Well-side anomalous body analysis method, device and equipment based on acoustic vector phased array and medium

Abstract

The invention discloses a near-well anomalous body analysis method, device and equipment based on an acoustic vector phased array, and a medium, and the method comprises the steps: calculating the time needed in the process that an elastic wave is transmitted to a near-well anomalous body and returns an echo to each sound pressure receiving unit from the near-well anomalous body, determining a first similarity coefficient, and drawing an initial three-dimensional sound wave image through the first similarity coefficient; calculating a three-dimensional scanning receiving waveform based on the echo signal, determining a second similarity coefficient, and optimizing the initial three-dimensional sound wave imaging based on the second similarity coefficient; calculating a particle vibration velocity circumferential component waveform based on the three-dimensional scanning receiving waveform, determining a third similarity coefficient and a sound pressure and vibration velocity waveform correlation coefficient, and adjusting the optimized three-dimensional sound wave image to obtain a target three-dimensional sound wave image; the abnormal body beside the well is analyzed through target three-dimensional sound wave imaging, the imaging signal-to-noise ratio and the azimuth measurement accuracy of the abnormal body beside the well are improved, the detection capacity of weak and deep abnormal bodies is enhanced, and the data processing efficiency and practicability are improved.

Description

Technical Field

[0001] This invention relates to the field of geophysical exploration technology for oil and gas, and in particular to a method, apparatus, equipment and medium for well-side anomaly analysis based on acoustic vector phased array. Background Technology

[0002] Currently, migration imaging processing methods applied to long-range acoustic logging mainly include Kirchhoff integral migration, FK (frequency-wavenumber) migration, reverse time migration, generalized Radon transform migration, equivalent offset migration, and Gaussian beam migration. Long-range acoustic logging instruments typically install a small number of acoustic receivers at short distances from the sound source. This differs significantly from seismic exploration, which involves a dense deployment of numerous shot points and receivers over a large spatial area. Furthermore, the reflected and scattered signals from deep formations near the wellbore are very weak compared to the borehole mode waves propagating along the wellbore. Even after wavefield separation, the waveform data still contains relatively large-amplitude borehole mode waves. Therefore, current imaging processing methods suffer from low signal-to-noise ratios. Furthermore, in oil and gas exploration and development, wellbore size is generally small, which limits the diameter of the acoustic receiving station in the cylindrical array of the acoustic remote detection logging instrument. The acoustic pressure waveforms recorded by different azimuth receiving units of the same acoustic receiving station are similar in arrival time and have small amplitude differences. Current imaging processing methods produce a large range of artifacts in the azimuth (circumferential direction) when imaging anomalies near the well, which may blur the actual target azimuth angle.

[0003] As can be seen from the above, how to improve the imaging signal-to-noise ratio and azimuth measurement accuracy of well-side anomalies, enhance the detection capability of weak and deep anomalies, and improve data processing efficiency and practicality are problems to be solved in this field. Summary of the Invention

[0004] In view of this, the purpose of this invention is to provide a method, apparatus, device, and medium for well-side anomaly analysis based on acoustic vector phased arrays, which can improve the imaging signal-to-noise ratio and azimuth measurement accuracy of well-side anomalies, enhance the detection capability of weak and deep anomalies, and improve data processing efficiency and practicality. The specific solution is as follows: In a first aspect, this application discloses a well-side anomaly analysis method based on an acoustic vector phased array, applied to a pre-set acoustic receiver array located in a formation. The pre-set acoustic receiver array includes an acoustic pressure receiving unit and a particle velocity receiving unit. The method includes: Acquire acoustic pressure echo waveform data; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data; An elastic wave is transmitted using a sound wave transmitter. The time required for the elastic wave to travel from the point of transmission to the well-side anomaly to the point of the echo returning from the well-side anomaly to each sound pressure receiving unit is calculated. A first similarity coefficient is determined based on the sound pressure echo waveform data and the time. An initial three-dimensional acoustic imaging is then drawn using the first similarity coefficient. The echo signal generated by the well-side anomaly is acquired using each acoustic pressure phased-array cylindrical receiver subarray. A three-dimensional scanning received waveform is calculated based on the echo signal. A second similarity coefficient is determined using the three-dimensional scanning received waveform. The initial three-dimensional acoustic imaging is optimized based on the second similarity coefficient to obtain an optimized three-dimensional acoustic imaging. The acoustic pressure phased-array cylindrical receiver subarray is constructed based on multiple acoustic pressure receiving units. The circumferential component waveform of particle velocity is calculated based on the received waveform of the three-dimensional scanning. The third similarity coefficient and the correlation coefficient between sound pressure and velocity waveform are determined using the circumferential component waveform of particle velocity. The optimized three-dimensional acoustic imaging is adjusted based on the third similarity coefficient and the correlation coefficient between sound pressure and velocity waveform to obtain the target three-dimensional acoustic imaging. The well-side anomaly is analyzed using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

[0005] Optionally, acoustic pressure echo waveform data is acquired; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data. An elastic wave is transmitted using a sound wave transmitter. The time required for the elastic wave to travel from the point of transmission to the well-side anomaly to the point of the echo returning from the well-side anomaly to each sound pressure receiving unit is calculated. A first similarity coefficient is determined based on the sound pressure echo waveform data and the time. An initial three-dimensional acoustic imaging is then drawn using the first similarity coefficient. The echo signal generated by the well-side anomaly is acquired using each acoustic pressure phased-array cylindrical receiver subarray. A three-dimensional scanning received waveform is calculated based on the echo signal. A second similarity coefficient is determined using the three-dimensional scanning received waveform. The initial three-dimensional acoustic imaging is optimized based on the second similarity coefficient to obtain an optimized three-dimensional acoustic imaging. The acoustic pressure phased-array cylindrical receiver subarray is constructed based on multiple acoustic pressure receiving units. The circumferential component waveform of particle velocity is calculated based on the received waveform of the three-dimensional scanning. The third similarity coefficient and the correlation coefficient between sound pressure and velocity waveform are determined using the circumferential component waveform of particle velocity. The optimized three-dimensional acoustic imaging is adjusted based on the third similarity coefficient and the correlation coefficient between sound pressure and velocity waveform to obtain the target three-dimensional acoustic imaging. The well-side anomaly is analyzed using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

[0006] Optionally, the preset acoustic receiver array is constructed based on an acoustic receiver station; the acoustic receiver station is composed of a sound pressure receiving unit and a particle velocity receiving unit; Accordingly, the formula for calculating the time required for the elastic wave to travel from the well-side anomaly to its return echo to each sound pressure receiving unit using the acoustic wave transmitter is as follows: ; in, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit Let P be the spatial coordinates of a scattering point P within the vertical plane. The coordinates of the center point of the sound wave transmitter are: For the first i The first sound wave receiving station j The coordinate vector of each sound pressure receiving unit. and All are ground acoustic velocities.

