and articles comprising the same
US9739120B2 (en) 2013-07-23 2017-08-22 Halliburton Energy Services, Inc. Electrical power storage for downhole tools
US9752414B2 (en) 2013-05-31 2017-09-05 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing downhole wireless switches
US9765595B2 (en) 2011-10-11 2017-09-19 Packers Plus Energy Services Inc. Wellbore actuators, treatment strings and methods
WO2017160337A1 (en) * 2016-03-18 2017-09-21 Completion Innovations, LLC Method and apparatus for actuation of downhole sleeves and other devices
US9777558B1 (en) 2005-03-12 2017-10-03 Thru Tubing Solutions, Inc. Methods and devices for one trip plugging and perforating of oil and gas wells
US9784070B2 (en) 2012-06-29 2017-10-10 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US9796918B2 (en) 2013-01-30 2017-10-24 Halliburton Energy Services, Inc. Wellbore servicing fluids and methods of making and using same
CN107304670A (en) * 2016-04-19 2017-10-31 中国石油天然气股份有限公司 Segmented transformation string
EP3119988A4 (en) * 2014-05-15 2017-11-01 Halliburton Energy Services, Inc. Control of oilfield tools using multiple magnetic signals
US9816339B2 (en) 2013-09-03 2017-11-14 Baker Hughes, A Ge Company, Llc Plug reception assembly and method of reducing restriction in a borehole
US9833838B2 (en) 2011-07-29 2017-12-05 Baker Hughes, A Ge Company, Llc Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle
US9856547B2 (en) 2011-08-30 2018-01-02 Bakers Hughes, A Ge Company, Llc Nanostructured powder metal compact
US9896908B2 (en) 2013-06-28 2018-02-20 Team Oil Tools, Lp Well bore stimulation valve
US9910026B2 (en) 2015-01-21 2018-03-06 Baker Hughes, A Ge Company, Llc High temperature tracers for downhole detection of produced water
US9909384B2 (en) 2011-03-02 2018-03-06 Team Oil Tools, Lp Multi-actuating plugging device
US9920600B2 (en) * 2011-06-10 2018-03-20 Schlumberger Technology Corporation Multi-stage downhole hydraulic stimulation assembly
US9920620B2 (en) 2014-03-24 2018-03-20 Halliburton Energy Services, Inc. Well tools having magnetic shielding for magnetic sensor
US9926766B2 (en) 2012-01-25 2018-03-27 Baker Hughes, A Ge Company, Llc Seat for a tubular treating system
US9970260B2 (en) 2015-05-04 2018-05-15 Weatherford Technology Holdings, Llc Dual sleeve stimulation tool
US10016810B2 (en) 2015-12-14 2018-07-10 Baker Hughes, A Ge Company, Llc Methods of manufacturing degradable tools using a galvanic carrier and tools manufactured thereof
US10221637B2 (en) 2015-08-11 2019-03-05 Baker Hughes, A Ge Company, Llc Methods of manufacturing dissolvable tools via liquid-solid state molding
US10240419B2 (en) 2009-12-08 2019-03-26 Baker Hughes, A Ge Company, Llc Downhole flow inhibition tool and method of unplugging a seat

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2561177A1 (en) 2010-04-22 2013-02-27 Packers Plus Energy Services Inc. Method and apparatus for wellbore control
AU2010244947B2 (en) 2009-05-07 2015-05-07 Packers Plus Energy Services Inc. Sliding sleeve sub and method and apparatus for wellbore fluid treatment
NO340685B1 (en) * 2014-02-10 2017-05-29 Trican Completion Solutions Ltd Expandable and drillable landing seat
CN103883280B (en) * 2014-03-25 2017-06-16 中国石油集团渤海钻探工程有限公司 Multi-stage fracturing and completion and production control sleeve tail pipe string structure

Citations (35)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3054415A (en) * 1959-08-03 1962-09-18 Baker Oil Tools Inc Sleeve valve apparatus
US4109725A (en) * 1977-10-27 1978-08-29 Halliburton Company Self adjusting liquid spring operating apparatus and method for use in an oil well valve
US5323856A (en) * 1993-03-31 1994-06-28 Halliburton Company Detecting system and method for oil or gas well
US5826661A (en) * 1994-05-02 1998-10-27 Halliburton Energy Services, Inc. Linear indexing apparatus and methods of using same
US5865252A (en) * 1997-02-03 1999-02-02 Halliburton Energy Services, Inc. One-trip well perforation/proppant fracturing apparatus and methods
US5947205A (en) * 1996-06-20 1999-09-07 Halliburton Energy Services, Inc. Linear indexing apparatus with selective porting
US6116343A (en) * 1997-02-03 2000-09-12 Halliburton Energy Services, Inc. One-trip well perforation/proppant fracturing apparatus and methods
US6422317B1 (en) * 2000-09-05 2002-07-23 Halliburton Energy Services, Inc. Flow control apparatus and method for use of the same
US20030029611A1 (en) * 2001-08-10 2003-02-13 Owens Steven C. System and method for actuating a subterranean valve to terminate a reverse cementing operation
US6520257B2 (en) * 2000-12-14 2003-02-18 Jerry P. Allamon Method and apparatus for surge reduction
US6634428B2 (en) * 2001-05-03 2003-10-21 Baker Hughes Incorporated Delayed opening ball seat
US6722427B2 (en) * 2001-10-23 2004-04-20 Halliburton Energy Services, Inc. Wear-resistant, variable diameter expansion tool and expansion methods
US6769490B2 (en) * 2002-07-01 2004-08-03 Allamon Interests Downhole surge reduction method and apparatus
US6789619B2 (en) * 2002-04-10 2004-09-14 Bj Services Company Apparatus and method for detecting the launch of a device in oilfield applications
