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WO2024250530A1 - 井筒的气侵监测装置及方法 - Google Patents

井筒的气侵监测装置及方法 Download PDF

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Publication number
WO2024250530A1
WO2024250530A1 PCT/CN2023/127400 CN2023127400W WO2024250530A1 WO 2024250530 A1 WO2024250530 A1 WO 2024250530A1 CN 2023127400 W CN2023127400 W CN 2023127400W WO 2024250530 A1 WO2024250530 A1 WO 2024250530A1
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WO
WIPO (PCT)
Prior art keywords
wellbore
gas
echo signal
ultrasonic transducer
fluid flow
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.)
Pending
Application number
PCT/CN2023/127400
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English (en)
French (fr)
Inventor
蔡骁
郭庆丰
赵庆
张景田
王正旭
门明磊
梁磊
李鹏飞
张鑫
康健
屈宪伟
王国伟
叶晨曦
吴楠
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.)
Beijing Petroleum Machinery Co Ltd
China National Petroleum Corp
CNPC Engineering Technology R&D Co Ltd
Original Assignee
Beijing Petroleum Machinery Co Ltd
China National Petroleum Corp
CNPC Engineering Technology R&D Co Ltd
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 Beijing Petroleum Machinery Co Ltd, China National Petroleum Corp, CNPC Engineering Technology R&D Co Ltd filed Critical Beijing Petroleum Machinery Co Ltd
Publication of WO2024250530A1 publication Critical patent/WO2024250530A1/zh
Anticipated expiration legal-status Critical
Pending legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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

Definitions

  • the present application relates to the field of oil and gas drilling, and in particular to a gas intrusion monitoring device and method for a wellbore.
  • Ultrasonic Doppler gas intrusion monitoring technology is a non-invasive monitoring method, but the current Doppler ultrasonic technology has the following disadvantages: First, when two or more moving objects appear in the sampling volume, the echo signals reflected by these moving objects will be recorded, resulting in the inability to confirm the source of the echo signal, lack of axial resolution, and inability to obtain fluid information at a specified position; second, the ultrasonic signal first increases and then decreases with the increase of gas content, resulting in the inability to directly use ultrasonic characteristic parameters to judge the gas intrusion status.
  • a gas intrusion monitoring method that can solve the above-mentioned technical defects is needed to improve the monitoring accuracy of underground gas flow information, which is of great significance for the prevention and control of accidents such as blowouts.
  • the purpose of the embodiments of the present application is to provide a gas intrusion monitoring device and method for a wellbore, so as to obtain fluid information at a specified position and directly determine the gas intrusion status by using ultrasonic characteristics.
  • the embodiment of the present application provides a gas intrusion monitoring device for a wellbore, the gas intrusion
  • the monitoring device comprises: an ultrasonic transducer for transmitting pulse ultrasonic waves to the annular pipe of the wellbore in a transmitting mode, wherein the pulse ultrasonic waves are reflected when encountering a mobile scatterer at a set position in the annular pipe and generate an echo signal; and receiving the echo signal in a receiving mode; a data processing device for processing the echo signal to obtain the Doppler amplitude of the echo signal; and a determination module for determining whether gas invasion occurs in the wellbore according to the Doppler amplitude of the echo signal.
  • determining whether gas invasion occurs in the wellbore includes: determining a fluid flow pattern of the annular pipe at the set position based on the Doppler amplitude of the echo signal; and determining whether gas invasion occurs in the wellbore based on the fluid flow pattern of the annular pipe at the set position.
  • determining the fluid flow type of the annular pipe at the set position includes: if the Doppler amplitude is less than a first threshold, determining that the fluid flow type is a bubble flow; if the Doppler amplitude is greater than the first threshold and less than a second threshold, determining that the fluid flow type is a plunger flow; and if the Doppler amplitude is greater than the second threshold, determining that the fluid flow type is a stirring flow.
  • the determining whether gas intrusion occurs in the wellbore includes: when the ultrasonic transducer is one ultrasonic transducer, if the fluid flow type is bubble flow, determining that gas intrusion does not occur in the wellbore, and if the fluid flow type is plunger flow or stirring flow, determining that gas intrusion occurs in the wellbore; or when the ultrasonic transducer is multiple ultrasonic transducers, if the fluid flow type of the annular pipe at multiple set positions is bubble flow, determining that gas intrusion does not occur in the wellbore, and if there is plunger flow or stirring flow in at least one set position of the annular pipe, determining that gas intrusion occurs in the wellbore.
  • the determination module is further used to determine the degree of gas invasion in the wellbore based on the fluid flow pattern of the annulus pipe at the set position, and the determination of the degree of gas invasion in the wellbore includes: when the ultrasonic transducer is a single ultrasonic transducer, if the fluid flow pattern is a plunger flow, it is determined that moderate gas invasion has occurred in the wellbore; if the fluid flow pattern is a stirring flow, it is determined that severe gas invasion has occurred in the wellbore; or when the ultrasonic transducer is a plurality of ultrasonic transducers, if there are bubble flow and plunger flow in the annulus pipe, it is determined that moderate gas invasion has occurred in the wellbore; if there is no bubble flow in the annulus pipe, it is determined that severe gas invasion has occurred in the wellbore.
  • the ultrasonic transducer is a plurality of ultrasonic transducers
  • the plurality of ultrasonic transducers are distributed at the bottom, middle and upper parts of the wellbore.
  • the ultrasonic transducer transmits pulsed ultrasonic waves to the annular pipe at a set incident angle in a transmission mode.
  • the gas intrusion monitoring device further includes a control device for issuing a pulse signal control instruction, and the ultrasonic transducer switches between the transmitting mode and the receiving mode at a set time interval according to the pulse signal control instruction.
  • the processing of the echo signal includes: extracting a Doppler signal from the echo signal using an orthogonal demodulation technique; performing a short-time Fourier transform on the Doppler signal to obtain a Fourier time-frequency diagram; performing a wavelet transform on the Fourier spectrum in the Fourier time-frequency diagram to obtain an energy distribution spectrum diagram on the time-frequency plane; and obtaining the Doppler amplitude of the echo signal from the energy distribution spectrum diagram.
  • the present application provides a method for monitoring gas intrusion in a wellbore, the method comprising: performing the following operations through an ultrasonic transducer: transmitting pulsed ultrasonic waves to the annular pipe of the wellbore in a transmitting mode, the pulsed ultrasonic waves encountering a mobile scatterer at a set position in the annular pipe to be reflected and generate the echo signal, and receiving the echo signal in a receiving mode; processing the echo signal to obtain the Doppler amplitude of the echo signal; and determining whether gas intrusion has occurred in the wellbore based on the Doppler amplitude of the echo signal.
  • the present application can have good axial resolution through the above technical solution, and can obtain information at a specified position by setting an ultrasonic transducer and setting the position of the ultrasonic transducer, and can measure the fluid at the specified position and extract fluid information.
  • the solution of the present application also has good timeliness and accuracy, and can monitor and warn in time when gas invasion occurs and increase the well control time.
  • FIG1 is a schematic diagram of a gas intrusion monitoring device for a wellbore according to an embodiment of the present application
  • FIGS. 2a-2b are schematic diagrams showing that the fluid flow pattern is a bubble flow according to an embodiment of the present application
  • 3a-3b are schematic diagrams showing a fluid flow pattern of a plunger flow according to an embodiment of the present application.
