WO2023119002A1 - Actionnement d'outil de fond de trou à cycle de pression - Google Patents

Actionnement d'outil de fond de trou à cycle de pression Download PDF

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Publication number
WO2023119002A1
WO2023119002A1 PCT/IB2022/061040 IB2022061040W WO2023119002A1 WO 2023119002 A1 WO2023119002 A1 WO 2023119002A1 IB 2022061040 W IB2022061040 W IB 2022061040W WO 2023119002 A1 WO2023119002 A1 WO 2023119002A1
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WO
WIPO (PCT)
Prior art keywords
pressure
assembly
downhole
pressure isolation
downhole tool
Prior art date
Application number
PCT/IB2022/061040
Other languages
English (en)
Inventor
Nauman H. MHASKAR
Ryan R. BACSIK
David Ward
Matthew L. Priesmeyer
Original Assignee
Weatherford Technology Holdings, Llc
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 Weatherford Technology Holdings, Llc filed Critical Weatherford Technology Holdings, Llc
Publication of WO2023119002A1 publication Critical patent/WO2023119002A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/04—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells

Definitions

  • This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in at least one example described below, more particularly provides for actuation of a downhole tool with multiple pressure cycles.
  • FIG. 1 is a representative partially cross-sectional view of an example of a downhole tool assembly and associated method which can embody principles of this disclosure.
  • FIG. 2 is a representative partially cross-sectional view of an example of a well system and associated method in which the downhole tool assembly can be incorporated, and which can embody the principles of this disclosure.
  • FIGS. 3A & B are representative cross-sectional views of successive axial sections of another example of the downhole tool assembly which can embody the principles of this disclosure.
  • FIGS. 4A-C are representative cross-sectional views of an example of a pressure reduction device in a series of configurations over a downhole fluid pressure cycle.
  • FIGS. 5A-C are representative cross-sectional views of an example of a pressure isolation module in a series of configurations over the downhole pressure cycle.
  • FIG. 6 is a representative cross-sectional view of an example of the pressure isolation module in a pressure isolation assembly of the downhole tool assembly.
  • FIG. 7 is a representative cross-sectional view of the downhole tool assembly with a downhole tool thereof in an actuated configuration.
  • FIG. 8 is a representative cross-sectional view of another example of the pressure isolation assembly.
  • FIG. 1 Representatively illustrated in FIG. 1 is a downhole tool assembly 10 and associated method which can embody principles of this disclosure.
  • the downhole tool assembly 10 and method are merely one example of an application of the principles of this disclosure in practice, and a wide variety of other examples are possible. Therefore, the scope of this disclosure is not limited at all to the details of the downhole tool assembly 10 and method described herein and/or depicted in the drawings.
  • the downhole tool assembly 10 is connected in a tubular string 12.
  • the tubular string 12 could be a casing, liner, segmented tubing, coiled tubing, pipe, drill, completion, stimulation, or other type of tubular string.
  • the downhole tool assembly 10 may not be connected in a tubular string.
  • the downhole tool assembly 10 includes a pressure isolation assembly 14 and a pressure actuated downhole tool 16.
  • the pressure isolation assembly 14 isolates the downhole tool 16 (or a portion thereof) from pressure in a downhole environment, until it is desired to actuate the downhole tool.
  • the downhole tool 16 may be any type of pressure actuated downhole tool.
  • pressure actuated downhole tools include, but are not limited to, packers, valves, gravel packing equipment, stimulation equipment, directional drilling equipment, etc.
  • the scope of this disclosure is not limited to use of any particular type of downhole tool in a downhole tool assembly.
  • the pressure isolation assembly includes four pressure isolation modules 18a-d connected in series. Any number of pressure isolation modules may be used in a pressure isolation assembly in keeping with the principles of this disclosure.
  • the pressure isolation modules 18a-d prevent downhole fluid pressure (indicated by arrow 20) from being communicated to the downhole tool 16, until it is desired to actuate the downhole tool.
  • the fluid pressure 20 is delivered via an internal flow passage 22 of the tubular string 12 (such as, from a pump or other pressure source connected to the tubular string).