[0007] Optionally, determining the first similarity coefficient based on the sound pressure echo waveform data and the time includes: The windowing start point on each waveform recorded by each sound pressure receiving unit is determined according to the time, the windowing length and the waveform data under the preset time length are determined, and the first similarity coefficient is determined based on the sound pressure echo waveform data, the windowing length and the waveform data under the preset time length. The formula for determining the first similarity coefficient is: ; ; ; in, The first similarity coefficient, N The number of sound wave receiving stations, M The number of sound pressure receiving units in each sound wave receiving station The length of the window opening. For the waveform data corresponding to the sound pressure receiving unit, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit.

[0008] Optionally, the step of acquiring the echo signal generated by the well-side anomaly using each acoustic pressure phased array cylindrical receiver subarray, and calculating the three-dimensional scan received waveform based on the echo signal, includes: The echo signal generated by the well-side anomaly is obtained by using each acoustic pressure phased cylindrical receiving subarray, and the coordinate vector of the acoustic pressure receiving unit is calculated based on the echo signal; The time delay is determined based on the coordinate vector of the sound pressure receiving unit; The received waveform of the three-dimensional scan is calculated using the time delay.

[0009] Optionally, the formula for calculating the circumferential component waveform of the particle velocity is: ; in, For the first j Waveform of the circumferential component of the particle velocity of each particle velocity receiving unit and For two spatial points, The static density of the medium. ω is the angular frequency.

[0010] Optionally, adjusting the optimized three-dimensional acoustic imaging based on the third similarity coefficient and the correlation coefficient between the sound pressure and vibration velocity waveforms includes: The weighted similarity coefficient is calculated using the third similarity coefficient and the correlation coefficient between sound pressure and vibration velocity waveforms; The optimized three-dimensional acoustic imaging is adjusted based on the weighted similarity coefficient. The formula for calculating the weighted similarity coefficient is: ; in, For any point on the three-dimensional space grid The weighted similarity coefficients of the generated echoes, The third similarity coefficient, This is the correlation coefficient between sound pressure and vibration velocity waveforms.

[0011] Secondly, this application discloses a well-side anomaly analysis device based on an acoustic vector phased array, applied to a preset acoustic receiver array located in a formation. The preset acoustic receiver array includes an acoustic pressure receiving unit and a particle velocity receiving unit. The device includes: The data acquisition module is used to acquire acoustic pressure echo waveform data; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data; The initial imaging rendering module is used to send elastic waves using a sound wave transmitter, calculate the time required for the elastic waves to travel from being emitted to the well-side anomaly to the return echo from the well-side anomaly to each sound pressure receiving unit, determine a first similarity coefficient based on the sound pressure echo waveform data and the time, and use the first similarity coefficient to render an initial three-dimensional sound wave image. The imaging optimization module is used to acquire the echo signal generated by the well-side anomaly using each acoustic pressure phased-array cylindrical receiver subarray, calculate the three-dimensional scanning received waveform based on the echo signal, determine the second similarity coefficient using the three-dimensional scanning received waveform, and optimize the initial three-dimensional acoustic imaging based on the second similarity coefficient to obtain the optimized three-dimensional acoustic imaging; the acoustic pressure phased-array cylindrical receiver subarray is constructed based on multiple acoustic pressure receiving units; The imaging adjustment module is used to calculate the circumferential component waveform of the particle velocity based on the received waveform of the three-dimensional scanning, determine the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform using the circumferential component waveform of the particle velocity, and adjust the optimized three-dimensional acoustic imaging based on the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform to obtain the target three-dimensional acoustic imaging. The analysis module is used to analyze the well-side anomaly using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

[0012] Thirdly, this application discloses an electronic device, including: Memory, used to store computer programs; A processor is used to execute the computer program to implement the aforementioned well-side anomaly analysis method based on acoustic vector phased array.

[0013] Fourthly, this application discloses a computer storage medium for storing a computer program; wherein, when the computer program is executed by a processor, it implements the steps of the aforementioned disclosed well-side anomaly analysis method based on acoustic vector phased array.

[0014] As can be seen, this application provides a well-side anomaly analysis method based on acoustic vector phased arrays, including acquiring acoustic pressure echo waveform data; the acoustic pressure echo waveform data is data obtained after preprocessing well logging data; using an acoustic transmitter to send elastic waves, calculating the time required for the elastic waves to travel from being transmitted to the well-side anomaly to the return echo from the well-side anomaly to each acoustic pressure receiving unit, determining a first similarity coefficient based on the acoustic pressure echo waveform data and the time, and using the first similarity coefficient to draw an initial three-dimensional acoustic image; using each acoustic pressure phased array cylindrical receiving subarray to acquire the echo signal generated by the well-side anomaly, calculating a three-dimensional scan received waveform based on the echo signal, determining a second similarity coefficient based on the three-dimensional scan received waveform, and based on the first similarity coefficient... The second similarity coefficient is used to optimize the initial three-dimensional acoustic imaging to obtain the optimized three-dimensional acoustic imaging; the acoustic pressure phased cylindrical receiving subarray is constructed based on multiple acoustic pressure receiving units; the circumferential component waveform of the particle velocity is calculated based on the three-dimensional scan received waveform, and the third similarity coefficient and the correlation coefficient between the acoustic pressure and the velocity waveform are determined using the circumferential component waveform of the particle velocity; the optimized three-dimensional acoustic imaging is adjusted based on the third similarity coefficient and the correlation coefficient between the acoustic pressure and the velocity waveform to obtain the target three-dimensional acoustic imaging; the well-side anomaly is analyzed using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.This application applies to a pre-set acoustic receiver array located in a formation. The pre-set acoustic receiver array includes acoustic pressure receiving units and particle velocity receiving units. Elastic waves are transmitted using an acoustic transmitter. The time required for the elastic waves to travel from the transmitted wave to a well-side anomaly and back to the acoustic pressure receiving units is calculated. A first similarity coefficient is determined based on the acoustic pressure echo waveform data and time. An initial three-dimensional acoustic image is drawn using the first similarity coefficient, establishing a basic three-dimensional imaging framework and improving the imaging signal-to-noise ratio and azimuth measurement accuracy of the well-side anomaly. Echo signals generated by the well-side anomaly are acquired using each acoustic pressure phased-array receiver subarray. A three-dimensional scanning received waveform is calculated based on the echo signals. A second similarity coefficient is determined using the three-dimensional scanning received waveform. The three-dimensional acoustic image is optimized based on the second similarity coefficient, enhancing the in-phase coherence and spatial filtering of the target azimuth echo, achieving spatially selective reception, accurately compensating for the path difference between units, and avoiding wave... Shape distortion is eliminated to ensure the accuracy of subsequent similarity coefficient calculations. Based on the received waveform of 3D scanning, the circumferential component waveform of particle velocity is calculated. The third similarity coefficient and the correlation coefficient between sound pressure and velocity waveforms are determined using the circumferential component waveform of particle velocity. Based on the third similarity coefficient and the correlation coefficient between sound pressure and velocity waveforms, the optimized 3D acoustic imaging is adjusted. The acoustic vector phased array function is realized without additional hardware, and particle velocity information independent of the sound pressure field is obtained, breaking through the limitations of a single physical field. This further improves the imaging signal-to-noise ratio and azimuth measurement accuracy of well-side anomalies. The well-side anomaly is analyzed using the target 3D acoustic imaging, and the analysis results are obtained. The well-side anomaly analysis results include the radial distance, azimuth, scale, tilt angle, and depth of the well-side anomaly, realizing the accurate characterization of geometric parameters such as the scale and depth of the anomaly, enhancing the detection capability of weak and deep anomalies, improving data processing efficiency and practicality, and improving the accuracy of well-side anomaly analysis. Attached Figure Description

[0015] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on the provided drawings without creative effort.