  • 4a-4b are schematic diagrams showing a fluid flow pattern of stirring flow according to an embodiment of the present application.
  • 5a-5c are schematic diagrams of fluid flow patterns at different positions in an annular pipe according to an embodiment of the present application.
  • FIG6 is a schematic diagram of a gas intrusion monitoring device for a wellbore according to an embodiment of the present application.
  • FIG7 is a schematic flow chart of a method for monitoring gas intrusion in a wellbore according to an embodiment of the present application
  • FIG8 is a schematic diagram of a wellbore gas intrusion monitoring simulation device according to an embodiment of the present application.
  • the present application provides a gas invasion monitoring device for a wellbore, as shown in FIG1.
  • the gas invasion monitoring device may include: an ultrasonic transducer 200, which is used to emit pulsed ultrasonic waves to the annular pipe 100 of the wellbore in a transmitting mode, and the pulsed ultrasonic waves are reflected by a mobile scatterer at a set position in the annular pipe 100 and generate an echo signal; and receive the echo signal in a receiving mode; a data processing device 300, which is used to process the echo signal to obtain the Doppler amplitude of the echo signal; and a determination module 400, which is used to determine whether gas invasion occurs in the wellbore according to the Doppler amplitude of the echo signal.
  • the ultrasonic transducer 200 transmits and receives pulsed ultrasonic waves to the annular pipe 100
  • the solid line indicates the communication relationship between the ultrasonic transducer 200 and the data processing device 300 , and between the data processing device 300 and the determination module 400 .
  • the present application uses ultrasonic pulse Doppler.
  • the self-transmitting and self-receiving ultrasonic transducer 200 it is possible to transmit and receive ultrasonic waves at certain time intervals, that is, it switches to the receiving mode after transmitting the ultrasonic wave, and switches to the transmitting mode after receiving the ultrasonic wave.
  • the present application sets the position of the transducer.
  • the device can realize the acquisition of information at the specified location, measure the fluid at the specified location and extract fluid information, and obtain information on the gas flow at the specified location.
  • the application also has good timeliness and accuracy, and can monitor and warn in time when gas invasion occurs and increase well control time.
  • the ultrasonic transducer 200 can be installed on the outside of the annular pipe 100 to avoid any impact on the drilling fluid in the annular pipe 100.
  • the ultrasonic transducer 200 can transmit pulse ultrasonic waves to the annular pipe 100 at a set incident angle in the transmission mode.
  • the role of setting the incident angle is to reduce the impact of the wellbore wall on the ultrasonic wave. These impacts can be reduced by adjusting the incident angle according to the different materials of the wellbore wall.
  • the incident angle is set to 30-60°.
  • the ultrasonic transducer 200 can be set to one or more.
  • the ultrasonic transducer 200 in order to better achieve the detection effect, the ultrasonic transducer 200 should be placed in the middle of the outer side of the wellbore, so that the accuracy and timeliness of monitoring can be taken into account at the same time.
  • three ultrasonic transducers can be provided, which are respectively distributed in the upper part, the middle part and the bottom part of the outer side of the wellbore.
  • the specific setting position can be adaptively adjusted according to the needs of different application scenarios.
  • the distance L1 of the upper ultrasonic transducer from the top of the wellbore can be set to 1/4-1/3L
  • the distance L2 of the middle ultrasonic transducer from the top of the wellbore can be set to 1/3-2/3L
  • the distance L3 of the bottom ultrasonic transducer from the top of the wellbore can be set to 2/3-3/4L. More preferably, the distance between two adjacent ultrasonic transducers is not less than 1/6-1/4L.
  • the determination module 400 may include: a fluid flow type determination module, used to determine the fluid flow type of the annular pipe 100 at a set position according to the Doppler amplitude of the echo signal; and a gas invasion determination module, used to determine whether gas invasion occurs in the wellbore according to the fluid flow type of the annular pipe 100 at a set position.
  • the fluid flow type determination module can be used to make the following determinations: if the Doppler amplitude is less than a first threshold, the fluid flow type is determined to be a bubble flow; if the Doppler amplitude is greater than the first threshold and less than a second threshold, the fluid flow type is determined to be a plug flow; and if the Doppler amplitude is greater than the second threshold, the fluid flow type is determined to be a stirring flow.
  • Figures 2a, 3a, and 4a are real pictures taken with high-speed cameras
  • Figures 2b, 3b, and 4b are time-frequency spectra of the processed Doppler amplitude.
  • FIG2a shows that small bubbles with a diameter of about 5 mm appear in the pipeline, which are called gas bubbles. Bubble flow. In this case, it is generally considered to be a normal phenomenon of gas in the liquid, and gas intrusion is not determined.
  • Figure 2b shows that the amplitude of the Doppler amplitude measured at the bubble position is at a low level.
  • Figure 3a shows that many small bubbles aggregate to form large bubbles with a diameter close to the inner diameter of the pipe, and many small bubbles follow at the tail, which is called plunger flow. At this time, the bubble velocity increases significantly, showing a certain degree of gas invasion. At the same time, Figure 3b shows that the measured Doppler amplitude also increases significantly.
  • Figure 4a shows that the gas flow in the pipeline has become more chaotic.
  • the shape of the large-sized bubbles appears irregular compared to the large-sized bubbles in the plunger flow.
  • the small-sized bubbles that appear surround the large-sized bubbles, and the number is large, which is called stirring flow.
  • Figure 4b shows that the amplitude of the measured Doppler amplitude has also increased significantly.
  • transition nodes for determining a specific fluid flow type for example, the first threshold from bubble flow to plunger flow, or the second threshold from plunger flow to stirring flow
  • a specific fluid flow type for example, the first threshold from bubble flow to plunger flow, or the second threshold from plunger flow to stirring flow
  • the ultrasonic transducer 200 when the ultrasonic transducer 200 is one ultrasonic transducer, the ultrasonic transducer is preferably disposed in the middle of the outer side of the wellbore. If the fluid flow pattern is a bubble flow, it is determined that no gas invasion occurs in the wellbore. If the fluid flow pattern is a plunger flow or a stirring flow, it is determined that gas invasion occurs in the wellbore.
  • the ultrasonic transducer 200 when the ultrasonic transducer 200 is a plurality of ultrasonic transducers, for example, three ultrasonic transducers are provided, as shown in FIGS. 5a-5c. At this time, the plurality of ultrasonic transducers are preferably provided at the bottom, the middle and the upper part of the outside of the wellbore. If the fluid flow patterns of the annular pipe 100 at a plurality of set positions are all bubble flows (FIG. 5a), it is determined that no gas invasion occurs in the wellbore. If there is a plunger flow or a stirring flow in the annular pipe 100 at at least one set position (FIG. 5b and FIG. 5c), it is determined that gas invasion occurs in the wellbore.
  • the determination module 400 when gas invasion occurs in the wellbore, is further used to determine the extent of gas invasion in the wellbore according to the fluid flow pattern of the annular pipe 100 at a set position.