  • the fluid pressure (indicated by arrow 24) could be delivered via an exterior of the tubular string 12 (such as, in an annulus formed between the tubular string 12 and a wellbore or another tubular string (not shown) surrounding the tubular string 12).
  • the fluid pressure could be delivered via a sidewall of the tubular string 12, or via a capillary or control line.
  • the scope of this disclosure is not limited to any particular technique for delivering the fluid pressure to the pressure isolation assembly 14.
  • the pressure isolation modules 18a-c block the flow passage 22 to thereby isolate the downhole tool 16 from the fluid pressure 20.
  • the flow passage 22 may extend through the pressure isolation assembly 14 and may extend through the downhole tool 16.
  • one portion of the downhole tool 16 may be exposed to the fluid pressure 20 without regard to a configuration of the pressure isolation assembly 14, in which case the pressure isolation assembly may isolate another portion of the downhole tool (such as, an actuator) from the fluid pressure 20 until it is desired to actuate the downhole tool.
  • the downhole tool 16 could be actuated by the fluid pressure 24 external to the tubular string 12, in which case the pressure isolation assembly 14 could isolate an internal portion of the downhole tool from the fluid pressure 24, until it is desired for the downhole tool to be actuated.
  • the pressure isolation modules 18a-d are connected in series in the pressure isolation assembly 14.
  • the pressure isolation modules 18a-d are all initially closed.
  • the pressure isolation modules 18a-d can be opened in succession (18a first, then 18b, then 18c, then 18d) in response to respective downhole fluid pressure cycles applied to the pressure isolation assembly 14 (such as, via the flow passage 22).
  • the downhole tool 16 can be actuated by the fluid pressure 20 delivered via the flow passage 22.
  • the number of the pressure isolation modules 18a-d is equal to the number of pressure cycles required to communicate the fluid pressure 20 to the downhole tool 16, since each of the pressure isolation modules can be opened in response to application of a single pressure cycle to the pressure isolation module.
  • a pressure isolation module may be opened by application of multiple pressure cycles.
  • the pressure isolation modules 18a-d are “modular” in that they are all the same or similarly configured for convenient selection and installation of varying numbers of the modules in the pressure isolation assembly 14. It may be desirable for different numbers of the pressure isolation modules to be used in corresponding different well operations.
  • the pressure isolation assembly 14 For example, in one well operation it may be desired for six pressure cycles to be applied to the pressure isolation assembly 14 before the downhole tool 16 is actuated, and in another well operation it may be desired for five pressure cycles to be applied before the downhole tool is actuated.
  • the modular characteristic of the pressure isolation modules permits the number to be changed conveniently and without a need to produce and inventory separate pressure isolation assemblies for each corresponding number of desired pressure cycles.
  • a pressure cycle used to open each of the pressure isolation modules 18a-d consists of a single fluid pressure increase to a level greater than a predetermined pressure, followed by a single fluid pressure decrease to a level less than another predetermined pressure.
  • the predetermined pressures could be the same, but in most examples the predetermined pressure for the pressure increase will be greater than the predetermined pressure for the pressure decrease.
  • the pressure isolation assembly 14 is connected to, but separate from, the downhole tool 16.
  • the pressure isolation assembly 14 and the downhole tool 16 could be integrated (such as, by sharing a common outer or inner housing, etc.).
  • the scope of this disclosure is not limited to any particular configuration of the pressure isolation assembly and the downhole tool.
  • FIG. 2 well system 30 and method utilize the downhole tool assembly 10.
  • the downhole tool assembly 10 can be used in other well systems and other methods, in keeping with the scope of this disclosure.
  • the downhole tool assembly 10 is connected in the tubular string 12.
  • the tubular string 12 is a casing string used to line a wellbore 32.
  • FIG. 2 For clarity of illustration, only a single casing string is shown in FIG. 2, but in actual practice multiple casing strings and perhaps liner strings may be installed in the wellbore 32.
  • the casing and/or liner strings may be cemented in the wellbore 32.