US6907936B2 (en) * 2001-11-19 2005-06-21 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US7021389B2 (en) * 2003-02-24 2006-04-04 Bj Services Company Bi-directional ball seat system and method
US20060124317A1 (en) * 2003-01-30 2006-06-15 George Telfer Multi-cycle downhole tool with hydraulic damping
US20060124312A1 (en) * 2004-12-14 2006-06-15 Rytlewski Gary L Technique and apparatus for completing multiple zones
US7108067B2 (en) * 2002-08-21 2006-09-19 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US20060243455A1 (en) * 2003-04-01 2006-11-02 George Telfer Downhole tool
US20070095573A1 (en) * 2003-05-28 2007-05-03 George Telfer Pressure controlled downhole operations
US7325617B2 (en) * 2006-03-24 2008-02-05 Baker Hughes Incorporated Frac system without intervention
US20080093080A1 (en) * 2006-10-19 2008-04-24 Palmer Larry T Ball drop circulation valve
US7377322B2 (en) * 2005-03-15 2008-05-27 Peak Completion Technologies, Inc. Method and apparatus for cementing production tubing in a multilateral borehole
US20080135248A1 (en) * 2006-12-11 2008-06-12 Halliburton Energy Service, Inc. Method and apparatus for completing and fluid treating a wellbore
US7387165B2 (en) * 2004-12-14 2008-06-17 Schlumberger Technology Corporation System for completing multiple well intervals
US20080156496A1 (en) * 2006-06-09 2008-07-03 Loyd East Methods and Devices for Treating Multiple-Interval Well Bores
US20080210429A1 (en) * 2007-03-01 2008-09-04 Bj Services Company System and method for stimulating multiple production zones in a wellbore
US20080302538A1 (en) * 2005-03-15 2008-12-11 Hofman Raymond A Cemented Open Hole Selective Fracing System
US7464764B2 (en) * 2006-09-18 2008-12-16 Baker Hughes Incorporated Retractable ball seat having a time delay material
US20090014168A1 (en) * 2007-01-25 2009-01-15 Welldynamics, Inc. Casing valves system for selective well stimulation and control
US7478676B2 (en) * 2006-06-09 2009-01-20 Halliburton Energy Services, Inc. Methods and devices for treating multiple-interval well bores
US7503398B2 (en) * 2003-06-18 2009-03-17 Weatherford/Lamb, Inc. Methods and apparatus for actuating a downhole tool
US7510010B2 (en) * 2006-01-10 2009-03-31 Halliburton Energy Services, Inc. System and method for cementing through a safety valve
US20090095486A1 (en) * 2007-10-11 2009-04-16 Williamson Jr Jimmie R Circulation control valve and associated method

Patent Citations (40)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3054415A (en) * 1959-08-03 1962-09-18 Baker Oil Tools Inc Sleeve valve apparatus
US4109725A (en) * 1977-10-27 1978-08-29 Halliburton Company Self adjusting liquid spring operating apparatus and method for use in an oil well valve
US5323856A (en) * 1993-03-31 1994-06-28 Halliburton Company Detecting system and method for oil or gas well
US5826661A (en) * 1994-05-02 1998-10-27 Halliburton Energy Services, Inc. Linear indexing apparatus and methods of using same
US6119783A (en) * 1994-05-02 2000-09-19 Halliburton Energy Services, Inc. Linear indexing apparatus and methods of using same
US5947205A (en) * 1996-06-20 1999-09-07 Halliburton Energy Services, Inc. Linear indexing apparatus with selective porting
US6116343A (en) * 1997-02-03 2000-09-12 Halliburton Energy Services, Inc. One-trip well perforation/proppant fracturing apparatus and methods
US5865252A (en) * 1997-02-03 1999-02-02 Halliburton Energy Services, Inc. One-trip well perforation/proppant fracturing apparatus and methods
US6422317B1 (en) * 2000-09-05 2002-07-23 Halliburton Energy Services, Inc. Flow control apparatus and method for use of the same
US6520257B2 (en) * 2000-12-14 2003-02-18 Jerry P. Allamon Method and apparatus for surge reduction
US6634428B2 (en) * 2001-05-03 2003-10-21 Baker Hughes Incorporated Delayed opening ball seat
US20030029611A1 (en) * 2001-08-10 2003-02-13 Owens Steven C. System and method for actuating a subterranean valve to terminate a reverse cementing operation
US6722427B2 (en) * 2001-10-23 2004-04-20 Halliburton Energy Services, Inc. Wear-resistant, variable diameter expansion tool and expansion methods
US6907936B2 (en) * 2001-11-19 2005-06-21 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US7134505B2 (en) * 2001-11-19 2006-11-14 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US6789619B2 (en) * 2002-04-10 2004-09-14 Bj Services Company Apparatus and method for detecting the launch of a device in oilfield applications
US6769490B2 (en) * 2002-07-01 2004-08-03 Allamon Interests Downhole surge reduction method and apparatus
US20090008083A1 (en) * 2002-08-21 2009-01-08 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US7108067B2 (en) * 2002-08-21 2006-09-19 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US7431091B2 (en) * 2002-08-21 2008-10-07 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US20060124317A1 (en) * 2003-01-30 2006-06-15 George Telfer Multi-cycle downhole tool with hydraulic damping
US7021389B2 (en) * 2003-02-24 2006-04-04 Bj Services Company Bi-directional ball seat system and method
