[go: up one dir, main page]

WO2011076850A1 - Procédé et système permettant d'améliorer la résolution spatiale d'un ensemble de détection acoustique répartie par fibre optique - Google Patents

Procédé et système permettant d'améliorer la résolution spatiale d'un ensemble de détection acoustique répartie par fibre optique Download PDF

Info

Publication number
WO2011076850A1
WO2011076850A1 PCT/EP2010/070495 EP2010070495W WO2011076850A1 WO 2011076850 A1 WO2011076850 A1 WO 2011076850A1 EP 2010070495 W EP2010070495 W EP 2010070495W WO 2011076850 A1 WO2011076850 A1 WO 2011076850A1
Authority
WO
WIPO (PCT)
Prior art keywords
fiber
channels
length
series
back reflections
Prior art date
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.)
Ceased
Application number
PCT/EP2010/070495
Other languages
English (en)
Inventor
Johannis Josephus Den Boer
Andre Franzen
Alex Groen
Daniel Joinson
Arthur Alexander Van Rooyen
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
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 Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Priority to US13/518,012 priority Critical patent/US9109944B2/en
Priority to AU2010334866A priority patent/AU2010334866B2/en
Priority to GB1210255.4A priority patent/GB2488710B/en
Priority to CA2782773A priority patent/CA2782773C/fr
Publication of WO2011076850A1 publication Critical patent/WO2011076850A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
    • G01D5/00—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable
    • G01D5/26—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light
    • G01D5/32—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light
    • G01D5/34—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells
    • G01D5/353—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
    • G01D5/35338—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre using other arrangements than interferometer arrangements
    • G01D5/35341—Sensor working in transmission
    • G01D5/35345—Sensor working in transmission using Amplitude variations to detect the measured quantity
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01H—MEASUREMENT OF MECHANICAL VIBRATIONS OR ULTRASONIC, SONIC OR INFRASONIC WAVES
    • G01H9/00—Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
    • G01H9/004—Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means using fibre optic sensors
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
    • G01D5/00—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable
    • G01D5/26—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light
    • G01D5/32—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light
    • G01D5/34—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells
    • G01D5/353—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
    • G01D5/35338—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre using other arrangements than interferometer arrangements
    • G01D5/35354—Sensor working in reflection
    • G01D5/35358—Sensor working in reflection using backscattering to detect the measured quantity
    • G01D5/35361—Sensor working in reflection using backscattering to detect the measured quantity using elastic backscattering to detect the measured quantity, e.g. using Rayleigh backscattering