  • a section of the wellbore 32 in which the principles of this disclosure are practiced may be uncased or open hole.
  • the scope of this disclosure is not limited to any particular details of the well system 30 as depicted in FIG. 2 or described herein.
  • the downhole tool assembly 10 is used as an initially closed “toe” valve connected near a distal end of the tubular string 12 in a lateral section of the wellbore 32. It is desired in this example to be able to open the toe valve prior to conducting a stimulation operation (such as, acidizing, fracturing, etc.), using fluid pressure 20 supplied by a surface pump 34.
  • a stimulation operation such as, acidizing, fracturing, etc.
  • the toe valve may be subject to application of one or more pressure increases during installation, cementing and pressure testing of the tubular string 12, and so it would be difficult to construct the toe valve so that it would not open when the tubular string is installed, cemented and pressure tested, but so that it would open when a subsequent pressure increase is applied.
  • the downhole tool assembly 10 solves this problem by requiring a selected number of pressure cycles to be applied prior to actuating the toe valve. In this manner, the toe valve will remain closed while the tubular string 12 is installed, cemented and pressure tested, and the toe valve will open when a pressure increase is applied after the selected number of pressure cycles are applied.
  • FIGS. 3A & B more detailed cross-sectional views of an example of the downhole tool assembly 10 are representatively illustrated.
  • the FIGS. 3A & B downhole tool assembly 10 may be used for the toe valve in the FIG. 2 well system and method, or it may be used for other purposes in other well systems and methods.
  • the downhole tool 16 in this example comprises a valve that selectively permits fluid communication between the internal flow passage 22 and an exterior of the downhole tool.
  • Ports 36 (only one of which is visible in FIG. 3A) are formed through a generally tubular outer housing 38.
  • An inner sleeve 40 initially blocks flow through the ports 36.
  • the inner sleeve 40 is releasably secured against displacement relative to the outer housing 38 by shear screws 42. Seals 44, 46 straddling the ports 36 prevent leakage of fluid between the outer housing 38 and the inner sleeve 40. An atmospheric chamber 48 is isolated between the seals 44 and seals 50 carried near an upper end of the inner sleeve 40.
  • An annular fluid passage 52 is formed at a lower end of the inner sleeve 40, radially between the outer housing 38 and a generally tubular housing 54 of the pressure isolation assembly 14. An upper end of the housing 54 is sealingly received in the inner sleeve 40.
  • the pressure isolation assembly 14 prevents application of downhole fluid pressure 20 to the fluid passage 52, until a selected number of pressure cycles have been applied to the pressure isolation assembly, and so in this example the pressure isolation assembly prevents the downhole tool 16 from opening until after the selected number of pressure cycles have been applied.
  • the pressure isolation assembly 14 includes three pressure isolation modules 18a-c arranged in series in a sidewall of the housing 54. Other numbers of the pressure isolation modules 18a-c may be used in other examples.
  • the FIG. 3B pressure isolation assembly 14 further includes a pressure reduction device 60 that functions to reduce the pressure applied to the pressure isolation modules 18a-c downhole. Thus, only a fraction of the downhole fluid pressure 20 is applied to the modules 18a-c in this example.
  • a rupture disk 62 prevents fluid communication between the flow passage 22 and a piston assembly 64 of the pressure reduction device 60, until the fluid pressure 20 exceeds a predetermined level.
  • the rupture disk 62 is ruptured, the fluid pressure 20 is applied to a lower end of the piston assembly 64 to thereby bias the piston assembly upward against a downwardly directed biasing force exerted by a biasing device 66 (such as, a compression spring).
  • FIGS. 4A-C cross-sectional views of the pressure reduction device 60 are representatively illustrated. In these views, a pressure cycle is applied to the pressure reduction device 60 after the rupture disk 62 has been ruptured.
  • the rupture disk 62 has not yet been ruptured.
  • the biasing device 66 maintains the piston assembly 64 at its lowermost position in a housing 68 of the pressure reduction device 60.
  • the piston assembly 64 includes a downwardly facing piston 70 and an upwardly facing piston 72.