[0016] Figure 1 This is a flowchart of a well-side anomaly analysis method based on acoustic vector phased array disclosed in this application; Figure 2 This application discloses a flowchart of a three-dimensional remote detection logging process based on an acoustic vector phased array. Figure 3 This is a schematic diagram of a three-dimensional scanning receiver using a sound pressure phased array disclosed in this application; Figure 4This is a schematic diagram of receiving a particle velocity circumferential component waveform disclosed in this application; Figure 5 This application discloses a specific flowchart for implementing well-side anomaly analysis; Figure 6 This is a schematic diagram of the well-side anomaly analysis device based on acoustic vector phased array disclosed in this application; Figure 7 This application provides a structural diagram of an electronic device. Detailed Implementation

[0017] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0018] Currently, migration imaging processing methods applied to long-range acoustic logging mainly include Kirchhoff integral migration, FK (frequency-wavenumber) migration, reverse time migration, generalized Radon transform migration, equivalent offset migration, and Gaussian beam migration. Long-range acoustic logging instruments typically install a small number of acoustic receivers at short distances from the sound source. This differs significantly from seismic exploration, which involves a dense deployment of numerous shot points and receivers over a large spatial area. Furthermore, the reflected and scattered signals from deep formations near the wellbore are very weak compared to the borehole mode waves propagating along the wellbore. Even after wavefield separation, the waveform data still contains relatively large-amplitude borehole mode waves. Therefore, current imaging processing methods suffer from low signal-to-noise ratios. Furthermore, in oil and gas exploration and development, wellbore sizes are generally small, limiting the diameter of the acoustic receiving station in the cylindrical array of acoustic remote detection logging instruments. The acoustic pressure waveforms recorded by different azimuth receiving units at the same acoustic receiving station arrive at similar times with minimal amplitude differences. Current imaging processing methods exhibit large-scale artifacts in the azimuth (circumferential direction) when imaging well-side anomalies, which may obscure the actual target azimuth. Therefore, improving the imaging signal-to-noise ratio and azimuth measurement accuracy of well-side anomalies, enhancing the detection capability of weak and deep anomalies, and improving data processing efficiency and practicality are problems that need to be solved in this field.

[0019] See Figure 1 As shown, this invention discloses a well-side anomaly analysis method based on an acoustic vector phased array, applied to a preset acoustic receiver array located in the formation. The preset acoustic receiver array includes an acoustic pressure receiving unit and a particle velocity receiving unit, specifically including: Step S11: Obtain acoustic pressure echo waveform data; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data.

[0020] In this embodiment, the logging data includes equal-source-distance waveforms; the equal-source-distance waveforms are acoustic signal waveforms where the distance between the preset acoustic receiver array and each acoustic source is the same; the preprocessing includes waveform restoration, bandpass filtering, and wavefield separation.

[0021] Specifically, the equal-source-spacing waveform is delayed and gain restored; the equal-source-spacing waveform is bandpass filtered to suppress low-frequency Stoneley wave direct waves and reflected waves, as well as high-frequency noise in the wave field; the equal-source-spacing waveform is subjected to FK filtering and median filtering to suppress borehole mode direct waves and borehole mode reflected waves in the wave field, so as to obtain the acoustic pressure echo waveform data after suppressing the borehole mode wave.

[0022] In this embodiment, the preset acoustic receiver array includes a sound pressure receiving unit; the preset acoustic receiver array is constructed based on an acoustic receiving station; the acoustic receiving station is composed of a sound pressure receiving unit and a particle velocity receiving unit.

[0023] Step S12: Use an acoustic wave transmitter to send an elastic wave, calculate the time required for the elastic wave to travel from the point of transmission to the well-side anomaly to the point of return echo to each acoustic pressure receiving unit, determine a first similarity coefficient based on the acoustic pressure echo waveform data and the time, and use the first similarity coefficient to draw an initial three-dimensional acoustic image.

[0024] In this embodiment, given an initial radial coordinate position and an initial axial coordinate position near the well, spatial scanning imaging is performed in the vertical plane through the well axis. Assuming that a certain spatial node is the scattering point of the anomalous body near the well, the formula for calculating the scattered wave echo of the elastic wave generated by the acoustic transmitter in the formation after scattering by the anomalous body and reaching each acoustic pressure receiving unit is used. According to the formula, the windowing starting point on each waveform recorded by each acoustic pressure receiving unit in the acoustic receiving station can be determined. By selecting a waveform of a certain time length (generally 2-3 times the period corresponding to the main frequency of the waveform), the first similarity coefficient of the acoustic pressure array waveform can be calculated.

[0025] The formula for calculating the time required for the elastic wave to travel from the well-side anomaly to its return echo to each sound pressure receiving unit, using an acoustic wave transmitter to send an elastic wave, is as follows: ; in, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit Let P be the spatial coordinates of a scattering point P within the vertical plane. The coordinates of the center point of the sound wave transmitter are: For the first i The first sound wave receiving station j The coordinate vector of each sound pressure receiving unit. and All are ground acoustic velocities.

[0026] In this embodiment, the windowing start point on each waveform recorded by each sound pressure receiving unit is determined according to the time, the windowing length and waveform data under a preset time length are determined, and a first similarity coefficient is determined based on the sound pressure echo waveform data, the windowing length, and the waveform data under the preset time length; the formula for determining the first similarity coefficient is: ; ; ; in, The first similarity coefficient, N The number of sound wave receiving stations, M The number of sound pressure receiving units in each sound wave receiving station The length of the window opening. For the waveform data corresponding to the sound pressure receiving unit, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit.

[0027] Specifically, the logging instrument is located inside the fluid-filled wellbore. The acoustic receiver array used for detecting anomalies near the well consists of N acoustic receiver stations evenly distributed along the axis of the logging instrument. The acoustic receiver stations are numbered in ascending order of source distance. Each sound wave receiving station The uniform distribution along the circumference of the drill collar M Each sound pressure receiving unit Composition, the three-dimensional remote detection logging process based on acoustic vector phased array is as follows: Figure 2 A schematic diagram of a three-dimensional scanning receiver using a phased array for sound pressure levels is shown below. Figure 3 As shown, the axial distance between two adjacent acoustic wave receiving stations is d, and the circumferential angular interval between two adjacent sound pressure receiving units is... The various sound pressure receiving units in the same sound wave receiving station are distributed at a radius of [missing information]. On the circumference of the circle.