US20060243455A1 (en) * 2003-04-01 2006-11-02 George Telfer Downhole tool
US20070095573A1 (en) * 2003-05-28 2007-05-03 George Telfer Pressure controlled downhole operations
US7503398B2 (en) * 2003-06-18 2009-03-17 Weatherford/Lamb, Inc. Methods and apparatus for actuating a downhole tool
US7377321B2 (en) * 2004-12-14 2008-05-27 Schlumberger Technology Corporation Testing, treating, or producing a multi-zone well
US7387165B2 (en) * 2004-12-14 2008-06-17 Schlumberger Technology Corporation System for completing multiple well intervals
US20060124312A1 (en) * 2004-12-14 2006-06-15 Rytlewski Gary L Technique and apparatus for completing multiple zones
US20080302538A1 (en) * 2005-03-15 2008-12-11 Hofman Raymond A Cemented Open Hole Selective Fracing System
US7377322B2 (en) * 2005-03-15 2008-05-27 Peak Completion Technologies, Inc. Method and apparatus for cementing production tubing in a multilateral borehole
US7510010B2 (en) * 2006-01-10 2009-03-31 Halliburton Energy Services, Inc. System and method for cementing through a safety valve
US7325617B2 (en) * 2006-03-24 2008-02-05 Baker Hughes Incorporated Frac system without intervention
US20080156496A1 (en) * 2006-06-09 2008-07-03 Loyd East Methods and Devices for Treating Multiple-Interval Well Bores
US7478676B2 (en) * 2006-06-09 2009-01-20 Halliburton Energy Services, Inc. Methods and devices for treating multiple-interval well bores
US7464764B2 (en) * 2006-09-18 2008-12-16 Baker Hughes Incorporated Retractable ball seat having a time delay material
US20080093080A1 (en) * 2006-10-19 2008-04-24 Palmer Larry T Ball drop circulation valve
US20080135248A1 (en) * 2006-12-11 2008-06-12 Halliburton Energy Service, Inc. Method and apparatus for completing and fluid treating a wellbore
US20090014168A1 (en) * 2007-01-25 2009-01-15 Welldynamics, Inc. Casing valves system for selective well stimulation and control
US20080210429A1 (en) * 2007-03-01 2008-09-04 Bj Services Company System and method for stimulating multiple production zones in a wellbore
US20090095486A1 (en) * 2007-10-11 2009-04-16 Williamson Jr Jimmie R Circulation control valve and associated method

Cited By (227)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9101978B2 (en) 2002-12-08 2015-08-11 Baker Hughes Incorporated Nanomatrix powder metal compact
US9109429B2 (en) 2002-12-08 2015-08-18 Baker Hughes Incorporated Engineered powder compact composite material
US9777558B1 (en) 2005-03-12 2017-10-03 Thru Tubing Solutions, Inc. Methods and devices for one trip plugging and perforating of oil and gas wells
US9534691B2 (en) 2008-01-02 2017-01-03 Utex Industries, Inc. Packing assembly for a pump
US8960292B2 (en) * 2008-08-22 2015-02-24 Halliburton Energy Services, Inc. High rate stimulation method for deep, large bore completions
US20100044041A1 (en) * 2008-08-22 2010-02-25 Halliburton Energy Services, Inc. High rate stimulation method for deep, large bore completions
US9133674B2 (en) 2009-02-24 2015-09-15 Schlumberger Technology Corporation Downhole tool actuation having a seat with a fluid by-pass
US20100212886A1 (en) * 2009-02-24 2010-08-26 Hall David R Downhole Tool Actuation having a Seat with a Fluid By-Pass
US9127521B2 (en) * 2009-02-24 2015-09-08 Schlumberger Technology Corporation Downhole tool actuation having a seat with a fluid by-pass
US8261761B2 (en) 2009-05-07 2012-09-11 Baker Hughes Incorporated Selectively movable seat arrangement and method
US9038656B2 (en) 2009-05-07 2015-05-26 Baker Hughes Incorporated Restriction engaging system
EA026933B1 (en) * 2009-06-22 2017-06-30 Трайкэн Велл Сервис Лтд. Apparatus and method for stimulating subterranean formations
WO2010148494A1 (en) * 2009-06-22 2010-12-29 Trican Well Service Ltd. Apparatus and method for stimulating subterranean formations
US8272445B2 (en) 2009-07-15 2012-09-25 Baker Hughes Incorporated Tubular valve system and method
US8960296B2 (en) 2009-07-24 2015-02-24 Halliburton Energy Services, Inc. Complex fracturing using a straddle packer in a horizontal wellbore
US8733444B2 (en) 2009-07-24 2014-05-27 Halliburton Energy Services, Inc. Method for inducing fracture complexity in hydraulically fractured horizontal well completions
US8439116B2 (en) 2009-07-24 2013-05-14 Halliburton Energy Services, Inc. Method for inducing fracture complexity in hydraulically fractured horizontal well completions
US8251154B2 (en) 2009-08-04 2012-08-28 Baker Hughes Incorporated Tubular system with selectively engagable sleeves and method
US8291988B2 (en) 2009-08-10 2012-10-23 Baker Hughes Incorporated Tubular actuator, system and method
US8397823B2 (en) 2009-08-10 2013-03-19 Baker Hughes Incorporated Tubular actuator, system and method
US8668016B2 (en) 2009-08-11 2014-03-11 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US8291980B2 (en) 2009-08-13 2012-10-23 Baker Hughes Incorporated Tubular valving system and method
US9279302B2 (en) 2009-09-22 2016-03-08 Baker Hughes Incorporated Plug counter and downhole tool
US8479823B2 (en) * 2009-09-22 2013-07-09 Baker Hughes Incorporated Plug counter and method
US20110067888A1 (en) * 2009-09-22 2011-03-24 Baker Hughes Incorporated Plug counter and method