  • the piston 70 is exposed to pressure in an annular space 74 formed between the housing 68 and another housing 76 in which the rupture disk 62 is installed (see FIG. 3B).
  • the downhole fluid pressure 20 is communicated to the annular space 74 when the rupture disk 62 is ruptured.
  • the piston 72 is exposed to an annular chamber 78 formed radially between the housing 68 and an inner mandrel 80.
  • the chamber 78 is filled with a clean fluid (such as, a hydraulic fluid suitable for use at downhole temperatures and pressures). In this manner, debris that may be in the flow passage 22 is prevented from passing through the pressure reduction device 60 to the pressure isolation modules 18a-c (see FIG. 3B) after the rupture disk 62 is ruptured.
  • the rupture disk 62 has been ruptured.
  • the increased fluid pressure 20 is communicated via the annular space 74 to the piston 70.
  • the piston assembly 64 is displaced upward against the biasing force exerted by the biasing device 66.
  • the upward displacement of the piston 72 forces the fluid in the chamber 78 to flow through a filter 82 into a fluid passage 84 in the housing 54.
  • the fluid passage 84 extends to the first pressure isolation module 18a (see FIG. 3B).
  • the piston 70 has a smaller piston area as compared to the piston 72.
  • the pressure applied to the chamber 78 by the upward displacement of the piston 72 is less than the fluid pressure 20 applied to the piston 70. That is, since the ratio of the piston areas of the pistons 70, 72 is less than one, the ratio of pressures acting on the pistons is greater than one.
  • the reduced pressure applied to the chamber 78 means that, when the fluid pressure 20 is reduced, the biasing device 66 does not have to exert as much force against the piston assembly 64 in order to return it to its initial position as it would otherwise have to exert. Similarly, biasing devices 94 of the pressure isolation modules 18a-c described below do not have to exert as much biasing force as they would have to if the pressure were not reduced.
  • the fluid pressure 20 has been decreased at the end of the pressure cycle.
  • the biasing device 66 has displaced the piston assembly 72 back to its initial position.
  • FIGS. 5A-C cross-sectional views of an example of a pressure isolation module 18 are representatively illustrated. These views show the pressure isolation module 18 in a series of configurations during a pressure cycle.
  • the FIGS. 5A-C pressure isolation module 18 may be used for any of the pressure isolation modules 18a-d described herein or shown in the drawings.
  • the pressure isolation module 18 includes a piston 86 sealingly received in a generally tubular housing 88.
  • a seal 90 carried near an upper end of the piston 86 is sealingly engaged with a seal bore 92 formed in an upper portion of the housing 88.
  • a seal 98 carried on the housing 88 seals between the housing 88 and a seal bore 100 formed in the sidewall of the housing 54 (see FIG. 6).
  • a fluid passage 102 is formed longitudinally through the housing 88. Initially, the piston 86 prevents flow through the fluid passage 102.
  • a biasing device 94 (such as, a compression spring) exerts a downwardly directed biasing force against the piston 86.
  • the piston 86 is releasably secured against displacement relative to the housing 88 by shear pins 96.
  • the rupture disk 62 (see FIG. 3B) has not yet been ruptured.
  • the shear pins 96 prevent the piston 86 from being displaced downward by the biasing device 94.
  • the rupture disk 62 has been ruptured by an increase in the fluid pressure 20 applied to the pressure reduction device 60 via the flow passage 22.
  • a reduced fluid pressure 20a (a fraction of the fluid pressure 20 corresponding to a ratio of the piston 70 piston area to the piston 72 piston area) is applied to the fluid passage 102 below the piston 86. Note that, if the pressure reduction device 60 is not used, then the fluid pressure applied to the fluid passage 102 will be the same as the fluid pressure 20 in the flow passage 22.
  • the shear pins 96 shear and allow the piston 86 to be displaced upward against the biasing force exerted by the biasing device 94. Due to the upward displacement of the piston 86, the biasing device 94 is compressed in the housing 88. The piston 86 remains sealingly received in the seal bore 92.
  • the fluid pressure 20 has been decreased, which also decreases the fluid pressure 20a applied to the lower end of the piston 86.