[0028] When performing three-dimensional acoustic imaging on anomalies near a well, a reference azimuth angle is given. By defining a vertical plane passing through the well axis and performing scanning imaging within this plane, the radial position of the well-side anomaly can be determined. r and axial positionz Parameters; by comparing vertical plane scanning images of the well axis from multiple azimuth angles, the azimuth angle of the well-side anomaly can be determined. Parameters. At this time, a certain scattering point in the vertical plane. P The spatial coordinates are: ; in, The reference azimuth angle for the above-mentioned well-axis imaging profile is... r and z These are the radial and axial coordinates of a scattering point within the well-axis imaging profile, respectively.

[0029] Given an initial radial and axial coordinate position near the well, spatial scanning imaging is performed in the vertical plane passing through the well axis. Assuming that a certain spatial node is the scattering point of the anomalous body near the well, the travel time of the scattered wave echoes generated by the acoustic transmitter in the formation after scattering by the anomalous body and reaching each acoustic pressure receiving unit is calculated according to the following formula: ; when and When all are formation P-wave (P) velocities, For the travel time of the PP wave, when and When both are formation shear wave (S) velocities, When the SS wave travels, For formation P-wave velocity, When the shear wave (S) velocity is the formation velocity, When the PS wave travels, For formation shear wave (S) velocity, When the P-wave velocity is the ground velocity, This refers to the travel time of the SP wave.

[0030] according to The windowing start point on each waveform recorded by each sound pressure receiving unit in the sound wave receiving station can be determined. By selecting a waveform of a certain time length (generally 2-3 times the period corresponding to the main frequency of the waveform), the first similarity coefficient of the sound pressure array waveform can be calculated.

[0031] Step S13: Obtain the echo signal generated by the well-side anomaly using each acoustic pressure phased cylindrical receiving subarray, calculate the three-dimensional scanning received waveform based on the echo signal, determine the second similarity coefficient using the three-dimensional scanning received waveform, and optimize the initial three-dimensional acoustic imaging based on the second similarity coefficient to obtain the optimized three-dimensional acoustic imaging; the acoustic pressure phased cylindrical receiving subarray is constructed based on multiple acoustic pressure receiving units.

[0032] In this embodiment, the echo signal generated by the well-side anomaly is obtained by each acoustic pressure phased cylindrical receiving subarray, and the coordinate vector of the acoustic pressure receiving unit is calculated based on the echo signal; the time delay is determined based on the coordinate vector of the acoustic pressure receiving unit; and the three-dimensional scanning received waveform is calculated using the time delay.

[0033] For example, the center point of the sound wave receiver array is used as the reference point (origin). O The unit vector v that determines the direction of planar echo propagation, and the sound pressure receiving unit. coordinate vector Given the spatial scanning azimuth of the echo from a well-side anomaly. Determine the acoustic receiving station in the acoustic receiver array. The spatial point on the circumference of the outer surface that is closest to the well-side anomaly O The coordinate vector of a point in space; O 'Using the origin of the new coordinate system, the sound pressure receiving unit in the sound wave receiver array is determined in the new coordinate system.' coordinate vector ; Calculate the echo arrival sound pressure receiving unit Relative to reference point O 'Time delay' Waveform data received by acoustic pressure receiving units facing the well-side anomaly is selected. Based on the beamforming principle, the delay time of the acoustic waveforms recorded by each acoustic pressure receiving unit is adjusted so that the echo waveforms are superimposed in phase, thus obtaining the directional received waveforms at any azimuth and vertical angle on the circumference of the acoustic receiving station. The travel time of the scattered wave echoes generated by the acoustic transmitter in the formation and scattered by the anomaly to each acoustic pressure phased array receiving unit is calculated. Based on the travel time, the windowing start point on each waveform recorded by each acoustic pressure phased array receiving unit in the acoustic receiving station can be determined. By selecting waveforms of a certain time length, the second similarity coefficient of the acoustic pressure phased array scan received waveforms can be calculated.

[0034] Specifically, such as Figure 3 As shown, multiple acoustic pressure receiving units in the same acoustic wave receiving station can form an acoustic pressure phased-controlled circular arc receiving subarray, and multiple phased-controlled circular arc receiving subarrays distributed along the axis of the logging instrument can form an acoustic pressure phased-controlled cylindrical receiving subarray. During logging, the acoustic wave transmitter on the instrument emits acoustic wave energy into the formation near the well. When the emitted acoustic wave encounters an anomaly near the well, it will generate anomaly echo signals such as reflected waves or scattered waves. When the radial distance between the anomaly near the well and the well axis is much larger than the wavelength of the acoustic wave and the scale of the acoustic pressure phased-controlled receiving subarray in the well, the echo of the anomaly near the well received by the acoustic pressure phased-controlled receiving subarray in the well can be approximated as a plane wave.

[0035] First, the center point of the acoustic wave receiver array is taken as the reference point (origin). OAt this point, the unit vector v in the direction of planar echo propagation is: ; in, Indicates transpose. This represents the azimuth angle of the echo from the well-side anomaly, with true north (positive y-axis direction) as... It increases in a clockwise direction; Let be the vertical angle of the echo from the wellbore anomaly, when the propagation direction of the echo is perpendicular to the well axis. When the echo is incident on the acoustic receiver array from top to bottom When the echo is incident on the acoustic receiver array from bottom to top .

[0036] Assuming a sound pressure receiving unit in a sound wave receiver array Azimuth angle of location ( y If the axis pointing north is aligned with the direction of true north, then the sound pressure receiving unit... coordinate vector for: ; in, i =1,…, N ; j =1,..., M , Indicates the number is i The sound wave receiving station is numbered j The coordinate vector of the sound pressure receiving unit.

[0037] When the azimuth angle of the echo from the well-side anomaly is At that time, the sound wave receiving station in the sound wave receiver array The spatial point on the circumference closest to the well-side anomaly O The coordinate vector of ' is: ; spatial points O As the origin of the new coordinate system, the sound pressure receiving unit in the sound wave receiver array is located in the new coordinate system. coordinate vector for: ; At this moment, the echo reaches the sound pressure receiving unit. Relative to reference point O 'Time delay' It can be represented as: ; in, cis the propagation speed of the echo, and is the propagation speed of the longitudinal or transverse waves in the strata.

[0038] Assuming at the reference point O The received signal waveform corresponding to the well-side anomaly echo is: Then, after propagation delay, the sound pressure receiving unit The received signal waveform corresponding to the echo of the anomaly is as follows: ; in, Indicates sound pressure receiving unit The received noise is a stationary white Gaussian noise with the same bandwidth as the echo signal and is independent of the echo signal.

[0039] The signals received by the entire acoustic receiver array can be represented by a matrix as follows: ; Based on the beamforming principle, by adjusting the delay time of the sound wave waveforms recorded by each sound pressure receiving unit, the echo waveforms are superimposed in phase, which is beneficial for directional reception of echo signals from any direction in three-dimensional space. directional incident scanning received waveform P The calculation formula is as follows: ; in, P express The scanning received waveform is incident in a specific direction, and at this time, the acoustic pressure phased cylindrical receiver subarray is composed of the entire acoustic wave receiver array.

