WO2002020942A1 - Systeme de commande hydraulique pour outils de fond de trou - Google Patents

Systeme de commande hydraulique pour outils de fond de trou Download PDF

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Publication number
WO2002020942A1
WO2002020942A1 PCT/US2000/024551 US0024551W WO0220942A1 WO 2002020942 A1 WO2002020942 A1 WO 2002020942A1 US 0024551 W US0024551 W US 0024551W WO 0220942 A1 WO0220942 A1 WO 0220942A1
Authority
WO
WIPO (PCT)
Prior art keywords
flowpath
pressure
control module
flowpaths
piston
Prior art date
Application number
PCT/US2000/024551
Other languages
English (en)
Inventor
Jimmie R. Williamson, Jr.
Virgilio Garcia-Soule
Perry C. Shy
Leo G. Collins
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 PCT/US2000/024551 priority Critical patent/WO2002020942A1/fr
Priority to AU2000271216A priority patent/AU2000271216A1/en
Priority to US09/931,322 priority patent/US6668936B2/en
Publication of WO2002020942A1 publication Critical patent/WO2002020942A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/004—Indexing systems for guiding relative movement between telescoping parts of downhole tools
    • E21B23/006—"J-slot" systems, i.e. lug and slot indexing mechanisms
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E21B21/103—Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E21B47/07—Temperature

Definitions

  • the present invention relates generally to methods and apparatus utilized in conjunction with subterranean wells and, in an embodiment described herein, more particularly provides a hydraulic control system for downhole tools.
  • a hydraulic control system which reduces the number of control lines extending relatively long distances to multiple well tool assemblies.
  • Well tool assemblies and methods of controlling operation of multiple well tool assemblies are also provided.
  • a control module is interconnected between a flowpath extending to a remote location, such as the surface, and flowpaths extending to multiple well tool assemblies.
  • the control module provides fluid communication between the flowpath extending to the remote location and selected ones of the flowpaths extending to the well tool assemblies, so that corresponding selected ones of the well tool assemblies may be operated by pressure in the flowpath extending to the remote location.
  • control module is operated to select from among the flowpaths extending to the well tool assemblies by pressure in another flowpath connected to the control module.
  • another flowpath may be connected to the control module to provide a pressure differential used to operate the control module.
  • a ratchet device or J-slot mechanism is used to control displacement of a member of the control module.
  • a member of the control module is displaced against a force exerted by a biasing device, such as a spring or a compressed fluid.
  • various well tool assemblies are provided, which may be operated by the disclosed hydraulic control systems.
  • a variable flow area sliding sleeve-type valve is disclosed. The valve is operated by applying a series of pressures to an actuator thereof to incrementally displace a sleeve of the valve. As the sleeve displaces, the available area for fluid flow through the valve is increased or decreased.
  • a temperature sensor and a pressure sensor are a temperature sensor and a pressure sensor.
  • Each of the sensors is operated by pressure in a flowpath thereof displacing a piston to a position in which the flowpath is placed in fluid communication with another flowpath.
  • the position of the piston corresponds to a known volume of a chamber in which a fluid exposed to the temperature is disposed.
  • the position of the piston corresponds to a known pressure differential between the flowpath and another flowpath exposed to the piston.
  • FIG. 1 is a schematic view of a method embodying principles ofthe present invention
  • FIGS. 2A-C are cross-sectional views of successive axial portions of a hydraulic control module usable in the method of FIG. 1 and embodying principles ofthe present invention
  • FIG. 3 is a developed view of a J-slot portion of the hydraulic control module
  • FIG.4 is an end view of the hydraulic control module
  • FIGS. 5A-5C are cross-sectional views of successive axial portions of the hydraulic control module in a configuration in which a hydraulic path has been selected for operation of a well tool
  • FIG. 6 is a developed view of the J-slot portion of the hydraulic control module in a configuration corresponding to the configuration of the hydraulic control module of FIGS.5A-C;
  • FIG. 7 is a schematic partially cross-sectional view of an alternate configuration of the method of FIG. 1 in which a selector module is utilized in conjunction with the hydraulic control module;
  • FIGS. 8A-C are cross-sectional views of successive axial portions of a well tool assembly embodying principles of the present invention, which may be utilized in the method of FIG. 1, and the operation of which may be controlled by the hydraulic control module of FIGS. 2A-C;
  • FIG. 9 is a schematic cross-sectional view of another hydraulic control module embodying principles of the present invention, which may be utilized in the method of FIG. 1;
  • FIG. 10 is a cross-sectional view of the hydraulic control module of FIG. 9, taken along line 10-10 thereof;
  • FIG. 11 is a schematic cross-sectional view of another well tool assembly embodying principles of the present invention, which may be utilized in the method of FIG. 1, and the operation of which may be controlled by the hydraulic control module of FIG. 9.
