EP2909440B1 - Mesure de vitesse d'écoulement et de vitesse acoustique par détection acoustique distribuée - Google Patents

Mesure de vitesse d'écoulement et de vitesse acoustique par détection acoustique distribuée Download PDF

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Publication number
EP2909440B1
EP2909440B1 EP14743240.5A EP14743240A EP2909440B1 EP 2909440 B1 EP2909440 B1 EP 2909440B1 EP 14743240 A EP14743240 A EP 14743240A EP 2909440 B1 EP2909440 B1 EP 2909440B1
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EP
European Patent Office
Prior art keywords
velocity
pressure pulse
acoustic
well
optical waveguide
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German (de)
English (en)
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EP2909440A4 (fr
EP2909440A1 (fr
Inventor
Neal G. Skinner
Etienne M. Samson
Christopher L. Stokely
John L. Maida
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/107—Locating fluid leaks, intrusions or movements using acoustic means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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

Definitions

  • a well flow velocity measurement system comprising: a pressure pulse generator configured to propagate at least one pressure pulse through multiple fluid compositions in a well; and a distributed acoustic sensing system configured to detect coherent Rayleigh backscattering along an optical waveguide in the well, whereby a velocity of the pressure pulse in the well is determined.
  • the pressure pulses 18 could be generated by detonating a series of explosive or other exothermic devices in the well.
  • the scope of this disclosure is not limited to any particular manner of generating the pressure pulses 18.
  • DAS distributed acoustic sensing
  • the DAS system 20 of FIG. 1 comprises surface optics, electronics and software, commonly known to those skilled in the art as an interrogator 24, and the optical waveguide 22.
  • the optical waveguide 22 may be installed in the wellbore 12, inside or outside of the casing 14 or other tubulars, optionally in the cement 16 surrounding the casing, etc.
  • the interrogator 24 launches light into the optical waveguide 22 (e.g., from an infrared laser or other light source 26).
  • a detector 28 detects the light returned via the same optical waveguide 22.
  • the DAS system 20 uses measurement of backscattered light (e.g., coherent Rayleigh backscattering) to detect the acoustic energy along the waveguide 22.
  • an array of weak fiber Bragg gratings or other artificially introduced reflectors can be used with the optical waveguide 38 to detect acoustic signals along the waveguide.
  • the interrogator 24 and/or the pressure pulse generator 30 may be controlled via a control system 32, for example, including at least a processor 34 and memory 36.
  • Signal processing is used to segregate the waveguide 22 into an array of individual "microphones" or acoustic sensors, typically corresponding to 1-10 meter segments of the waveguide.
  • the waveguide 22 may be housed in a metal tubing or control line and positioned in the wellbore 12. In some examples, the waveguide 22 may be in cement surrounding the casing 14, in a wall of the casing or other tubular, suspended in the wellbore 12, in or attached to a tubular, etc. The scope of this disclosure is not limited to any particular placement of the waveguide 22.
  • the pressure pulse 18 is reflected back through the wellbore 12, and the reflected pressure pulse 38 is also detected by the DAS system 20.
  • the DAS system 20 detects the propagation of the pressure pulse 18 and the reflected pressure pulse 38 as they displace through the wellbore 12.
  • the pressure pulse 18 may be reflected off of a bottom of the well, off of a plug or other obstruction in the wellbore 12, or at a fluid/air or fluid/metal interface at or near the surface.
  • other changes in acoustic impedance can cause the pressure pulse 18 to be reflected.
  • Such changes in acoustic impedance can include changes in acoustic velocity due to changes in fluid composition in the wellbore 12, changes in casing 14 diameter, etc.