  • the ultrasonic transducer 200 when the ultrasonic transducer 200 is one ultrasonic transducer, the ultrasonic transducer is preferably disposed in the middle of the outer side of the wellbore. If the fluid flow pattern is a plug flow, it is determined that moderate gas invasion occurs in the wellbore. If the fluid flow pattern is a stirring flow, it is determined that severe gas invasion occurs in the wellbore.
  • the ultrasonic transducer 200 when the ultrasonic transducer 200 is a plurality of ultrasonic transducers, for example, three ultrasonic transducers are provided, as shown in FIG. 5b and FIG. 5c.
  • the plurality of ultrasonic transducers are preferably provided at the bottom, the middle and the upper part of the outer side of the wellbore. If there is a bubble flow and a plunger flow ( FIG. 5b), it is determined that moderate gas invasion occurs in the wellbore; if there is no bubble flow in the annulus pipe 100 (FIG. 5c), it is determined that severe gas invasion occurs in the wellbore.
  • the monitoring device may further include a control device for issuing a pulse signal control instruction, and the ultrasonic transducer 200 switches between the transmission mode and the reception mode at a set time interval according to the pulse signal control instruction.
  • the control device may include a computer 320 and an ultrasonic detector 210, and the computer 320 is used to control the ultrasonic detector 210 to issue a pulse signal control instruction.
  • the data processing device 300 may further include a digitizer 310 and a computer 320 .
  • the digitizer 310 is used to convert the echo signal into a digital signal
  • the computer 320 is used to process the digital signal.
  • processing the echo signal includes: extracting the Doppler signal from the echo signal using orthogonal demodulation technology; performing a short-time Fourier transform on the Doppler signal to obtain a Fourier time-frequency diagram; performing a wavelet transform on the Fourier spectrum in the Fourier time-frequency diagram to obtain an energy distribution spectrum diagram on the time-frequency plane; and obtaining the Doppler amplitude of the echo signal from the energy distribution spectrum diagram.
  • the received echo signal may contain various clutters, so it is necessary to perform orthogonal demodulation on the received echo signal, extract the useful Doppler signal after orthogonal demodulation, perform short-time Fourier transform and obtain the energy distribution spectrum diagram based on empirical wavelet transform.
  • the Fourier spectrum of the Doppler echo signal can be adaptively segmented by the EWT algorithm, and the single component containing the Doppler frequency shift can be extracted. Then, the single component component can be Hilbert transformed to obtain the energy distribution spectrum diagram of the signal on the time-frequency plane.
  • Various flow types can be identified by observing the changes in the Doppler amplitude and the changes in the energy distribution.
  • the pulse Doppler technology can detect the flow direction of the fluid at each position in the annular pipe 100, and then determine the velocity vector of the fluid at that position.
  • the velocity vector of the fluid can be used to assist in verifying whether gas invasion occurs in the wellbore.
  • the present application also provides a gas invasion monitoring method for a wellbore, as shown in Figure 7.
  • the gas invasion monitoring method may include: S100, performing the following operations by means of an ultrasonic transducer: transmitting pulse ultrasonic waves to the annular pipe in a transmitting mode, wherein the pulse ultrasonic waves are reflected by a mobile scatterer at a set position in the annular pipe and generate the echo signal, and receiving the echo signal in a receiving mode; S200, processing the echo signal to obtain the Doppler amplitude of the echo signal; and S300, determining whether gas invasion occurs in the wellbore according to the Doppler amplitude of the echo signal.
  • the present application adopts ultrasonic pulse Doppler, and through the self-transmitting and self-receiving ultrasonic transducer, it can transmit and receive ultrasonic waves at a certain time interval, that is, it is converted to the receiving mode after transmitting the ultrasonic wave, and converted to the transmitting mode after receiving the ultrasonic wave.
  • the present application can have axial resolution.
  • the acquisition of information at the specified position can be realized, and the fluid at the specified position can be measured and the fluid information can be extracted to obtain the information of the gas flow at the specified position.
  • the present application also has good timeliness and accuracy, and can monitor and warn in time when gas invasion occurs and increase the well control time.
  • the ultrasonic transducer can be installed outside the annular pipe to avoid any impact on the drilling fluid in the annular pipe.
  • the ultrasonic transducer can transmit pulse ultrasonic waves to the annular pipe at a set incident angle in the transmission mode.
  • the role of setting the incident angle is to reduce the impact of the wellbore wall on the ultrasonic wave. These impacts can be reduced by adjusting the incident angle according to the different materials of the wellbore wall.
  • the incident angle is set to 30-60°.
  • the ultrasonic transducer in step S100 can be set to one or more.
  • the ultrasonic transducer in order to achieve a better detection effect, the ultrasonic transducer should be placed in the middle of the outer side of the wellbore, so that the accuracy and timeliness of monitoring can be taken into account at the same time.
  • three ultrasonic transducers can be provided, respectively located at the upper part, the middle part and the bottom of the outer side of the wellbore.
  • a control device may be provided for issuing a pulse signal control instruction, and the ultrasonic transducer 200 switches between the transmitting mode and the receiving mode at a set time interval according to the pulse signal control instruction.
  • the control device may include a computer 320 and an ultrasonic detector 210, and the computer 320 is used to control the ultrasonic detector 210 to issue the pulse signal control instruction.
  • a digitizer 310 and a computer 320 may be provided.
  • the digitizer 310 is used to convert the echo signal into a digital signal
  • the computer 320 is used to process the digital signal.
  • the processing of the echo signal S200 includes: S210, using orthogonal demodulation technology to extract the Doppler signal from the echo signal; S220, performing short-time Fourier transform on the Doppler signal to obtain a Fourier time-frequency diagram; S230, performing empirical wavelet transform on the Fourier spectrum in the Fourier time-frequency diagram to obtain an energy distribution spectrum diagram on the time-frequency plane; and S240, obtaining the echo signal from the energy distribution spectrum diagram.
  • the Doppler amplitude of the wave signal is: using orthogonal demodulation technology to extract the Doppler signal from the echo signal; S220, performing short-time Fourier transform on the Doppler signal to obtain a Fourier time-frequency diagram; S230, performing empirical wavelet transform on the Fourier spectrum in the Fourier time-frequency diagram to obtain an energy distribution spectrum diagram on the time-frequency plane; and S240, obtaining the echo signal from the energy distribution spectrum diagram.
  • the Doppler amplitude of the wave signal is amplitude of the wave signal.
  • the received echo signal may contain various clutters. Therefore, it is necessary to perform orthogonal demodulation on the received echo signal, extract the useful Doppler signal after orthogonal demodulation, and perform short-time Fourier transform to obtain the time-frequency diagram.
  • the Fourier spectrum of the Doppler echo signal can be adaptively segmented by the EWT algorithm, and the single component containing the Doppler frequency shift can be extracted. Then, the single component component can be Hilbert transformed to obtain the energy distribution spectrum of the signal on the time-frequency plane.
  • Various flow types can be identified by observing the changes in the Doppler amplitude and the changes in the energy distribution.
  • the pulse Doppler technology can detect the flow direction of the fluid at each position in the annular pipe, and then determine the velocity vector of the fluid at that position.
  • the velocity vector of the fluid can be used to assist in verifying whether gas invasion has occurred in the wellbore.
