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US20150198034A1 - Production fluid monitoring system including a downhole acousting sensing system having a downhole pulsator - Google Patents

Production fluid monitoring system including a downhole acousting sensing system having a downhole pulsator Download PDF

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Publication number
US20150198034A1
US20150198034A1 US14/156,645 US201414156645A US2015198034A1 US 20150198034 A1 US20150198034 A1 US 20150198034A1 US 201414156645 A US201414156645 A US 201414156645A US 2015198034 A1 US2015198034 A1 US 2015198034A1
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Prior art keywords
downhole
control input
piston
control
production fluid
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Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
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US14/156,645
Inventor
Erik N. Lee
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Baker Hughes Holdings LLC
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Baker Hughes 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.)
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Publication date
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Priority to US14/156,645 priority Critical patent/US20150198034A1/en
Assigned to BAKER HUGHES INCORPORATED reassignment BAKER HUGHES INCORPORATED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: LEE, Erik N.
Priority to PCT/US2014/071483 priority patent/WO2015108668A1/en
Publication of US20150198034A1 publication Critical patent/US20150198034A1/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
    • 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
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • 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

Definitions

  • the present invention relates to the art of production fluid monitoring systems and, more particularly, to a production fluid monitoring system including a downhole acoustic sensing system having a downhole pulsator.
  • Acoustic devices are used to measure various parameters in a downhole environment. Often times, an acoustic device may be used to determine parameters of a downhole acoustic medium including solids and/or fluids proximate to a drill head. In such cases, the acoustic device may be mounted to the drill string. In many cases, the acoustic device takes the form of a piezo-electric transducer. Piezo-electric transducers may also be mounted to production tubing and operated to transmit and/or receive acoustic signals through the acoustic medium.
  • a downhole acoustic sensing system includes a pulsator device configured and disposed to be arranged in a downhole environment, and a control system operatively connected to the pulsator device.
  • the control system delivers at least one control input to the pulsator device to generate a sinusoidal acoustic signal.
  • a production fluid monitoring system includes a pulsator device configured and disposed to be arranged in a downhole environment and a control system operatively connected to the pulsator device.
  • the control system delivers at least one control input to the pulsator device to deliver a sinusoidal acoustic signal through downhole fluids.
  • a data acquisition system is configured and disposed to detect the sinusoidal acoustic signal passing through the downhole production fluids.
  • a method of monitoring downhole production fluids includes delivering a positive pressure pulse from a downhole pulsator to form a first portion of a downhole acoustic signal, delivering a negative pressure pulse downhole to form a second portion of the downhole acoustic signal, passing the acoustic signal through a production fluid, and sensing the acoustic signal to determine a quality of the production fluid.
  • FIG. 1 is a partial cross-sectional view of a downhole production tubing passing alongside a downhole acoustic device, in accordance with an exemplary embodiment
  • FIG. 2 is a schematic view of a downhole production fluid acoustic sensing system including the downhole acoustic device of FIG. 1 ;
  • FIG. 3 is a view of the downhole acoustic device of FIG. 1 delivering a negative pressure pulse
  • FIG. 4 is a view of the downhole acoustic device of FIG. 1 delivering a positive pressure pulse
  • FIG. 5 is a graphical representation of an acoustic signal produced by the downhole acoustic device, in accordance with an exemplary embodiment.
  • Exploration companies routinely drill wells in a medium, indicated at 2 in FIG. 1 , in search of natural resources such as natural gas and/or oil.
  • the wells are formed by drilling a bore, indicted generally at 4 , into medium 2 .
  • Bore 4 extends to a zone or region (not shown) in which a natural resource resides.
  • production tubing 6 is inserted downhole into the bore 4 .
  • downhole refers to a zone within medium 2 in which bore 4 is formed. Bore 4 may begin at an exposed earthen or sand surface, or under water.
  • uphole refers to a zone or region outside of medium 2 .
  • a production fluid monitoring system is employed to monitor production fluids passing through production tubing 6 .