US8631872B2 (en) 2009-09-24 2014-01-21 Halliburton Energy Services, Inc. Complex fracturing using a straddle packer in a horizontal wellbore
US8418769B2 (en) 2009-09-25 2013-04-16 Baker Hughes Incorporated Tubular actuator and method
US8316951B2 (en) 2009-09-25 2012-11-27 Baker Hughes Incorporated Tubular actuator and method
US8646531B2 (en) 2009-10-29 2014-02-11 Baker Hughes Incorporated Tubular actuator, system and method
US8272443B2 (en) 2009-11-12 2012-09-25 Halliburton Energy Services Inc. Downhole progressive pressurization actuated tool and method of using the same
US9227243B2 (en) 2009-12-08 2016-01-05 Baker Hughes Incorporated Method of making a powder metal compact
US8327931B2 (en) 2009-12-08 2012-12-11 Baker Hughes Incorporated Multi-component disappearing tripping ball and method for making the same
US9267347B2 (en) 2009-12-08 2016-02-23 Baker Huges Incorporated Dissolvable tool
US9022107B2 (en) 2009-12-08 2015-05-05 Baker Hughes Incorporated Dissolvable tool
US9079246B2 (en) 2009-12-08 2015-07-14 Baker Hughes Incorporated Method of making a nanomatrix powder metal compact
US9243475B2 (en) 2009-12-08 2016-01-26 Baker Hughes Incorporated Extruded powder metal compact
US10240419B2 (en) 2009-12-08 2019-03-26 Baker Hughes, A Ge Company, Llc Downhole flow inhibition tool and method of unplugging a seat
US9682425B2 (en) 2009-12-08 2017-06-20 Baker Hughes Incorporated Coated metallic powder and method of making the same
US8714268B2 (en) 2009-12-08 2014-05-06 Baker Hughes Incorporated Method of making and using multi-component disappearing tripping ball
US8839871B2 (en) 2010-01-15 2014-09-23 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US9822609B2 (en) 2010-01-15 2017-11-21 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US8893786B2 (en) 2010-01-15 2014-11-25 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US9388669B2 (en) 2010-01-15 2016-07-12 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US20110174484A1 (en) * 2010-01-15 2011-07-21 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US8365832B2 (en) 2010-01-27 2013-02-05 Schlumberger Technology Corporation Position retention mechanism for maintaining a counter mechanism in an activated position
US20110180270A1 (en) * 2010-01-27 2011-07-28 Schlumberger Technology Corporation Position retention mechanism for maintaining a counter mechanism in an activated position
GB2477396A (en) * 2010-01-27 2011-08-03 Schlumberger Holdings Well tool actuator
US8479822B2 (en) * 2010-02-08 2013-07-09 Summit Downhole Dynamics, Ltd Downhole tool with expandable seat
US20110192607A1 (en) * 2010-02-08 2011-08-11 Raymond Hofman Downhole Tool With Expandable Seat
US8887811B2 (en) * 2010-02-08 2014-11-18 Peak Completion Technologies, Inc. Downhole tool with expandable seat
CN102859112A (en) * 2010-02-08 2013-01-02 三弥特井下动力有限责任公司 Downhole tool with expandable seat
NO338704B1 (en) * 2010-02-11 2016-10-03 I Tec As Drop ball Activated apparatus and method for enabling a plurality of such devices
US8215401B2 (en) 2010-02-12 2012-07-10 I-Tec As Expandable ball seat
US20110198100A1 (en) * 2010-02-12 2011-08-18 I-Tec As Expandable Ball Seat
US20110198096A1 (en) * 2010-02-15 2011-08-18 Tejas Research And Engineering, Lp Unlimited Downhole Fracture Zone System
US8424610B2 (en) 2010-03-05 2013-04-23 Baker Hughes Incorporated Flow control arrangement and method
US9279311B2 (en) 2010-03-23 2016-03-08 Baker Hughes Incorporation System, assembly and method for port control
US20110232915A1 (en) * 2010-03-23 2011-09-29 Baker Hughes Incorporated System, assembly and method for port control
US8701776B2 (en) 2010-03-26 2014-04-22 Petrowell Limited Downhole actuating apparatus
WO2011117601A3 (en) * 2010-03-26 2012-06-21 Petrowell Limited Downhole actuating apparatus
WO2011117602A3 (en) * 2010-03-26 2012-06-21 Petrowell Limited Mechanical counter
US9194197B2 (en) 2010-03-26 2015-11-24 Petrowell Limited Mechanical counter
AU2011231339B2 (en) * 2010-03-26 2015-01-22 Weatherford Technology Holdings, Llc Downhole actuating apparatus
US8403068B2 (en) * 2010-04-02 2013-03-26 Weatherford/Lamb, Inc. Indexing sleeve for single-trip, multi-stage fracing
US8505639B2 (en) * 2010-04-02 2013-08-13 Weatherford/Lamb, Inc. Indexing sleeve for single-trip, multi-stage fracing
US20110240311A1 (en) * 2010-04-02 2011-10-06 Weatherford/Lamb, Inc. Indexing Sleeve for Single-Trip, Multi-Stage Fracing
US20110240301A1 (en) * 2010-04-02 2011-10-06 Robison Clark E Indexing Sleeve for Single-Trip, Multi-Stage Fracing
US9441457B2 (en) 2010-04-02 2016-09-13 Weatherford Technology Holdings, Llc Indexing sleeve for single-trip, multi-stage fracing
AU2012200380B2 (en) * 2010-04-02 2013-11-21 Weatherford Technology Holdings, Llc Indexing sleeve for single-trip, multi-stage fracing
US20120227973A1 (en) * 2010-06-29 2012-09-13 Baker Hughes Incorporated Tool with Multisize Segmented Ring Seat
US9303475B2 (en) * 2010-06-29 2016-04-05 Baker Hughes Incorporated Tool with multisize segmented ring seat
US9404330B2 (en) * 2010-07-12 2016-08-02 Schlumberger Technology Corporation Method and apparatus for a well employing the use of an activation ball
