US20170183938A1 - Valves For Regulating Downhole Fluids Using Contactless Actuation - Google Patents

Valves For Regulating Downhole Fluids Using Contactless Actuation Download PDF

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Publication number
US20170183938A1
US20170183938A1 US15/310,225 US201415310225A US2017183938A1 US 20170183938 A1 US20170183938 A1 US 20170183938A1 US 201415310225 A US201415310225 A US 201415310225A US 2017183938 A1 US2017183938 A1 US 2017183938A1
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United States
Prior art keywords
valve
signal generator
conduit
actuator
actuation signal
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Abandoned
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US15/310,225
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English (en)
Inventor
Peter D.W. Inglis
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
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Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: INGLIS, PETER DEREK WALTER
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: INGLIS, PETER DEREK WALTER
Publication of US20170183938A1 publication Critical patent/US20170183938A1/en
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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
    • 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
    • E21B47/122—
    • E21B47/123—
    • 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
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
    • 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
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
    • E21B47/135—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
    • 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
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/138—Devices entrained in the flow of well-bore fluid for transmitting data, control or actuation signals
    • 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
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • E21B47/18—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid, e.g. mud pressure pulse telemetry
    • E21B2034/002—
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/04—Ball valves
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves

Definitions

  • the present disclosure relates generally to the recovery of subterranean deposits, and more specifically to an actuator used to open or close valves in a production string.
  • Crude oil and natural gas occur naturally in subterranean deposits and their extraction includes drilling a well.
  • the well provides access to a production fluid that often contains crude oil and natural gas.
  • Drilling of the well generally involves deploying a drill string into a formation.
  • the drill string includes a drill bit that removes material from the formation as the drill string is lowered to form a wellbore.
  • a casing may be deployed in the wellbore to isolate portions of the wellbore wall and prevent the ingress of fluids from parts of the formation that are not likely to produce desirable fluids.
  • a production string may be deployed into the well to facilitate the flow of desirable fluids from producing areas of the formation to the surface for collection and processing.
  • packers and other tools may operate in the wellbore to fix the production string relative to a casing or wellbore wall, and may also function to isolate production zones (also referred to as “intervals”) of the well so that hydrocarbon-rich fluids are collected from the wellbore instead of undesirable fluids (such as water).
  • These packers and tools may operate in a wide variety of downhole environments, including extreme downhole environments having very high pressures and very high temperatures.
  • Valves may be incorporated into the production string at intervals between packers to allow or cease flow into the production string from the production zone that abuts the wellbore between the packers, and for other purposes.
  • Downhole valves may also be included in drilling tool strings to divert drilling fluid to, for example, facilitate a logging while drilling or measurement while drilling measurement or sampling.
  • Downhole valves may be valves may be actuated by using pressure pulses or by transmitting a control signal directly to a valve actuator using a hydraulic or electronic control line.
  • FIG. 1 is a schematic, elevation view with a portion shown in cross-section of a production system that includes a downhole valve including a contactless actuator;
  • FIG. 2A is a schematic, elevation view with a portion shown in cross-section of a drilling system that includes a valve including a contactless actuator, wherein the system is deployed in a subterranean well;
  • FIG. 2B is a schematic, elevation view with a portion shown in cross-section of a drilling system that includes a valve including a contactless actuator, wherein the system is deployed in a subsea well;
  • FIG. 3 is a detail, cross-sectional view of the downhole valve of FIG. 1 ;
  • FIG. 4 is a schematic diagram of the downhole valve of FIG. 3 ;
  • FIG. 5 is a schematic flowchart of an illustrative method for contactless actuation of a downhole valve, according to an embodiment.
  • downhole valves are typically actuated using electronic or hydraulic control lines that utilize a line connection to a surface controller.
  • the illustrative embodiments described herein relate to a downhole valve system having a contactless actuator, which may incorporate a number of signal generators and receivers to open and close a downhole valve without utilizing a dedicated control line.
  • any use of any form of the terms “connect,” “engage,” “couple,” “attach,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.
  • the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to”. Unless otherwise indicated, as used throughout this document, “or” does not require mutual exclusivity.