  • FIG. 1 Representatively illustrated in FIG. 1 is a method 10 which embodies principles of the present invention.
  • directional terms such as
  • multiple well tool assemblies 12, 14, 16, 18 are interconnected in a tubular string 20 positioned in a wellbore 22.
  • each of the tool assemblies 12, 14, 16, 18 is hydraulically operated and is configured for controlling fluid flow between the wellbore 22 and one of multiple formations or zones 24, 26, 28, 30 intersected by the wellbore.
  • the tool assemblies 12, 14, 16, 18 may be, for example, valves, chokes, or some other type of flow control devices.
  • FIG. 1 Four of the tool assemblies 12, 14, 16, 18 are shown in FIG. 1 for controlling fluid flow for four corresponding zones 24, 26, 28, 30.
  • any number of well tool assemblies may be utilized in a wellbore intersecting any number of zones, and well tool assemblies other than flow control devices may be utilized, without departing from the principles of the present invention.
  • the method 10 is merely illustrative of one example of an application of the principles of the present invention.
  • Operation of selected ones of the tool assemblies 12, 14, 16, 18 is controlled by a hydraulic control module 32 interconnected in the tubular string 20.
  • One or more control lines 34, or other type of flowpaths extend to a remote location, such as the earth's surface, or to a remote location within the wellbore 22, etc.
  • the control module 32 places one or more of the control lines 34 in fluid communication with one or more lines 36, or other types of flowpaths, extending to the tool assemblies 12, 14, 16, 18 when it is desired to operate selected ones of the tool assemblies, for example, to open or close one or more of the tool assemblies.
  • the control module 32 is interconnected between the lines 34 and the lines 36 and operates in response to pressure in one or more of the lines 34. For example, pressure in one of the lines 34 may be increased to thereby provide fluid commumcation between another one of the lines 34 and one or more of the lines
  • a pressure differential between two of the lines 34 maybe used to cause the control module 32 to provide fluid communication between another one of the lines 34 and one or more of the lines 36.
  • a series of pressure differentials maybe applied to the lines 34 to select certain one or more of the lines 36 for fluid communication with certain one or more of the lines 34, etc.
  • the control module 38 maybe utilized for the control module 32 in the method 10, or the control module 38 maybe used in other methods, without departing from the principles of the present invention.
  • the control module 38 is configured for interconnection in a tubular string, such as the tubular string 20 of the method 10, in which case an internal flow passage 40 of the control module would be a part of the internal flow passage of the tubular string, but it is to be clearly understood that the control module may be differently configured, for example, as an integral portion of an actuator or other well tool, without departing from the principles of the present invention.
  • the control module 38 includes an outer housing assembly 42, an inner sleeve member 44 and a ratchet device 46.
  • the sleeve 44 is axially reciprocably disposed within the housing 42. Displacement of the sleeve 44 relative to the housing 42 is controlled in part by the ratchet device 46 in a manner described in further detail below.
  • the sleeve 44 has piston areas formed externally on opposite sides of a seal 48.
  • a flowpath 50 is in fluid communication with the sleeve piston area below the seal 48, and a flowpath 52 is in fluid communication with the sleeve piston area above the seal. It will be readily appreciated by one skilled in the art that, if pressure in the flowpath 50 exceeds pressure in the flowpath 52, the sleeve 44 will be biased upwardly by the pressure differential, and if pressure in the flowpath 52 exceeds pressure in the flowpath 50, the sleeve 44 will be biased downwardly by the pressure differential.
  • the sleeve piston areas above and below the seal 48 are approximately equal, and so the sleeve 44 is displaced with equal force in either direction in response to equal differentials between pressure in the flowpath 50 and pressure in the flowpath 52.
  • the manner of displacing the sleeve 44 and its response to differentials between pressure in the flowpath 50 and pressure in the flowpath 52 may be readily changed by, for example, providing unequal piston areas, providing biasing devices, such as springs or compressed fluids, etc., as desired to produce certain forces on, or displacements of, the sleeve.
