WO2009023611A2 - Soupape multi-position pour la fracturation et le contrôle du sable et procédés de complétion associés - Google Patents

Soupape multi-position pour la fracturation et le contrôle du sable et procédés de complétion associés Download PDF

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Publication number
WO2009023611A2
WO2009023611A2 PCT/US2008/072733 US2008072733W WO2009023611A2 WO 2009023611 A2 WO2009023611 A2 WO 2009023611A2 US 2008072733 W US2008072733 W US 2008072733W WO 2009023611 A2 WO2009023611 A2 WO 2009023611A2
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WO
WIPO (PCT)
Prior art keywords
valve
sleeve
port
string
ports
Prior art date
Application number
PCT/US2008/072733
Other languages
English (en)
Other versions
WO2009023611A3 (fr
Inventor
Sean L. Gaudette
Douglas J. Murray
Original Assignee
Baker Hughes Incorporated
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
Priority claimed from US11/891,706 external-priority patent/US7628210B2/en
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to PCT/US2008/072733 priority Critical patent/WO2009023611A2/fr
Priority to BRPI0815177-6A priority patent/BRPI0815177B1/pt
Priority to RU2010108946/03A priority patent/RU2475626C2/ru
Priority to AU2008287022A priority patent/AU2008287022B2/en
Priority to EP08797572A priority patent/EP2185790A2/fr
Publication of WO2009023611A2 publication Critical patent/WO2009023611A2/fr
Publication of WO2009023611A3 publication Critical patent/WO2009023611A3/fr
Priority to EG2010020226A priority patent/EG25568A/xx