  • FIG. 1 shows an illustrative embodiment of a system 100 including a valve assembly 102 that is actuated using a contactless actuator.
  • the system 100 is depicted in a schematic, elevation view with a portion shown in cross-section.
  • the system 100 includes a rig 108 atop a surface 110 of a well 112 .
  • Beneath the rig 108 a wellbore 106 is formed within a geological formation 114 , which is expected to produce hydrocarbons in the form of production fluid 104 .
  • the wellbore 106 may be formed in the geological formation 114 using a drill string that includes a drill bit to remove material from the geological formation 114 .
  • the wellbore 106 may follow a vertical, partially-vertical, angled, or even a partially-horizontal path through the geological formation 114 .
  • a production tool string 116 is deployed from the rig 108 , which may be a drilling rig, a completion rig, a workover rig, or another type of rig.
  • the rig 108 includes a derrick 118 and a rig floor 120 .
  • the production tool string 116 extends downward through the rig floor 120 , through a fluid diverter 122 and blowout preventer 124 that provide a fluidly sealed interface between the wellbore 106 and external environment, and into the wellbore 106 and geological formation 114 .
  • Coupled to the fluid diverter 122 is a pump 128 coupled to a control system 126 .
  • the pump 128 is operational to deliver or receive fluid through an internal bore of the production tool string 116 by applying a positive or negative pressure to the internal bore.
  • the pump 128 may also deliver or receive fluid through an annulus 130 by applying a positive or negative pressure to the annulus 130 .
  • the annulus 130 is formed between an exterior of the production tool string 116 and a wellbore casing 132 or between the wall of the wellbore 106 and the exterior of the production tool string 116 when production tool string 116 is disposed within the wellbore 106 .
  • the production tool string 116 may be equipped with tools and deployed within the wellbore 106 to prepare, operate, or maintain the well 112 .
  • the production tool string 116 may incorporate tools that are actuated after deployment in the wellbore 106 , including without limitation bridge plugs, composite plugs, cement retainers, high expansion gauge hangers, straddles, and packers. Actuation of such tools may result in centering the production tool string 116 within the wellbore 106 , anchoring the production tool string 116 , isolating a segment of the wellbore 106 , or other functions related to positioning and operating the production tool string 116 .
  • the production tool string 116 is depicted with a packer 134 within a production zone of the geological formation 114 .
  • the packer 134 is configured to provide a fluid seal between the production tool string 116 and the wellbore 106 , thereby defining an interval or production zone adjacent the production tool string 116 .
  • Packers 134 are typically used to prepare the wellbore 106 for hydrocarbon production during operations such as fracturing of the formation or for service during formation of the well during operations such as acidizing or cement squeezing.
  • valve assembly 102 that controls the flow of production fluid 104 into the production string 116 .
  • the illustrative valve assembly 102 is coupled to, or includes, an actuator that may be triggered using a contactless signal generator, as described in more detail below.
  • the signal generator may be a device that emits a light source, a magnetic field, a radio signal, an acoustic signal, a radioactive signal, or a combination thereof.
  • the actuator may be used to actuate tools or assemblies within the production tool string 116 , such as the packer 134 or other tools.
  • fluid may be provided to the wellbore from the pump 128 .
  • the pump 128 is coupled to the surface controller 126 , which may include a signal generator dispenser or “hopper” that dispenses one or more signal generators into a fluid that is being provided downhole in response to a user generated or computer generated instruction to actuate the valve assembly 102 or other tool. Fluid may be circulated downhole for various purposes.
  • the signal generators may be a clear ball or another suitable type of particle that includes a signal generator to generate any one of the types of signals described above.
  • the valve assembly 102 or other tool may be actuated by the control system 126 dispensing a signal generator into the wellbore 126 , which may be detected by a downhole detector that is communicatively coupled to the actuator. Detection of the signal generator by the detector may result in actuation of the valve or other downhole device.