  • the sleeve 44 may be displaced by use of a pressure differential between flowpaths, or for the sleeve to be displaced by use of a pressure differential at all.
  • pressure in the flowpath 50 may be used to displace the sleeve 44 against a force exerted by a biasing device.
  • the sleeve 44 may be displaced in any manner, without departing from the principles ofthe present invention.
  • the sleeve 44 has a fluid passage 54 formed internally in a sidewall thereof.
  • the fluid passage 54 communicates with the exterior of the sleeve 44 via two openings 56, 58.
  • the fluid passage 54 remains in fluid communication with another flowpath 60 formed in the housing 42 via the opening 56 as the sleeve 44 displaces relative to the housing.
  • the other opening 58 is placed in fluid communication with one of the flowpath 60 or additional flowpaths 62, 64, 66, 68 formed in the housing 42, depending upon the position of the sleeve 44 relative to the housing.
  • FIG. 2C Of the flowpaths 62, 64, 66, 68, only the flowpath 68 is completely visible in FIG. 2C. Portions of the flowpaths 62, 64, 66 are shown in FIGS. 2B & C, so that it may be seen how the flowpaths 62, 64, 66, 68 are arranged in relation to seals 70 and the opening 58 of the sleeve 44.
  • a lower end view of the control module 38 is shown in FIG. 4, in which it may be seen that the flowpaths 62, 64, 66, 68 are actually circumferentially distributed in the housing 42.
  • the fluid passage 54 is in fluid communication with only the flowpath 60 via the openings 56, 58.
  • the fluid passage 54 will be placed in fluid communication with the flowpath 62, and will thereby provide fluid communication between the flowpaths 60 and 62.
  • the opening 58 may be positioned between the seals 70 straddling each one of the other flowpaths 64, 66, 68 to thereby provide fluid communication between that flowpath and the flowpath 60.
  • the sleeve 44 is displaced relative to the housing 42 by pressure differentials between the flowpaths 50, 52 as described above.
  • the ratchet device 46 controls the position relative to the housing 42 to which the sleeve 44 is displaced when the pressure differentials are generated in the flowpaths 50, 52.
  • a certain number of pressure differential reversals between the flowpaths 50, 52 is used to alternately upwardly and downwardly displace the sleeve 44 a desired number of times, so that the sleeve is finally placed in a position in which a desired one of the flowpaths 62, 64, 66, 68 is in fluid communication with the flowpath 60.
  • the ratchet device 46 is of the type well known to those skilled in the art as a J-slot mechanism.
  • the ratchet device 46 includes a pair of balls 72, a ball retainer 74 and continuous J-slot profiles 76 formed externally on the sleeve 44.
  • the ball retainer 74 secures the balls 72 in 180° opposed positions relative to the housing 42.
  • the balls 72 traverse the J-slot paths 76, thus limiting the extent of the sleeve's displacement in a manner well known to those skilled in the art.
  • a portion of the exterior of the sleeve 44 is shown "unrolled" in FIG. 3 and rotated 90°. In this view only one of the paths 76 may be completely seen, but it may also be seen that the paths are interconnected, so that, in effect, the path is duplicated each 180° about the sleeve 44.
  • One of the balls 72 is also visible in FIG. 3. The ball 72 is positioned in one of four lower portions 78 ofthe path 76. Note that, when the ball 72 is positioned in one of the lower portions 78, the sleeve 44 is positioned relative to the housing 42 as depicted in FIGS 2A-C, and none of the flowpaths 62, 64, 66, 68 is in fluid communication with the flowpath 60. This position of the sleeve 44 is obtained by displacing the sleeve 44 upwardly relative to the housing 42 by generating a pressure in the flowpath 50 greater than a pressure in the flowpath 52.
  • Each of upper portions 80, 82, 84, 86 of the path 76 corresponds to a position of the sleeve 44 relative to the housing 42 in which a respective one of the flowpaths 62, 64, 66, 68 is placed in fluid communication with the flowpath 60.
  • the flowpath 62 is placed in fluid communication with the flowpath 60.
  • the flowpath 64 is placed in fluid communication with the flowpath 60.
  • the flowpath 66 is placed in fluid communication with the flowpath 60.
  • the flowpath 68 is placed in fluid communication with the flowpath 60.
  • the ball 72 is received in one of the portions 80, 82, 84, 86 by downwardly displacing the sleeve 44 relative to the housing 42.