  • the biasing device 94 can displace the piston 86 downwardly relative to the housing 88, until the piston is no longer sealingly received in the seal bore 92.
  • fluid pressure 20a can now be communicated through the housing 88 via the fluid passage 102.
  • the seal 90 on the piston 86 is positioned in an enlarged bore 104, which enables fluid to flow through a space radially between the seal 90 and the bore 104.
  • Fluid passages 106 are formed in a lower portion of the piston 86 to enable fluid to flow through the lower portion of the piston.
  • the pressure isolation module 18 is open and allows fluid communication between the upper and lower ends of the housing 88. If another pressure isolation module 18 is connected above the FIG. 5C pressure isolation module, then the fluid pressure 20a can now be communicated to the pressure isolation module connected above the FIG. 5C pressure isolation module. Note that such pressure communication is not permitted in the FIGS. 5A & B configurations of the pressure isolation module 18.
  • FIG. 6 a cross-sectional view of the pressure isolation module 18c in the pressure isolation assembly 14 of the downhole tool assembly 10 is representatively illustrated.
  • the pressure isolation module 18c has not yet been opened. Since the pressure isolation modules 18a- c are connected in series (see FIG. 3B), the pressure isolation module 18c cannot be opened with a pressure cycle until the pressure isolation module 18b is opened with a pressure cycle, and the pressure isolation module 18b cannot be opened with a pressure cycle until the pressure isolation module 18a is opened with a pressure cycle.
  • a plug 108 is sealingly received in the seal bore 100 and is releasably secured with a shear screw 110.
  • the plug 108 prevents fluid communication between the fluid passage 102 in the pressure isolation module 18c and the fluid passage 52 in the annular space between the housings 38, 54.
  • the pressure isolation module 18c When the pressure isolation module 18c is opened in response to the application of a third pressure cycle, a lower end of the plug 108 will be exposed to the fluid pressure 20a (see FIGS. 5B & C), or the fluid pressure 20 if the pressure reduction device 60 is not used. If a sufficient fluid pressure is subsequently applied through the open pressure isolation modules 18a-c, the shear screw 110 will shear and thereby allow the plug 108 to be ejected upwardly out of the seal bore 100. At that point, the fluid pressure 20a (or 20) will be communicated to the fluid passage 52 and the downhole tool 16 can be actuated by the fluid pressure as described above.
  • FIG. 7 a cross-sectional view of the downhole tool assembly 10 is representatively illustrated.
  • the pressure isolation modules 18a-c have all been opened, the shear screw 110 has sheared and the plug 108 has been displaced upward and out of the seal bore 100, and a subsequent increase in the fluid pressure 20 has been applied to cause the inner sleeve 40 to displace upward.
  • Flow is now permitted through the ports 38 between the flow passage 22 and an exterior of the downhole tool 16.
  • FIG. 8 a cross-sectional view of another example of the downhole tool assembly 10 is representatively illustrated.
  • the pressure reduction device 60 is not used. Instead, when the rupture disk 62 is ruptured, the fluid pressure 20 is communicated directly to the lower end of the first pressure isolation module 18a. When all of the pressure isolation modules 18a-c have been opened by application of three pressure cycles, the fluid pressure 20 is communicated to the plug 108. A subsequent sufficient pressure increase will cause the downhole tool 16 to be actuated due to communication of the fluid pressure 20 to the fluid passage 52.
  • the downhole tool assembly 10 described above allows for multiple pressure cycles to be applied before the downhole tool 16 is actuated by downhole fluid pressure 20.
  • the number of pressure cycles can be varied by varying the number of pressure isolation modules 18 connected in series in the pressure isolation assembly 14.
  • the pressure isolation assembly 14 can comprise multiple pressure isolation modules 18 arranged in series and configured to isolate the pressure actuated downhole tool 16 from a downhole fluid pressure 20a or 20.
  • Each of the pressure isolation modules 18 is configured to open in response to a single pressure cycle comprising an increase in the downhole fluid pressure 20a or 20 followed by a decrease in the downhole fluid pressure 20a or 20.