Definitions

  • the invention relates to a method and system for enhancing the spatial resolution of a fiber optical
  • DAS Distributed Acoustic Sensing
  • a series of light pulses are transmitted through the fiber optical cable by a light transmission and receiving assembly arranged at or near one end of the cable and back reflections of the transmitted light pulses are received by means of an interrogator assembly arranged at or near said end.
  • vibration sensor can be achieved in a number of ways.
  • One method is to launch a pulse of coherent laser light into a fiber. As the pulse travels through the fiber imperfections in the crystal lattice making up the fiber cause light to be reflected back along the fiber and dispersed out of the fiber. Under normal conditions, say for communications purposes, these back reflections are loss terms.
  • the nature of the reflection causing imperfections are a function of the strain state of the fiber and as such by measuring the intensity of the back reflections and with multiple pulses it is possible to determine the strain state of the fiber as this varies temporally. Therefore an acoustic or vibration source which changed the strain state of the fiber could be measured using the back reflection data.
  • the launched laser pulse is precisely timed such that it's length in the fiber is known (10m is a possible value for the pulse length) .
  • the pulse is launched the back reflections are measured.
  • the measurement is made with a photodetector , which forms part of a light pulse transmission and receiving assembly and which integrates or adds up the number of photons received in a time period giving a figure relating to the total
  • the time period can be matched to the laser pulse length and by using multiple contiguous readings will provide a measurement of how the back reflected light varies over the length of the optical fiber. Further by launching laser pulses in close succession and at a fixed rate (for example about 10000 pulses per second) a discretized representation of the change in strain state of the optical fiber as a function of both time and space can be achieved.
  • DAS Acoustic Sensing
  • SNR Signal to Noise Ratio
  • a method for enhancing the spatial resolution of a fiber optical distributed acoustic sensing (DAS ) assembly comprising:
  • an optical fiber comprising a series of contiguous channels in a U-shaped loop such that the fiber comprises substantially parallel fiber sections with pairs of channels that are arranged at least
  • series of contiguous channels means that these channels form a succession of fiber segments that are sensitive to acoustic signals or vibration.
  • the light transmission and receiving assembly is:
  • the channels are arranged along the length of the fiber such that a first channel begins at or near the light transmission and receiving assembly and the U- shaped loop has a mid-point which is located at a
  • a U-shaped loop has a mid-point that is located at a distance from an interface between a pair of contiguous channels and from a mid ⁇ point of a channel, this implies that the mid-point of the U-shaped loop does not coincide with said interface and mid-point such that pairs of channels that are arranged staggered and only partially side by side.
  • the percentage of overlap of such pairs of channels may vary between 1 and 99%.
  • a system for enhancing the spatial resolution of a fiber optical distributed acoustic sensing (DAS) assembly comprising:
  • optical fiber comprising a series of contiguous channels, which fiber is arranged in a U-shaped loop configuration, such that the fiber comprises
  • Figure 1 shows a looped DAS assembly according to the invention
  • Figure 2 shows a prior art DAS assembly with an optical fiber suspended in a single run within a
  • Figures 3-5 show various alternative embodiments of DAS assemblies with a looped optical fiber within a wellbore according to the invention
  • FIG. 6A-D shows how optical signal back
  • Figures 7-9 show various other embodiments of looped DAS assemblies according to the invention.
  • the method and system according to the present invention improve the spatial resolution of a fiber optical Distributed Acoustic Sensing (DAS) assembly without needing to reduce the length of the launched laser pulse.
  • DAS Distributed Acoustic Sensing
  • Figure 1 shows a DAS assembly according to the invention, which is based on the insight that one or more loops of fiber 1 are more effective than the conventional single fiber 1 arrangement shown in Figure 2.
  • Figure 2 shows a conventional configuration of a single optical fiber 1 in a wellbore 2 in which a
  • the single fiber assembly shown in Figure 2 is configured in accordance with is standard practice by using a single optical fiber 1 with upper and lower end terminations to measure acoustic signals as disclosed in International patent application
  • WO2007/049004 wherein the fiber 1 is divided into a series of contiguous 10m channels C1-C7 and an acoustic signal 3 transmitted by an acoustic source 4 at a certain location along the length of the fiber 1 are measured by a single channel, for example channel C4.
  • a single channel for example channel C4.
  • DAS assembly a series of light pulses 5A, 5B are
  • a light transmission and receiving assembly 7 arranged at or near a first end 10 of the cable 1.
  • Back reflections 6A, 6B of the transmitted light pulses 5A, 5B are received by means of a photodetector in the light transmission and