  • the sleeve 44 is downwardly displaced relative to the housing 42 by generating a pressure in the flowpath 52 greater than a pressure in the flowpath 50.
  • the extent to which the sleeve 44 displaces downwardly is limited by the particular portion 80, 82, 84, 86 of the path 76 in which the ball 72 is received when the sleeve displaces downwardly.
  • the particular portion 80, 82, 84, 86 in which the ball 72 is received depends upon which of the lower portions 78 of the path 76 the ball is received in prior to the downward displacement ofthe sleeve.
  • the ball 72 circulates about the path 76, and is successively received in alternating ones of the upper portions 80, 82, 84, 86 and lower portions 78 as the pressure differentials between the flowpaths 50, 52 continue to be reversed. Therefore, it will be readily appreciated by one skilled in the art that any one of the flowpaths 62, 64, 66, 68 may be placed in fluid communication with the flowpath 60 by applying a certain number of pressure differential reversals to the flowpaths 50, 52, the last pressure differential downwardly displacing the sleeve 44 so that the ball 72 is received in a respective one ofthe portions 80, 82, 84, 86. Fluid communication between the flowpath 60 and all of the flowpaths 62, 64, 66, 68 may be prevented by upwardly displacing the sleeve, so that the ball 72 is received in any one of the portions 78 of the path 76.
  • control module 38 is depicted in a configuration in which the sleeve 44 has been displaced downwardly relative to the housing 42 to a position in which the flowpath 60 has been placed in fluid communication with the flowpath 68.
  • FIG. 6 it may be seen that the ball 72 is now received in the upper portion 86 of the path 76, corresponding to the selection of the flowpath 68 for fluid communication with the flowpath 60.
  • the flowpaths 50, 52, 60 would be connected to respective ones of the lines 34, and the flowpaths 62, 64, 66, 68 would be connected to respective ones of the lines 36.
  • Manipulation of pressure differentials on the ones of the lines 34 connected to the flowpaths 50, 52 would cause the one of the lines 34 connected to the flowpath 60 to be placed in fluid communication with a particular one of the lines 36 connected to a respective one of the flowpaths 62, 64, 66, 68 to thereby permit operation of a selected one of the well tool assemblies 12, 14, 16, 18 to which that particular one of the lines 36 is connected.
  • different numbers of well tool assemblies, and different types of well tool assemblies may be controlled with the control module 38, or a differently configured control module, without departing from the principles of the present invention.
  • FIG. 7 an alternate embodiment of the method 10 embodying principles of the present invention is representatively illustrated. Only a portion of the well schematically shown in FIG. 1 is shown in
  • FIG. 7 Specifically, only a portion of the tubular string 20 in the wellbore 22 is illustrated in FIG. 7.
  • control module 38 of FIGS. 2A- C is used for the control module 32 and, in addition, a selector module 88 is interconnected between the control module 38 and one of the lines 34.
  • a line or other flowpath 90 extending to a remote location is connected to the selector module 88 and two lines or other flowpaths 92, 94 extend from the selector module to the control module 38.
  • the selector module 88 is of the type well known to those skilled in the art which provides fluid communication between an input port and one of multiple output ports. Which one of the multiple output ports is placed in fluid communication with the input port depends upon the pressure at the input port.
  • the line 90 is placed in fluid communication with the line 92 when pressure in the line 90 is less than a predetermined pressure, and the line 90 is placed in fluid communication with the line 94 when pressure in the line is greater than a predetermined pressure.
  • a suitable selector module for use as the selector module 88 in the method 10 as depicted in FIG. 7 is the Mini- Hydraulic Module available from Petroleum Engineering Services, Inc.
  • a well tool assembly 100 embodying principles of the present invention is representatively illustrated.
  • the tool assembly 100 may be utilized for any of the tool assemblies 12, 14, 16, 18 in the method 10.
  • the tool assembly 100 may also be used in other methods, without departing from the principles ofthe present invention.
  • the tool assembly 100 includes an actuator 102, a housing assembly 104 and a closure sleeve 106.
  • the actuator 102 displaces the sleeve 106 relative to the housing 104 to thereby regulate fluid flow through a series of openings 108 formed through a sidewall ofthe housing.
  • the sleeve 106 is displaced downwardly relative to the housing 104 to block fluid flow through successive ones of the openings 108 by engaging a seal 112 carried on the sleeve with successive ones of a series of seal surfaces 110 formed internally on the housing 104 between the openings.