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells

Definitions

  • the field of the invention relates to completion techniques involving fracturing and more particularly the ability to fracture discrete segments of a formation in a desired order through valved ports which can then be configured for sand control duty to let production begin without using a crossover tool and a separate run for sand control screens after the fracturing operation.
  • Typical completion sequences in the past involve running in an assembly of screens with a crossover tool and an isolation packer above the crossover tool.
  • the crossover tool has a squeeze position where it eliminates a return path to allow fluid pumped down a work string and through the packer to cross over to the annulus outside the screen sections and into the formation through, for example, a cemented and perforated casing.
  • the casing could have telescoping members that are extendable into the formation and the tubular from which they extend could be cemented or not cemented.
  • the fracture fluid in any event, would go into the annular space outside the screens and get squeezed into the formation that is isolated by the packer above the crossover tool and another downhole packer or the bottom of the hole.
  • a completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage.
  • the valve assembly has three positions, adding a fully closed position to the other two mentioned.
  • the valves can be put in the wide open position in any order desired to fracture.
  • the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order.
  • the tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular.
  • the tubular can be in open hole and simply have openings for passage of fracture fluid and external isolators to allow fracturing in any desired order.
  • FIG. 1 is a half section view showing three position valves in the open position for run in with the optional telescoping passages retracted;
  • FIG. 2 is the view of FIG. 1 with the tubular cemented and the telescoping passages extended but still blocked off;
  • FIG. 3 is the view of FIG. 2 with the upper valve closed and the lower valve open with the passage through the lower telescoping passage open and ready for fracturing;
  • FIG. 4 is the view of FIG. 3 with the fracturing completed through the lower telescoping passage and the upper valve opened for fracturing through the upper telescoping passage;
  • FIG. 5 is the view of FIG. 4 with fracturing complete through the upper telescoping passage
  • FIG. 6 is the view of FIG. 5 with both valves put in screening position
  • FIG. 7 is a close up view of a three position valve in the closed position
  • FIG. 8 is the view of FIG. 7 with the valve in the wide open fracturing position
  • FIG. 9 is the view of FIG. 8 with the travel stops for the sliding sleeve shifted right;
  • FIG. 10 is the view of FIG. 9 with the sleeve shifted against a relocated travel stop to the filtration position;
  • FIG. 1 1 is a section view of a j-slot guided version of the three position valve in the wide open position for fracturing;
  • FIG. 12 is the view of FIG. 11 with the valve in the closed position
  • FIG. 13 is the view of FIG. 12 with the valve in the filtration position
  • FIG. 14 is one possible j-slot layout to achieve the three positions shown in FIGS. 11-13;
  • FIG. 15 is an alternative j-slot to the one in FIG. 14 to achieve the three positions shown in FIGS. 11-13;
  • FIG. 16 is a detailed view of a sliding sleeve design that operates on pressure differential between an annulus around a tubing string and pressure inside it;
  • FIG. 17 is the overall view of a three position valve in the closed position showing the indexing device for the three positions;
  • FIG. 18 is the view of FIG. 17 with the valve in the filtration position
  • FIG. 19 is the view of FIG. 18 with the valve in the wide open position
  • FIG. 20 is an alternative pressure based way of moving the multi-position valve shown in a position for pushing the piston downhole;
  • FIG. 21 is the view of FIG. 19 in a position to push the piston uphole
  • FIG. 22 is the view of FIG. 20 in a neutral position where pressure does not cause movement
  • FIG. 23 shows an open hole before insertion of the tubular for a completion
  • FIG. 24 is the view of FIG. 23 with the completion assembly supported from cemented casing and the multi-position valves closed;
  • FlG. 25 is the view of FIG. 24 with the external packer set
  • FIG. 26 is the view of FIG. 25 with the lower valve open in a fracturing mode
  • FIG. 27 is the view of FIG. 26 with the string picked up and ready to open the upper valve for fracturing
  • FIG. 28 is the view of FIG. 27 with fracturing complete
  • FIG. 29 is the view of FIG. 28 with the string lowered in preparation for putting both valves in filtration mode
  • FIG. 30 is the view of FIG. 29 with the string removed and both valves shifted to filtration mode
  • FIG. 31 is a schematic view of an alternative embodiment using discrete ports in the tubular for fracturing and filtering showing the closed ports position;
  • FIG. 32 is the view of FIG. 31 with the fracture ports open.
  • FIG. 33 is the view of FIG. 32 with the filtering ports open. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT
  • FIG. 1 One way to illustrate the method of the present invention is to refer to FIG. 1.
  • Wellbore 10 has a casing 12 that is cemented 14.
  • a work string 16 suspends a tubular string 18 that has an external liner hanger/seal 20, shown in a set position to support string 18 from casing 12.
  • string 18 is shown with upper ports 22 and lower ports 24. While only a single port 22 or 24 is shown, those skilled in the art will understand that the drawing is schematic and each hole represents multiple openings arranged in any order desired to meet the flow requirements.