  • the detector may be selected based on the type of signal generated by the signal generator. For example, a photocell may be used to detect a light source, a magnetic or electromagnetic field sensor may be used to detect a magnetic field, an antenna may be used to detect a radio signal, a hydrophone or similar device may be used to detect an acoustic signal, and a radioactive isotope identification device may be used to detect a radioactive signal.
  • FIG. 1 relates to a stationary, land-based rig for raising, lowering, and setting the production tool string 116
  • mobile rigs, wellbore servicing units e.g., coiled tubing units, slickline units, or wireline units
  • wellbore servicing units e.g., coiled tubing units, slickline units, or wireline units
  • the systems and methods described herein may instead be operated in subsea well configurations accessed by a fixed or floating platform.
  • FIG. 2A shows an alternative deployment of a valve assembly 270 including, or coupled to, a contactless actuator and deployed in a drilling system 200 .
  • the drilling system 200 is deployed in a well 202 including a wellbore 206 that extends from a surface 210 of the well 202 to or through a subterranean formation 214 .
  • the well 202 is illustrated onshore in FIG. 2A with a drill string 216 deployed to operate a drill bit 222 to form the wellbore 206 .
  • the drilling system 200 and associated valve assembly 270 and contactless actuator may be deployed in a sub-sea well 201 accessed by a fixed or floating platform 221 , as shown in FIG. 2B .
  • valve assembly 270 and contactless actuator each illustrate possible implementations of such systems, and while the following description of the valve assembly 270 and contactless actuator focuses primarily on the use of the valve assembly 270 and a related control system 226 with the onshore well 202 of FIG. 2A , the valve assembly 270 and contactless actuator may be used instead in the well configuration illustrated in FIG. 2B , as well as in other well configurations where it is desirable to actuate a downhole valve or other tool using a contactless actuator. Similar components in FIGS. 2A and 2B are identified with similar reference numerals.
  • the well 202 is formed by a drilling process in which a drill bit 222 is turned by the drill string 216 to remove material from the formation and form the wellbore 206 .
  • the drill string 216 extends from the drill bit 222 at the bottom of the wellbore 206 to the surface 210 of the well 202 , where it is joined with a kelly 228 .
  • the drill string 216 may be made up of one or more connected tubes or pipes of varying or similar cross-section.
  • the drill string 216 may refer to the collection of pipes or tubes as a single component, or alternatively to the individual pipes or tubes that comprise the string.
  • drill string is not meant to be limiting in nature and may refer to any component or components that are capable of transferring rotational energy from the surface of the well to the drill bit 222 .
  • the drill string 216 may include a central passage disposed longitudinally in the drill string 216 and capable of allowing fluid communication between the surface 210 of the well and downhole locations.
  • the drill string 216 may include or be coupled to the kelly 228 .
  • the kelly 228 may have a square, hexagonal or octagonal cross-section.
  • the kelly 228 is connected at one end to the remainder of the drill string 216 and at an opposite end to a rotary swivel 232 .
  • the kelly 228 passes through a rotary table 236 that is capable of rotating the kelly 228 and thus the remainder of the drill string 216 and drill bit 222 .
  • the rotary swivel 232 allows the kelly 228 to rotate without rotational motion being imparted to the rotary cable 242 .
  • a hook 238 , the cable 242 , a traveling block (not shown), and a hoist (not shown) are provided to lift or lower the drill bit 222 , drill string 216 , kelly 228 and rotary swivel 232 .
  • the drill string 216 may be raised or lowered as needed to add additional sections of tubing to the drill string 216 as the drill bit 222 advances, or to remove sections of tubing from the drill string 216 if removal of the drill string 216 and drill bit 222 from the well 202 are not desired.
  • drilling fluid 204 is stored in a drilling fluid reservoir 244 and pumped into an inlet conduit 252 using a pump 229 , or plurality of pumps disposed along the inlet conduit 252 .
  • the drilling fluid 204 passes through the inlet conduit 252 and into the drill string 216 via a fluid coupling at the rotary swivel 232 .
  • the drilling fluid 204 is circulated into the drill string 216 to maintain pressure in the drill string 216 and wellbore 206 and to lubricate the drill bit 222 as it cuts material from the formation 214 to deepen or enlarge the wellbore 206 .