  • the actuator 102 displaces the sleeve 106 downwardly in an incremental fashion in response to an application of pressure to an input port or other flowpath 114.
  • Each application of appropriate pressure to the port 114 produces a corresponding incremental downward displacement of the sleeve 106.
  • an annular piston 116 of the actuator 102 is displaced downward into contact with a colletted annular slip member 118.
  • a spring stack or other biasing device 120 compresses a spring stack or other biasing device 120.
  • the pressure applied to the port 114 must be sufficiently great to cause compression of the spring stack 120.
  • the sleeve 106 may be displaced incrementally downward a desired total distance by alternately applying pressure to the port 114 and releasing the pressure from the port a sufficient number of times.
  • the spring stack 120 will displace the piston 116 and slip 118 upward when the pressure at the port 114 is relieved, so that they are again in position to displace the sleeve 106 downwardly when the next application of pressure is made to the port 114.
  • a flow area through the housing 104 sidewall maybe adjusted as desired, for example to regulate a rate of production from a zone, to regulate a rate of fluid injection into a zone, etc.
  • the sleeve Since the slip 118 does not grip the sleeve 106 unless pressure is applied to the port 114, the sleeve is free to displace upwardly when pressure is applied to the other port 128. Pressure at the port 128 causes upward displacement of the sleeve 106 due to a piston area formed on the sleeve below a seal 130 carried on the sleeve. In this manner, the sleeve 106 may be "reset" to its position in which all of the openings 108 are open to flow therethrough, and then, if desired, the sleeve may again be incrementally displaced downwardly by applying a series of pressures to the port 114. If the tool assembly 100 is used in the method 10 as depicted in FIG.
  • the port 114 would be connected to one of the lines 36 and the port 128 would be connected to another one of the lines 36.
  • the control module 38 is used for the control module 32 in the method 10
  • one of the flowpaths 62, 64, 66, 68 would be connected to the port 114 and another one of the flowpaths 62, 64, 66, 68 would be connected to the port 128, so that pressure applied to the flowpath 60 could be used to either incrementally displace the sleeve 106 downwardly, or to displace the sleeve upwardly, as desired.
  • another hydraulic control module is used for the control module 32 in the method 10.
  • control module 132 embodying principles of the present invention is schematically and representatively illustrated.
  • the control module 132 may be used for the control module 32 in the method 10, or it may be used in other methods, without departing from the principles of the present invention.
  • the control module 132 includes a housing assembly 134, an annular piston member 136 and a biasing device or spring 138.
  • the piston 136 is displaced downwardly relative to the housing 134 against a biasing force exerted by the spring 138 to thereby place openings 140 formed radially through the piston in fluid communication with a selected one of four flowpaths 142, 144, 146, 148 formed in the housing.
  • a greater or lesser number of flowpaths may be provided, without departing from the principles of the present invention.
  • FIG. 10 it may be seen that the flowpaths 142, 144, 146, 148 are circumferentially distributed in the housing 134. Each of the flowpaths 142, 144, 146, 148 is in fluid communication with the exterior of the piston 136, but seals 150 straddling each of the flowpaths ensure that only one of the flowpaths may be placed in fluid communication with the openings 140 at a time. Of course, multiple flowpaths could be simultaneously placed in fluid communication with the openings 140, if desired.
  • the openings 140 are in fluid communication with the flowpath 142.
  • the openings 140 permit fluid communication between the flowpath 142 and another flowpath 152 formed in the housing 134.
  • the flowpath 152 is in fluid communication with the openings 140 via a recess 154 internally formed on the piston 136.
  • the flowpath 152 remains in fluid communication with the opening 140 via the recess 154 when the piston 136 is displaced downwardly relative to the housing 134.
  • each of the flowpaths 142, 144, 146, 148 may be selectively placed in fluid communication with the flowpath 152 by displacing the piston 136 to a particular position relative to the housing 134.
  • the piston 136 is displaced downwardly relative to the housing 134 by applying pressure to another flowpath 156 formed in the housing. Pressure in the flowpath 156 biases the piston 136 downward against the upwardly biasing force of the spring 138 and an upwardly biasing force on the piston due to pressure external to the housing 134, communicated to the piston via an opening 158 formed through a sidewall of the housing.
  • the biasing force exerted by the spring 138 will increase as the piston 136 is displaced downwardly. Therefore, by applying a certain pressure to the flowpath 156, a known downward displacement of the piston 136 may be achieved, corresponding to a known upwardly biasing force exerted by the spring 138 and by the known pressure external to the housing 134.