  • each opening 22 and 24 has a telescoping assembly 26 and 28 respectively that are shown in a retracted position for run in. Assemblies 26 and 28 could also be within string 18 for run in.
  • Assemblies 26 and 28 respectively have passages 30 and 32 which are initially respectively blocked by rupture discs 34 and 36. Openings 22 and 24 respectively have a valve assembly 38 and 40 located nearby in tubular 18.
  • valve assemblies have a clear port 42 and 44 and a filtration port 46 and 48. They also have a long blank section 50 and 52.
  • the way valve assemblies 38 and 40 operate will be explored in detail later.
  • the filtration material in port 46 is preferably a sintered metal but other filtration materials can be used such as mesh screens.
  • the assembly 38 is shown as a three position valve but it can be also be a two position valve that only presents either opening 42 or 46 aligned with port 22. In that configuration, there is no closing the valve assembly 38.
  • FIG. 2 shows the assemblies 26 and 28 extended and the tubular 18 cemented with cement 54. These two steps can be in either order. None else has changed.
  • FIG. 3 shows a work string 56 lowered into position and ready to break rupture disc 36 to fracture through assembly 28.
  • FIG. 4 the rupture disc 36 is broken and proppant slurry 58 is pumped under pressure into the formation 60 through assembly 28 via aligned ports 44 and 24. Pressure is maintained until flow drops off indicating the fracture through assemblies 28 is complete.
  • FIG. 5 the work string 56 is raised up in preparation for fracturing through assemblies 26 by breaking rupture disc 34 and delivering proppant or sand slurry 62 into formation 64.
  • a fluid loss control device such as a fluid loss control pill or another mechanism common to the art may be employed.
  • FIG. 6 illustrates the valve assemblies 38 and 40 shifted up to align respectively port 46 with 22 and port 48 with 24.
  • a production string can be inserted and the formations 60 or/and 64 can be produced in any desired order or two or more formations at once.
  • FIG. 23 shows a wellbore 70 that is an open hole at its lower end 72.
  • Casing 74 is cemented with cement 76.
  • a running string 78 carries in a tubular string 80 until it can be secured to casing 74 with a hanger/packer 82.
  • the string 80 has for example two arrays of ports 84 and 86. Each array represents the needed number of openings properly sized and in any desired pattern.
  • Each array of ports 84 and 86 has an associated valve member 88 and 90 respectively.
  • each valve member has two hole arrays to match the patterns of ports 84 and 86.
  • valve member 88 that would be arrays 92 and 94 and in valve member 90 it would be arrays 96 and 98.
  • Arrays 92 and 96 are open ports while arrays 94 and 98 have preferably a sintered metal filtration media but other types of screen materials such as wire mesh could also be used.
  • FIG. 24 position there is no array alignment with ports 84 or 86 rendering those ports closed.
  • the valve assemblies need not all be identical. Some can be two position with no closed position and others can be three position with a closed, fracture and screen positions, as required.
  • valve assemblies 88 or 90 The actual operation of valve assemblies 88 or 90 will be discussed below.
  • An external packer 100 is shown in the run in position. It can be one of a variety of packer styles and can be set by swelling or by expansion of string 80 with an adjustable swage, for example that can be run in through the work string 78 past valve assembly 88 to expand string 80 from inside in the region of the external packer 100. Other packer types are also envisioned.
  • the packer 100 is set to isolate portion 102 from portion 104 of the wellbore 70. Ports 84 and 86 are both closed.
  • FIG. 26 a work string 106 with a schematically illustrated shifter 108 is run into the wellbore 70 to put the array of openings 96 into alignment with matching array 86 so that segment 104 can be fractured. Openings 84 are still closed.
  • FIG. 27 shows the portion 104 of the wellbore 70 fully fractured and the string 106 repositioned and ready to align array 92 with array 84.
  • the frac job for portion 102 of the wellbore 70 uphole of packer 100 has been fractured.
  • the work string 106 has shifted up and is in position to be further manipulated to reposition valve assemblies 88 and 90 into a filtration position.
  • FIG. 29 shows the work string repositioned prior to movement of valve assemblies 88 and 90.
  • the work string 106 is removed and arrays 94 and 98 are respectively aligned with arrays 84 and 86.
  • the wellbore 70 can now go into production when a production string and a packer are set into position in string 80.
  • the string 78 that delivers the tubing string 80 can also do duty as a shifting device taking away any need to run a separate string 106 with a shifting device 108 on its lower end.
  • the same string that delivers string 80 can also shift valve assemblies 88 and 90 as described and ultimately with a proper external packer (not shown) can also serve as the production string after the valve assemblies 88 and 90 are in the filtration mode shown in FIG. 30.
  • the advantage of the method shown in FIGS. 24-30 is that screens and a crossover tool need not be run at all.
  • the fracturing job can be done in any sequence desired by moving valves in the right order and setting external packers to isolate ports such as 84 and 86 in the open hole using a packer such as 100 between pairs of hole arrays. From fracturing the well can go right to production through the filter media in the arrays such as 94 and 98 when aligned with respective arrays 84 and 86.
  • Removing the crossover tool reduces risks of its failure from erosion or from getting stuck and not assuming the squeeze and then the circulation positions it must be put into to do fracturing followed by gravel packing.