  • the determining whether gas invasion occurs in the wellbore S300 may include: S310, determining the fluid flow pattern of the annular pipe at a set position according to the Doppler amplitude of the echo signal; and S320, determining whether gas invasion occurs in the wellbore according to the fluid flow pattern of the annular pipe at the set position.
  • the step S310 of determining the fluid flow type of the annular pipe at a set position may include: S311, if the Doppler amplitude is less than a first threshold, determining that the fluid flow type is a bubble flow; S312, if the Doppler amplitude is greater than the first threshold and less than a second threshold, determining that the fluid flow type is a plunger flow; and S313, if the Doppler amplitude is greater than the second threshold, determining that the fluid flow type is a stirring flow.
  • the determination of whether gas intrusion occurs in the wellbore S320 may include: S321, when the ultrasonic transducer is a single ultrasonic transducer (preferably the ultrasonic transducer is disposed in the middle of the outer side of the wellbore), if the fluid flow pattern is a bubble flow, it is determined that gas intrusion does not occur in the wellbore; if the fluid flow pattern is a plunger flow or a stirring flow, it is determined that gas intrusion occurs in the wellbore.
  • the determination of whether gas invasion has occurred in the wellbore S320 may further include: S322, in the case where the ultrasonic transducer is a plurality of ultrasonic transducers (for example, three ultrasonic transducers are provided, as shown in FIGS. 5a-5c. At this time, the plurality of ultrasonic transducers are preferably provided at the bottom, the middle and the upper part of the outside of the wellbore), if the fluid flow types of the annular pipe at a plurality of set positions are all bubble flows (FIG. 5a), it is determined that gas invasion has not occurred in the wellbore; if there is a plunger flow or a stirring flow in the annular pipe at at least one set position (FIG. 5b and FIG. 5c), it is determined that gas invasion has occurred in the wellbore.
  • the ultrasonic transducer is a plurality of ultrasonic transducers (for example, three ultrasonic transducers are provided, as shown in FIGS. 5a-5c.
  • the gas invasion monitoring method may further include: S400, determining the extent of gas invasion in the wellbore according to the fluid flow pattern of the annular pipe at a set position.
  • determining the extent of gas invasion in the wellbore S400 may include: S401, in the excess When the acoustic transducer is an ultrasonic transducer (preferably the ultrasonic transducer is arranged in the middle of the outer side of the wellbore), if the fluid flow pattern is a plug flow, it is determined that moderate gas invasion occurs in the wellbore; if the fluid flow pattern is a stirring flow, it is determined that severe gas invasion occurs in the wellbore.
  • the determination of the degree of gas invasion in the wellbore S400 may further include: S402, when the ultrasonic transducer is a plurality of ultrasonic transducers (for example, three ultrasonic transducers are provided, as shown in FIG. 5b and FIG. 5c. At this time, the plurality of ultrasonic transducers are preferably provided at the bottom, middle and upper part of the outside of the wellbore), if there is bubble flow and plunger flow in the annular pipe (FIG. 5b), it is determined that moderate gas invasion has occurred in the wellbore; if there is no bubble flow in the annular pipe (FIG. 5c), it is determined that severe gas invasion has occurred in the wellbore.
  • S402 when the ultrasonic transducer is a plurality of ultrasonic transducers (for example, three ultrasonic transducers are provided, as shown in FIG. 5b and FIG. 5c.
  • the plurality of ultrasonic transducers are preferably provided at the bottom, middle and upper part of the outside
  • the gas invasion monitoring device and method provided by the present application adopts pulse Doppler technology, which can not only monitor the velocity of gas-liquid two-phase flow, but also obtain the fluid information of the specified position in real time, and realize the real-time monitoring of the gas content and flow type of gas invasion in the well. And only a single ultrasonic transducer needs to be installed to realize the functions of transmission and reception, which is relatively low in cost and can adapt to most environments.
  • FIG. 8 In order to further illustrate the present application, an embodiment is provided below in conjunction with FIG. 8 to simulate the gas intrusion monitoring device of the present application.
  • the apparatus includes: a drilling fluid pool, a water pool, a pump, an annular pipe, an ultrasonic transducer (1, 2, 3), an ultrasonic detector, a digital instrument, a computer, an air compressor, and a gas and liquid flow meter.
  • the annular pipe is composed of a drill pipe and a wellbore wall, and the drilling fluid in the drilling fluid pool is injected into the annular pipe through a pump to simulate the working environment of a real drill pipe.
  • the gas intrusion simulation device is composed of an air compressor, a water pool, a gas flow meter, a liquid flow meter and a bubble crushing device.
  • the gas flow meter can control the speed of gas injection by the air compressor to simulate gas intrusion and gas intrusion of different degrees in an underbalanced state.
  • the ultrasonic transducer can be set to three, which are installed at the bottom, middle and top of the outside of the wellbore.
  • the computer can control the ultrasonic detector to send out a pulse signal control instruction.
  • the ultrasonic transducer emits a pulse wave with an incident angle of 45° into the annular pipe according to the pulse signal control instruction. Then the ultrasonic transducer is converted into a receiving mode to receive the echo signal.
  • the digitizer converts the echo signal into a digital signal and stores it in the computer.
  • the drilling process is complicated, and the received echo signal contains various clutters. Therefore, we first use the orthogonal demodulation technology to orthogonally demodulate the received echo signal and extract the Doppler signal from the echo signal. After orthogonal demodulation, the useful Doppler signal is extracted and short-time Fourier transform is performed to obtain the Fourier time-frequency diagram. The Fourier spectrum in the Fourier time-frequency diagram is subjected to wavelet transform (such as empirical wavelet transform) to obtain an energy distribution spectrum diagram on the time-frequency plane. Finally, the Doppler amplitude of the echo signal is obtained from the energy distribution spectrum diagram.
  • wavelet transform such as empirical wavelet transform
  • gas intrusion monitoring device and method of the present application have good timeliness and accuracy for the oil and gas drilling field, and can well improve the monitoring accuracy of underground gas flow information. Therefore, it has obvious technical advantages and is of great significance for the prevention and control of accidents such as blowouts.