  • biasing devices may be used in the control module 132 in place of the spring 138.
  • a compressed fluid such as Nitrogen, could be used to exert an upwardly biasing force on the piston 136.
  • the principles of the present invention are not limited to the specific embodiment ofthe control module 132 described herein.
  • one of the lines 34 would be connected to the flowpath 152 and another one of the lines 34 would be connected to the flowpath 156.
  • the flowpaths 142, 144, 146, 148 would be connected to respective ones of the lines 36.
  • a predetermined pressure applied to one of the lines 34 connected to the flowpath 156 would cause the other one of the lines 34 connected to the flowpath 152 to be placed in fluid communication with a selected one of the lines 36 connected to a corresponding one of the flowpaths 142, 144, 146, 148 for operation of one of the well tools 12, 14, 16, 18 connected thereto.
  • a well tool assembly 160 embodying principles of the present invention is schematically and representatively illustrated.
  • the tool assembly 160 is of a type the operation of which may be controlled utilizing either of the control modules 38, 132 described herein.
  • the tool assembly 160 includes a housing assembly 166 containing a hydraulically actuated temperature sensor 162 and a hydraulically actuated pressure sensor 164.
  • the temperature sensor 162 includes a piston 168 and a chamber 170.
  • the chamber 170 contains a gas, such as Nitrogen, or another fluid which responds Theologically to changes in temperature.
  • the fluid in the chamber 170 is exposed to the temperature in a well when the tool assembly 160 is interconnected in a tubular string, such as the tubular string 20 in the method 10, or is otherwise positioned in the well.
  • the temperature sensor 162 further includes flowpaths 172 and 174 formed in the housing 166. The piston 168 initially prevents fluid communication between the flowpaths 172, 174.
  • the pressure in the flowpath 172 which results in the piston 168 being displaced to produce a known volume of the chamber will correspond to a particular temperature of the fluid in the chamber 170.
  • a person skilled in the art may readily determine the corresponding temperature of the fluid in the chamber 170. As depicted in FIG. 11, areas of the piston 168 exposed to pressure in the flowpath 172 and in the chamber 170 are approximately equal, and the piston is balanced with respect to pressure in the flowpath 174.
  • the areas of the piston 168 exposed to each of the flowpaths 172, 174 and the chamber 170 may be varied as desired to produce different relationships between pressures in the flowpaths and chamber when fluid communication is permitted between the flowpaths.
  • the pressure sensor 164 includes a piston 176 and a biasing device or spring 178. In its position as depicted in FIG. 11, the piston 176 prevents fluid communication between two flowpaths 180, 182 formed in the housing 166. The spring 178 biases the piston 176 upward toward the position depicted in FIG. 11.
  • the flowpath 182 is in fluid communication with the interior ofthe housing 166, but it could alternatively be in fluid communication with the exterior of the housing, or it could be in fluid communication with any other region, the pressure of which is to be measured using the pressure sensor 164.
  • the pressure in the flowpath 180 is gradually increased, and eventually the downwardly biasing force on the piston 176 resulting therefrom overcomes the upwardly biasing forces due to the spring 178 and the pressure in the flowpath
  • the point at which fluid communication between the flowpaths 180, 182 is permitted will be indicated by a drop in the pressure in the flowpath 180, if the pressure in the flowpath 182 is less than the pressure in the flowpath 180, thereby venting the pressure in the flowpath 180.
  • the spring rate of the spring 178, the initial compression (preload) of the spring and the additional compression of the spring 178 needed to permit the piston 176 to displace downwardly a sufficient distance for the seal 184 to enter the recess 186 are known. Therefore, the maximum pressure achieved in the flowpath 180 to cause the piston 176 to permit fluid communication between the flowpaths 180, 182 corresponds to a certain pressure in the flowpath 182.
  • the tool assembly 160 By recording the maximum pressure achieved in the flowpath 180, a person skilled in the art may readily determine the pressure of the pressure source in communication with the flowpath 182. As an example of a use of the tool assembly 160, it may be interconnected to the control module 132 and positioned in a well in the method 10. In that case, one of the lines 34 would be connected to the flowpath 152, another one of the lines 34 would be connected to the flowpath 156, one of the lines 36 would be connected between the flowpath 142 and the flowpath 172, and another of the lines 36 would be connected between the flowpath 144 and the flowpath 180.