[0040] During downhole measurements, selecting only the waveform data received by the receiving unit facing the well-side anomaly can effectively achieve in-phase superposition of the echoes, thereby improving the signal-to-noise ratio of the scanned received waveform and ultimately enhancing the azimuth measurement resolution of the well-side anomaly. This paper combines three adjacent acoustic pressure receiving units facing the well-side anomaly into a three-element acoustic pressure phased-array circular receiver subarray, and further combines these three subarrays into a nine-element acoustic pressure phased-array cylindrical receiver subarray. Figure 3 As shown. At this time, directional incident scanning received waveform P The calculation formula becomes: ; in, express The scanning received waveform is incident from a specific direction, at which point the acoustic pressure phased cylindrical receiver subarray is numbered as follows: The three acoustic receiving stations are numbered as follows: It consists of nine sound pressure receiving units, among which the basic requirement is that the sound pressure receiving unit... With reference point O The distance between them is the shortest.

[0041] According to the above formula, the acoustic receiver array includes multiple acoustic pressure phased cylindrical receiver subarrays, and each acoustic pressure phased cylindrical receiver subarray can output any azimuth angle. and vertical angle The directional received waveform at the location; such as Figure 3 As shown in the right sub-figure, with M For example, =8, from the numbered The acoustic pressure phased array receiver subarray, composed of three acoustic wave receiving stations, can output scanning received waveforms at azimuth angles of 0°, 45°, ..., 315° respectively. , , …, abbreviated as , , ..., .

[0042] Each acoustic pressure phased array cylindrical receiver subarray in the acoustic wave receiver array can output a directional received waveform at any azimuth angle on the circumference. Based on the scanning received waveform output by the acoustic pressure phased array, the second similarity coefficient of the scanning received waveform of the acoustic pressure phased array can be calculated, as shown in the following formula: .

[0043] Step S14: Calculate the circumferential component waveform of the particle velocity based on the received three-dimensional scanning waveform, determine the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform using the circumferential component waveform of the particle velocity, and adjust the optimized three-dimensional acoustic imaging based on the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform to obtain the target three-dimensional acoustic imaging.

[0044] In this embodiment, the formula for calculating the circumferential component waveform of the particle velocity is: ; in, For the first j Waveform of the circumferential component of the particle velocity of each particle velocity receiving unit and For two spatial points, The static density of the medium. ω is the angular frequency.

[0045] In this embodiment, a weighted similarity coefficient is calculated using the third similarity coefficient and the correlation coefficients of sound pressure and vibration velocity waveforms; the optimized three-dimensional acoustic imaging is adjusted based on the weighted similarity coefficient; the formula for calculating the weighted similarity coefficient is: ; in, For any point on the three-dimensional space grid The weighted similarity coefficients of the generated echoes, The third similarity coefficient, This is the correlation coefficient between sound pressure and vibration velocity waveforms.

[0046] In this embodiment, each acoustic pressure phased cylindrical receiving subarray in the acoustic receiver array can output a directional received waveform at any azimuth angle on the circumference. Any two adjacent spatial points on the circumference are selected, requiring the distance between these two points to be much smaller than the wavelength of the acoustic wave. The circumferential component of the particle vibration velocity along the line connecting these two points is then calculated. Each acoustic receiver station in the acoustic receiver array includes multiple particle vibration velocity circumferential component receiving units, with the center point of the acoustic receiver array serving as the reference point (origin). O ), determine the circumferential component receiving unit of particle vibration velocity coordinate vector The travel time of the scattered wave echoes generated by the acoustic transmitter in the formation, after being scattered by the anomalous body, reaches each acoustic pressure phased array receiving unit and each particle velocity circumferential component receiving unit. Based on the travel time, the windowing start point on each waveform recorded by each acoustic pressure phased array receiving unit and each particle velocity circumferential component receiving unit in the acoustic receiving station can be determined. Based on the scanned received waveform output by the acoustic pressure phased array and the waveform recorded by each particle velocity circumferential component receiving unit in the acoustic receiving station, the third similarity coefficient of the acoustic vector phased array waveform is calculated. When the radial distance between the well-side anomalous body and the well axis is much greater than the wavelength of the acoustic wave, the acoustic pressure and velocity waveforms of the well-side anomalous body echo signal at any location of the acoustic receiver in the fluid-filled wellbore are completely correlated. Based on this, the correlation coefficient between the acoustic pressure and velocity waveforms can be calculated, and finally, the weighted similarity coefficient is calculated.

[0047] Specifically, the formula relating sound pressure and particle vibration velocity is as follows: ; in, For vibration velocity, The waveform represents the vibration velocity. A unit vector describing the direction of vibration velocity. For sound pressure, The static density of the medium. Let ω be the angular frequency. When using the above formula to calculate the particle vibration velocity component on the line connecting two spatially close points from their sound pressure values, the basic requirement is that the distance between the two points is close enough to be much smaller than the wavelength of the sound wave. In this case, based on the sound pressure information received at any two points in space, the particle vibration velocity on the line connecting these two points can be calculated.

[0048] According to step S13, each acoustic pressure phased cylindrical receiver subarray in the acoustic receiver array can output any azimuth angle on the circumference. The schematic diagram of the directional received waveform and the circumferential component waveform of the particle velocity at the location is shown below. Figure 4 As shown, by number The three acoustic wave receiving stations, forming a sound pressure phased array, can output azimuth angles of respectively. and Scanning received waveform at time and ,when When smaller, and The distance between the two corresponding spatial points will be very close, much smaller than the wavelength of the sound wave. The circumferential component of the particle's vibration velocity along the line connecting these two points can be calculated using the following formula: ; in, This is the waveform of the circumferential component of the particle vibration velocity.

[0049] Using the center point of the acoustic receiver array as the reference point (origin) O Assuming the sound wave receiver array contains a circumferential component receiving unit for particle velocity... If the azimuth angle is consistent with true north, then the circumferential component receiving unit of the particle velocity... coordinate vector for: ; in, , , Indicates the number is i The sound wave receiving station is numbered j The coordinate vector of the receiving unit for the circumferential component of the particle velocity. The radius of the receiving unit represents the circumferential component of the particle velocity. .

[0050] Each acoustic receiver station in the acoustic receiver array includes M For each particle velocity circumferential component receiving unit, the travel time of the scattered wave echoes reaching each particle velocity circumferential component receiving unit after scattering by the anomalous body and the elastic wave generated by the acoustic transmitter in the formation is calculated according to the following formula: ; in, For the number i The sound wave receiving station is numbered j The echo travel time of the receiving unit for the circumferential component of particle vibration velocity. Indicates the number is i The sound wave receiving station is numbered j The coordinate vector of the receiving unit for the circumferential component of the particle velocity.