  • the optical fiber 1 as an acoustic or vibration sensor can be achieved by launching a series of pulses 5A, 5B of coherent laser light into a fiber 1.
  • pulses 5A, 5B travel through the fiber 1 imperfections in the crystal lattice making up the fiber 1 cause light to be reflected back along the fiber and dispersed out of the fiber.
  • the nature of the back reflection causing imperfections are a function of the strain state of the fiber and as such by measuring the intensity of the back reflections 6A, 6B and with multiple pulses 5A, 5B it is possible to determine the strain state of the fiber 1 as this varies temporally. Therefore an acoustic or
  • vibration source 4 which changed the strain state of the fiber could be measured using the back reflection data 6A, 6B.
  • Figure 1 depicts an U-shaped looped fiber 1 with two substantially parallel fiber sections 1A and IB, also referred to as upward and downward fiber runs or legs 1A and IB, that are connected near the bottom of the well 2 by a single U-bend Ul .
  • Light pulses 5A, 5B are transmitted into the fiber 1 by a light pulse transmission and receiving assembly 7, which also monitors back
  • all channels C1-C14 can be considered to be sampled simultaneously as the propagation time of the laser pulse 5A, which travels at the speed of light, is much higher than the frequencies of interest in the acoustic signals 3, which travel at the speed of sound.
  • Figure 3 shows a DAS assembly comprising a single U- shaped loop Ul, which is located at an interface between a pair of adjacent channels C7 and C8.
  • the looped DAS assembly with a pair of substantially parallel downward and upward legs 1A, IB shown in FIG.3 is substantially similar to that of FIG.l and has a U-shaped loop Ul arranged in the well 2 at a depth of about 70 meters below the earth surface.
  • Figure 4 shows a DAS assembly comprising a single U- shaped loop Ul, which is located at a quarter of the 10m channel length of channel C8, so that the channels C9-C15 on the downward leg 1A of the fiber 1 will be offset from the channels C1-C7 on the upward leg IB of the fiber 1.
  • Figures 5 and 6A-D show that a 50% overlap of 10 m long channels C1-C22 will improve the ability of the DAS assembly according to the invention to provide spatial discrimination to detect acoustic waves 3 transmitted by an underground sound source 4 at 5 m intervals by
  • the left hand diagram in Figure 6A depicts a pulse input
  • FIG. 6Band C show the detection of the pulse input 5A in the whole-spaced and staggered channels C1-C22 of Fig.5.
  • the right hand diagram in Figure 6D shows the detection in the virtual half-spaced channels Cl1 ⁇ 2 , C21 ⁇ 2 , C31 ⁇ 2 , etc, created by the overlapping portions of the staggered channels CI and C22, C2 and C22, etc. in accordance with the method according to the invention.
  • Figure 7 shows that it is also possible to use the method according to the invention to further increase spatial resolution, such that the spatial resolution is improved from 10m to 2.5m by installing the fiber 1 in a zig-zag pattern with three loops U1-U3 which divide the fiber in two downward fiber runs 1A, 1C and two upward fiber runs IB, ID.
  • each loop U1-U3 is equal to 3 ⁇ 4 of the channel length.
  • the length of the fiber 1 is also equal to 3 ⁇ 4 of the channel length.
  • the method according to the invention can be further extended with more fiber runs and different length loops. This follows the basic formula that the fiber runs should be whole numbers of channels long and the loops at the top and bottom should length of the desired overlap of detection, such that:
  • the ratio 1/x does not need to be a accurately predetermined ratio.
  • the number of increments is only limited by the range of the optical pulse (up to about 40 or 50km) and the number of substantially parallel fiber runs 1A-1D that can be installed downhole in a wellbore 2 (5 pairs of substantially parallel fiber runs is fairly standard) .
  • Another feature of the method and system according to the invention is that they can to an extend be
  • Figure 8 shows that in the case of a single fiber loop 1A, IB the method is simple and can be achieved
  • the channels are arranged such that they receive signals from the same spatial location. It would be necessary to establish that this situation had been achieved through measurement of the fiber or calibration with a known source. However, once a calibration of channel position had been achieved, it becomes trivial to modify the channel positions as shown in Figure 9.
  • Figures 10 and 11 show that with multiple zig-zag fiber loops U1-U4 it is only necessary that the loops U1,U3 at the bottom of the well are of equal distance from the surface, that the fiber runs 1A-1D are a whole number of channel lengths (which can be adjusted from surface) and that the loop U2 at surface 22 is equal to length of the incremental steps (1/4 channel length in the case of a 4 fiber run, 1 ⁇ 4 channel resolution system) .
  • Figures 10 and 11 further show that it is also possible to configure a system of for example four fiber runs 1A-1D and three fiber loops U1-U3 to provide two separate measurements of the same depth with one pair of fiber runs 1A, IB offset from the other 1C, ID by a half channel length.
  • This configuration with four fiber run 1A-1D is shown in Figure 10 and allows to increase the
  • SNR Signal to Noise Ration
  • Figure 11 shows that the DAS assembly 1 shown in Figure 10 can later be reconfigured at surface to provide 3 ⁇ 4 channel spacing simply by reducing the length of the surface loop U2 and altering the timing of the