  • the drilling fluid 204 After exiting the drill string 216 , the drilling fluid 204 carries cuttings from the drill bit 222 back to the surface 210 through an annulus 230 formed by the space between the inner wall of the wellbore 206 and outer wall of the drill string 216 . At the surface 210 , the drilling fluid 204 exits the annulus 230 and is carried to a repository. Where the drilling fluid 204 is recirculated through the drill string 216 , the drilling fluid 204 may return to the drilling fluid reservoir 244 via an outlet conduit 264 that couples the annulus 230 to the drilling fluid reservoir 244 . The path that the drilling fluid 204 follows from the reservoir 244 , into and out of the drill string 216 , through the annulus 230 , and to the repository may be referred to as the fluid flow path.
  • a measurement module 272 is depicted as being downhole from the valve assembly 270 .
  • the valve assembly 270 may be oriented in the drill string 216 such that when the valve assembly 270 is in a first orientation, the drilling fluid 204 is directed downward through the downhole measurement module 272 to the drill bit 222 , and when the valve is in a second orientation, the drilling fluid bypasses the downhole measurement module 272 and is directed into the annulus 230 and back toward the surface. This configuration may also facilitate the continuous circulation of drilling fluid 204 through the wellbore 206 even when operation of the drill bit 222 is suspended.
  • the valve assembly 270 includes a contactless actuator that may be used to operate the valve assembly 270 without an established electronic or hydraulic control line. Further, the valve assembly 270 is discussed merely as an illustrative system and it is noted that the contactless actuator may be instead used to actuate other types of downhole tools, including, for example, a measurement module 272 .
  • FIG. 3 shows a detail view, in partial cross-section, of a valve and contactless actuator assembly 310 , as indicated in FIG. 3 .
  • the valve assembly 310 is the valve assembly 102 of FIG. 1 .
  • the valve assembly 310 is the valve assembly 270 of FIGS. 2A and 2B .
  • the valve assembly 310 includes an actuator 332 , which, as described in more detail below, may be a contactless actuator that actuates a downhole tool, such as a valve 330 .
  • the valve 330 may be a ball valve as shown or any other suitable type of valve, such as a sleeve valve.
  • the actuator 332 is coupled to a hydraulic pump 334 , which is also coupled to a movable member 336 of the valve 330 .
  • the valve 330 includes a sealing member, such as a valve ball 350 having an aperture 352 that allows fluid to flow through the valve 330 when the valve 330 is open and ceases fluid flow when the valve 330 is closed.
  • the valve 330 may include a t-valve that allows fluid to flow through the tubing segment that includes the valve 330 when open and diverts fluid flow outside of the tubing segment when closed.
  • the actuator 332 includes a passive detector or sensor 315 that detects one or more signals generated by a signal generator.
  • the signal generator may be a device that emits a light source, such as a clear ball with an embedded or enclosed LED, a permanent magnet, a radio-frequency identification (RFID) tag, a mud-pulse telemetry broadcasting device or speaker, or an acoustic signal, a radioactive isotope, or a combination thereof.
  • the detector or sensor 315 may be selected based on the type of signal generated by the signal generator.
  • the sensor 315 may include a photocell, a magnetic or electromagnetic field sensor, an antenna, a hydrophone, a radioactive isotope identification device or radiation detector, or any other suitable sensor 4 .
  • the actuator 332 Upon detection of the signal generator by the sensor 315 , the actuator 332 causes the hydraulic pump 334 to actuate the movable member 336 of the valve 330 , which turns the valve ball 350 to close the valve 330 and prevent flow therethrough. Closing of the valve 330 may facilitate the closing of a zone of the well or enable the buildup of pressure in the tool string that includes the valve 330 so that, for example, a packer may be set up-hole from the valve 330 . Similarly, opening of the valve 330 facilitates the renewal of flow through the valve 330 , either to or from a downhole location.
  • the actuator 332 includes a power source, controller, memory, a power source, an actuating member, and a sensor.