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Abstract

一种井筒的气侵监测装置，包括：超声换能器（200），用于在发射模式下向井筒的环空管道（100）发射脉冲超声波，脉冲超声波遇到环空管道（100）内设定位置的移动散射体发生反射并产生回波信号；以及在接收模式下接收回波信号；数据处理装置（300），用于对回波信号进行处理，以获取回波信号的多普勒振幅；以及判定模块（400），用于根据回波信号的多普勒振幅，判定井筒是否发生气侵。该气侵监测装置具有很好的轴向分辨力，能够对指定位置的流体测量进而提取流体信息，在发生气侵时能够及时监控预警并增加井控时间。还包括一种井筒的气侵监测方法。

Description

井筒的气侵监测装置及方法
相关申请的交叉引用
本申请要求2023年06月07日提交的中国专利申请202310671506.4的权益，该申请的内容通过引用被合并于本文。
技术领域
本申请涉及油气钻井领域，尤其是涉及一种井筒的气侵监测装置及方法。
背景技术
当前随着油气井开发的地质条件越来越复杂，钻井过程中易遇到异常高压地层，发生气侵现象并出现井喷等各种钻井安全事故，极大地威胁了工人生命安全和环境保护。所以井喷等事故的预防和控制在钻井过程中的作用越来越大。
钻井过程中若发生气侵现象，在气侵发生的初始阶段，很难根据钻井液池的流体增量或流量差溢流等监测方法检测到。同时因为井口深度的增加，提早发现气侵现象的难度增大，明显减少了井控的时间。而通过井下随钻监测的方法则易受井下条件的干扰，易失真，对高温高压的环境适应性差。
超声波多普勒气侵监测技术是一种非侵入式监测方法，但目前的多普勒超声技术有如下缺点：一是当采样容积中出现两个或两个以上的运动物体时，这些运动物体反射的回波信号都将被记录下来，导致无法确认回波信号的来源，不具备轴向分辨力，无法获取指定位置的流体信息；二是超声信号随着含气率的增大呈现先增大后下降，导致无法直接利用超声特征参数判断气侵状态。
因此，需要一种能够解决上述技术缺陷的气侵监测方法，从而提高对井下气体流动信息的监测精度，对于对井喷等事故的预防和控制方面具有极大意义。
发明内容
本申请实施例的目的是提供一种井筒的气侵监测装置及方法，以达到获得指定位置的流体信息并直接利用超声特征判断气侵状态的效果。
为了实现上述目的，本申请实施例提供一种井筒的气侵监测装置，所述气侵 监测装置包括：超声换能器，用于在发射模式下向所述井筒的环空管道发射脉冲超声波，所述脉冲超声波遇到所述环空管道内设定位置的移动散射体发生反射并产生回波信号；以及在接收模式下接收所述回波信号；数据处理装置，用于对所述回波信号进行处理，以获取所述回波信号的多普勒振幅；以及判定模块，用于根据所述回波信号的多普勒振幅，判定所述井筒是否发生气侵。
可选的，所述判定所述井筒是否发生气侵包括：根据所述回波信号的多普勒振幅，判定所述环空管道在所述设定位置的流体流型；以及根据所述环空管道在所述设定位置的流体流型，判定所述井筒是否发生气侵。
可选的，所述判定所述环空管道在所述设定位置的流体流型包括：若所述多普勒振幅小于第一阈值，则判定所述流体流型为气泡流；若所述多普勒振幅大于所述第一阈值且小于第二阈值，则判定所述流体流型为柱塞流；以及若所述多普勒振幅大于所述第二阈值，则判定所述流体流型为搅拌流。
可选的，所述判定所述井筒是否发生气侵包括：在所述超声换能器为一个超声换能器的情况下，若所述流体流型为气泡流，则判定所述井筒未发生气侵，若所述流体流型为柱塞流或搅拌流，则判定所述井筒发生气侵；或者在所述超声换能器为多个超声换能器的情况下，若所述环空管道在多个设定位置的流体流型均为气泡流，则判定所述井筒未发生气侵，若所述环空管道在至少一个设定位置内存在柱塞流或搅拌流，则判定所述井筒发生气侵。
可选的，在所述井筒发生气侵的情况下，所述判定模块还用于根据环空管道在所述设定位置的流体流型，判定所述井筒发生气侵的程度，所述判定所述井筒发生气侵的程度包括：在所述超声换能器为一个超声换能器的情况下，若所述流体流型为柱塞流，则判定所述井筒发生中度气侵，若所述流体流型为搅拌流，则判定所述井筒发生重度气侵；或者在所述超声换能器为多个超声换能器的情况下，若所述环空管道内存在气泡流和柱塞流，则判定所述井筒发生中度气侵，若所述环空管道内不存在气泡流，则判定所述井筒发生重度气侵。
可选的，在所述超声换能器为多个超声换能器的情况下，所述多个超声换能器分布设置在所述井筒的底部、中部以及上部。
可选的，所述超声换能器在发射模式下以设定入射角度向所述环空管道发射脉冲超声波。
可选的，所述气侵监测装置还包括控制装置，用于发出脉冲信号控制指令，所述超声换能器根据所述脉冲信号控制指令以设定时间间隔在所述发射模式和所述接收模式中转换。
可选的，所述对所述回波信号进行处理包括：利用正交解调技术，从所述回波信号中提取多普勒信号；对所述多普勒信号进行短时傅里叶变换，以获得傅里叶时频图；对所述傅里叶时频图中的傅里叶频谱进行小波变换，以获得在时频平面上的能量分布频谱图；以及从所述能量分布频谱图获取所述回波信号的多普勒振幅。
另一方面，本申请提供一种井筒的气侵监测方法，所述气侵监测方法包括：通过超声换能器执行以下操作：在发射模式下向所述井筒的环空管道发射脉冲超声波，所述脉冲超声波遇到所述环空管道内设定位置的移动散射体发生反射并产生所述回波信号，以及在接收模式下接收回波信号；对所述回波信号进行处理，以获取所述回波信号的多普勒振幅；以及根据所述回波信号的多普勒振幅，判定所述井筒是否发生气侵。
相对于现有技术，本申请通过上述技术方案可以具有很好的轴向分辨力，通过设置超声换能器以及设置超声换能器的位置可以实现指定位置的信息的获取，能够对指定位置的流体测量进而提取流体信息。同时本申请的方案还具有良好的时效性以及准确性，在发生气侵时能够及时监控预警并增加井控时间。
本申请实施例的其它特征和优点将在随后的具体实施方式部分予以详细说明。
附图说明
附图是用来提供对本申请实施例的进一步理解，并且构成说明书的一部分，与下面的具体实施方式一起用于解释本申请实施例，但并不构成对本申请实施例的限制。在附图中：
图1是根据本申请一实施例的井筒的气侵监测装置示意图；
图2a-2b是根据本申请一实施例的流体流型为气泡流的示意图；
图3a-3b是根据本申请一实施例的流体流型为柱塞流的示意图；
图4a-4b是根据本申请一实施例的流体流型为搅拌流的示意图；
图5a-5c是根据本申请一实施例的环空管道内不同位置的流体流型示意图；
图6是根据本申请一实施例的井筒的气侵监测装置示意图；
图7是根据本申请一实施例的井筒的气侵监测方法流程示意图；
图8是根据本申请一实施例的井筒的气侵监测模拟装置示意图。
附图标记说明
100、环空管道；200、超声换能器；300、数据处理装置；400、判定模块；
210、超声检测仪；310、数字化仪器；320、计算机。