US8425651B2 (en) 2010-07-30 2013-04-23 Baker Hughes Incorporated Nanomatrix metal composite
US8448700B2 (en) * 2010-08-03 2013-05-28 Thru Tubing Solutions, Inc. Abrasive perforator with fluid bypass
US9447663B1 (en) * 2010-08-03 2016-09-20 Thru Tubing Solutions, Inc. Abrasive perforator with fluid bypass
US8905125B1 (en) * 2010-08-03 2014-12-09 Thru Tubing Solutions, Inc. Abrasive perforator with fluid bypass
US20120031615A1 (en) * 2010-08-03 2012-02-09 Thru Tubing Solutions, Inc. Abrasive perforator with fluid bypass
US8776884B2 (en) 2010-08-09 2014-07-15 Baker Hughes Incorporated Formation treatment system and method
US8789600B2 (en) * 2010-08-24 2014-07-29 Baker Hughes Incorporated Fracing system and method
US9188235B2 (en) 2010-08-24 2015-11-17 Baker Hughes Incorporated Plug counter, fracing system and method
US20120048556A1 (en) * 2010-08-24 2012-03-01 Baker Hughes Incorporated Plug counter, fracing system and method
GB2497678B (en) * 2010-08-24 2017-04-05 Baker Hughes Inc Plug counter fracing system and method
US8668013B2 (en) 2010-08-24 2014-03-11 Baker Hughes Incorporated Plug counter, fracing system and method
US9127515B2 (en) 2010-10-27 2015-09-08 Baker Hughes Incorporated Nanomatrix carbon composite
US9090955B2 (en) 2010-10-27 2015-07-28 Baker Hughes Incorporated Nanomatrix powder metal composite
US8573295B2 (en) 2010-11-16 2013-11-05 Baker Hughes Incorporated Plug and method of unplugging a seat
US8973657B2 (en) 2010-12-07 2015-03-10 Halliburton Energy Services, Inc. Gas generator for pressurizing downhole samples
US8978765B2 (en) 2010-12-13 2015-03-17 I-Tec As System and method for operating multiple valves
US8662162B2 (en) 2011-02-03 2014-03-04 Baker Hughes Incorporated Segmented collapsible ball seat allowing ball recovery
CN103477026A (en) * 2011-02-07 2013-12-25 克雷麦克控股有限公司 Wellbore injection system
US20120199353A1 (en) * 2011-02-07 2012-08-09 Brent Daniel Fermaniuk Wellbore injection system
AU2012215164B2 (en) * 2011-02-10 2015-06-18 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US8668012B2 (en) * 2011-02-10 2014-03-11 Halliburton Energy Services, Inc. System and method for servicing a wellbore
CN103415674A (en) * 2011-02-10 2013-11-27 哈里伯顿能源服务公司 System and method for servicing a wellbore
US8695710B2 (en) 2011-02-10 2014-04-15 Halliburton Energy Services, Inc. Method for individually servicing a plurality of zones of a subterranean formation
US9428976B2 (en) 2011-02-10 2016-08-30 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US9458697B2 (en) 2011-02-10 2016-10-04 Halliburton Energy Services, Inc. Method for individually servicing a plurality of zones of a subterranean formation
US20120205121A1 (en) * 2011-02-10 2012-08-16 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US9909384B2 (en) 2011-03-02 2018-03-06 Team Oil Tools, Lp Multi-actuating plugging device
WO2012118889A3 (en) * 2011-03-02 2014-04-17 Team Oil Tools, Lp Multi-actuating seat and drop element
US9004179B2 (en) 2011-03-02 2015-04-14 Team Oil Tools, Lp Multi-actuating seat and drop element
WO2012118889A2 (en) * 2011-03-02 2012-09-07 Team Oil Tools, Lp Multi-actuating seat and drop element
US20120266994A1 (en) * 2011-04-19 2012-10-25 Baker Hughes Incorporated Tubular actuating system and method
US8770299B2 (en) * 2011-04-19 2014-07-08 Baker Hughes Incorporated Tubular actuating system and method
US8631876B2 (en) 2011-04-28 2014-01-21 Baker Hughes Incorporated Method of making and using a functionally gradient composite tool
US9631138B2 (en) 2011-04-28 2017-04-25 Baker Hughes Incorporated Functionally gradient composite article
US9080098B2 (en) 2011-04-28 2015-07-14 Baker Hughes Incorporated Functionally gradient composite article
US9611719B2 (en) 2011-05-02 2017-04-04 Peak Completion Technologies, Inc. Downhole tool
CN102182438A (en) * 2011-06-03 2011-09-14 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 Layered fracturing technology for variable-length graded sliding sleeve
US8893811B2 (en) 2011-06-08 2014-11-25 Halliburton Energy Services, Inc. Responsively activated wellbore stimulation assemblies and methods of using the same
US9920600B2 (en) * 2011-06-10 2018-03-20 Schlumberger Technology Corporation Multi-stage downhole hydraulic stimulation assembly
US9139928B2 (en) 2011-06-17 2015-09-22 Baker Hughes Incorporated Corrodible downhole article and method of removing the article from downhole environment
US9926763B2 (en) 2011-06-17 2018-03-27 Baker Hughes, A Ge Company, Llc Corrodible downhole article and method of removing the article from downhole environment
US8757274B2 (en) 2011-07-01 2014-06-24 Halliburton Energy Services, Inc. Well tool actuator and isolation valve for use in drilling operations
US10202824B2 (en) 2011-07-01 2019-02-12 Halliburton Energy Services, Inc. Well tool actuator and isolation valve for use in drilling operations
US9707739B2 (en) 2011-07-22 2017-07-18 Baker Hughes Incorporated Intermetallic metallic composite, method of manufacture thereof and articles comprising the same