[0051] according to and The windowing start point on each waveform recorded by each acoustic pressure phased array receiving unit and each mass velocity circumferential component receiving unit in the acoustic wave receiving station can be determined, based on the scanning received waveform output by the acoustic pressure phased array. The waveforms recorded by the circumferential component receiving unit of each particle velocity in the acoustic wave receiving station This allows us to calculate the similarity coefficients of the acoustic vector phased array waveforms. It becomes: ; in, For any point on the three-dimensional space grid The corresponding scanning azimuth angle, Indicates the number is i The sound wave receiving station is numbered j The azimuth angle of the receiving unit for the circumferential component of the particle velocity.

[0052] Furthermore, when the radial distance between the wellbore anomaly and the well axis is much greater than the wavelength of the acoustic wave, the acoustic pressure and vibration velocity waveforms of the wellbore anomaly echo signal at any location of the acoustic receiver in the fluid-filled wellbore are completely correlated. Based on this, the correlation coefficient between the acoustic pressure and vibration velocity waveforms can be calculated. ; in, C This is the correlation coefficient between sound pressure and vibration velocity waveforms.

[0053] Using the correlation coefficient between sound pressure and vibration velocity waveforms as weighting coefficients, the weighted similarity coefficient is defined as follows: Performing scanning calculations in three-dimensional space enables... The spatial trial point where the maximum value is obtained is the three-dimensional spatial coordinate of the well-side anomaly.

[0054] Step S15: Analyze the well-side anomaly using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

[0055] Specifically, by analyzing the well-side anomaly using three-dimensional acoustic imaging of the target, the radial position of the well-side anomaly can be determined. r and axial position z Parameters; by comparing vertical plane scanning images of the well axis from multiple azimuth angles, the azimuth angle of the well-side anomaly can be determined. Furthermore, parameters such as the size, dip angle, and depth of the well-side anomaly can be obtained.

[0056] This invention proposes a method for well-side anomaly analysis based on acoustic vector phased arrays. The specific process for well-side anomaly analysis is as follows: Figure 5 As shown, the acoustic receiver array includes multiple acoustic pressure phased-array cylindrical receiver subarrays. Each acoustic pressure phased-array cylindrical receiver subarray can output a three-dimensional scan reception waveform at any azimuth angle. The acoustic pressure phased array scanning reception can effectively achieve in-phase superposition of echoes, improve the signal-to-noise ratio of the echo waveform, and ultimately improve the azimuth measurement resolution of well-side anomalies. Each acoustic pressure phased-array cylindrical receiver subarray in the acoustic receiver array can output a scan reception waveform at any azimuth angle on the circumference. The acoustic pressure scan reception waveforms corresponding to two spatial points on the circumference that are much smaller than the acoustic wavelength can be used to calculate the circumferential component of the particle vibration velocity along the line connecting these two points. This method can reduce the spatial distance between the two points, weaken the influence of the instrument backing on the waveform amplitude, improve the calculation accuracy of the particle vibration velocity, and further suppress the wellbore mode wave signal, thereby improving the signal-to-noise ratio of the echo signal.

[0057] Compared with the three-dimensional acoustic imaging method based on acoustic pressure receiving unit, the three-dimensional acoustic imaging method based on acoustic pressure phased array can suppress imaging artifacts outside the true azimuth of the well-side anomaly, while enhancing the imaging amplitude of the anomaly near the true azimuth. The three-dimensional acoustic imaging method based on acoustic vector phased array combines the advantages of both acoustic pressure phased array and acoustic vector array, and comprehensively utilizes the acoustic pressure phased array scanning received waveform and the circumferential component waveform of particle velocity for imaging, which can further significantly improve the imaging signal-to-noise ratio and azimuth resolution of the well-side anomaly, and effectively improve the imaging effect of long-range acoustic detection.

[0058] In this embodiment, acoustic pressure echo waveform data is acquired; the acoustic pressure echo waveform data is obtained after preprocessing well logging data; an elastic wave is transmitted using an acoustic wave transmitter, and the time required for the elastic wave to travel from being transmitted to the well-side anomaly to returning to each acoustic pressure receiving unit is calculated. A first similarity coefficient is determined based on the acoustic pressure echo waveform data and the time, and an initial three-dimensional acoustic imaging is drawn using the first similarity coefficient; the echo signal generated by the well-side anomaly is acquired using each acoustic pressure phased-array cylindrical receiver subarray, and a three-dimensional scanning received waveform is calculated based on the echo signal. A second similarity coefficient is determined using the three-dimensional scanning received waveform, and the initial three-dimensional image is drawn based on the second similarity coefficient. The acoustic imaging is optimized to obtain an optimized three-dimensional acoustic imaging. The acoustic pressure phased cylindrical receiving subarray is constructed based on multiple acoustic pressure receiving units. The circumferential component waveform of the particle velocity is calculated based on the three-dimensional scan received waveform. The third similarity coefficient and the correlation coefficient between the acoustic pressure and the velocity waveform are determined using the circumferential component waveform of the particle velocity. The optimized three-dimensional acoustic imaging is adjusted based on the third similarity coefficient and the correlation coefficient between the acoustic pressure and the velocity waveform to obtain the target three-dimensional acoustic imaging. The target three-dimensional acoustic imaging is used to analyze the well-side anomaly to obtain the well-side anomaly analysis results. The well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.This application applies to a pre-set acoustic receiver array located in a formation. The pre-set acoustic receiver array includes acoustic pressure receiving units and particle velocity receiving units. Elastic waves are transmitted using an acoustic transmitter. The time required for the elastic waves to travel from the transmitted wave to a well-side anomaly and back to the acoustic pressure receiving units is calculated. A first similarity coefficient is determined based on the acoustic pressure echo waveform data and time. An initial three-dimensional acoustic image is drawn using the first similarity coefficient, establishing a basic three-dimensional imaging framework and improving the imaging signal-to-noise ratio and azimuth measurement accuracy of the well-side anomaly. Echo signals generated by the well-side anomaly are acquired using each acoustic pressure phased-array receiver subarray. A three-dimensional scanning received waveform is calculated based on the echo signals. A second similarity coefficient is determined using the three-dimensional scanning received waveform. The three-dimensional acoustic image is optimized based on the second similarity coefficient, enhancing the in-phase coherence and spatial filtering of the target azimuth echo, achieving spatially selective reception, accurately compensating for the path difference between units, and avoiding wave... Shape distortion is eliminated to ensure the accuracy of subsequent similarity coefficient calculations. Based on the received waveform of 3D scanning, the circumferential component waveform of particle velocity is calculated. The third similarity coefficient and the correlation coefficient between sound pressure and velocity waveforms are determined using the circumferential component waveform of particle velocity. Based on the third similarity coefficient and the correlation coefficient between sound pressure and velocity waveforms, the optimized 3D acoustic imaging is adjusted. The acoustic vector phased array function is realized without additional hardware, and particle velocity information independent of the sound pressure field is obtained, breaking through the limitations of a single physical field. This further improves the imaging signal-to-noise ratio and azimuth measurement accuracy of well-side anomalies. The well-side anomaly is analyzed using the target 3D acoustic imaging, and the analysis results are obtained. The well-side anomaly analysis results include the radial distance, azimuth, scale, tilt angle, and depth of the well-side anomaly, realizing the accurate characterization of geometric parameters such as the scale and depth of the anomaly, enhancing the detection capability of weak and deep anomalies, improving data processing efficiency and practicality, and improving the accuracy of well-side anomaly analysis.