  • pressure in the flowpath 156 would be adjusted as needed to place the flowpath 152 in fluid communication with the flowpath 142, and then pressure in the flowpath 152, and thus the flowpaths 142 and 172, would be gradually increased until fluid communication is permitted between the flowpaths 172, 174.
  • This pressure corresponds to a certain temperature of the fluid in the chamber 170. If it were desired to sense the pressure in the well (for example, the pressure in the interior ofthe tubular string 20, with the pressure sensor 164 configured as depicted in FIG.
  • sensing temperature and sensing pressure utilizing the tool assembly 160 may be repeated as often as desired by merely applying pressure to either of the flowpaths 172, 180, and recording the pressure at which fluid communication is permitted between the flowpaths 172, 174 or between the flowpaths 180, 182.
  • the temperature sensor 162 and pressure sensor 164 have been depicted in FIG. 11 as being combined in the tool 160 configured for interconnection in a tubular string, it is to be clearly understood that the sensors may be separately utilized, and that the sensors may each be used as components in other hydraulic circuits.
  • the sensors 162, 164 may be used as hydraulic circuit components in a manner similar to that in which other components, such as check valves, etc., are utilized in various hydraulic circuits.
  • a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the invention, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of the present invention. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
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  • Fluid-Pressure Circuits (AREA)

Abstract

L'invention concerne un système de commande hydraulique et des procédés associés permettant de commander sélectivement le fonctionnement de plusieurs montages d'outils de puits. Selon mode de réalisation décrit dans cette invention, un système de commande hydraulique comprend un module de commande pourvu d'un élément, pouvant être déplacé dans plusieurs positions prédéterminées de manière à sélectionner l'un des nombreux montages d'outils de puits pour le faire fonctionner. Lorsque l'élément se trouve dans une position choisie, un actionneur de l'un des montages d'outils correspondant est placé en communication fluidique avec une voie de passage reliée au module de commande. Lorsque l'élément se trouve dans une autre position, la voie de passage est placée en communication fluidique avec un actionneur d'un autre montage d'outils de puits.
PCT/US2000/024551 2000-09-07 2000-09-07 Systeme de commande hydraulique pour outils de fond de trou WO2002020942A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
PCT/US2000/024551 WO2002020942A1 (fr) 2000-09-07 2000-09-07 Systeme de commande hydraulique pour outils de fond de trou
AU2000271216A AU2000271216A1 (en) 2000-09-07 2000-09-07 Hydraulic control system for downhole tools
US09/931,322 US6668936B2 (en) 2000-09-07 2001-08-16 Hydraulic control system for downhole tools

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2000/024551 WO2002020942A1 (fr) 2000-09-07 2000-09-07 Systeme de commande hydraulique pour outils de fond de trou

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WO2004033849A1 (fr) * 2002-10-11 2004-04-22 Baker Hughes Incorporated Manchon coulissant actionne par une soupape hydraulique d'entrainement pas a pas
GB2402692A (en) * 2000-10-03 2004-12-15 Halliburton Energy Serv Inc Downhole flow control device with ratchet mechanism
GB2432173A (en) * 2005-11-09 2007-05-16 Schlumberger Holdings Hydraulically actuated indexing tool providing feedback indicating tool position
US7306043B2 (en) 2003-10-24 2007-12-11 Schlumberger Technology Corporation System and method to control multiple tools through one control line
WO2012039620A1 (fr) * 2010-09-21 2012-03-29 Ziebel As Procédé et dispositif pour commande hydraulique d'actionneurs de fond de trou
WO2013032687A2 (fr) * 2011-08-29 2013-03-07 Halliburton Energy Services, Inc. Injection de fluide dans des zones sélectionnées parmi de multiples zones à l'aide d'outils de puits réagissant de façon sélective à des motifs magnétiques
US8757274B2 (en) 2011-07-01 2014-06-24 Halliburton Energy Services, Inc. Well tool actuator and isolation valve for use in drilling operations
US8776897B2 (en) 2011-01-03 2014-07-15 Schlumberger Technology Corporation Method and apparatus for multi-drop tool control
US8839871B2 (en) 2010-01-15 2014-09-23 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
US8973657B2 (en) 2010-12-07 2015-03-10 Halliburton Energy Services, Inc. Gas generator for pressurizing downhole samples