  • Production fluid monitoring system 14 includes a downhole acoustic sensing system 20 and a data acquisition system 24 .
  • Downhole acoustic sensing system 20 includes a pulsator device 30 which, as will be discussed more fully below, delivers an acoustic signal into production fluids passing through production tubing 6 .
  • Pulsator device 30 may include a piston 32 shiftably mounted in a cylinder 34 .
  • pulsator device 30 may take on a variety of forms including diaphragms, pumps and the like, capable of delivering a pressure pulse into production fluids passing through production tubing 6 .
  • cylinder 34 extends from a first end 36 exposed to the production fluids to a second, closed end 38 defining a volume 40 .
  • Piston 30 includes a first piston element 43 exposed at first end 36 and a second piston element 45 spaced from first piston element 43 by a support rod 47 . Second piston element 45 separates volume 40 into a first portion 54 and a second portion 56 .
  • pulsator device 30 is operatively connected to a control system 70 .
  • Control system 70 is connected to a valve 74 which, in turn, may be fluidically coupled to a source of fluid 78 and pulsator device 30 .
  • Valve 74 may take the form of a ball valve or other form of fast switching valve.
  • valve 74 is fluidically connected to cylinder 34 through a first control input 84 and a second control input 86 .
  • First control input 84 takes the form of a first hydraulic line 90 and second control input 86 takes the form of a second hydraulic line 92 .
  • Control system 70 operates valve 74 to alternatingly deliver control signals to pulsator device 30 causing an acoustic signal to pass into the production fluids.
  • the control signals may take the form of pulses of a fluid passing through first and second hydraulic lines 90 and 92 .
  • the fluid may be a non-compressible fluid or a compressible fluid.
  • control system 70 operates valve 74 to delver a pulse of fluid through first hydraulic line 90 causing piston 32 to move in a first direction towards second end 38 of cylinder 34 creating a negative pressure pulse 96 ( FIG. 5 ) into the production fluid, as shown in FIG. 3 .
  • Control system 70 then operates valve 74 to deliver another pulse of fluid into second hydraulic line 92 causing piston 32 to move in a second direction away from second end 38 of cylinder 34 creating a positive pressure pulse 98 ( FIG. 5 ) into the production fluid, as shown in FIG. 4 .
  • Control system 70 alternates between sending pulses of fluid to first and second hydraulic lines 90 and 92 creating a sinusoidal acoustic signal 100 , as shown in FIG. 5 , that is delivered into the production fluid.
  • the sinusoidal signal may represent a summation of sinusoids.
  • data acquisition system 24 includes a data collection and analysis device 104 operatively connected to a plurality of downhole sensors 108 .
  • Downhole sensors 108 may take the form of fiber optic sensors 110 that are arranged at various points along production tubing 6 .
  • Acoustic signal(s) 100 passes in an uphole direction and a downhole direction through the production fluids.
  • Data acquisition system 24 collects and analyzes acoustic signal(s) 100 at various points along production tubing 6 to monitor the production fluids.
  • the exemplary embodiments describe a system for delivering pressure pulses into production fluids passing through production tubing in a resource collection system.
  • the pressure pulses form an acoustic source that may be monitored to determine various attributes of the production fluid.
  • the timing, duration, period and frequency of the pressure pulses may be varied depending upon desired sensing parameters. For example, a low frequency acoustic signal may be desirable when sensing deep downhole.
  • a low frequency acoustic signal may be desirable when sensing deep downhole.
  • the present invention may employ a single control signal.
  • a second control may be provided by a spring that is compressed by the piston in response to the single control signal.
  • other systems including electric and magnetic may be used to drive the piston.
  • control system may be provided uphole to provide technicians with greater control of the acoustic signal.
  • the pulsator device of the present invention may be operated only during select periods. Periodic, as opposed to continuous operation, may extend an overall service life of the downhole acoustic sensing system.
  • maintenance may be performed to further extend service life.
  • both the valve and the control system may be arranged downhole.

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Acoustics & Sound (AREA)
  • Remote Sensing (AREA)
  • Geophysics (AREA)
  • Apparatuses For Generation Of Mechanical Vibrations (AREA)
  • Investigating Or Analyzing Materials By The Use Of Ultrasonic Waves (AREA)

Abstract

A downhole acoustic sensing system includes a pulsator device configured and disposed to be arranged in a downhole environment, and a control system operatively connected to the pulsator device. The control system delivers at least one control input to the pulsator device to generate a sinusoidal acoustic signal.