  • the elimination of the gravel packing also removes risks of bridging during gravel packing or complex structures such as bypass tubes in the annulus to get around sand bridges that form during gravel packing. Countless hours of rig time are saved as well as equipment charges to the well operator.
  • Valve assemblies such as 38 and 40 can be arranged for individual operation or for tandem operation, as needed. They can be locally actuated through a work string 56 with a shifting tool 101 or they can be locally powered or powered by applied pressure, pressure differential, locally mounted and powered motors or other ways.
  • FIG. 7 shows the movable sleeve 110 disposed in a recess 112 whose ends are defined by movable travel stops 114 and 116. Lower end 118 is against stop 116 in FIG. 7 and that puts both ports 120 that is unobstructed and ports 122 that have a filtration media preferably sintered metal 124 out of alignment with ports 126 of the tubular 128. This defines the closed position because a blank wall straddles seals 130 and 132 mounted to the tubular 128.
  • FIG. 7 shows the movable sleeve 110 disposed in a recess 112 whose ends are defined by movable travel stops 114 and 116. Lower end 118 is against stop 116 in FIG. 7 and that puts both ports 120 that is unobstructed and ports 122 that have a filtration media preferably sintered metal 124 out of alignment with ports 126 of the tubular 128. This defines the closed position because a blank wall straddles seals 130 and 132 mounted to the tubular 128.
  • FIG. 8 shows the sleeve 110 shifted so that upper end 134 is against stop 114 to get ports 120 into alignment with ports 126 to define the fracturing position.
  • a known shifting tool (not shown) can grab sleeve 110 at grooves 136 or 138 and move sleeve 110 in opposed directions for closing ports 126, as shown in FIG. 7, or putting them in a fully open and unobstructed position for fracturing, as shown in FIG. 8. It should be noted that with the stops 114 and 116 in the FIGS. 7 and 8 positions the ports 122 cannot be put into alignment with ports 126.
  • Stops 114 and 116 are rotatably mounted using threads 140 and 142 respectively. Stops 114 and 116 have a series of recesses schematically illustrated as 144 and 146 that allow a tool (not shown) to be run in and make contact there to rotate stops 114 and 116 about their respective threads 140 or 142 for repositioning of one or both stops as needed. In FIG. 9 both stops 114 and 116 have been shifted right or downhole. Sleeve 110 has moved in tandem with stop 140 but ports 126 are still closed. FIG. 10 shows sleeve 110 shifted with a tool (not shown) that attached at groove 138.
  • stops 114 and 116 could be eliminated and sleeve 110 can be secured in recess 112 by a thread so that rotating it advances it longitudinally or sleeve 110 can be connected by a rack and pinion and driven longitudinally in opposed directions by a locally mounted motor or a driving force provided from a running tool, hydrostatic pressure or applied pressure in the wellbore, to name a few examples.
  • Sleeve 110 can be made in pieces that move relative to each other so that instead of moving the travel stops 114 or 116 one portion of the sleeve 110 can be moved with respect to another to reposition the sleeve or openings thereon to achieve the same choice of positions for ports 126. Yet other modes of manipulation of the sleeve such as 110 will be described below.
  • FIG. 11 shows a valve member 148 in a housing 150 that has port arrays 152 and 154 for example.
  • Valve member 148 has unobstructed arrays 156 and 158 shown aligned with ports 152 and 154 to define the fracturing position.
  • the valve member 148 is secured to the housing 150 with a j-slot mechanism, two examples of which are illustrated in FIGS. 14 and 15.
  • One way of manipulating the valve member 148 is to use a shifting tool (not shown) and grab an internal recess 160 so that a pickup or set down force can be applied to sleeve 148 to move it to the FIGS.
  • FIG. 12 shows the valve member shifted from the FIG. 11 position so that ports 152 and 154 are obstructed by valve member 148 to define the fully closed position.
  • FIG. 13 shows port arrays 160 and 162 that carry a filtering material, preferably sintered metal, and now in alignment with ports 152 and 154 which is the ready for production position that is used after fracturing is complete. Fracturing occurs with the components in the FIG. 11 position. There are thus, three positions for the illustrated valve assembly which need definition in the j-slot mechanism. The j-stot in FIG.
  • valve 14 operates to change positions of the valve member 148 by a combination of a pick up and a set down of weight.
  • the pin (not shown) lands at the uppermost point 164 of the rolled open j- slot pattern shown in FIG. 14 the valve member 148 is in the FIG. 13 position for production with screening. In the 166 position, the valve member is in the fracturing position of FIG. 11. Finally, when the j-slot pin lands at position 168 the valve member 148 is in the closed position of FIG. 12.
  • the three positions can be obtained with a j-slot that uses pick up and hold at point 170 of FIG. 15 as the production with filtration position shown in FIG. 13.
  • Position 174 for the j-slot pin corresponds to the fracture position of FIG. 1 1 and position 172 corresponds to the closed position of FIG. 12.
  • valve member 148 Although a single sleeve is shown with two spaced arrays where at each location there are unobstructed and filtered ports there could be additional or fewer such arrays on a single valve member 148.
  • the closed position is optional. Movement of the valve member 148 can also be accomplished using pressure techniques as will be described below.
  • FIGS. 16-19 One such pressure technique is illustrated in FIGS. 16-19.
  • a housing 176 joined by threaded connections has an annular wall recess 178 in which is mounted a movable piston 180 that has seals 182 and 184 and a port 186 that leads into recess 178. Seals 188 and 190 allow the piston to reciprocate while holding pressure in recess 178.