[0059] See Figure 6 As shown, this embodiment of the invention discloses a well-side anomaly analysis device based on an acoustic vector phased array, applied to a preset acoustic receiver array located in a formation. The preset acoustic receiver array includes an acoustic pressure receiving unit and a particle velocity receiving unit, specifically including: Data acquisition module 11 is used to acquire acoustic pressure echo waveform data; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data; The initial imaging rendering module 12 is used to send elastic waves using a sound wave transmitter, calculate the time required for the elastic waves to travel from being sent to the well-side anomaly to the return echo from the well-side anomaly to each sound pressure receiving unit, determine a first similarity coefficient based on the sound pressure echo waveform data and the time, and use the first similarity coefficient to render an initial three-dimensional sound wave image. The imaging optimization module 13 is used to acquire the echo signal generated by the well-side anomaly using each acoustic pressure phased cylindrical receiving subarray, calculate the three-dimensional scanning received waveform based on the echo signal, determine the second similarity coefficient using the three-dimensional scanning received waveform, and optimize the initial three-dimensional acoustic imaging based on the second similarity coefficient to obtain the optimized three-dimensional acoustic imaging; the acoustic pressure phased cylindrical receiving subarray is constructed based on multiple acoustic pressure receiving units; The imaging adjustment module 14 is used to calculate the circumferential component waveform of the particle velocity based on the three-dimensional scanning received waveform, determine the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform using the circumferential component waveform of the particle velocity, and adjust the optimized three-dimensional acoustic imaging based on the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform to obtain the target three-dimensional acoustic imaging. Analysis module 15 is used to analyze the well-side anomaly using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

[0060] In some specific embodiments, the logging data includes equal-source-distance waveforms; the equal-source-distance waveforms are acoustic signal waveforms where the distance between the preset acoustic receiver array and each acoustic source is the same; the preprocessing includes waveform recovery, bandpass filtering, and wavefield separation.

[0061] In some specific embodiments, the preset acoustic receiver array is constructed based on an acoustic receiver station; the acoustic receiver station is composed of a sound pressure receiving unit and a particle velocity receiving unit; The formula for calculating the time required for the elastic wave to travel from the point of transmission to the well-side anomaly and back to the sound pressure receiving units using a sound wave transmitter is as follows: ; in, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit Let P be the spatial coordinates of a scattering point P within the vertical plane. The coordinates of the center point of the sound wave transmitter are: For the first i The first sound wave receiving station j The coordinate vector of each sound pressure receiving unit. and All are ground acoustic velocities.

[0062] In some specific embodiments, the imaging optimization module 13 may specifically include: The coordinate vector calculation module is used to obtain the echo signal generated by the well-side anomaly using each acoustic pressure phased cylindrical receiving subarray, and to calculate the coordinate vector of the acoustic pressure receiving unit based on the echo signal. The time delay determination module is used to determine the time delay based on the coordinate vector of the sound pressure receiving unit; A three-dimensional scanning received waveform calculation module is used to calculate the three-dimensional scanning received waveform using the time delay.

[0063] In some specific embodiments, the formula for calculating the circumferential component waveform of the particle velocity is: ; in, For the first j Waveform of the circumferential component of the particle velocity of each particle velocity receiving unit and For two spatial points, The static density of the medium. ω is the angular frequency.

[0064] In some specific embodiments, the imaging adjustment module 14 may specifically include: The weighted similarity coefficient calculation module is used to calculate the weighted similarity coefficient using the third similarity coefficient and the correlation coefficient between sound pressure and vibration velocity waveforms. The imaging adjustment module is used to adjust the optimized three-dimensional acoustic imaging based on the weighted similarity coefficient; The formula for calculating the weighted similarity coefficient is: ; in, For any point on the three-dimensional space grid The weighted similarity coefficients of the generated echoes, The third similarity coefficient, This is the correlation coefficient between sound pressure and vibration velocity waveforms.

[0065] Figure 7 This is a schematic diagram of an electronic device provided in an embodiment of this application. The electronic device 20 may specifically include: at least one processor 21, at least one memory 22, a power supply 23, a communication interface 24, an input / output interface 25, and a communication bus 26. The memory 22 stores a computer program, which is loaded and executed by the processor 21 to implement the relevant steps in the well-side anomaly analysis method based on acoustic vector phased arrays disclosed in any of the foregoing embodiments.

[0066] In this embodiment, the power supply 23 is used to provide operating voltage for each hardware device on the electronic device 20; the communication interface 24 can create a data transmission channel between the electronic device 20 and external devices, and the communication protocol it follows can be any communication protocol applicable to the technical solution of this application, and is not specifically limited here; the input / output interface 25 is used to acquire external input data or output data to the outside world, and its specific interface type can be selected according to specific application needs, and is not specifically limited here.

[0067] In addition, the memory 22, as a carrier for resource storage, can be a read-only memory, random access memory, disk or optical disk, etc. The resources stored thereon include operating system 221, computer program 222 and data 223, etc., and the storage method can be temporary storage or permanent storage.

[0068] The operating system 221 manages and controls the various hardware devices on the electronic device 20 and the computer program 222 to enable the processor 21 to perform operations and processing on the data 223 in the memory 22. It can be Windows, Unix, Linux, etc. The computer program 222, in addition to including a computer program capable of performing the well-side anomaly analysis method based on acoustic vector phased arrays as disclosed in any of the foregoing embodiments, may further include computer programs capable of performing other specific tasks. The data 223 may include data received by the well-side anomaly analysis device based on acoustic vector phased arrays from external devices, and may also include data collected by its own input / output interface 25.

[0069] The steps of the methods or algorithms described in conjunction with the embodiments disclosed herein can be implemented directly by hardware, a software module executed by a processor, or a combination of both. The software module can be located in random access memory (RAM), main memory, read-only memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, registers, hard disk, removable disk, CD-ROM, or any other form of storage medium known in the art.

[0070] Furthermore, this application also discloses a computer-readable storage medium storing a computer program. When the computer program is loaded and executed by a processor, it implements the steps of the well-side anomaly analysis method based on acoustic vector phased array disclosed in any of the foregoing embodiments.

[0071] Finally, it should be noted that in this document, relational terms such as "first" and "second" are used only to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.

[0072] The above provides a detailed description of the well-side anomaly analysis method, apparatus, device, and storage medium based on acoustic vector phased array provided by the present invention. Specific examples have been used to illustrate the principles and implementation methods of the present invention. The descriptions of the above embodiments are only for the purpose of helping to understand the method and core ideas of the present invention. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of the present invention. Therefore, the content of this specification should not be construed as a limitation of the present invention.