  • Each of the pressure isolation modules 18 may have a first configuration (see FIG. 5A) in which pressure communication through the pressure isolation module 18 is prevented and the downhole fluid pressure 20a or 20 is less than a first predetermined level, a second configuration (see FIG. 5B) in which pressure communication through the pressure isolation module 18 is prevented and the downhole fluid pressure 20a or 20 is greater than the first predetermined level, and a third configuration (see FIG. 5C) in which pressure communication through the pressure isolation module 18 is permitted and the downhole fluid pressure 20a or 20 is less than a second predetermined level.
  • Each of the pressure isolation modules 18 may comprise a piston 86 sealingly received in a bore 92, and a release member (e.g., shear pins 96) configured to release the piston 86 for displacement relative to the bore 92 in response to a predetermined pressure applied to the piston 86.
  • Each of the pressure isolation modules 18 may further comprise a biasing device 94 configured to displace the piston 86 to a position in which pressure communication through the bore 92 is permitted.
  • the pressure isolation assembly 14 may include a pressure reduction device 60 configured to apply a fraction of the downhole fluid pressure 20 to the pressure isolation modules 18.
  • the fraction is preferably less than one.
  • the pressure reduction device 60 may include first and second piston areas.
  • the fraction may be a ratio of the first and second piston areas.
  • a number of the pressure isolation modules 18 in the pressure isolation assembly 14 may equal a number of the pressure cycles necessary to enable actuation of the downhole tool 16 with the downhole fluid pressure 20a or 20.
  • the downhole tool assembly 10 can comprise: a pressure actuated downhole tool 16 configured to actuate in response to application of a downhole fluid pressure 20 to the downhole tool assembly 10; and a pressure isolation assembly 14 that isolates a fluid passage 52 of the downhole tool 16 from the downhole fluid pressure 20a or 20.
  • the pressure isolation assembly 14 is configured to permit communication of at least a fraction of the downhole fluid pressure 20 to the fluid passage 52 in response to application of a predetermined number of pressure cycles to the pressure isolation assembly 14.
  • Each of the pressure cycles comprises a single increase in the downhole fluid pressure 20 followed by a single decrease in the downhole fluid pressure 20.
  • the pressure isolation assembly 14 may include multiple pressure isolation modules 18 arranged in series.
  • the multiple pressure isolation modules 18 may include at least first and second pressure isolation modules 18a,b.
  • the first pressure isolation module 18a may be configured to isolate the second pressure isolation module 18b from the downhole fluid pressure 20a or 20 until a first one of the pressure cycles is applied.
  • the number of the pressure cycles may be equal to a number of the pressure isolation modules 18.
  • Each of the pressure isolation modules 18 may be configured to open in response to application of a respective one of the pressure cycles.
  • Each of the pressure isolation modules 18 may be configured to open in response to the decrease in the downhole fluid pressure of the respective one of the pressure cycles.
  • the pressure isolation assembly 14 may include a pressure reduction device 60 configured to apply the fraction of the downhole fluid pressure 20 to the downhole tool 16.
  • the fraction may be less than one.
  • the method comprises: determining a number of downhole fluid pressure cycles to apply in a subterranean well to enable actuation of a downhole tool 16; installing a number of pressure isolation modules 18 in a pressure isolation assembly 14, the number of pressure isolation modules 18 corresponding to the number of pressure cycles; deploying the downhole tool 16 and the pressure isolation assembly 14 into the well while the pressure isolation assembly 14 isolates a fluid passage 52 of the downhole tool 16 from downhole fluid pressure 20a or 20; and applying the number of pressure cycles in the well, the pressure isolation assembly 14 thereby permitting communication of at least a fraction of the downhole fluid pressure 20 to the fluid passage 52.
  • the installing step may include connecting the pressure isolation modules 18 in series in the pressure isolation assembly 14.
  • the applying step may include opening each of the pressure isolation modules 18 in response to application of a respective one of the pressure cycles.
  • the applying step may include opening each of the pressure isolation modules 18 in response to a downhole fluid pressure decrease of the respective one of the pressure cycles.