  • the sensor monitors the fluid within a predetermined range of the actuator 332 for the presence of one or more signal generators, and is operable to detect the presence of a signal generator and the frequency at which signal generators are detected as a function of time.
  • the controller of the actuator 332 is operable to execute instructions stored in the memory for actuating the valve 330 based on conditions detected by the sensor.
  • the power source which may include a battery, provides a local power to the components of the actuator 332 , including the sensor, controller, and actuating member.
  • the actuating member is a motor and gearbox that are coupled to and configured to operate the hydraulic pump.
  • the actuating member may be a solenoid.
  • the actuator 332 and its constituent components are arranged about the periphery of the assembly 310 to avoid interference with fluid flowing along a fluid flow path through the valve 330 and assembly 310 .
  • the controller of the actuator 332 will operate the actuating member of the actuator 332 to open or close the valve 330 in accordance with the operating instructions of the actuator 332 .
  • the actuator 332 thereby operates the hydraulic pump 334 , which provides at least one hydraulic control line to the movable member 336 .
  • at least one hydraulic control lines extends from the pump 334 to the movable member 336 of the valve 330 .
  • the valve 330 comprises a substantially cylindrical body having an axial bore running therethrough to facilitate the flow of fluids therethrough.
  • the body may include ports or an access sleeve that connects the actuator to the movable member 336 .
  • the movable member 336 includes a valve ball 350 arranged on a pivot so that the valve ball 350 can rotate within the bore to open and close the valve 330 .
  • the valve ball 350 includes an aperture running therethrough, which is sized to match the diameter of the bore.
  • the movable member 336 may also include a ball arm that is operated with a piston that is translated back and forth with the hydraulic pump to open and close the valve 330 .
  • valve ball 350 may be used between the valve ball 350 and its housing to prevent fluid leakage through the valve 330 .
  • valve 330 may instead be formed from concentric sleeves having overlapping flow ports that are moved in and out of alignment by translation of one of the sleeves caused by movement of the piston.
  • the actuator 332 when the sensor 315 detects a signal generator and the actuator 332 determines to open the valve 330 , the actuator 332 operates the hydraulic pump 334 to evacuate the control line to retract the piston or to provide pressure to a second control line that causes the piston to retract and open.
  • FIG. 4 shows a schematic diagram of a contactless actuator system 400 including a valve 402 within a downhole tool string, such as a production string or a drilling string.
  • a conduit 404 forms a fluid flow path 406 through the tool string, and includes a sensor 410 operable to detect a signal generator 416 in the conduit 404 .
  • the conduit 404 is fluidly coupled to the valve 402 .
  • the sensor 410 is coupled to a control module that includes a processor 414 , a memory 415 , and a power supply 412 .
  • the power supply 412 may include a battery and/or a downhole power generation device, such as a turbine, to generate power to be stored in the battery.
  • the power supply 412 supplies electrical energy to the sensor 410 and an actuating member 408 , which may be a solenoid or a motor coupled to a hydraulic pump, as noted previously.
  • the actuating member 408 is coupled to the valve 402 , or a movable member thereof, and is thereby operable to open and close the valve 402 .
  • the actuator system 400 functions as a contactless tool that replaces a mechanical interface that is typically used to open and close a valve, e.g., in the form of a dropped ball or mechanical manipulation of an entire tool string, such as pulling up (close) or pushing down (open) using a collet or shifting tool that is attached to the end of the tool string.
  • the signal generator may be a magnet, a radioactive source (such as strontium-90, tritium, carbon-14, phosphorus-32, nickel-63, or a combination thereof), and electronic signal generator such as an RFID tag, or an acoustic sound generator (such as a speaker or projector operable to generate a periodic SONAR ping).
  • the sensor 410 may be a magnetic field sensor, such as a MEMS magnetic field sensor, a radiation detector or Gieger counter, an antenna or RFID tag reader, or a hydrophone that is configured to detect the signal generator.
  • the actuator system 400 may be configured to actuate and close the valve 402 in response to the sensor 410 detecting a signal generator 416 , the sensor 410 detecting a threshold quantity of signal generators 416 , or the passage of a time delay following detection of a signal generator 416 .