  • the scope of this disclosure is not limited to any particular manner of producing the reflected pressure pulse 38.
  • flow velocity, V f and acoustic velocity, V a of fluid compositions in the wellbore 12 can be readily determined. If flow velocity is known, a volumetric flow rate can be readily calculated by multiplying the flow velocity by flow area.
  • the acoustic velocity V a in a fluid composition depends on the fluids in the composition and a compliance of a pipe or conduit containing the fluid composition. If one knows the acoustic velocity of the fluid composition, the fluids in the composition (for example, an oil/water ratio) can be readily estimated.
  • FIG. 1 example two sets of perforations 42a,b are depicted in the casing 14, so that respective fluid compositions 40a,b are produced into the wellbore 12. Below the bottom perforations 42a, no flow enters the well. Between the perforations 42a,b, only the fluid composition 40a is present in the wellbore 12. Above the upper perforations 42b, the fluid compositions 40a,b are commingled.
  • the pressure pulse 18 is generated at the surface, which causes an acoustic wave or signal to travel from the surface through the wellbore 12 with velocity V o (in this case, opposing the direction of flow of the fluids 40a,b).
  • V o in this case, opposing the direction of flow of the fluids 40a,b.
  • the reflected pulse 38 may return to the surface and be reflected again through the wellbore 12.
  • the optical waveguide 22 installed in the well and connected to the DAS interrogator 24, it is possible to observe the propagation of the pulses 18, 38, and it may be possible to observe multiple round trips of a pressure pulse.
  • V a V w + V o / 2 and, thus, the acoustic velocity V a is simply the average of the velocities of the generated signal 36a and the reflected signal 36b in the FIG. 1 example.
  • Pipe compliance of a steel pipe is caused by not having infinitely stiff walls. It causes the acoustic wave traveling down the pipe to move slower than it would in a pipe with infinitely stiff walls.
  • the method can comprise: transmitting an acoustic signal (such as the pressure pulse 18) through at least one fluid composition 40a,b in a well; detecting velocities V u , V d of the acoustic signal in both opposite directions along an optical waveguide 22 in the well, the optical waveguide 22 being included in a distributed acoustic sensing system 20; and determining an acoustic velocity V a in the fluid composition based on the velocities of the acoustic signal.
  • an acoustic signal such as the pressure pulse 18
  • the transmitting step can include propagating at least one pressure pulse 18 through the fluid composition 40a,b.
  • the detecting step can include detecting at least one reflection of the pressure pulse 18.
  • Determining the acoustic velocity V a in the fluid composition 40a,b can include compensating for pipe compliance.
  • the distributed acoustic sensing system 20 may include an interrogator 24 which detects coherent Rayleigh backscattering in the optical waveguide 22.
  • Another well flow velocity measurement method described above can comprise: propagating at least one pressure pulse 18 through at least one fluid composition 40 a,b in a well; detecting a velocity of the pressure pulse 18 along an optical waveguide 22 in the well, the optical waveguide being included in a distributed acoustic sensing system 20; and determining an acoustic velocity V a in the fluid composition based on the velocity of the pressure pulse.
  • the detecting step can include detecting the velocity of the pressure pulse 18 in both opposite directions along the optical waveguide 22.
  • the propagating step includes propagating the pressure pulse 18 through multiple fluid compositions 40 a,b in the well.
  • the system 10 may include a processor 34 which determines an acoustic velocity V a in the fluid composition 40 a,b based on the velocity of the pressure pulse 18.