US20130025876A1 (en) * 2011-07-28 2013-01-31 Baker Hughes Incorporated Selective hydraulic fracturing tool and method thereof
AU2012287346B2 (en) * 2011-07-28 2016-09-22 Baker Hughes Incorporated Selective hydraulic fracturing tool and method thereof
US8783365B2 (en) * 2011-07-28 2014-07-22 Baker Hughes Incorporated Selective hydraulic fracturing tool and method thereof
CN103688014A (en) * 2011-07-28 2014-03-26 贝克休斯公司 Selective hydraulic fracturing tool and method thereof
US9833838B2 (en) 2011-07-29 2017-12-05 Baker Hughes, A Ge Company, Llc Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle
US9643250B2 (en) 2011-07-29 2017-05-09 Baker Hughes Incorporated Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle
US10092953B2 (en) 2011-07-29 2018-10-09 Baker Hughes, A Ge Company, Llc Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle
US9574414B2 (en) 2011-07-29 2017-02-21 Packers Plus Energy Services Inc. Wellbore tool with indexing mechanism and method
US9057242B2 (en) 2011-08-05 2015-06-16 Baker Hughes Incorporated Method of controlling corrosion rate in downhole article, and downhole article having controlled corrosion rate
US9033055B2 (en) 2011-08-17 2015-05-19 Baker Hughes Incorporated Selectively degradable passage restriction and method
US10301909B2 (en) 2011-08-17 2019-05-28 Baker Hughes, A Ge Company, Llc Selectively degradable passage restriction
US8899334B2 (en) 2011-08-23 2014-12-02 Halliburton Energy Services, Inc. System and method for servicing a wellbore
US20130048290A1 (en) * 2011-08-29 2013-02-28 Halliburton Energy Services, Inc. Injection of fluid into selected ones of multiple zones with well tools selectively responsive to magnetic patterns
US9151138B2 (en) 2011-08-29 2015-10-06 Halliburton Energy Services, Inc. Injection of fluid into selected ones of multiple zones with well tools selectively responsive to magnetic patterns
US9090956B2 (en) 2011-08-30 2015-07-28 Baker Hughes Incorporated Aluminum alloy powder metal compact
US9925589B2 (en) 2011-08-30 2018-03-27 Baker Hughes, A Ge Company, Llc Aluminum alloy powder metal compact
US9802250B2 (en) 2011-08-30 2017-10-31 Baker Hughes Magnesium alloy powder metal compact
US9109269B2 (en) 2011-08-30 2015-08-18 Baker Hughes Incorporated Magnesium alloy powder metal compact
US9856547B2 (en) 2011-08-30 2018-01-02 Bakers Hughes, A Ge Company, Llc Nanostructured powder metal compact
US9643144B2 (en) 2011-09-02 2017-05-09 Baker Hughes Incorporated Method to generate and disperse nanostructures in a composite material
US9347119B2 (en) 2011-09-03 2016-05-24 Baker Hughes Incorporated Degradable high shock impedance material
US9133695B2 (en) 2011-09-03 2015-09-15 Baker Hughes Incorporated Degradable shaped charge and perforating gun system
US9187990B2 (en) 2011-09-03 2015-11-17 Baker Hughes Incorporated Method of using a degradable shaped charge and perforating gun system
US8662178B2 (en) 2011-09-29 2014-03-04 Halliburton Energy Services, Inc. Responsively activated wellbore stimulation assemblies and methods of using the same
US9765595B2 (en) 2011-10-11 2017-09-19 Packers Plus Energy Services Inc. Wellbore actuators, treatment strings and methods
GB2509636B (en) * 2011-10-14 2019-02-13 Nov Downhole Eurasia Ltd Downhole tool actuator
WO2013054099A3 (en) * 2011-10-14 2013-12-27 Nov Downhole Eurasia Limited Downhole tool actuator
US9359866B2 (en) 2011-10-14 2016-06-07 Nov Downhole Eurasia Limited Downhole tool actuator
GB2509636A (en) * 2011-10-14 2014-07-09 Nov Downhole Eurasia Ltd Downhole tool actuator
US9284812B2 (en) 2011-11-21 2016-03-15 Baker Hughes Incorporated System for increasing swelling efficiency
US8950496B2 (en) 2012-01-19 2015-02-10 Baker Hughes Incorporated Counter device for selectively catching plugs
CN104126050A (en) * 2012-01-19 2014-10-29 贝克休斯公司 Counter device for selectively catching plugs
WO2013109394A1 (en) * 2012-01-19 2013-07-25 Baker Hughes Incorporated Counter device for selectively catching plugs
US9926766B2 (en) 2012-01-25 2018-03-27 Baker Hughes, A Ge Company, Llc Seat for a tubular treating system
US9228422B2 (en) 2012-01-30 2016-01-05 Thru Tubing Solutions, Inc. Limited depth abrasive jet cutter
US9068428B2 (en) 2012-02-13 2015-06-30 Baker Hughes Incorporated Selectively corrodible downhole article and method of use
US9004180B2 (en) * 2012-03-20 2015-04-14 Team Oil Tools, L.P. Method and apparatus for actuating a downhole tool
US20130248201A1 (en) * 2012-03-20 2013-09-26 Team Oil Tools, Lp Method and apparatus for actuating a downhole tool
US9506324B2 (en) 2012-04-05 2016-11-29 Halliburton Energy Services, Inc. Well tools selectively responsive to magnetic patterns
US8887803B2 (en) 2012-04-09 2014-11-18 Halliburton Energy Services, Inc. Multi-interval wellbore treatment method
US8991509B2 (en) 2012-04-30 2015-03-31 Halliburton Energy Services, Inc. Delayed activation activatable stimulation assembly
US9605508B2 (en) 2012-05-08 2017-03-28 Baker Hughes Incorporated Disintegrable and conformable metallic seal, and method of making the same
US9234406B2 (en) 2012-05-09 2016-01-12 Utex Industries, Inc. Seat assembly with counter for isolating fracture zones in a well