  • the actuator system 400 may be configured to actuate and open the valve 402 in response to the sensor 410 detecting a signal generator 416 , the sensor 410 detecting a threshold quantity of signal generators 416 , the passage of a time delay following detection of a signal generator 416 , or the passage of time delay following the closing of the valve 402 .
  • the signal generator 416 may be a discrete object, such as a ball or small particle deployed in the fluid flow path 406 , or a signal generator 416 that is remotely deployed from the surface by, for example, a slickline or wireline cable deployed within the tool string or wellbore annulus in an area that will be detected by the sensor 410 . Such a signal generator may thereby be a contactless tool that is deployed without a dedicated electrical connection or power supply to open or close a downhole valve.
  • the senor 410 may also include a pressure sensor and thereby be configured to detect pressure pulses, or brief surges or variations in the fluid pressure at the sensor location.
  • the memory may be provided with instructions for opening or closing the valve 402 in response to detecting a pressure pulse or a sequence of pressure pulses.
  • a timed sequence of pressure pulses may be associated with a command to open the valve 402 and a second timed sequence of pressure pulses may be associated with a command to close the valve 402 .
  • the actuator system 400 will transition to an open state in response to the sensor 410 detecting the first timed sequence of pressure pulses and transition to a closed state in response to the sensor 410 detecting the second timed sequence of pressure pulses.
  • the senor 410 may also include a contact sensor or wet connect that is configured to receive an electrical current, and a wire delivering the electrical current may be the signal generator.
  • the wire may be a low voltage wire that is easily provided downhole by a slickline or wireline application.
  • the sensor 410 may also be configured to receive and transmit the electrical current to the power supply 412 to charge the battery of the actuator.
  • the electrical current may thereby facilitate charging of a power supply 412 , thereby extending the life of such valves.
  • the actuator system 400 or a plurality of actuators may be coupled to one or more valves or other tools, such as packers or measuring devices that may also be actuated by such an actuator system 400 , three way valves, etc.
  • the sensor 410 may include a photo-sensor, or photo-electric cell that is selected to detect a signal generator 416 that is a LED or similar light source included in a clear glass or plastic ball that is deployed downhole.
  • a plurality of such signal generators may be deployed downhole, each producing a selected different wavelength of light.
  • a plurality of actuator systems 400 may be configured to detect different wavelengths of light so that each tool may be actuated by deploying a signal generator 416 that corresponds to the tool.
  • a first valve may be actuated by deploying a signal generator 416 that generates a blue light to a sensor 410 of an actuator that is configured actuate the valve in response to the detection of blue light.
  • a second tool may be actuated by deploying a signal generator 416 that emits a red light to a sensor 410 of an actuator system 400 that is configured to actuate the tool in response to detecting red light.
  • deployment of signal generators 416 that emit different wavelengths of light or otherwise discernible signals of the types described above may be deployed in succession to actuated a plurality of tools within a tool string.
  • the actuator 332 of FIG. 1 includes the sensor 410 , the power supply 412 , the processor 414 , the memory 415 , and the actuating member 408 of FIG. 4 , and operates in accordance with one or more of the foregoing embodiments of the contactless actuation system 400 of FIG. 4 .
  • the method 500 may be used with any of the previous illustrative embodiments.
  • the method 500 includes a step 502 of conveying an actuation signal generator into a conduit of a downhole tool using a fluid.
  • the actuation signal generator is selected from the group consisting of a light source, a magnetic field source, a radioactive source, and an acoustic source.
  • the method 500 also includes a step 504 of monitoring the conduit for entry of the actuation signal generator.
  • the step 504 of monitoring the conduit includes detecting electromagnetic radiation from a light emitting diode using a photo-detector.
  • the method 500 involves a decision, represented by interrogatory 506 , to determine if the actuation signal generator has been detected. Such a determination may include detecting a threshold quantity of actuation signal generators. If the no actuation signal generator has been detected, the method 500 returns to the step 504 of monitoring the conduit. However, if the actuation signal generator is detected at the interrogatory 506 , the method 500 proceeds to a step 508 of actuating the downhole valve.