Landscapes

  • Physics & Mathematics (AREA)
  • General Physics & Mathematics (AREA)
  • Measurement Of Mechanical Vibrations Or Ultrasonic Waves (AREA)
  • Electrostatic, Electromagnetic, Magneto- Strictive, And Variable-Resistance Transducers (AREA)
  • Optical Radar Systems And Details Thereof (AREA)

Abstract

Selon l'invention, la résolution spatiale d'un ensemble de détection acoustique répartie (DAS) par fibre optique est améliorée - par la disposition d'une fibre DAS optique (1) avec une série de canaux contigus (C1 à C14) qui sont sensibles à une vibration dans une boucle en U (Ul) de sorte que des sections fibre sensiblement parallèles (IA, IB) comprennent des paires de canaux (C1 et C14, C2 et C13, C3 et C12…, etc.) qui sont disposés au moins partiellement côte à côte ; - par la transmission d'une série d'impulsions lumineuses (5A, 5B) par le biais de la fibre optique (1) et la réception en retour de réflexions (6A, 6B) desdites impulsions lumineuses (5A, 5B) par un ensemble émetteur-récepteur de lumière (7) ; et - par le traitement des réflexions reçues en retour (6A, 6B) de sorte que les réflexions en retour provenant d'au moins deux canaux (C1, C14 ; C2, C13) qui sont disposés au moins partiellement côte à côte soient corrélées entre elles.
PCT/EP2010/070495 2009-12-23 2010-12-22 Procédé et système permettant d'améliorer la résolution spatiale d'un ensemble de détection acoustique répartie par fibre optique Ceased WO2011076850A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
US13/518,012 US9109944B2 (en) 2009-12-23 2010-12-22 Method and system for enhancing the spatial resolution of a fiber optical distributed acoustic sensing assembly
AU2010334866A AU2010334866B2 (en) 2009-12-23 2010-12-22 Method and system for enhancing the spatial resolution of a fiber optical distributed acoustic sensing assembly
GB1210255.4A GB2488710B (en) 2009-12-23 2010-12-22 Method and system for enhancing the spatial resolution of a fiber optical distributed acoustic sensing assembly
CA2782773A CA2782773C (fr) 2009-12-23 2010-12-22 Procede et systeme permettant d'ameliorer la resolution spatiale d'un ensemble de detection acoustique repartie par fibre optique

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP09180657.0 2009-12-23
EP09180657 2009-12-23

Publications (1)

Publication Number Publication Date
WO2011076850A1 true WO2011076850A1 (fr) 2011-06-30

Family

ID=42046285

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2010/070495 Ceased WO2011076850A1 (fr) 2009-12-23 2010-12-22 Procédé et système permettant d'améliorer la résolution spatiale d'un ensemble de détection acoustique répartie par fibre optique

Country Status (4)

Country Link
AU (1) AU2010334866B2 (fr)
CA (1) CA2782773C (fr)
GB (1) GB2488710B (fr)
WO (1) WO2011076850A1 (fr)

Cited By (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8245780B2 (en) 2009-02-09 2012-08-21 Shell Oil Company Method of detecting fluid in-flows downhole
WO2013098321A2 (fr) 2011-12-30 2013-07-04 Shell Internationale Research Maatschappij B.V. Système et procédé avancés permettant la production de fluide hydrocarbure
WO2013011283A3 (fr) * 2011-07-15 2013-07-18 Optasense Holdings Limited Prospection géophysique sismique
US8994929B2 (en) 2011-08-09 2015-03-31 Shell Oil Company Method and apparatus for measuring seismic parameters of a seismic vibrator
US9003888B2 (en) 2009-02-09 2015-04-14 Shell Oil Company Areal monitoring using distributed acoustic sensing
US9074462B2 (en) 2011-03-09 2015-07-07 Shell Oil Company Integrated fiber optic monitoring system for a wellsite and method of using same
US9080949B2 (en) 2009-12-23 2015-07-14 Shell Oil Company Detecting broadside and directional acoustic signals with a fiber optical distributed acoustic sensing (DAS) assembly
US9091589B2 (en) 2011-06-20 2015-07-28 Shell Oil Company Fiber optic cable with increased directional sensitivity
US9234999B2 (en) 2010-12-21 2016-01-12 Shell Oil Company System and method for making distributed measurements using fiber optic cable
US9347313B2 (en) 2011-06-13 2016-05-24 Shell Oil Company Hydraulic fracture monitoring using active seismic sources with receivers in the treatment well
US9416598B2 (en) 2011-05-18 2016-08-16 Shell Oil Company Method and system for protecting a conduit in an annular space around a well casing
US9470083B2 (en) 2008-12-31 2016-10-18 Shell Oil Company Method for monitoring physical parameters of well equipment
US9494461B2 (en) 2011-12-15 2016-11-15 Shell Oil Company Detecting broadside acoustic signals with a fiber optical distrubuted acoustic sensing (DAS) assembly
US10088353B2 (en) 2012-08-01 2018-10-02 Shell Oil Company Cable comprising twisted sinusoid for use in distributed sensing
CN111757973A (zh) * 2018-01-08 2020-10-09 沙特阿拉伯石油公司 定向敏感的光纤线缆井眼系统
CN114008294A (zh) * 2019-04-24 2022-02-01 沙特阿拉伯石油公司 地下井鱼雷分布式声学感测系统和方法