US9353598B2 (en) * 2012-05-09 2016-05-31 Utex Industries, Inc. Seat assembly with counter for isolating fracture zones in a well
US20130299199A1 (en) * 2012-05-09 2013-11-14 Utex Industries, Inc. Seat assembly with counter for isolating fracture zones in a well
US9784070B2 (en) 2012-06-29 2017-10-10 Halliburton Energy Services, Inc. System and method for servicing a wellbore
WO2014020335A3 (en) * 2012-07-31 2014-09-18 Petrowell Limited Downhole apparatus and method
WO2014020335A2 (en) * 2012-07-31 2014-02-06 Petrowell Limited Downhole apparatus and method
US20150167429A1 (en) * 2012-07-31 2015-06-18 Petrowell Limited Downhole apparatus and method
US10077633B2 (en) 2012-07-31 2018-09-18 Petrowell Limited Downhole apparatus and method
GB2506265A (en) * 2012-07-31 2014-03-26 Petrowell Ltd Downhole Apparatus And Method
US10018015B2 (en) 2012-07-31 2018-07-10 Weatherford Technology Holdings, Llc Downhole apparatus and method
US10053958B2 (en) * 2012-07-31 2018-08-21 Weatherford Technology Holdings, Llc Downhole apparatus and method
US9016376B2 (en) 2012-08-06 2015-04-28 Halliburton Energy Services, Inc. Method and wellbore servicing apparatus for production completion of an oil and gas well
US9260930B2 (en) 2012-08-30 2016-02-16 Halliburton Energy Services, Inc. Pressure testing valve and method of using the same
US10132134B2 (en) 2012-09-06 2018-11-20 Utex Industries, Inc. Expandable fracture plug seat apparatus
US9556704B2 (en) 2012-09-06 2017-01-31 Utex Industries, Inc. Expandable fracture plug seat apparatus
US20140102797A1 (en) * 2012-10-12 2014-04-17 Smith International, Inc. Selective deployment of underreamers and stabilizers
US9428962B2 (en) * 2012-10-12 2016-08-30 Smith International, Inc. Selective deployment of underreamers and stabilizers
US9988872B2 (en) 2012-10-25 2018-06-05 Halliburton Energy Services, Inc. Pressure relief-assisted packer
US9169705B2 (en) 2012-10-25 2015-10-27 Halliburton Energy Services, Inc. Pressure relief-assisted packer
WO2014087153A3 (en) * 2012-12-04 2014-12-24 Petrowell Limited Downhole apparatus and method
RU2655074C2 (en) * 2012-12-04 2018-05-23 ВЕЗЕРФОРД ТЕКНОЛОДЖИ ХОЛДИНГЗ, ЭлЭлСи Downhole apparatus and method
AU2013353836B2 (en) * 2012-12-04 2017-01-19 Weatherford Technology Holdings, Llc Downhole apparatus and method
US10233724B2 (en) * 2012-12-19 2019-03-19 Schlumberger Technology Corporation Downhole valve utilizing degradable material
US20150369003A1 (en) * 2012-12-19 2015-12-24 Schlumberger Technology Corporation Downhole Valve Utilizing Degradable Material
CN102979495A (en) * 2012-12-28 2013-03-20 中国石油集团渤海钻探工程有限公司 Multi-cluster current limiting fracturing string of open hole horizontal well and fracturing method thereof
US9334710B2 (en) 2013-01-16 2016-05-10 Halliburton Energy Services, Inc. Interruptible pressure testing valve
US9260940B2 (en) 2013-01-22 2016-02-16 Halliburton Energy Services, Inc. Pressure testing valve and method of using the same
US9279310B2 (en) 2013-01-22 2016-03-08 Halliburton Energy Services, Inc. Pressure testing valve and method of using the same
US9546537B2 (en) * 2013-01-25 2017-01-17 Halliburton Energy Services, Inc. Multi-positioning flow control apparatus using selective sleeves
US9796918B2 (en) 2013-01-30 2017-10-24 Halliburton Energy Services, Inc. Wellbore servicing fluids and methods of making and using same
US9587486B2 (en) 2013-02-28 2017-03-07 Halliburton Energy Services, Inc. Method and apparatus for magnetic pulse signature actuation
US10221653B2 (en) 2013-02-28 2019-03-05 Halliburton Energy Services, Inc. Method and apparatus for magnetic pulse signature actuation
US8757265B1 (en) 2013-03-12 2014-06-24 EirCan Downhole Technologies, LLC Frac valve
US9587487B2 (en) 2013-03-12 2017-03-07 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9562429B2 (en) 2013-03-12 2017-02-07 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9982530B2 (en) 2013-03-12 2018-05-29 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9366134B2 (en) 2013-03-12 2016-06-14 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9051810B1 (en) 2013-03-12 2015-06-09 EirCan Downhole Technologies, LLC Frac valve with ported sleeve
US9726009B2 (en) 2013-03-12 2017-08-08 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9284817B2 (en) 2013-03-14 2016-03-15 Halliburton Energy Services, Inc. Dual magnetic sensor actuation assembly
WO2014140605A3 (en) * 2013-03-15 2015-01-08 Petrowell Limited Downhole catching apparatus
US20140318815A1 (en) * 2013-04-30 2014-10-30 Halliburton Energy Services, Inc. Actuator ball retriever and valve actuation tool
US9752414B2 (en) 2013-05-31 2017-09-05 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing downhole wireless switches
US9458698B2 (en) 2013-06-28 2016-10-04 Team Oil Tools Lp Linearly indexing well bore simulation valve
US9896908B2 (en) 2013-06-28 2018-02-20 Team Oil Tools, Lp Well bore stimulation valve
US9441467B2 (en) 2013-06-28 2016-09-13 Team Oil Tools, Lp Indexing well bore tool and method for using indexed well bore tools
US8863853B1 (en) 2013-06-28 2014-10-21 Team Oil Tools Lp Linearly indexing well bore tool