具体实施方式
以下结合附图对本申请实施例的具体实施方式进行详细说明。应当理解的是，此处所描述的具体实施方式仅用于说明和解释本申请实施例，并不用于限制本申请实施例。
本申请提供了一种井筒的气侵监测装置，如图1所示。该气侵监测装置可以包括：超声换能器200，用于在发射模式下向井筒的环空管道100发射脉冲超声波，脉冲超声波遇到环空管道100内设定位置的移动散射体发生反射并产生回波信号；以及在接收模式下接收回波信号；数据处理装置300，用于对回波信号进行处理，以获取回波信号的多普勒振幅；以及判定模块400，用于根据回波信号的多普勒振幅，判定井筒是否发生气侵。
其中，图1中的虚线表示超声换能器200向环空管道100发射并接收脉冲超声波，实线表示超声换能器200与数据处理装置300之间，以及数据处理装置300与判定模块400之间的通信关系。
在超声波进入环空管道100后，由于气液各相之间的声强反射率不同，接收到的回波信号也不同，因此可以根据回波信号的信号差异来分辨出移动散射体的差异。相对于现有技术中采用的波多普勒技术，本申请采用了超声脉冲多普勒，通过自发自收的超声换能器200，能够按照一定时间间隔发射和接收超声波，即，在发射超声波后转换为接收模式，在接收超声波后转换为发射模式。由于超声波在介质中的速度较为稳定，因此通过控制脉冲重复频率，即控制发射和接收超声波的时间间隔，可以有选择性地接收所需测量点的回波信号(且所接受的回波信号不发生重合)，因此可以具备轴向分辨力。同时，本申请通过设置换能器的位 置可以实现指定位置的信息的获取，能够对指定位置的流体测量进而提取流体信息，获取指定位置气体流动的信息。另外，本申请还具有良好的时效性以及准确性，在发生气侵时能够及时监控预警并增加井控时间。
在一实施例中，超声换能器200可以安装在环空管道100的外侧，从而避免对环空管道100内的钻井液流体产生任何影响。另外，超声换能器200在发射模式下可以以设定入射角度向环空管道100发射脉冲超声波。设定入射角度的作用是减少井筒壁对超声波的影响。可以根据井筒壁材料的不同，通过调整入射角度来减小这些影响。优选地，设定入射角度为30-60°。
在一实施例中，超声换能器200可以设置为一个或多个。在设置一个超声换能器的情况下，为了更好地起到检测效果，该超声换能器200应放置在井筒外侧的中部，这样可以同时兼顾监测的准确度和时效。优选地，在设置多个超声换能器的情况下，应保证至少有一个超声换能器位于井筒外侧的中部。例如，可以设置有三个超声换能器，分别分布位于井筒外侧的上部、中部和底部。具体的设置位置根据不同应用场景的需求可以适应性调整。例如，井筒总长度为L，则可以将上部的超声换能器距井筒顶端的距离L1设置为1/4-1/3L，可以将中部的超声换能器距井筒顶端的距离L2设置为1/3-2/3L，可以将底部的超声换能器距井筒顶端的距离L3设置为2/3-3/4L。更加优选地，相邻两个超声换能器之间的距离不小于1/6-1/4L。
在一实施例中，判定模块400可以包括：流体流型判定模块，用于根据回波信号的多普勒振幅，判定环空管道100在设定位置的流体流型；以及气侵判定模块，用于根据环空管道100在设定位置的流体流型，判定井筒是否发生气侵。
在一实施例中，流体流型判定模块可以用于做以下判定：若多普勒振幅小于第一阈值，则判定流体流型为气泡流；若多普勒振幅大于第一阈值且小于第二阈值，则判定流体流型为柱塞流；以及若多普勒振幅大于第二阈值，则判定流体流型为搅拌流。
在原理上，当发生气侵现象时，气体侵入环形管道内，并且呈现气液两相流动状态。因此可以根据流体流型来判断气体侵入量的大小。例如，可能会出现如图2a、3a、4a所示的三种情况，即，气泡流、柱塞流以及搅拌流。其中，图2a、3a、4a是高速相机实拍图，图2b、3b、4b是处理得到的多普勒振幅的时频谱图。
具体地，图2a为管道中出现分散直径约为5mm的小尺寸气泡，称之为气 泡流。在这种情况下，通常认为是液体中含气的正常现象，不判定发生气侵。同时图2b表示测得的气泡位置的多普勒振幅的幅值处于较低水平。
图3a出现了许多小尺寸气泡发生聚合现象，形成直径接近管道内径的大尺寸气泡，且尾部跟随着许多小尺寸气泡，称之为柱塞流。此时气泡速度明显升高，呈现出一定程度的气侵现象，同时图3b表示测得的多普勒振幅的幅值也明显增大。
图4a为管道中的气体流动变得更加混乱，出现的大尺寸气泡形状相比于柱塞流中的大尺寸气泡显得无规则，出现的小尺寸气泡包围了大尺寸气泡，且数量较多，称之为搅拌流。此时可以认定为明显发生气侵，同时图4b表示测得的多普勒振幅的幅值也已经非常明显地增大。
值得说明的是，由于应用场景不同，例如液体密度、管道直径、环境温度、环境压力等因素的影响，判定特定流体流型的转变节点(例如，从气泡流到柱塞流的第一阈值，或者从柱塞流到搅拌流的第二阈值)并不相同，本领域技术人员可以根据实际应用情况来适应性设置，本申请并不对此做具体限定。
在一实施例中，在超声换能器200为一个超声换能器的情况下，此时，优选地将该超声换能器设置在井筒外侧的中部。若流体流型为气泡流，则判定井筒未发生气侵。若流体流型为柱塞流或搅拌流，则判定井筒发生气侵。
在一实施例中，在超声换能器200为多个超声换能器的情况下，例如设置三个超声换能器，如图5a-5c所示。此时，优选地将所述多个超声换能器设置在井筒外侧的底部、中部以及上部。若环空管道100在多个设定位置的流体流型均为气泡流(图5a)，则判定井筒未发生气侵。若环空管道100在至少一个设定位置内存在柱塞流或搅拌流(图5b和图5c)，则判定井筒发生气侵。
在一实施例中，在井筒发生气侵的情况下，判定模块400还用于根据环空管道100在设定位置的流体流型，判定井筒发生气侵的程度。
在一实施例中，在超声换能器200为一个超声换能器的情况下，此时，优选地将该超声换能器设置在井筒外侧的中部。若流体流型为柱塞流，则判定井筒发生中度气侵。若流体流型为搅拌流，则判定井筒发生重度气侵。
在一实施例中，在超声换能器200为多个超声换能器的情况下，例如设置三个超声换能器，如图5b和图5c所示。此时，优选地将所述多个超声换能器设置在井筒外侧的底部、中部以及上部。若环空管道100内存在气泡流和柱塞流(图 5b)，则判定井筒发生中度气侵；若环空管道100内不存在气泡流(图5c)，则判定井筒发生重度气侵。
在一实施例中，如图6所示，该监测装置还可以包括控制装置，用于发出脉冲信号控制指令，超声换能器200根据脉冲信号控制指令以设定时间间隔在发射模式和接收模式中转换。可选地，该控制装置可以包括计算机320和超声检测仪210，计算机320用于控制超声检测仪210发出脉冲信号控制指令。
在一实施例中，数据处理装置300还可以包括数字化仪器310和计算机320，数字化仪器310用于将回波信号转化为数字信号，计算机320用于对数字信号进行处理。