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4545253A (en) * 1983-08-29 1985-10-08 Exxon Production Research Co. Fiber optical modulator and data multiplexer
WO2001027569A1 (fr) * 1999-10-12 2001-04-19 Future Fibre Technologies Pty Ltd Procede et dispositif de pesee d'un vehicule en mouvement
WO2007049004A1 (fr) 2005-10-25 2007-05-03 Qinetiq Limited Dispositif de detection et de surveillance du trafic

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4545253A (en) * 1983-08-29 1985-10-08 Exxon Production Research Co. Fiber optical modulator and data multiplexer
WO2001027569A1 (fr) * 1999-10-12 2001-04-19 Future Fibre Technologies Pty Ltd Procede et dispositif de pesee d'un vehicule en mouvement
WO2007049004A1 (fr) 2005-10-25 2007-05-03 Qinetiq Limited Dispositif de detection et de surveillance du trafic

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9752425B2 (en) 2008-12-31 2017-09-05 Shell Oil Company Carrier rod for an optical fiber assembly and system for monitoring deformation of well equipment
US9470083B2 (en) 2008-12-31 2016-10-18 Shell Oil Company Method for monitoring physical parameters of well equipment
US8245780B2 (en) 2009-02-09 2012-08-21 Shell Oil Company Method of detecting fluid in-flows downhole
US9003888B2 (en) 2009-02-09 2015-04-14 Shell Oil Company Areal monitoring using distributed acoustic sensing
US9080949B2 (en) 2009-12-23 2015-07-14 Shell Oil Company Detecting broadside and directional acoustic signals with a fiber optical distributed acoustic sensing (DAS) assembly
US9234999B2 (en) 2010-12-21 2016-01-12 Shell Oil Company System and method for making distributed measurements using fiber optic cable
US9074462B2 (en) 2011-03-09 2015-07-07 Shell Oil Company Integrated fiber optic monitoring system for a wellsite and method of using same
US9416598B2 (en) 2011-05-18 2016-08-16 Shell Oil Company Method and system for protecting a conduit in an annular space around a well casing
US9347313B2 (en) 2011-06-13 2016-05-24 Shell Oil Company Hydraulic fracture monitoring using active seismic sources with receivers in the treatment well
US9091589B2 (en) 2011-06-20 2015-07-28 Shell Oil Company Fiber optic cable with increased directional sensitivity
EA026854B1 (ru) * 2011-07-15 2017-05-31 Оптасенс Холдингз Лимитед Сейсмическое геофизическое исследование
GB2506789A (en) * 2011-07-15 2014-04-09 Optasense Holdings Ltd Seismic geophysical surveying using a fibre optic distributed sensing apparatus
US9465126B2 (en) 2011-07-15 2016-10-11 Optasense Holdings Limited Seismic geophysical surveying
WO2013011283A3 (fr) * 2011-07-15 2013-07-18 Optasense Holdings Limited Prospection géophysique sismique
GB2506789B (en) * 2011-07-15 2017-05-17 Optasense Holdings Ltd Seismic geophysical surveying
US9234972B2 (en) 2011-08-09 2016-01-12 Shell Oil Company Method and apparatus for measuring seismic parameters of a seismic vibrator
US8994929B2 (en) 2011-08-09 2015-03-31 Shell Oil Company Method and apparatus for measuring seismic parameters of a seismic vibrator
US9494461B2 (en) 2011-12-15 2016-11-15 Shell Oil Company Detecting broadside acoustic signals with a fiber optical distrubuted acoustic sensing (DAS) assembly
US9766119B2 (en) 2011-12-15 2017-09-19 Shell Oil Company Detecting broadside acoustic signals with a fiber optical distributed acoustic sensing (DAS) assembly
US10139269B2 (en) 2011-12-15 2018-11-27 Shell Oil Company Detecting broadside acoustic signals with a fiber optical distributed acoustic sensing (DAS) assembly
WO2013098321A2 (fr) 2011-12-30 2013-07-04 Shell Internationale Research Maatschappij B.V. Système et procédé avancés permettant la production de fluide hydrocarbure
US10088353B2 (en) 2012-08-01 2018-10-02 Shell Oil Company Cable comprising twisted sinusoid for use in distributed sensing
US10788359B2 (en) 2012-08-01 2020-09-29 Shell Oil Company Cable comprising sinusoidal paths along longitudinal surfaces for use in distributed sensing
CN111757973A (zh) * 2018-01-08 2020-10-09 沙特阿拉伯石油公司 定向敏感的光纤线缆井眼系统
CN114008294A (zh) * 2019-04-24 2022-02-01 沙特阿拉伯石油公司 地下井鱼雷分布式声学感测系统和方法