  • Each of the pressure cycles may comprise a single downhole fluid pressure increase followed by a single downhole fluid pressure decrease.
  • the applying step may include applying the fraction of the downhole fluid pressure 20 to the pressure isolation modules 18, the fraction being less than one.

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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)
  • Fluid-Pressure Circuits (AREA)

Abstract

La présente invention concerne un ensemble d'isolement de pression qui peut comprendre de multiples modules d'isolement de pression agencés en série et isole un outil de fond de trou actionné par pression d'une pression de fluide de fond de trou. Chacun des modules peut être conçu pour s'ouvrir en réponse à un cycle de pression unique comprenant une augmentation de la pression de fluide de fond de trou suivie d'une diminution de la pression de fluide de fond de trou. Un procédé peut consister à déterminer un certain nombre de cycles de pression de fluide à appliquer pour permettre l'actionnement d'un outil de fond de trou ; à installer un certain nombre de modules d'isolement de pression dans un ensemble d'isolement de pression, le nombre correspondant au nombre de cycles de pression ; à déployer l'outil de fond de trou et l'ensemble d'isolement de pression tandis que l'ensemble d'isolement de pression isole un passage de fluide de l'outil de fond de trou de la pression de fluide de fond de trou ; et à appliquer le nombre de cycles de pression, permettant ainsi la communication d'au moins une fraction de la pression de fluide de fond de trou au passage de fluide.
PCT/IB2022/061040 2021-12-21 2022-11-16 Actionnement d'outil de fond de trou à cycle de pression WO2023119002A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US17/558,426 2021-12-21
US17/558,426 US20230193719A1 (en) 2021-12-21 2021-12-21 Pressure cycle downhole tool actuation

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WO2023119002A1 true WO2023119002A1 (fr) 2023-06-29

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Citations (8)

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US20070056724A1 (en) * 2005-09-14 2007-03-15 Schlumberger Technology Corporation Downhole Actuation Tools
US7337850B2 (en) * 2005-09-14 2008-03-04 Schlumberger Technology Corporation System and method for controlling actuation of tools in a wellbore
US20110011597A1 (en) * 2009-07-15 2011-01-20 Baker Hughes Incorporated Tubular valve system and method
US20110209873A1 (en) * 2010-02-18 2011-09-01 Stout Gregg W Method and apparatus for single-trip wellbore treatment
US8188881B2 (en) * 2008-03-26 2012-05-29 Schlumberger Technology Corporation System and method for controlling multiple well tools
US8757274B2 (en) * 2011-07-01 2014-06-24 Halliburton Energy Services, Inc. Well tool actuator and isolation valve for use in drilling operations
US20190292862A1 (en) * 2018-03-21 2019-09-26 Baker Hughes, A Ge Company, Llc Actuation trigger
US20210102433A1 (en) * 2019-10-02 2021-04-08 Halliburton Energy Services, Inc. Pressure cycle device

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070056724A1 (en) * 2005-09-14 2007-03-15 Schlumberger Technology Corporation Downhole Actuation Tools
US7337850B2 (en) * 2005-09-14 2008-03-04 Schlumberger Technology Corporation System and method for controlling actuation of tools in a wellbore
US8188881B2 (en) * 2008-03-26 2012-05-29 Schlumberger Technology Corporation System and method for controlling multiple well tools
US20110011597A1 (en) * 2009-07-15 2011-01-20 Baker Hughes Incorporated Tubular valve system and method
US20110209873A1 (en) * 2010-02-18 2011-09-01 Stout Gregg W Method and apparatus for single-trip wellbore treatment
US8757274B2 (en) * 2011-07-01 2014-06-24 Halliburton Energy Services, Inc. Well tool actuator and isolation valve for use in drilling operations
US20190292862A1 (en) * 2018-03-21 2019-09-26 Baker Hughes, A Ge Company, Llc Actuation trigger
US20210102433A1 (en) * 2019-10-02 2021-04-08 Halliburton Energy Services, Inc. Pressure cycle device

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