在一实施例中，对回波信号进行处理包括：利用正交解调技术，从回波信号中提取多普勒信号；对多普勒信号进行短时傅里叶变换，以获得傅里叶时频图；对傅里叶时频图中的傅里叶频谱进行小波变换，以获得在时频平面上的能量分布频谱图；以及从能量分布频谱图获取回波信号的多普勒振幅。
由于钻井过程工况复杂，接收的回波信号中可能会包含各种杂波，因此需要将接收的回波信号进行正交解调，正交解调后提取有用的多普勒信号进行短时傅里叶变换和基于经验小波变换获得能量分布频谱图。例如可以通过EWT算法对多普勒回波信号的Fourier频谱进行自适应分割，提取出含有多普勒频移的单分量成分，然后对单分量成分做Hilbert变换，可以得到信号在时频平面上的能量分布频谱图。通过观察多普勒振幅的变化以及能量分布的变化实现对各种流型的识别。另外，通过多普勒频移信号，脉冲多普勒技术可以检测环空管道100内每个位置流体的流动方向，进而确定该位置流体的速度矢量，可以利用该流体的速度矢量来辅助验证所述井筒是否发生气侵。
本申请还提供了一种井筒的气侵监测方法，如图7所示。该气侵监测方法可以包括：S100，通过超声换能器执行以下操作：在发射模式下向所述环空管道发射脉冲超声波，所述脉冲超声波遇到所述环空管道内设定位置的移动散射体发生反射并产生所述回波信号，以及在接收模式下接收回波信号；S200，对回波信号进行处理，以获取回波信号的多普勒振幅；以及S300，根据回波信号的多普勒振幅，判定井筒是否发生气侵。
在超声波进入环空管道后，由于气液各相之间的声强反射率不同，接收到的 回波信号也不同，因此可以根据回波信号的信号差异来分辨出移动散射体的差异。相对于现有技术，本申请采用了超声脉冲多普勒，通过自发自收的超声换能器，能够按照一定时间间隔发射和接收超声波，即，在发射超声波后转换为接收模式，在接收超声波后转换为发射模式。由于超声波在介质中的速度较为稳定，因此通过控制脉冲重复频率，即控制发射和接收超声波的时间间隔，可以有选择性地接收所需测量点的回波信号(且所接受的回波信号不发生重合)，因此本申请可以具备轴向分辨力。同时，通过设置换能器的位置可以实现指定位置的信息的获取，能够对指定位置的流体测量进而提取流体信息，获取指定位置气体流动的信息。另外，本申请还具有良好的时效性以及准确性，在发生气侵时能够及时监控预警并增加井控时间。
在一实施例中，超声换能器可以安装在环空管道的外部，从而避免对环空管道内的钻井液流体产生任何影响。另外，超声换能器在发射模式下可以以设定入射角度向环空管道发射脉冲超声波。设定入射角度的作用是减少井筒壁对超声波的影响。可以根据井筒壁材料的不同，通过调整入射角度来减小这些影响。优选地，设定入射角度为30-60°。
在一实施例中，步骤S100中的超声换能器可以设置为一个或多个。在设置一个超声换能器的情况下，为了更好地起到检测效果，该超声换能器应放置在井筒外侧的中部，这样可以同时兼顾监测的准确度和时效。在设置多个超声换能器的情况下，应保证至少有一个超声换能器位于井筒外侧的中部。优选地，可以设置有三个超声换能器，分别位于井筒外侧的上部、中部和底部。
在一实施例中，如图4所示，可以设置有控制装置，用于发出脉冲信号控制指令，超声换能器200根据脉冲信号控制指令以设定时间间隔在发射模式和接收模式中转换。可选地，该控制装置可以包括计算机320和超声检测仪210，计算机320用于控制超声检测仪210发出脉冲信号控制指令。
在一实施例中，还可以设置有数字化仪器310和计算机320，数字化仪器310用于将回波信号转化为数字信号，计算机320用于对数字信号进行处理。
在一实施例中，对回波信号进行处理S200包括：S210，利用正交解调技术，从回波信号中提取多普勒信号；S220，对多普勒信号进行短时傅里叶变换，以获得傅里叶时频图；S230，对傅里叶时频图中的傅里叶频谱进行基于经验小波变换，以获得在时频平面上的能量分布频谱图；以及S240，从能量分布频谱图获取回 波信号的多普勒振幅。
由于钻井过程工况复杂，接收的回波信号中可能会包含各种杂波，因此需要将接收的回波信号进行正交解调，正交解调后提取有用的多普勒信号进行短时傅里叶变换获得时频图。例如可以通过EWT算法对多普勒回波信号的Fourier频谱进行自适应分割，提取出含有多普勒频移的单分量成分，然后对单分量成分做Hilbert变换，可以得到信号在时频平面上的能量分布频谱图。通过观察多普勒振幅的变化以及能量分布的变化实现对各种流型的识别。另外，通过多普勒频移信号，脉冲多普勒技术可以检测环空管道内每个位置流体的流动方向，进而确定该位置流体的速度矢量，可以利用该流体的速度矢量来辅助验证所述井筒是否发生气侵。
在一实施例中，所述判定所述井筒是否发生气侵S300可以包括：S310，根据回波信号的多普勒振幅，判定环空管道在设定位置的流体流型；以及S320，根据环空管道在设定位置的流体流型，判定井筒是否发生气侵。
在一实施例中，所述判定环空管道在设定位置的流体流型S310可以包括：S311，若多普勒振幅小于第一阈值，则判定流体流型为气泡流；S312，若多普勒振幅大于第一阈值且小于第二阈值，则判定流体流型为柱塞流；以及S313，若多普勒振幅大于第二阈值，则判定流体流型为搅拌流。
在一实施例中，所述判定井筒是否发生气侵S320可以包括：S321，在超声换能器为一个超声换能器的情况下(优选地将该超声换能器设置在井筒外侧的中部)，若流体流型为气泡流，则判定井筒未发生气侵；若流体流型为柱塞流或搅拌流，则判定井筒发生气侵。
在一实施例中，所述判定井筒是否发生气侵S320还可以包括：S322，在超声换能器为多个超声换能器的情况下(例如设置三个超声换能器，如图5a-5c所示。此时，优选地将所述多个超声换能器设置在井筒外侧的底部、中部以及上部)，若环空管道在多个设定位置的流体流型均为气泡流(图5a)，则判定井筒未发生气侵；若环空管道在至少一个设定位置内存在柱塞流或搅拌流(图5b和图5c)，则判定井筒发生气侵。
在一实施例中，在井筒发生气侵的情况下，该气侵监测方法还可以包括：S400，根据环空管道在设定位置的流体流型，判定井筒发生气侵的程度。
在一实施例中，所述判定井筒发生气侵的程度S400可以包括：S401，在超 声换能器为一个超声换能器的情况下(优选地将该超声换能器设置在井筒外侧的中部)，若流体流型为柱塞流，则判定井筒发生中度气侵；若流体流型为搅拌流，则判定井筒发生重度气侵。
在一实施例中，所述判定井筒发生气侵的程度S400还可以包括：S402，在超声换能器为多个超声换能器的情况下(例如设置三个超声换能器，如图5b和图5c所示。此时，优选地将所述多个超声换能器设置在井筒外侧的底部、中部以及上部)，若环空管道内存在气泡流和柱塞流(图5b)，则判定井筒发生中度气侵；若环空管道内不存在气泡流(图5c)，则判定井筒发生重度气侵。