Description

    BACKGROUND
  • The present invention relates to the art of production fluid monitoring systems and, more particularly, to a production fluid monitoring system including a downhole acoustic sensing system having a downhole pulsator.
  • Acoustic devices are used to measure various parameters in a downhole environment. Often times, an acoustic device may be used to determine parameters of a downhole acoustic medium including solids and/or fluids proximate to a drill head. In such cases, the acoustic device may be mounted to the drill string. In many cases, the acoustic device takes the form of a piezo-electric transducer. Piezo-electric transducers may also be mounted to production tubing and operated to transmit and/or receive acoustic signals through the acoustic medium.
    • SUMMARY
  • A downhole acoustic sensing system includes a pulsator device configured and disposed to be arranged in a downhole environment, and a control system operatively connected to the pulsator device. The control system delivers at least one control input to the pulsator device to generate a sinusoidal acoustic signal.
  • A production fluid monitoring system includes a pulsator device configured and disposed to be arranged in a downhole environment and a control system operatively connected to the pulsator device. The control system delivers at least one control input to the pulsator device to deliver a sinusoidal acoustic signal through downhole fluids. A data acquisition system is configured and disposed to detect the sinusoidal acoustic signal passing through the downhole production fluids.
  • A method of monitoring downhole production fluids includes delivering a positive pressure pulse from a downhole pulsator to form a first portion of a downhole acoustic signal, delivering a negative pressure pulse downhole to form a second portion of the downhole acoustic signal, passing the acoustic signal through a production fluid, and sensing the acoustic signal to determine a quality of the production fluid.
    • BRIEF DESCRIPTION OF THE DRAWINGS
  • Referring now to the drawings wherein like elements are numbered alike in the several Figures:
  • FIG. 1 is a partial cross-sectional view of a downhole production tubing passing alongside a downhole acoustic device, in accordance with an exemplary embodiment;
  • FIG. 2 is a schematic view of a downhole production fluid acoustic sensing system including the downhole acoustic device of FIG. 1;
  • FIG. 3 is a view of the downhole acoustic device of FIG. 1 delivering a negative pressure pulse;
  • FIG. 4 is a view of the downhole acoustic device of FIG. 1 delivering a positive pressure pulse; and
  • FIG. 5 is a graphical representation of an acoustic signal produced by the downhole acoustic device, in accordance with an exemplary embodiment.
    •  DETAILED DESCRIPTION
  • Exploration companies routinely drill wells in a medium, indicated at 2 in FIG. 1, in search of natural resources such as natural gas and/or oil. The wells are formed by drilling a bore, indicted generally at 4, into medium 2. Bore 4 extends to a zone or region (not shown) in which a natural resource resides. After forming bore 4, production tubing 6 is inserted downhole into the bore 4. At this point it should be understood that the term “downhole” refers to a zone within medium 2 in which bore 4 is formed. Bore 4 may begin at an exposed earthen or sand surface, or under water. The term “uphole” as used herein refers to a zone or region outside of medium 2.
  • In accordance with an exemplary embodiment, a production fluid monitoring system, indicated generally at 14 in FIG. 2, is employed to monitor production fluids passing through production tubing 6. Production fluid monitoring system 14 includes a downhole acoustic sensing system 20 and a data acquisition system 24. Downhole acoustic sensing system 20 includes a pulsator device 30 which, as will be discussed more fully below, delivers an acoustic signal into production fluids passing through production tubing 6.
  • Pulsator device 30 may include a piston 32 shiftably mounted in a cylinder 34. Of course, it should be understood that pulsator device 30 may take on a variety of forms including diaphragms, pumps and the like, capable of delivering a pressure pulse into production fluids passing through production tubing 6. In the exemplary embodiment shown, cylinder 34 extends from a first end 36 exposed to the production fluids to a second, closed end 38 defining a volume 40. Piston 30 includes a first piston element 43 exposed at first end 36 and a second piston element 45 spaced from first piston element 43 by a support rod 47. Second piston element 45 separates volume 40 into a first portion 54 and a second portion 56.