  • Piston 180 divides recess 178 into variable volume cavities 192 and 194.
  • port 196 communicates with cavity 194.
  • Piston 180 is connected to valve member 198 that has an array of unobstructed openings 200 and an array of filtered openings 202.
  • a travel stop 204 defines the FIG.
  • Housing 176 also has a series of spaced projections 208, 210 and 212 that are preferably on a predetermined spacing.
  • Valve member 198 has a depression 214 shown in FIG. 17 to be registered with projection 208 to hold the position of FIG. 17 with ports 206 closed.
  • a running string 218 has an external seal 220 that is shown positioned between openings 186 and 196.
  • Piston 180 has a port 222 that permits pressure delivered through string 218 to go through port 196 and then through port 222 to reach cavity 194 to push piston 180 to the left or uphole. Movement of piston 180 uphole takes with it valve member 198 as recess 214 jumps over projections 208 and moves uphole until recesses 214 registers with projection 210. This position is shown in FIG. 18 and illustrates the alignment of array of filtration ports 202 with housing ports 206.
  • piston 180 can be reversed by simply applying pressure into annular space 226 to push down piston 180 while displacing fluid from cavity 194 through ports 222 and then 196 followed by a return into the string 218.
  • FIGS. 20-22 an alternative using applied pressure is illustrated in FIGS. 20-22.
  • the parts in the housing 176' are identical to the FIGS. 16-19 embodiment.
  • work string 230 has an internal sleeve 232 with a series of radial ports 234 that emerge between seals 236 and 238.
  • Annular cavities 240 and 242 are formed respectively between seal pairs 238 and 244 for cavity 242 and seals 236 and 246 for cavity 240.
  • Passage 248 fluidly connects cavities 240 and 242.
  • Passage 250 exits from cavity 242 through the wall of string 230 and above external seal 254.
  • Passage 252 exits cavity 240 between external seals 256 and 258.
  • Ports 234 provide a radial exit from within string 230 through its wall and between external seals 254 and 256. Assuming string 230 is closed or can be closed at its lower end 260 or the extension of the tubular housing 176' is closed to pressure below lower end 260, applying pressure in the Fig. 20 position directs pressure from ports 234 into cavity 192' to move the piston 180' as the cavity 192' gets bigger while cavity 194' gets smaller by displacing fluid through ports 222' followed by ports 196' followed by annulus 262, which is equalized with cavities 240 and 242. In this manner, the piston 180' can be advanced to its other positions as previously described.
  • ports 234 are now in fluid communication with ports 196' instead of 186' as in FIG. 20.
  • Ports 250 are now in communication with the annulus 262.
  • Pressure applied from string 230 through ports 234 communicates to ports 196' and then through ports 222' to push piston 180' in a direction to make cavity 194' larger in volume and cavity 192' smaller in volume.
  • the displaced fluid from cavity 192' goes through ports 186', then into cavity 240, then into cavity 242 through passage 248, then through ports 250 and into annulus 262.
  • the resulting movement of the valve member (not shown in FIGS. 20-22) is the same as described with regard to FIGS. 16-19.
  • FIG. 22 shows another way to get the same result as the position of the string 230 in FIG. 20.
  • the pressure is simply delivered out the lower end 260 and goes into ports 186'. From there, the pressure enlarges cavity 192' and displaces fluid from cavity 194' in series through ports 222', 196', 252, passage 248, ports 250 and into annular space 262.
  • the present invention allows for dual purpose ports in a tubular string that can accommodate fracturing and then be switched to filtration so that in an open hole completion, for example, there is no need to run in a screen assembly and a crossover tool.
  • the ports can be configured for fracturing in any order needed and can have external isolators in the open hole between them so as to allow different portions of the wellbore to be treated individually or together as needed and in any desired order. By the same token, different regions can be produced or shut off as needed.
  • the valve assembly can be two positions for fracturing and production or three positions by adding a closed position.
  • Trips to the well can be reduced further by using the same run in string to deliver the completion string, move the valves in it as needed and also serve as the production string after putting the required valves in production mode.
  • Different techniques can be used to actuate the valves including mechanical force, pressure and a j-slot combined with physical manipulation to name a few.
  • the elimination of a crossover tool and a screen section not only saves rig time but eliminates the operational risks that are associated with using crossover tools and gravel packing screens, such as erosion in the crossover tool and bridging in the gravel pack.
  • FIGS. 31-33 An alternative embodiment is illustrated in FIGS. 31-33.
  • the tubular 300 has a fracturing port array 302 and a filtration port array 304 with a filer media 306 associated with each port 304.
  • FIG. 32 shows the fracturing position
  • FIG. 33 shows the filtration position for production.
  • the present invention incorporates the option of using a common port on the tubular with the filter material on the sliding sleeve or having sets of ports on the tubular with the filter material on one set of tubular ports and the other set wide open for fracturing as illustrated in FIGS. 31-33.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Multiple-Way Valves (AREA)
  • Filtration Of Liquid (AREA)
  • Details Of Valves (AREA)