综上所述，本申请提供的一种井筒的气侵监测装置与方法采用脉冲多普勒技术，不仅可以监测气液两相流流速，而且可以实时获取指定位置的流体信息，实现对井下气侵气体含量及流型的实时监测。并且只需要安装单一超声换能器，即可实现发射和接收的功能，成本相对低下，能够适应绝大多数环境。
为了进一步阐述本申请，下面结合图8提供一实施例对本申请的气侵监测装置进行模拟。
如图8中所示，包括：钻井液池、水池、泵、环空管道、超声换能器(1、2、3)、超声检测仪、数字化仪器、计算机、空气压缩机以及气体和液体流量计。其中，环空管道由钻杆和井筒壁组成，通过泵将钻井液池内的钻井液注入环空管道模拟真实钻杆的工作环境。
另外，由空气压缩机、水池、气体流量计、液体流量计以及气泡粉碎装置组成气侵模拟装置。气体流量计可以控制空气压缩机注入气体的速度，用于模拟欠平衡状态下发生气侵以及不同程度的气侵。
超声换能器可以设置为三个，分别安装在井筒外侧的底部、中部、上部三个位置。计算机可以控制超声检测仪发出脉冲信号控制指令，超声换能器根据脉冲信号控制指令向环空管道内发射入射角度为45°的脉冲波，紧接着超声换能器转换为接收模式，接收回波信号，数字化仪器将回波信号转化为数字信号，并存储在计算机内。
钻井过程工况复杂，接收的回波信号包含各种杂波。因此首先利用正交解调技术，将接收的回波信号进行正交解调，从回波信号中提取多普勒信号。正交解调后，提取有用的多普勒信号进行短时傅里叶变换，以获得傅里叶时频图。再对 傅里叶时频图中的傅里叶频谱进行小波变换(例如经验小波变换)，以获得在时频平面上的能量分布频谱图。最后从能量分布频谱图获取回波信号的多普勒振幅。
结合时频谱图的变化，通过观察多普勒振幅的变化以及能量分布的变化对各种流型的识别，结合本申请如上文所述的气侵监测方法，可以对是否发生气侵以及发生气侵的程度进行测量与实时监控的验证。
经过模拟试验，对于不同类型的气侵，使用本申请的气侵监测方法，均能够及时准确地识别出。可见采用本申请的气侵监测装置及方法对于油气钻井领域来说具有良好的时效性以及准确性，能够很好地提高对井下气体流动信息的监测精度，因此有着明显的技术优势，对于对井喷等事故的预防和控制方面具有极大意义。
还需要说明的是，术语“包括”、“包含”或者其任何其他变体意在涵盖非排他性的包含，从而使得包括一系列要素的过程、方法、商品或者设备不仅包括那些要素，而且还包括没有明确列出的其他要素，或者是还包括为这种过程、方法、商品或者设备所固有的要素。在没有更多限制的情况下，由语句“包括一个……”限定的要素，并不排除在包括要素的过程、方法、商品或者设备中还存在另外的相同要素。
以上仅为本申请的实施例而已，并不用于限制本申请。对于本领域技术人员来说，本申请可以有各种更改和变化。凡在本申请的精神和原理之内所作的任何修改、等同替换以及改进等，均应包含在本申请的权利要求的范围之内。

Claims (10)

  1. 一种井筒的气侵监测装置，其特征在于，所述气侵监测装置包括：
    超声换能器，用于在发射模式下向所述井筒的环空管道发射脉冲超声波，所述脉冲超声波遇到所述环空管道内的设定位置处的移动散射体发生反射并产生回波信号；以及在接收模式下接收所述回波信号；
    数据处理装置，用于对所述回波信号进行处理，以获取所述回波信号的多普勒振幅；以及
    判定模块，用于根据所述回波信号的多普勒振幅，判定所述井筒是否发生气侵。
  2. 根据权利要求1所述的井筒气侵监测装置，其特征在于，所述判定所述井筒是否发生气侵包括：
    根据所述回波信号的多普勒振幅，判定所述环空管道在所述设定位置的流体流型；以及
    根据所述环空管道在所述设定位置的流体流型，判定所述井筒是否发生气侵。
  3. 根据权利要求2所述的井筒气侵监测装置，其特征在于，所述判定所述环空管道在所述设定位置的流体流型包括：
    若所述多普勒振幅小于第一阈值，则判定所述流体流型为气泡流；
    若所述多普勒振幅大于所述第一阈值且小于第二阈值，则判定所述流体流型为柱塞流；以及
    若所述多普勒振幅大于所述第二阈值，则判定所述流体流型为搅拌流。
  4. 根据权利要求3所述的井筒气侵监测装置，其特征在于，所述判定所述井筒是否发生气侵包括：
    在所述超声换能器为一个超声换能器的情况下，若所述流体流型为气泡流，则判定所述井筒未发生气侵，若所述流体流型为柱塞流或搅拌流，则判定所述井筒发生气侵；或者
    在所述超声换能器为多个超声换能器的情况下，若所述环空管道在多个设定位置的流体流型均为气泡流，则判定所述井筒未发生气侵，若所述环空管道在至少一个设定位置内存在柱塞流或搅拌流，则判定所述井筒发生气侵。
  5. 根据权利要求4所述的井筒气侵监测装置，其特征在于，在所述井筒发生气侵的情况下，所述判定模块还用于根据环空管道在所述设定位置的流体流型，判定所述井筒发生气侵的程度，
    所述判定所述井筒发生气侵的程度包括：
    在所述超声换能器为一个超声换能器的情况下，若所述流体流型为柱塞流，则判定所述井筒发生中度气侵，若所述流体流型为搅拌流，则判定所述井筒发生重度气侵；或者
    在所述超声换能器为多个超声换能器的情况下，若所述环空管道内存在气泡流和柱塞流，则判定所述井筒发生中度气侵，若所述环空管道内不存在气泡流，则判定所述井筒发生重度气侵。
  6. 根据权利要求4或5所述的井筒气侵监测装置，其特征在于，在所述超声换能器为多个超声换能器的情况下，所述多个超声换能器分布设置在所述井筒外侧的底部、中部以及上部。
  7. 根据权利要求1-5任一项所述的井筒气侵监测装置，其特征在于，所述超声换能器在发射模式下以设定入射角度向所述环空管道发射脉冲超声波。
  8. 根据权利要求1-5任一项所述的井筒气侵监测装置，其特征在于，所述气侵监测装置还包括控制装置，用于发出脉冲信号控制指令，所述超声换能器根据所述脉冲信号控制指令以设定时间间隔在所述发射模式和所述接收模式中转换。
  9. 根据权利要求1-5任一项所述的井筒气侵监测装置，其特征在于，所述对所述回波信号进行处理包括：
    利用正交解调技术，从所述回波信号中提取多普勒信号；
    对所述多普勒信号进行短时傅里叶变换，以获得傅里叶时频图；
    对所述傅里叶时频图中的傅里叶频谱进行小波变换，以获得在时频平面上的能量分布频谱图；以及
    从所述能量分布频谱图获取所述回波信号的多普勒振幅。
  10. 一种井筒的气侵监测方法，其特征在于，所述气侵监测方法包括：
    通过超声换能器执行以下操作：
    在发射模式下向所述井筒的环空管道发射脉冲超声波，所述脉冲超声波遇到所述环空管道内设定位置的移动散射体发生反射并产生所述回波信号，以及
    在接收模式下接收回波信号；
    对所述回波信号进行处理，以获取所述回波信号的多普勒振幅；以及
    根据所述回波信号的多普勒振幅，判定所述井筒是否发生气侵。
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