  • In accordance with an exemplary embodiment, pulsator device 30 is operatively connected to a control system 70. Control system 70 is connected to a valve 74 which, in turn, may be fluidically coupled to a source of fluid 78 and pulsator device 30. Valve 74 may take the form of a ball valve or other form of fast switching valve. In the exemplary embodiment, shown, valve 74 is fluidically connected to cylinder 34 through a first control input 84 and a second control input 86. First control input 84 takes the form of a first hydraulic line 90 and second control input 86 takes the form of a second hydraulic line 92. Control system 70 operates valve 74 to alternatingly deliver control signals to pulsator device 30 causing an acoustic signal to pass into the production fluids. The control signals may take the form of pulses of a fluid passing through first and second hydraulic lines 90 and 92. The fluid may be a non-compressible fluid or a compressible fluid.
  • In accordance with an aspect of an exemplary embodiment, control system 70 operates valve 74 to delver a pulse of fluid through first hydraulic line 90 causing piston 32 to move in a first direction towards second end 38 of cylinder 34 creating a negative pressure pulse 96 (FIG. 5) into the production fluid, as shown in FIG. 3. Control system 70 then operates valve 74 to deliver another pulse of fluid into second hydraulic line 92 causing piston 32 to move in a second direction away from second end 38 of cylinder 34 creating a positive pressure pulse 98 (FIG. 5) into the production fluid, as shown in FIG. 4. Control system 70 alternates between sending pulses of fluid to first and second hydraulic lines 90 and 92 creating a sinusoidal acoustic signal 100, as shown in FIG. 5, that is delivered into the production fluid. Of course it should be understood that the sinusoidal signal may represent a summation of sinusoids.
  • In accordance with an aspect of an exemplary embodiment, data acquisition system 24 includes a data collection and analysis device 104 operatively connected to a plurality of downhole sensors 108. Downhole sensors 108 may take the form of fiber optic sensors 110 that are arranged at various points along production tubing 6. Acoustic signal(s) 100 passes in an uphole direction and a downhole direction through the production fluids. Data acquisition system 24 collects and analyzes acoustic signal(s) 100 at various points along production tubing 6 to monitor the production fluids.
  • At this point it should be understood that the exemplary embodiments describe a system for delivering pressure pulses into production fluids passing through production tubing in a resource collection system. The pressure pulses form an acoustic source that may be monitored to determine various attributes of the production fluid. The timing, duration, period and frequency of the pressure pulses may be varied depending upon desired sensing parameters. For example, a low frequency acoustic signal may be desirable when sensing deep downhole. It should also be understood that while described as a hydraulically actuated piston responding to two control signals, the present invention may employ a single control signal. A second control may be provided by a spring that is compressed by the piston in response to the single control signal. Further, other systems including electric and magnetic may be used to drive the piston.
  • It should be further understood that the control system may be provided uphole to provide technicians with greater control of the acoustic signal. For example, in contrast to current acoustic sources used during drilling which operate continuously, the pulsator device of the present invention may be operated only during select periods. Periodic, as opposed to continuous operation, may extend an overall service life of the downhole acoustic sensing system. Moreover, by mounting the control system and the valve uphole, maintenance may be performed to further extend service life. However, it should be understood that both the valve and the control system may be arranged downhole.
  • While one or more embodiments have been shown and described, modifications and substitutions may be made thereto without departing from the spirit and scope of the invention. Accordingly, it is to be understood that the present invention has been described by way of illustrations and not limitation.