Claims

1. A well-side anomaly analysis method based on acoustic vector phased array, characterized in that, A method for using a pre-defined acoustic receiver array located in a geological formation, the pre-defined acoustic receiver array including a sound pressure receiving unit and a particle velocity receiving unit, comprising: Acquire acoustic pressure echo waveform data; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data; An elastic wave is transmitted using a sound wave transmitter. The time required for the elastic wave to travel from the point of transmission to the well-side anomaly to the point of the echo returning from the well-side anomaly to each sound pressure receiving unit is calculated. A first similarity coefficient is determined based on the sound pressure echo waveform data and the time. An initial three-dimensional sound wave image is then drawn using the first similarity coefficient. The echo signal generated by the well-side anomaly is acquired using each acoustic pressure phased-array cylindrical receiver subarray. A three-dimensional scanning received waveform is calculated based on the echo signal. A second similarity coefficient is determined using the three-dimensional scanning received waveform. The initial three-dimensional acoustic imaging is optimized based on the second similarity coefficient to obtain an optimized three-dimensional acoustic imaging. The acoustic pressure phased-array cylindrical receiver subarray is constructed based on multiple acoustic pressure receiving units. The circumferential component waveform of particle velocity is calculated based on the received waveform of the three-dimensional scanning. The third similarity coefficient and the correlation coefficient between sound pressure and velocity waveform are determined using the circumferential component waveform of particle velocity. The optimized three-dimensional acoustic imaging is adjusted based on the third similarity coefficient and the correlation coefficient between sound pressure and velocity waveform to obtain the target three-dimensional acoustic imaging. The well-side anomaly is analyzed using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

2. The well-side anomaly analysis method based on acoustic vector phased array according to claim 1, characterized in that, The logging data includes equal-source-distance waveforms; the equal-source-distance waveforms are acoustic signal waveforms where the distance between the preset acoustic receiver array and each acoustic source is the same; the preprocessing includes waveform recovery, bandpass filtering, and wavefield separation.

3. The well-side anomaly analysis method based on acoustic vector phased array according to claim 1, characterized in that, The preset acoustic receiver array is constructed based on an acoustic receiver station; the acoustic receiver station is composed of a sound pressure receiving unit and a particle vibration velocity receiving unit. Accordingly, the formula for calculating the time required for the elastic wave to travel from the point of transmission to the well-side anomaly and back to the sound pressure receiving unit is as follows: ； in, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit Let P be the spatial coordinates of a scattering point P within the vertical plane. The coordinates of the center point of the sound wave transmitter are: For the first i The first sound wave receiving station j The coordinate vector of each sound pressure receiving unit. and All are ground acoustic velocities.

4. The well-side anomaly analysis method based on acoustic vector phased array according to claim 1, characterized in that, The determination of the first similarity coefficient based on the sound pressure echo waveform data and the time includes: The windowing start point on each waveform recorded by each sound pressure receiving unit is determined according to the time, the windowing length and the waveform data under the preset time length are determined, and the first similarity coefficient is determined based on the sound pressure echo waveform data, the windowing length and the waveform data under the preset time length. The formula for determining the first similarity coefficient is: ； ； ； in, The first similarity coefficient, N The number of sound wave receiving stations, M The number of sound pressure receiving units in each sound wave receiving station The length of the window opening. For the waveform data corresponding to the sound pressure receiving unit, For the first i The first sound wave receiving station j The time calculated by each sound pressure receiving unit.

5. The well-side anomaly analysis method based on acoustic vector phased array according to claim 1, characterized in that, The process of acquiring the echo signal generated by the well-side anomaly using each acoustic pressure phased-array cylindrical receiver subarray, and calculating the three-dimensional scan received waveform based on the echo signal, includes: The echo signal generated by the well-side anomaly is obtained by using each acoustic pressure phased cylindrical receiving subarray, and the coordinate vector of the acoustic pressure receiving unit is calculated based on the echo signal; The time delay is determined based on the coordinate vector of the sound pressure receiving unit; The received waveform of the three-dimensional scan is calculated using the time delay.

6. The well-side anomaly analysis method based on acoustic vector phased array according to claim 1, characterized in that, The formula for calculating the circumferential component waveform of a particle's vibration velocity is: ； in, For the first j Waveform of the circumferential component of the particle velocity of each particle velocity receiving unit and For two spatial points, The static density of the medium. ω is the angular frequency.

7. The well-side anomaly analysis method based on acoustic vector phased array according to any one of claims 1 to 6, characterized in that, The adjustment of the optimized three-dimensional acoustic imaging based on the third similarity coefficient and the correlation coefficients of sound pressure and vibration velocity waveforms includes: The weighted similarity coefficient is calculated using the third similarity coefficient and the correlation coefficient between sound pressure and vibration velocity waveforms; The optimized three-dimensional acoustic imaging is adjusted based on the weighted similarity coefficient. The formula for calculating the weighted similarity coefficient is: ； in, For any point on the three-dimensional space grid The weighted similarity coefficients of the generated echoes, The third similarity coefficient, This is the correlation coefficient between sound pressure and vibration velocity waveforms.

8. A well-side anomaly analysis device based on acoustic vector phased array, characterized in that, A preset acoustic wave receiver array applied to a geological formation, the preset acoustic wave receiver array including a sound pressure receiving unit and a particle velocity receiving unit, the device comprising: The data acquisition module is used to acquire acoustic pressure echo waveform data; the acoustic pressure echo waveform data is obtained after preprocessing the well logging data; The initial imaging rendering module is used to send elastic waves using a sound wave transmitter, calculate the time required for the elastic waves to travel from being sent to the well-side anomaly to the return echo from the well-side anomaly to each sound pressure receiving unit, determine a first similarity coefficient based on the sound pressure echo waveform data and the time, and use the first similarity coefficient to render an initial three-dimensional sound wave image. The imaging optimization module is used to acquire the echo signal generated by the well-side anomaly using each acoustic pressure phased-array cylindrical receiver subarray, calculate the three-dimensional scanning received waveform based on the echo signal, determine the second similarity coefficient using the three-dimensional scanning received waveform, and optimize the initial three-dimensional acoustic imaging based on the second similarity coefficient to obtain the optimized three-dimensional acoustic imaging; the acoustic pressure phased-array cylindrical receiver subarray is constructed based on multiple acoustic pressure receiving units; The imaging adjustment module is used to calculate the circumferential component waveform of the particle velocity based on the received waveform of the three-dimensional scanning, determine the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform using the circumferential component waveform of the particle velocity, and adjust the optimized three-dimensional acoustic imaging based on the third similarity coefficient and the correlation coefficient between the sound pressure and the velocity waveform to obtain the target three-dimensional acoustic imaging. The analysis module is used to analyze the well-side anomaly using the target three-dimensional acoustic imaging to obtain the well-side anomaly analysis results; the well-side anomaly analysis results include the radial distance, azimuth, scale, dip angle, and depth of the well-side anomaly.

9. An electronic device, characterized in that, include: Memory, used to store computer programs; A processor for executing the computer program to implement the well-side anomaly analysis method based on acoustic vector phased array as described in any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, Used to store computer programs; wherein, when the computer programs are executed by a processor, they implement the well-side anomaly analysis method based on acoustic vector phased array as described in any one of claims 1 to 7.

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