Abstract

Un tube de complétion est placé dans une position adjacente à la zone ou aux zones à fracturer et produire. Il présente de préférence des soupapes à manchon coulissant qui peuvent adopter au moins deux configurations : grand ouverte et ouverte avec un matériau de tamis juxtaposé dans le passage d'écoulement. Dans un mode de réalisation préféré, l'ensemble de soupape présente trois positions, une position entièrement fermée étant ajoutée aux deux autres mentionnées. Après le rodage, les soupapes peuvent être placées dans la position grande ouverte dans n'importe quel ordre souhaité en vue de la fracturation. Après la fracturation, les soupapes peuvent être fermées ou placées de manière sélective en position de filtration en vue de la production à partir des zones fracturées dans n'importe quel ordre souhaité. Diverses manières d'actionner les soupapes sont décrites. Le tube peut présenter des pistons télescopiques à travers lesquels la fracturation peut avoir lieu si l'application nécessite un tube cimenté. En variante, le tube peut se trouver dans un trou ouvert et présenter simplement des ouvertures pour le passage du fluide de fracturation et des isolateurs externes pour permettre la fracturation dans n'importe quel ordre souhaité.
PCT/US2008/072733 2007-08-13 2008-08-10 Soupape multi-position pour la fracturation et le contrôle du sable et procédés de complétion associés WO2009023611A2 (fr)

Priority Applications (6)

Application Number Priority Date Filing Date Title
PCT/US2008/072733 WO2009023611A2 (fr) 2007-08-13 2008-08-10 Soupape multi-position pour la fracturation et le contrôle du sable et procédés de complétion associés
BRPI0815177-6A BRPI0815177B1 (pt) 2007-08-16 2008-08-10 Válvula para uso em fundo do poço e método para completação
RU2010108946/03A RU2475626C2 (ru) 2007-08-16 2008-08-10 Многопозиционный клапан для гидроразрыва пласта и борьбы с пескопроявлением и способ заканчивания скважины
AU2008287022A AU2008287022B2 (en) 2007-08-13 2008-08-10 Multi-position valve for fracturing and sand control and associated completion methods
EP08797572A EP2185790A2 (fr) 2007-08-13 2008-08-10 Soupape multi-position pour la fracturation et le contrôle du sable et procédés de complétion associés
EG2010020226A EG25568A (en) 2007-08-13 2010-02-10 Multi-position valve for fracturing and sand control and associated completion methods

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US11/891,706 2007-08-13
US11/891,706 US7628210B2 (en) 2007-08-13 2007-08-13 Ball seat having ball support member
PCT/US2008/072733 WO2009023611A2 (fr) 2007-08-13 2008-08-10 Soupape multi-position pour la fracturation et le contrôle du sable et procédés de complétion associés

Publications (2)

Publication Number Publication Date
WO2009023611A2 true WO2009023611A2 (fr) 2009-02-19
WO2009023611A3 WO2009023611A3 (fr) 2009-04-16

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AU (1) AU2008287022B2 (fr)
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GB2453238B (en) * 2007-09-17 2010-04-07 Schlumberger Holdings A system for completing injector wells
EP2222936A2 (fr) * 2007-12-03 2010-09-01 Baker Hughes Incorporated Soupapes multipositions pour fissuration et procédés de second uvre associés au contrôle de sable
WO2011106579A3 (fr) * 2010-02-25 2013-02-21 Hansen Energy Solutions Llc Vanne de puits, système de puits et procédé de production de fluides de réservoir
US9523261B2 (en) 2011-08-19 2016-12-20 Weatherford Technology Holdings, Llc High flow rate multi array stimulation system
WO2018148426A1 (fr) * 2017-02-09 2018-08-16 Baker Hughes, A Ge Company, Llc Manchon baladeur actionné par pression sans intervention avec fonctionnement de secours avec intervention

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AU2008287022A1 (en) 2009-02-19
AU2008287022B2 (en) 2013-12-19
WO2009023611A3 (fr) 2009-04-16
EP2185790A2 (fr) 2010-05-19
EG25568A (en) 2012-02-28

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