Claims (15)

  1. Procédé de mesure de vitesse d'écoulement de puits, comprenant :
    la propagation d'au moins une impulsion de pression (18) à travers de multiples compositions de fluide (40a, b) dans un puits (12) ;
    la détection d'une vitesse de l'impulsion de pression le long d'un guide d'ondes optique (22) dans le puits, le guide d'ondes optique étant inclus dans un système de détection acoustique distribuée (20) ; et
    la détermination d'une vitesse acoustique dans la composition de fluide sur la base de la vitesse de l'impulsion de pression.
  2. Procédé selon la revendication 1, dans lequel la détection comprend en outre la détection de la vitesse de l'impulsion de pression dans les deux directions opposées le long du guide d'ondes optique.
  3. Procédé selon la revendication 1 ou la revendication 2, dans lequel le système de détection acoustique distribuée détecte une rétrodiffusion de Rayleigh cohérente le long du guide d'ondes optique.
  4. Procédé selon une quelconque revendication précédente, dans lequel la détection comprend en outre la détection d'au moins une réflexion de l'impulsion de pression.
  5. Procédé selon une quelconque revendication précédente, dans lequel la détermination comprend en outre la détermination de la vitesse acoustique dans chacune des multiples compositions de fluide.
  6. Procédé selon une quelconque revendication précédente, dans lequel le système de détection acoustique distribuée indique une énergie acoustique le long du guide d'ondes optique.
  7. Procédé selon une quelconque revendication précédente, dans lequel le système de détection acoustique distribuée inclut un interrogateur qui détecte une rétrodiffusion de Rayleigh cohérente dans le guide d'ondes optique.
  8. Procédé selon une quelconque revendication précédente, dans lequel la propagation comprend en outre la génération du signal acoustique à un emplacement situé entre la surface de la terre et un fond du puits, le signal acoustique se propageant dans des directions opposées depuis l'emplacement.
  9. Procédé selon une quelconque revendication précédente, dans lequel la propagation comprend en outre l'application d'un impact sur une colonne tubulaire.
  10. Procédé selon une quelconque revendication précédente, dans lequel la détermination de la vitesse acoustique dans la composition de fluide comprend en outre la compensation de la souplesse de tube.
  11. Procédé selon une quelconque revendication précédente, dans lequel :
    l'impulsion de pression se déplace comme un signal acoustique ; et
    la détection de vitesses du signal acoustique a lieu dans les deux directions opposées le long du guide d'ondes optique (22) .
  12. Système de mesure de vitesse d'écoulement de puits, comprenant :
    un générateur d'impulsions de pression (30) configuré pour propager au moins une impulsion de pression (18) à travers de multiples compositions de fluide (40a, b) dans un puits (12) ; et
    un système de détection acoustique distribuée (20) configuré pour détecter une rétrodiffusion de Rayleigh cohérente le long d'un guide d'ondes optique (22) dans le puits, grâce à quoi une vitesse de l'impulsion de pression dans le puits est déterminée.
  13. Système selon la revendication 12, dans lequel :
    un ordinateur est configuré pour déterminer une vitesse acoustique dans la composition de fluide sur la base de la vitesse de l'impulsion de pression ; et/ou
    lors de l'utilisation du système, une vitesse acoustique dans chacune des multiples compositions de fluide est déterminée.
  14. Système selon la revendication 12 ou la revendication 13, dans lequel :
    lors de l'utilisation du système, la vitesse de l'impulsion de pression dans les deux directions opposées le long du guide d'ondes optique est déterminée ; et/ou
    le système de détection acoustique distribuée est configuré pour détecter au moins une réflexion de l'impulsion de pression.
  15. Système selon l'une quelconque des revendications 12 à 14, dans lequel :
    le système de détection acoustique distribuée est configuré pour indiquer une énergie acoustique le long du guide d'ondes optique ; et/ou
    le générateur d'impulsions de pression est configuré pour appliquer un impact sur une colonne tubulaire (14) ; et/ou
    le générateur d'impulsions de pression est configuré pour propager l'impulsion de pression dans des directions opposées depuis un emplacement dans le puits.
EP14743240.5A 2013-01-24 2014-01-08 Mesure de vitesse d'écoulement et de vitesse acoustique par détection acoustique distribuée Active EP2909440B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US13/748,720 US20140202240A1 (en) 2013-01-24 2013-01-24 Flow velocity and acoustic velocity measurement with distributed acoustic sensing
PCT/US2014/010682 WO2014116424A1 (fr) 2013-01-24 2014-01-08 Mesure de vitesse d'écoulement et de vitesse acoustique par détection acoustique distribuée

Publications (3)

Publication Number Publication Date
EP2909440A1 EP2909440A1 (fr) 2015-08-26
EP2909440A4 EP2909440A4 (fr) 2016-07-20
EP2909440B1 true EP2909440B1 (fr) 2019-06-26

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US (1) US20140202240A1 (fr)
EP (1) EP2909440B1 (fr)
CA (1) CA2891596A1 (fr)
WO (1) WO2014116424A1 (fr)

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Also Published As

Publication number Publication date
EP2909440A4 (fr) 2016-07-20
CA2891596A1 (fr) 2014-07-31
US20140202240A1 (en) 2014-07-24
EP2909440A1 (fr) 2015-08-26
WO2014116424A1 (fr) 2014-07-31

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