Claims (20)

1. A downhole acoustic sensing system comprising:
a pulsator device configured and disposed to be arranged in a downhole environment; and
a control system operatively connected to the pulsator device, the control system delivering at least one control input to the pulsator device to generate a sinusoidal acoustic signal.
2. The downhole acoustic sensing system according to claim 1, wherein the pulsator device comprises a piston.
3. The downhole acoustic sensing system according to claim 2, wherein the at least one control input includes a first control input configured and disposed to drive the piston in a first direction and a second control input configured to drive the piston in a second direction substantially opposite the first direction.
4. The downhole acoustic sensing system according to claim 3, further comprising: a hydraulic line operatively connected to the control system and fluidically connected to the piston, the at least one control input comprising a non-compressible fluid passing through the hydraulic line.
5. The downhole acoustic sensing system according to claim 4, wherein the at least one control input comprises a non-compressible fluid passing through the hydraulic line.
6. The downhole acoustic sensing system according to claim 2, further comprising: a valve fluidically connected between the control system and the pulsator device, the valve selectively delivering the first and second control input.
7. The downhole acoustic sensing system according to claim 1, wherein the control system is configured and disposed to be arranged uphole and connected to the pulsator device through at least one hydraulic line.
8. A production fluid monitoring system comprising:
a pulsator device configured and disposed to be arranged in a downhole environment;
a control system operatively connected to the pulsator device, the control system delivering at least one control input to the pulsator device to deliver a sinusoidal acoustic signal through downhole production fluids; and
a data acquisition system includes at least one downhole sensor configured and disposed to detect the sinusoidal acoustic signal passing through the downhole production fluids.
9. The production fluid monitoring system according to claim 8, wherein the pulsator device comprises a piston.
10. The production fluid monitoring system according to claim 9, wherein the at least one control input includes a first control input configured and disposed to drive the piston in a first direction and a second control input configured to drive the piston in a second direction substantially opposite the first direction.
11. The production fluid monitoring system according to claim 10, further comprising: a hydraulic line operatively connected to the control system and fluidically connected to the piston, the at least one control input comprising a non-compressible fluid passing through the hydraulic line.
12. The production fluid monitoring system according to claim 11, wherein the at least one control input comprises a non-compressible fluid passing through the hydraulic line.
13. The production fluid monitoring system according to claim 9, further comprising: a valve fluidically connected between the control system and the pulsator device, the valve selectively delivering the first and second control inputs.
14. The production fluid monitoring system according to claim 8, wherein the control system is configured and disposed to be arranged uphole and connected to the pulsator device through at least one control input.
15. The production fluid monitoring system according to claim 14, wherein the at least one control input comprises a first hydraulic line configured to deliver a first control input and a second hydraulic line configured to deliver a second control input.
16. A method of monitoring downhole production fluids, the method comprising:
delivering a positive pressure pulse from a downhole pulsator to form a first portion of a acoustic signal;
delivering a negative pressure pulse downhole to form a second portion of the acoustic signal;
passing the acoustic signal through a production fluid; and
sensing the acoustic signal to determine a quality of the production fluid.
17. The method according to claim 16, wherein delivering the positive pressure pulse includes driving a piston in a first direction and delivering the negative pressure pulse includes driving the piston in a second, opposing direction.
18. The method of claim 17, wherein driving the piston on one of the first and second directions includes passing a control signal from an control system to the piston.
19. The method of claim 18, wherein passing the control signal includes sending a flow of fluid toward the piston.
20. The method of claim 16, wherein passing the acoustic signal through the production fluid includes passing the acoustic signal in an uphole direction and a downhole direction.
US14/156,645 2014-01-16 2014-01-16 Production fluid monitoring system including a downhole acousting sensing system having a downhole pulsator Abandoned US20150198034A1 (en)

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US14/156,645 US20150198034A1 (en) 2014-01-16 2014-01-16 Production fluid monitoring system including a downhole acousting sensing system having a downhole pulsator
PCT/US2014/071483 WO2015108668A1 (en) 2014-01-16 2014-12-19 Production fluid monitoring system including a downhole acoustic sensing system having a downhole pulsator

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BR112019003196A2 (en) 2016-09-26 2019-06-18 Halliburton Energy Services Inc computer-implemented method and system and method for detecting sand in a wellbore
GB2566910B (en) 2016-10-13 2021-08-25 Halliburton Energy Services Inc Systems and methods to utilize a sensor to provide spatial resolution in downhole leak detection
WO2018217207A1 (en) 2017-05-25 2018-11-29 Halliburton Energy Services, Inc. Systems and methods to use triangulation through one sensor beamforming in downhole leak detection
WO2019132975A1 (en) 2017-12-29 2019-07-04 Halliburton Energy Services, Inc. Systems and methods to utilize sensors to provide spatial rosolution in downhole leak detection
WO2020005281A1 (en) 2018-06-29 2020-01-02 Halliburton Energy Services, Inc. Systems and methods to utilize a sensor to provide spatial resolution in downhole leak detection

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Owner name: BAKER HUGHES INCORPORATED, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:LEE, ERIK N.;REEL/FRAME:032115/0700

Effective date: 20140117

STCB Information on status: application discontinuation

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