  • the system may end 510 , or return to a point between the step 502 and the step 504 to wait for further signals to actuate the valve again.
  • the method 500 further includes the step (not shown) of releasing the actuation signal generator in the fluid. This step is typically performed before the step 502 of conveying the actuation signal generator.
  • a valve assembly comprising:
  • Example 1 The valve assembly of Example 1, further comprising a power source coupled to the actuator.
  • Example 1 further comprising a controller coupled to the detector, the controller having at least one processor and at least one memory, the at least one processor and the at least one memory perform logical operations and calculations in relation to the actuation signal generator sensed by the detector.
  • Example 1 The valve assembly of Example 1 or any of Examples 2-3, wherein the sealing member comprises a ball having a throughbore and movably arranged within the fluid conduit, the ball movable between the open position, where the throughbore is axially aligned with the fluid conduit, and the closed position, where the throughbore is perpendicular to the conduit.
  • the sealing member comprises a ball having a throughbore and movably arranged within the fluid conduit, the ball movable between the open position, where the throughbore is axially aligned with the fluid conduit, and the closed position, where the throughbore is perpendicular to the conduit.
  • Example 1 The valve assembly of Example 1 or any of Examples 2-3, wherein the sealing member comprises a sleeve valve.
  • Example 1 The valve assembly of Example 1 or any of Examples 2-5, wherein the actuator comprises a hydraulic pump fluidly-coupled to the sealing member.
  • Example 1 The valve assembly of Example 1 or any of Examples 2-6, wherein the actuation signal generator is selected from the group consisting of a light source, a magnetic field generator, a radioactive source, and an acoustic signal generator.
  • the actuation signal generator is selected from the group consisting of a light source, a magnetic field generator, a radioactive source, and an acoustic signal generator.
  • Example 1 The valve assembly of Example 1 or any of Examples 2-6, wherein the actuation signal generator comprises a light source and wherein the detector comprises a photo sensor.
  • Example 8 The valve assembly of Example 8, wherein the light source comprises a transparent body containing a light emitting diode.
  • a contactless valve actuation system comprising:
  • valve actuator further comprises a local power source to provide power to a movable member.
  • Example 10 The system of Example 10 or Example 11, wherein quantities of the actuation signal generator are released into fluid.
  • Example 10 The system of Example 10 or any of Examples 11-12, wherein the controller determines a position of the valve based on a signal received from the sensor.
  • valve actuator comprises a hydraulic pump fluidly-coupled to the valve.
  • Example 10 wherein the valve comprises a ball having a throughbore and movably arranged with the conduit, the throughbore axially-aligned with conduit in the open position and perpendicular to the conduit in the closed position.
  • Example 10 The system of Example 10 or any of Examples 11-14, wherein the valve is a sleeve valve.
  • Example 10 The system of Example 10 or any of Examples 11-16, wherein the actuation signal generator is selected from the group consisting of a light source, a magnetic field source, a radioactive source, and an acoustic source.
  • the actuation signal generator is selected from the group consisting of a light source, a magnetic field source, a radioactive source, and an acoustic source.
  • Example 10 The system of Example 10 or any of Examples 11-16, wherein the actuation signal generator comprises a light emitting diode and wherein the sensor comprises a photo sensor.
  • a method of actuating a valve comprising:
  • Example 19 The method of Example 19, further comprising the step of releasing the actuation signal generator into the fluid.
  • Example 19 The method of Example 19 or Example 20, wherein the actuation signal generator is selected from the group consisting of a light source, a magnetic field source, a radioactive source, and an acoustic source.
  • the actuation signal generator is selected from the group consisting of a light source, a magnetic field source, a radioactive source, and an acoustic source.
  • Example 19 wherein the step of monitoring the conduit comprises detecting electromagnetic radiation from a light emitting diode using a photo-detector.