Also Published As

Publication number Publication date
GB201210255D0 (en) 2012-07-25
AU2010334866B2 (en) 2014-09-04
GB2488710B (en) 2015-07-08
CA2782773C (fr) 2017-04-11
GB2488710A (en) 2012-09-05
AU2010334866A1 (en) 2012-06-21
CA2782773A1 (fr) 2011-06-30

Similar Documents

Publication Publication Date Title
CA2782773C (fr) Procede et systeme permettant d'ameliorer la resolution spatiale d'un ensemble de detection acoustique repartie par fibre optique
US9109944B2 (en) Method and system for enhancing the spatial resolution of a fiber optical distributed acoustic sensing assembly
US8315486B2 (en) Distributed acoustic sensing with fiber Bragg gratings
US9140815B2 (en) Signal stacking in fiber optic distributed acoustic sensing
CA2762454C (fr) Debimetre a capteur acoustique distribue
AU2017230721B2 (en) Measuring downhole temperature by combining DAS/DTS data
AU2012228034B2 (en) Subsurface monitoring using distributed acoustic sensors
EP3126878B1 (fr) Surveillance de fond de trou
US9003888B2 (en) Areal monitoring using distributed acoustic sensing
US10725174B2 (en) Method and system for determining the distance to an acoustically reflective object in a conduit
JP2013506828A (ja) 位相ベース検知
US20220283330A1 (en) Gauge Length Correction For Seismic Attenuation From Distributed Acoustic System Fiber Optic Data
EA026854B1 (ru) Сейсмическое геофизическое исследование
Willis et al. Important aspects of acquiring distributed acoustic sensing (DAS) data for geoscientists
Madsen et al. Simultaneous multiwell VSP using distributed acoustic sensing
CN119104102A (zh) 一种陷落柱位置和导水性监测系统与监测方法

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 10795394

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 2010334866

Country of ref document: AU

ENP Entry into the national phase

Ref document number: 2782773

Country of ref document: CA

ENP Entry into the national phase

Ref document number: 1210255

Country of ref document: GB

Kind code of ref document: A

Free format text: PCT FILING DATE = 20101222

WWE Wipo information: entry into national phase

Ref document number: 1210255.4

Country of ref document: GB

ENP Entry into the national phase

Ref document number: 2010334866

Country of ref document: AU

Date of ref document: 20101222

Kind code of ref document: A

WWE Wipo information: entry into national phase

Ref document number: 13518012

Country of ref document: US

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 10795394

Country of ref document: EP

Kind code of ref document: A1