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
US9284817B2 (en) 2013-03-14 2016-03-15 Halliburton Energy Services, Inc. Dual magnetic sensor actuation assembly
US9366134B2 (en) 2013-03-12 2016-06-14 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
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
US9587486B2 (en) 2013-02-28 2017-03-07 Halliburton Energy Services, Inc. Method and apparatus for magnetic pulse signature actuation
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
US9920620B2 (en) 2014-03-24 2018-03-20 Halliburton Energy Services, Inc. Well tools having magnetic shielding for magnetic sensor
US10808523B2 (en) 2014-11-25 2020-10-20 Halliburton Energy Services, Inc. Wireless activation of wellbore tools
US10907471B2 (en) 2013-05-31 2021-02-02 Halliburton Energy Services, Inc. Wireless activation of wellbore tools

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Cited By (38)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2402692A (en) * 2000-10-03 2004-12-15 Halliburton Energy Serv Inc Downhole flow control device with ratchet mechanism
WO2004033849A1 (fr) * 2002-10-11 2004-04-22 Baker Hughes Incorporated Manchon coulissant actionne par une soupape hydraulique d'entrainement pas a pas
US6782952B2 (en) 2002-10-11 2004-08-31 Baker Hughes Incorporated Hydraulic stepping valve actuated sliding sleeve
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US7306043B2 (en) 2003-10-24 2007-12-11 Schlumberger Technology Corporation System and method to control multiple tools through one control line
GB2432173A (en) * 2005-11-09 2007-05-16 Schlumberger Holdings Hydraulically actuated indexing tool providing feedback indicating tool position
US7584800B2 (en) 2005-11-09 2009-09-08 Schlumberger Technology Corporation System and method for indexing a tool in a well
GB2432173B (en) * 2005-11-09 2010-05-19 Schlumberger Holdings System and method for indexing a tool in a well
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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
US9388669B2 (en) 2010-01-15 2016-07-12 Halliburton Energy Services, Inc. Well tools operable via thermal expansion resulting from reactive materials
WO2012039620A1 (fr) * 2010-09-21 2012-03-29 Ziebel As Procédé et dispositif pour commande hydraulique d'actionneurs de fond de trou
US8973657B2 (en) 2010-12-07 2015-03-10 Halliburton Energy Services, Inc. Gas generator for pressurizing downhole samples
US8776897B2 (en) 2011-01-03 2014-07-15 Schlumberger Technology Corporation Method and apparatus for multi-drop tool control
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
WO2013032687A2 (fr) * 2011-08-29 2013-03-07 Halliburton Energy Services, Inc. Injection de fluide dans des zones sélectionnées parmi de multiples zones à l'aide d'outils de puits réagissant de façon sélective à des motifs magnétiques
WO2013032687A3 (fr) * 2011-08-29 2013-07-11 Halliburton Energy Services, Inc. Injection de fluide dans des zones sélectionnées parmi de multiples zones à l'aide d'outils de puits réagissant de façon sélective à des motifs magnétiques
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
US9506324B2 (en) 2012-04-05 2016-11-29 Halliburton Energy Services, Inc. Well tools selectively responsive to magnetic patterns
US9169705B2 (en) 2012-10-25 2015-10-27 Halliburton Energy Services, Inc. Pressure relief-assisted packer
US9988872B2 (en) 2012-10-25 2018-06-05 Halliburton Energy Services, Inc. Pressure relief-assisted packer
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
US9982530B2 (en) 2013-03-12 2018-05-29 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing near-field communication
US9726009B2 (en) 2013-03-12 2017-08-08 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
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
US9284817B2 (en) 2013-03-14 2016-03-15 Halliburton Energy Services, Inc. Dual magnetic sensor actuation assembly
US9752414B2 (en) 2013-05-31 2017-09-05 Halliburton Energy Services, Inc. Wellbore servicing tools, systems and methods utilizing downhole wireless switches
US10907471B2 (en) 2013-05-31 2021-02-02 Halliburton Energy Services, Inc. Wireless activation of wellbore tools
US9739120B2 (en) 2013-07-23 2017-08-22 Halliburton Energy Services, Inc. Electrical power storage for downhole tools
US9482072B2 (en) 2013-07-23 2016-11-01 Halliburton Energy Services, Inc. Selective electrical activation of downhole tools
US9920620B2 (en) 2014-03-24 2018-03-20 Halliburton Energy Services, Inc. Well tools having magnetic shielding for magnetic sensor
US10808523B2 (en) 2014-11-25 2020-10-20 Halliburton Energy Services, Inc. Wireless activation of wellbore tools

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