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  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Remote Sensing (AREA)
  • Geophysics (AREA)
  • Mechanical Engineering (AREA)
  • Electromagnetism (AREA)
  • Acoustics & Sound (AREA)
  • Indication Of The Valve Opening Or Closing Status (AREA)
  • Preventing Unauthorised Actuation Of Valves (AREA)
  • Lift Valve (AREA)
  • Multiple-Way Valves (AREA)
US15/310,225 2014-07-02 2014-07-02 Valves For Regulating Downhole Fluids Using Contactless Actuation Abandoned US20170183938A1 (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2014/045223 WO2016003457A1 (en) 2014-07-02 2014-07-02 Valves for regulating downhole fluids using contactless actuation

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US20170183938A1 true US20170183938A1 (en) 2017-06-29

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AU (1) AU2014399897C1 (ko)
BR (1) BR112016028013B1 (ko)
CA (1) CA2951011A1 (ko)
GB (1) GB2545790B (ko)
NO (1) NO20161785A1 (ko)
SG (1) SG11201609156VA (ko)
WO (1) WO2016003457A1 (ko)

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10781665B2 (en) 2012-10-16 2020-09-22 Weatherford Technology Holdings, Llc Flow control assembly
US10844689B1 (en) 2019-12-19 2020-11-24 Saudi Arabian Oil Company Downhole ultrasonic actuator system for mitigating lost circulation
US10865620B1 (en) 2019-12-19 2020-12-15 Saudi Arabian Oil Company Downhole ultraviolet system for mitigating lost circulation
US11078780B2 (en) 2019-12-19 2021-08-03 Saudi Arabian Oil Company Systems and methods for actuating downhole devices and enabling drilling workflows from the surface
US11230918B2 (en) 2019-12-19 2022-01-25 Saudi Arabian Oil Company Systems and methods for controlled release of sensor swarms downhole
US11686196B2 (en) 2019-12-19 2023-06-27 Saudi Arabian Oil Company Downhole actuation system and methods with dissolvable ball bearing

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Publication number Priority date Publication date Assignee Title
US4422618A (en) * 1981-12-01 1983-12-27 Armco Inc. Remotely operated valve
GB9819965D0 (en) * 1998-09-15 1998-11-04 Expro North Sea Ltd Improved ball valve
GB0423015D0 (en) * 2004-10-16 2004-11-17 Enovate Systems Ltd Improved ball valve
US8534361B2 (en) * 2009-10-07 2013-09-17 Baker Hughes Incorporated Multi-stage pressure equalization valve assembly for subterranean valves
US8733448B2 (en) * 2010-03-25 2014-05-27 Halliburton Energy Services, Inc. Electrically operated isolation valve
US20130048290A1 (en) * 2011-08-29 2013-02-28 Halliburton Energy Services, Inc. Injection of fluid into selected ones of multiple zones with well tools selectively responsive to magnetic patterns

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10781665B2 (en) 2012-10-16 2020-09-22 Weatherford Technology Holdings, Llc Flow control assembly
US10844689B1 (en) 2019-12-19 2020-11-24 Saudi Arabian Oil Company Downhole ultrasonic actuator system for mitigating lost circulation
US10865620B1 (en) 2019-12-19 2020-12-15 Saudi Arabian Oil Company Downhole ultraviolet system for mitigating lost circulation
US11078780B2 (en) 2019-12-19 2021-08-03 Saudi Arabian Oil Company Systems and methods for actuating downhole devices and enabling drilling workflows from the surface
US11230918B2 (en) 2019-12-19 2022-01-25 Saudi Arabian Oil Company Systems and methods for controlled release of sensor swarms downhole
US11686196B2 (en) 2019-12-19 2023-06-27 Saudi Arabian Oil Company Downhole actuation system and methods with dissolvable ball bearing

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AU2014399897C1 (en) 2017-09-14
NO20161785A1 (en) 2016-11-11
CA2951011A1 (en) 2016-01-07
WO2016003457A1 (en) 2016-01-07
BR112016028013A2 (ko) 2017-08-22
BR112016028013B1 (pt) 2022-05-10
AU2014399897A1 (en) 2016-11-24
AU2014399897B2 (en) 2017-05-25
SG11201609156VA (en) 2016-12-29
GB2545790B (en) 2021-01-27
GB2545790A (en) 2017-06-28

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