US9482072B2 (en) 2013-07-23 2016-11-01 Halliburton Energy Services, Inc. Selective electrical activation of downhole tools
US9739120B2 (en) 2013-07-23 2017-08-22 Halliburton Energy Services, Inc. Electrical power storage for downhole tools
US9447668B2 (en) 2013-08-21 2016-09-20 Halliburton Energy Services, Inc. Wellbore steam injector
WO2015026340A1 (en) * 2013-08-21 2015-02-26 Halliburton Energy Services, Inc. Wellbore steam injector
US9816339B2 (en) 2013-09-03 2017-11-14 Baker Hughes, A Ge Company, Llc Plug reception assembly and method of reducing restriction in a borehole
US9732566B2 (en) * 2013-11-22 2017-08-15 Weatherford Technology Holdings, Llc Downhole release tool
US20150144358A1 (en) * 2013-11-22 2015-05-28 Weatherford Technology Holdings, Llc Downhole release tool
RU2611083C2 (en) * 2013-12-04 2017-02-21 Везерфорд/Лэм, Инк. Rupturing coupling and positive indication of coupling opening for hydraulic fracturing
US9885224B2 (en) 2013-12-04 2018-02-06 Weatherford Technology Holdings, Llc Burst sleeve and positive indication for fracture sleeve opening
US9920620B2 (en) 2014-03-24 2018-03-20 Halliburton Energy Services, Inc. Well tools having magnetic shielding for magnetic sensor
EP3119988A4 (en) * 2014-05-15 2017-11-01 Halliburton Energy Services, Inc. Control of oilfield tools using multiple magnetic signals
CN104234683A (en) * 2014-09-12 2014-12-24 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 Reducing mechanism
WO2016074078A1 (en) * 2014-11-11 2016-05-19 Rapid Design Group Inc. Wellbore tool with pressure actuated indexing mechanism and method
US9910026B2 (en) 2015-01-21 2018-03-06 Baker Hughes, A Ge Company, Llc High temperature tracers for downhole detection of produced water
US9970260B2 (en) 2015-05-04 2018-05-15 Weatherford Technology Holdings, Llc Dual sleeve stimulation tool
GB2555254A (en) * 2015-06-10 2018-04-25 Weatherford Tech Holdings Llc Sliding sleeve having indexing mechanism and expandable sleeve
WO2016200819A1 (en) * 2015-06-10 2016-12-15 Weatherford Technology Holdings, LLC. Sliding sleeve having indexing mechanism and expandable sleeve
US10221637B2 (en) 2015-08-11 2019-03-05 Baker Hughes, A Ge Company, Llc Methods of manufacturing dissolvable tools via liquid-solid state molding
US10016810B2 (en) 2015-12-14 2018-07-10 Baker Hughes, A Ge Company, Llc Methods of manufacturing degradable tools using a galvanic carrier and tools manufactured thereof
GB2566370A (en) * 2016-03-18 2019-03-13 Completion Innovations Llc Method and apparatus for actuation of downhole sleeves and other devices
WO2017160337A1 (en) * 2016-03-18 2017-09-21 Completion Innovations, LLC Method and apparatus for actuation of downhole sleeves and other devices
CN107304670A (en) * 2016-04-19 2017-10-31 中国石油天然气股份有限公司 Segmented transformation string

Also Published As

Publication number Publication date
CA2668129A1 (en) 2009-12-16

Similar Documents

Publication Publication Date Title
US6520257B2 (en) Method and apparatus for surge reduction
US6782948B2 (en) Remotely operated multi-zone packing system
AU2011318193B2 (en) Tools and methods for use in completion of a wellbore
CA2529962C (en) System for completing multiple well intervals
US6446729B1 (en) Sand control method and apparatus
US7051812B2 (en) Fracturing tool having tubing isolation system and method
US5103912A (en) Method and apparatus for completing deviated and horizontal wellbores
US9010447B2 (en) Sliding sleeve sub and method and apparatus for wellbore fluid treatment
CA2768756C (en) System and method for servicing a wellbore
AU2009317047B2 (en) Apparatus and method for servicing a wellbore
EP3404200A1 (en) A method for individually servicing a plurality of zones of a subterranean formation
CA2810412C (en) Wellbore frac tool with inflow control
US7681645B2 (en) System and method for stimulating multiple production zones in a wellbore
US8863850B2 (en) Apparatus and method for stimulating subterranean formations
EP1101012B1 (en) Mechanism for dropping a plurality of balls into tubulars used in drilling, completion and workover of oil, gas and geothermal wells, and method of using same
US5865252A (en) One-trip well perforation/proppant fracturing apparatus and methods
US6474419B2 (en) Packer with equalizing valve and method of use
US20100089587A1 (en) Fluid logic tool for a subterranean well
CA2412072C (en) Method and apparatus for wellbore fluid treatment
US7926571B2 (en) Cemented open hole selective fracing system
US8272443B2 (en) Downhole progressive pressurization actuated tool and method of using the same
US6230807B1 (en) Valve operating mechanism
US9074451B2 (en) Method and apparatus for wellbore fluid treatment
CA2770428C (en) Multi-zone fracturing completion
US6006838A (en) Apparatus and method for stimulating multiple production zones in a wellbore

Legal Events

Date Code Title Description
AS Assignment

Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HOWELL, MATTHEW;VARGUS, GREGORY;WEBB, SHAWN;SIGNING DATES FROM 20080708 TO 20080814;REEL/FRAME:021471/0897

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION