Three-dimensional far-detection acoustic logging method and device based on acoustic vector array

Abstract

The present application discloses a three-dimensional far-detection acoustic logging method and device based on an acoustic vector array, which relates to the field of oil and gas geophysical exploration. The method includes: synthesizing multi-directional sound pressure waveforms received by a receiving transducer array into multi-component vibration velocity waveforms; performing pairwise combination and coordinate transformation on the multi-component vibration velocity waveforms to obtain multiple groups of orthogonal component vibration velocity waveforms; performing polarization analysis on each group of orthogonal component vibration velocity waveforms to obtain the particle polarization direction in the horizontal plane and the main component vibration velocity waveforms; determining the azimuth of a near-well abnormal geological body according to the particle polarization direction, the amplitude of the multi-directional sound pressure waveforms, and the echo mode type; imaging the multi-directional sound pressure waveforms and the main component vibration velocity waveforms to obtain a spatial distribution image of the near-well abnormal geological body. The present application comprehensively utilizes the sound pressure and vibration velocity information in the far-detection sound field, can suppress borehole mode waves and noise signals, improve the signal-to-noise ratio of echo signals, and simultaneously quickly estimate the azimuth of a near-well abnormal geological body.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas geophysical exploration, and specifically relates to a three-dimensional long-range detection acoustic logging method and device based on an acoustic vector array. Background Art

[0002] Existing long-range detection acoustic logging instruments use a multi-pole emitter as the radiation sound source, and use a cylindrical array receiver including multiple acoustic receiving stations as the receiving acoustic train. Each acoustic receiving station is composed of eight or more sound pressure receiving transducer units evenly distributed on the same circumference. When using a monopole sound source to radiate sound waves, the receiving acoustic train mainly records multiple-channel sound pressure signals in the borehole fluid, and the traditional data processing process only uses the sound pressure information. Sound pressure is a scalar, and a single sound pressure receiving unit cannot provide the azimuth information of the abnormal body beside the well, while vibration velocity is a vector, and a vibration velocity receiving sensor can provide the azimuth information of the abnormal body beside the well.

[0003] When using an orthogonal dipole sound source to radiate sound waves, the receiving acoustic train mainly records four-component orthogonal dipole data, that is, the vibration velocity signal in the borehole fluid. The traditional working mode only uses the waveform information recorded by four receiving units in the acoustic receiving station, which makes at least half of the sound field information in the recorded waveform of the acoustic receiving station not be effectively utilized.

[0004] In addition, when calculating the azimuth of the abnormal geological body beside the well, the traditional method is to first use the migration method to obtain two-dimensional imaging maps on imaging profiles with different reference azimuths passing through the well axis, and then obtain the azimuth information of the abnormal geological body beside the well by comparing the imaging amplitudes of the migration imaging maps with different azimuths. The azimuth calculation accuracy of this method is related to the number of reference azimuths of the migration imaging map, and the improvement of the accuracy requires a large increase in the migration imaging time as the price, which is not conducive to the real-time processing of long-range detection acoustic logging data. Summary of the Invention

[0005] In order to solve the problems existing in the prior art, in a first aspect, the present application provides a three-dimensional long-range detection acoustic logging method based on an acoustic vector array, including:

[0006] Obtaining multi-directional sound pressure waveform signals collected by a receiving transducer array and generating multi-component vibration velocity waveform signals based on the multi-directional sound pressure waveform signals, where the multi-directional sound pressure waveform signals are formed when an abnormal geological body beside the well reflects and / or scatters the pulsed acoustic wave signals radiated by the multi-pole emitter; the multi-pole emitter and the receiving transducer array are arranged in a fluid-filled borehole of the formation to be measured;

[0007] Performing pairwise combination and grouped coordinate transformation on the multi-component vibration velocity waveform signals corresponding to each acoustic receiving station respectively to obtain multiple groups of orthogonal component vibration velocity waveform signals corresponding to each acoustic receiving station;

[0008] Perform polarization analysis on the orthogonal component velocity waveforms of each group corresponding to each acoustic wave receiving station respectively, to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component velocity waveform signal in the particle polarization direction;

[0009] Determine the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signal and the echo mode type;

[0010] Perform imaging according to the multi-directional sound pressure waveform signal and the main component velocity waveform signal to obtain the spatial distribution image of the abnormal geological body beside the well.

[0011] In one embodiment, the receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M receiving units, where M is an even number greater than or equal to 4. Two receiving units with an azimuth difference of 180° in each acoustic wave receiving station form a velocity component receiving sensor; the multi-directional sound pressure waveform signal includes the sound pressure waveform signals received by each receiving unit;

[0012] The generating multi-component velocity waveform signals based on the multi-directional sound pressure waveform signal includes:

[0013] Determine a plurality of velocity component waveform signals according to the sound pressure waveform signals received by the receiving units in the velocity component receiving sensor, the radius of the receiving transducer array, and the static density of the fluid filled in the fluid-filled wellbore.

[0014] In one embodiment, the performing pairwise combination and grouped coordinate transformation on the multi-component velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain multiple groups of orthogonal component velocity waveform signals corresponding to each acoustic wave receiving station includes:

[0015] Perform pairwise full permutation combination on the multi-component velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain multiple groups of components;

[0016] Perform coordinate transformation on each group of components respectively to obtain multiple groups of orthogonal component velocity waveform signals;

[0017] Rotate and transform the representation form of each group of orthogonal component velocity waveform signals into the representation form in a preset coordinate system.

[0018] In one embodiment, the performing polarization analysis on the orthogonal component velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component velocity waveform signal of each acoustic wave receiving station in the particle polarization direction includes:

[0019] Perform open-time windowing and mean removal operations on the orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station to form covariance matrices corresponding to each group of orthogonal component particle velocity waveform signals;

[0020] Perform eigenvalue decomposition on the covariance matrix to obtain the particle polarization directions corresponding to each group of orthogonal component particle velocity waveform signals;

[0021] Superimpose the particle polarization directions corresponding to each group of orthogonal component particle velocity waveform signals to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array;

[0022] Obtain the principal component particle velocity waveform signals corresponding to each orthogonal component particle velocity waveform signal based on each group of orthogonal component particle velocity waveform signals and the particle polarization direction in the horizontal plane;

[0023] Superimpose the principal component particle velocity waveform signals of each group of orthogonal component particle velocity waveform signals in the particle polarization direction according to the acoustic wave receiving stations to obtain the principal component particle velocity waveform signals corresponding to each acoustic wave receiving station.

[0024] In one embodiment, the determining the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-azimuth acoustic pressure waveform signals, and the echo mode type includes:

[0025] Determine the angle between the particle polarization direction and the due north direction according to the particle polarization direction in the horizontal plane;

[0026] Determine two predicted azimuth values of the abnormal geological body beside the well according to the echo mode type;

[0027] Determine the accurate azimuth value of the abnormal geological body beside the well from the predicted azimuth values according to the amplitude information of the multi-azimuth acoustic pressure waveform signals.

[0028] In one embodiment, the imaging based on the multi-azimuth acoustic pressure waveform signals and the principal component particle velocity waveform signals to obtain the spatial distribution image of the abnormal geological body beside the well includes:

[0029] Perform imaging based on the multi-azimuth acoustic pressure waveform signals to obtain the first spatial distribution image of the abnormal geological body beside the well;

[0030] Perform imaging based on the principal component particle velocity waveform signals to obtain the second spatial distribution image of the abnormal geological body beside the well;

[0031] Perform weighting on the first spatial distribution image and the second spatial distribution image to obtain the spatial distribution image of the abnormal geological body beside the well.

[0032] In a second aspect, the present application provides a three-dimensional far-detection acoustic wave logging device based on an acoustic vector array, including:

[0033] A multi-component vibration velocity waveform signal determination module, configured to obtain multi-directional sound pressure waveform signals collected by a receiving transducer array and generate multi-component vibration velocity waveform signals based on the multi-directional sound pressure waveform signals, wherein the multi-directional sound pressure waveform signals are formed when an abnormal geological body beside the well reflects and / or scatters the pulsed acoustic wave signals radiated by a multi-pole transmitting transducer; the multi-pole transmitting transducer and the receiving transducer array are arranged in a fluid-filled wellbore of the formation to be measured;

[0034] An orthogonal component vibration velocity waveform signal determination module, configured to perform pairwise combination and grouped coordinate transformation on the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station respectively, to obtain multiple groups of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station;

[0035] A principal component vibration velocity waveform signal determination module, configured to perform polarization analysis on each group of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station respectively, to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the principal component vibration velocity waveform signal in the direction of the particle polarization;

[0036] An azimuth information determination module, configured to determine the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signals, and the echo mode type;

[0037] An abnormal geological body distribution determination module, configured to perform imaging according to the multi-directional sound pressure waveform signals and the principal component vibration velocity waveform signals, to obtain a spatial distribution image of the abnormal geological body beside the well.

[0038] In one embodiment, the receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M receiving units, wherein M is an even number greater than or equal to 4, and two receiving units with an azimuth difference of 180° in each acoustic wave receiving station form a vibration velocity component receiving sensor; the multi-directional sound pressure waveform signals include the sound pressure waveform signals received by each receiving unit;

[0039] The multi-component vibration velocity waveform signal determination module is specifically configured to:

[0040] Determine a plurality of vibration velocity component waveform signals according to the sound pressure waveform signals received by the receiving units in the vibration velocity component receiving sensor, the radius of the receiving transducer array, and the static density of the fluid filled in the fluid-filled wellbore.

[0041] In one embodiment, the orthogonal component vibration velocity waveform signal determination module includes:

[0042] A grouping unit, configured to perform pairwise full permutation combination on the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station respectively, to obtain multiple groups of components;

[0043] A coordinate conversion unit for performing coordinate conversion on each group of components respectively to obtain multiple groups of orthogonal component vibration velocity waveform signals;

[0044] A rotation transformation unit for rotating and transforming the representation forms of each group of orthogonal component vibration velocity waveform signals into the representation forms in a preset coordinate system.

[0045] In one embodiment, the main component vibration velocity waveform signal determination module includes:

[0046] A covariance matrix determination unit for performing window opening and mean removal operations on each group of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station respectively to form covariance matrices corresponding to each group of orthogonal component vibration velocity waveform signals;

[0047] A particle polarization direction determination unit for performing eigenvalue decomposition on the covariance matrix to obtain the particle polarization directions corresponding to each group of orthogonal component vibration velocity waveform signals;

[0048] A particle polarization direction superposition unit for superposing the particle polarization directions corresponding to each group of orthogonal component vibration velocity waveform signals to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array;

[0049] A main component vibration velocity waveform signal determination unit for obtaining the main component vibration velocity waveform signals corresponding to each orthogonal component vibration velocity waveform signal according to each group of orthogonal component vibration velocity waveform signals and the particle polarization direction in the horizontal plane;

[0050] A main component vibration velocity waveform signal superposition unit for superposing the main component vibration velocity waveform signals of each group of orthogonal component vibration velocity waveform signals in the particle polarization direction according to the acoustic wave receiving stations to obtain the main component vibration velocity waveform signals corresponding to each acoustic wave receiving station.

[0051] In one embodiment, the azimuth information determination module includes:

[0052] An included angle determination unit for determining the included angle between the particle polarization direction and the due north direction according to the particle polarization direction in the horizontal plane;

[0053] A predicted azimuth value determination unit for determining two predicted azimuth values of the abnormal geological body beside the well according to the echo mode type;

[0054] An accurate azimuth value determination unit for determining the accurate azimuth value of the abnormal geological body beside the well from the predicted azimuth values according to the amplitude information of the multi-azimuth sound pressure waveform signals.

[0055] In one embodiment, the abnormal geological body distribution determination module includes:

[0056] The first imaging unit is configured to perform imaging based on the multi-directional sound pressure waveform signal to obtain a first spatial distribution image of the abnormal geological body beside the well;

[0057] The second imaging unit is configured to perform imaging based on the principal component particle velocity waveform signal to obtain a second spatial distribution image of the abnormal geological body beside the well;

[0058] The spatial distribution image determination unit is configured to weight the first spatial distribution image and the second spatial distribution image to obtain a spatial distribution image of the abnormal geological body beside the well.

[0059] In a third aspect, the present application provides a computer device, including a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the computer program, any three-dimensional far-detection acoustic logging method based on an acoustic vector array provided by the present application is implemented.

[0060] In a fourth aspect, the present application provides a computer-readable storage medium. The computer-readable storage medium stores a computer program. When the computer program is executed by a processor, any three-dimensional far-detection acoustic logging method based on an acoustic vector array provided by the present application is implemented.

[0061] The three-dimensional far-detection acoustic logging method and device based on an acoustic vector array of the present application, by jointly processing the sound pressure and particle velocity information in the acoustic field of the far-detection acoustic logging wellbore, fully utilizes the waveform information recorded by all receiving units of each acoustic wave receiving station in the receiving acoustic train. More information will inevitably bring better data processing results. Compared with the traditional monopole emission and sound pressure measurement system and the orthogonal dipole emission and orthogonal dipole measurement system, this acoustic vector array joint processing system has better noise anti-interference ability, can suppress the wellbore mode wave, and improve the signal-to-noise ratio of the echo signal. In addition, the present application can directly utilize the recorded waveform of the acoustic vector array to quickly and effectively extract the azimuth information of the abnormal body beside the well, laying a foundation for the application of acoustic far-detection in LWD geological steering. Description of the Drawings

[0062] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments or the prior art. Obviously, the following drawings are only some embodiments of the present invention. For those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts. In the drawings:

[0063] Figure 1 It is a schematic diagram of the three-dimensional far-detection acoustic logging method based on an acoustic vector array provided by the present application.

[0064] Figure 2Schematic diagram of the downhole acoustic signal acquisition system provided by this application.

[0065] Figure 3 Schematic diagram of the cylindrical array acoustic wave receiver provided by this application.

[0066] Figure 4 Schematic diagram of the multi-component vibration velocity waveform signal provided by this application.

[0067] Figure 5 Another schematic diagram of the three-dimensional far-detection acoustic logging method based on the acoustic vector array provided by this application.

[0068] Figure 6 Schematic diagram of the non-orthogonal α-angle coordinate system a-b and the orthogonal coordinate system x-y provided by this application.

[0069] Figure 7 Another schematic diagram of the three-dimensional far-detection acoustic logging method based on the acoustic vector array provided by this application.

[0070] Figure 8 Another schematic diagram of the three-dimensional far-detection acoustic logging method based on the acoustic vector array provided by this application.

[0071] Figure 9 Another schematic diagram of the three-dimensional far-detection acoustic logging method based on the acoustic vector array provided by this application.

[0072] Figure 10 A schematic diagram of the three-dimensional far-detection acoustic logging device based on the acoustic vector array provided by this application.

[0073] Figure 11 Another schematic diagram of the three-dimensional far-detection acoustic logging device based on the acoustic vector array provided by this application.

[0074] Figure 12 Another schematic diagram of the three-dimensional far-detection acoustic logging device based on the acoustic vector array provided by this application.

[0075] Figure 13 Another schematic diagram of the three-dimensional far-detection acoustic logging device based on the acoustic vector array provided by this application.

[0076] Figure 14 Another schematic diagram of the three-dimensional far-detection acoustic logging device based on the acoustic vector array provided by this application.

[0077] Figure 15 A schematic diagram of a computer device provided by this application. Specific implementation mode

[0078] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer and more understandable, the following further describes the embodiments of the present invention in detail with reference to the accompanying drawings. Herein, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but not to limit the present invention.

[0079] In a first aspect, the present application provides a three-dimensional far-detection acoustic logging method based on an acoustic vector array. As Figure 1 shown, the method includes the following steps S101 to S106:

[0080] Step S101: Obtain multi-directional sound pressure waveform signals collected by a receiving transducer array, where the multi-directional sound pressure waveform signals are formed when a near-well abnormal geological body reflects and / or scatters the pulsed acoustic wave signals radiated by a multi-pole transmitting transducer; the multi-pole transmitting transducer and the receiving transducer array are disposed in a fluid-filled wellbore of the formation to be measured.

[0081] Specifically, before implementing the three-dimensional far-detection acoustic logging method based on an acoustic vector array of the present application, a multi-pole transmitting transducer and a receiving transducer array need to be disposed in a fluid-filled wellbore of the formation to be measured first, as Figure 2 described. In the fluid-filled wellbore, a cylindrical coordinate system can be established with the well axis as the z-axis, θ representing the azimuth angle. The present application defines the due north direction as θ = 0°, and θ increases in the clockwise direction. r represents the radius, and P(r, z, θ) represents the reflection point. Among them, the multi-pole transmitting transducer serves as a radiation sound source and radiates pulsed acoustic wave signals in the fluid-filled wellbore. The energy of the pulsed acoustic wave signals enters the formation to be measured and propagates outward. When encountering a near-well abnormal geological body in the formation to be measured, it will be reflected and / or scattered by the near-well abnormal geological body, thereby generating echoes.

[0082] The receiving transducer array can receive various mode echoes generated by abnormal geological bodies in the formation to be measured. Figure 3 The shown receiving transducer array is a cylindrical array acoustic receiver, and the radius of the cylindrical array acoustic receiver is r tool , which is composed of N acoustic receiving stations R1 to R N , with a spacing of d between them. Each acoustic receiving station is composed of M receiving units E1 to E M uniformly distributed on the same circumference, with a spacing of ε (ε = 360° / M). Then, the jth azimuth receiving unit of the ith acoustic receiving station can be denoted as R i E j . The receiving unit R i E j records the sound pressure signal in the wellbore fluid, where 1 ≤ i ≤ N, 1 ≤ j ≤ M, N is a positive integer, and M is an even number greater than or equal to 4. For example Figure 3Where M = 8. When the sound source in the fluid-filled wellbore radiates a pulsed acoustic wave signal, all receiving units of all acoustic wave receiving stations can receive the acoustic pressure waveform signals reflected and / or scattered by the abnormal geological body beside the well for the pulsed acoustic wave signal. That is, the acoustic pressure waveform signals directly measured by the receiving units of the present application are the acoustic pressure waveform signals in the wellbore fluid.

[0083] Step S102, generating a multi-component particle velocity waveform signal based on the multi-directional acoustic pressure waveform signals; the multi-component particle velocity waveform signal reflects the motion law of the particles in the horizontal plane of the fluid medium in the well, that is, in the plane perpendicular to the well axis.

[0084] For example, using Figure 3 the shown receiving transducer array to collect the multi-directional acoustic pressure waveform signals reflected and / or scattered by the abnormal geological body beside the well, then a total of N groups of acoustic pressure waveform signals corresponding to the particles can be collected, and each group of acoustic pressure waveform signals contains M acoustic pressure waveform signals. Based on these N×M acoustic pressure waveform signals and a preset formula, the multi-component particle velocity waveform signal can be obtained. More specific steps will be described in the subsequent embodiments.

[0085] The multi-component particle velocity waveform signal can be obtained through the above method.

[0086] Step S103, respectively performing pairwise combination and grouped coordinate transformation on the multi-component particle velocity waveform signals corresponding to each acoustic wave receiving station to obtain multiple groups of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station;

[0087] For example, performing pairwise arbitrary combination on the multi-component particle velocity waveform signals corresponding to each acoustic wave receiving station to obtain multiple groups of components, and each group of components contains 2 different component particle velocity waveform signals; then respectively performing coordinate transformation on each group of components to obtain multiple groups of orthogonal component particle velocity waveform signals.

[0088] For the convenience of subsequent arithmetic processing, the multiple groups of orthogonal component particle velocity waveform signals can be rotated from the local coordinate system to the global coordinate system. Among them, the local coordinate system refers to a two-dimensional orthogonal coordinate system x-y with the unit vectors of the orthogonal components as the basis vectors, and the global coordinate system refers to a two-dimensional orthogonal coordinate system X-Y in which the positive direction of the Y axis coincides with the due north direction and the positive direction of the X axis coincides with the due east direction.

[0089] Step S104, respectively performing polarization analysis on each group of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component particle velocity waveform signal in the particle polarization direction.

[0090] In this step, polarization analysis is performed on the orthogonal component vibration velocity waveform signals of each group of N acoustic wave receiving stations to obtain N main component vibration velocity waveform signals. That is, polarization analysis of the orthogonal component vibration velocity waveform signals of each group for each acoustic wave receiving station can obtain a main component vibration velocity waveform signal.

[0091] Step S105: Determine the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signal, and the echo mode type.

[0092] Step S106: Perform imaging based on the multi-directional sound pressure waveform signal and the main component vibration velocity waveform signal to obtain a spatial distribution image of the abnormal geological body beside the well.

[0093] This application makes full use of the waveform information recorded by all receiving units of each acoustic wave receiving station in the receiving acoustic system, can increase the redundancy of waveform information, suppress noise, and improve the calculation accuracy and stability.

[0094] In one embodiment, when the diameter 2r of the cylindrical array acoustic wave receiver tool is much smaller than the acoustic wave wavelength in the formation beside the well, two receiving units with an azimuth difference of 180° in the same acoustic wave receiving station form a vibration velocity component receiving sensor. Assuming Figure 3 as an example, the receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M = 8 receiving units, then each acoustic wave receiving station includes 4 vibration velocity component receiving sensors.

[0095] Therefore, step S102 of generating multi-component vibration velocity waveform signals based on the multi-directional sound pressure waveform signal includes:

[0096] Determine a plurality of vibration velocity component waveform signals according to the sound pressure waveform signals received by the receiving units in the vibration velocity component receiving sensor, the radius of the receiving transducer array, and the static density of the fluid filled in the fluid-filled wellbore.

[0097] For example, as Figure 4 shown, the calculation formula for the multi-component vibration velocity signal at the center (point O) of one of the acoustic wave receiving stations is as follows:

[0098]

[0099]

[0100]

[0101]

[0102] Wherein, v1, v2, v3, and v4 respectively represent the vibration velocity component waveform signals in 4 directions at point O; E1 to E8 respectively represent the sound pressure waveform signals in 8 azimuths, and r tool is the radius of the cylindrical array receiver, ρ0 is the static density of the fluid, ω is the angular frequency, F represents the forward Fourier transform, and F -1 represents the inverse Fourier transform. In this application, data vectors are represented in bold.

[0103] After the above operations, the 8×N channel sound pressure waveform signals R1(E1~E8), R2(E1~E8), …, R N (E1~E8) received by the cylindrical array receiver composed of N acoustic wave receiving stations can be converted into 4×N channel vibration velocity component waveform signals R1(v1, v2, v3, v4), R2(v1, v2, v3, v4), …, R N (v1, v2, v3, v4).

[0104] Furthermore, after generating the multi-component vibration velocity waveform signals based on the multi-azimuth sound pressure waveform signals, band-pass filtering and wave field separation can also be performed on the sound pressure waveform signals and the vibration velocity component waveform signals to suppress the borehole mode waves and noise and highlight the echo signals from the abnormal geological bodies beside the well.

[0105] Therefore, in one embodiment, as Figure 5 shown, in step S103, pairwise combination and grouped coordinate transformation are respectively performed on the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station to obtain multiple groups of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station, including the following processing for the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station:

[0106] In step S1031, pairwise full permutation combinations are respectively performed on the multi-component vibration velocity waveform signals corresponding to the acoustic wave receiving station to obtain multiple groups of components. Each group of components includes 2 linearly independent component vibration velocity waveform signals;

[0107] Assume that the receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M receiving units. Taking one of the acoustic wave receiving stations as an example, from the multi-component vibration velocity waveform signals corresponding to this acoustic wave receiving station, any 2 different (linearly independent) component vibration velocity waveform signals are taken as a group of components, then there are combinations. Continuing with the previous example, when M = 8, for the sound pressure acoustic wave signals collected by the 8 receiving units in one acoustic wave receiving station, 4 vibration velocity component waveform signals v1, v2, v3, and v4 can be calculated. At this time, the number of combinations is which are respectively represented as (v1, v2), (v1, v3), (v1, v4), (v2, v3), (v2, v4), and (v3, v4).

[0108] This data combination, or data superposition, can make full use of the rich information repeatability in the received waveform data, greatly suppressing or eliminating the residual direct wave and noise, and greatly improving the reliability of data inversion. It is a more stable and reliable method for calculating the distance and azimuth of anomalies beside the well.

[0109] Step S1032: Perform coordinate transformation on each group of components to obtain multiple groups of orthogonal component vibration velocity waveform signals.

[0110] For example, Figure 6 shows the non-orthogonal α-angle coordinate system a-b and the orthogonal coordinate system x-y. It is assumed that the unit vectors in the positive directions of the a-axis and the b-axis are e a and e b respectively, and the unit vectors in the positive directions of the x-axis and the y-axis are e x and e y respectively. Then the conversion relationship between the non-orthogonal α-angle coordinate system a-b and the orthogonal coordinate system x-y is as follows:

[0111]

[0112] e = e

[0113] e y = e a

[0114] Therefore, the transformation matrix T for transforming two vibration velocity component waveform signals with an included angle of α into orthogonal component vibration velocity waveform signals is expressed as:

[0115]

[0116] Based on the above transformation matrix T, perform the following coordinate transformation on each group of components:

[0117]

[0118]

[0119]

[0120]

[0121]

[0122]

[0123] Thus, multiple groups of orthogonal component vibration velocity waveform signals can be obtained, which are respectively expressed as (x1, y1), (x2, y2), (x3, y3), (x4, y4), (x5, y5), (x6, y6).

[0124] Step S1033: Rotate the vibration velocity waveform signals of each group of orthogonal components from the local coordinate system x-y to the global coordinate system X-Y (the positive direction of the Y-axis coincides with the due north direction).

[0125] Specifically, the rotation matrix R for rotating the local coordinate system x-y to the global coordinate system X-Y can be expressed as:

[0126]

[0127] where β is the azimuth angle of the y-axis in the local coordinate system.

[0128] Assume that the azimuth angle β of the y1-axis in the local coordinate system is AZ. Then the rotation formulas for each group of orthogonal components are:

[0129]

[0130]

[0131]

[0132]

[0133]

[0134]

[0135] At this time, the vibration velocity waveform signals of each group of orthogonal components rotated to the global coordinate system X-Y are respectively represented as (X1, Y1), (X2, Y2), (X3, Y3), (X4, Y4), (X5, Y5), (X6, Y6).

[0136] By processing the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station through the above steps S1031 to S1033, the group of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station can be obtained.

[0137] In an embodiment, as Figure 7 shown, step S104: Perform polarization analysis on the vibration velocity waveform signals of each group of orthogonal components corresponding to each acoustic wave receiving station to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component vibration velocity waveform signals of each acoustic wave receiving station in the particle polarization direction, including:

[0138] Step S1041: Perform window opening and mean removal operations on the vibration velocity waveform signals of each group of orthogonal components corresponding to each acoustic wave receiving station to form the covariance matrix corresponding to each group of orthogonal component vibration velocity waveform signals;

[0139] Specifically, taking a set of orthogonal component vibration velocity waveform signals (X1, Y1) corresponding to an acoustic wave receiving station as an example, perform an operation of opening a time window and removing the mean on the waveforms of this set of orthogonal component vibration velocity waveform signals to obtain the following covariance matrix:

[0140]

[0141] In the formula, C1 corresponding to the orthogonal components (X1, Y1) is the covariance matrix, M1 is the orthogonal component data obtained by opening the time window, nt1 is the starting point of the opened time window, and nt2 is the end point of the time window.

[0142] Similarly, the covariance matrices corresponding to the remaining sets of orthogonal component vibration velocity waveform signals (X2, Y2), (X3, Y3), (X4, Y4), (X5, Y5), (X6, Y6) of this acoustic wave receiving station can be obtained, which are respectively represented as: C2, C3, C4, C5, C6, as well as the covariance matrices corresponding to the sets of orthogonal component vibration velocity waveform signals of the remaining acoustic wave receiving stations.

[0143] Step S1042: Perform eigenvalue decomposition on the covariance matrix to obtain the particle polarization directions corresponding to each set of orthogonal component vibration velocity waveform signals.

[0144] Specifically, taking a set of orthogonal component vibration velocity waveform signals (X1, Y1) corresponding to an acoustic wave receiving station as an example, decompose the covariance matrix C1 corresponding to the orthogonal component vibration velocity waveform signals (X1, Y1) into the following form through eigenvalue decomposition:

[0145]

[0146] In the formula, the columns ξ1, ζ1 of matrix I1 are the right eigenvectors of covariance matrix C1, and the values λ1, μ1 on the main diagonal of matrix Λ1 are the eigenvalues of covariance matrix C1. Among them, the eigenvector ξ1 corresponding to the largest eigenvalue λ1 is the particle polarization direction corresponding to the orthogonal components (X1, Y1).

[0147] Similarly, eigenvalue decomposition can be performed on covariance matrices C2, C3, C4, C5, C6 respectively to obtain the particle polarization directions corresponding to the remaining sets of orthogonal component vibration velocity waveform signals (X2, Y2), (X3, Y3), (X4, Y4), (X5, Y5), (X6, Y6) of this acoustic wave receiving station, which are respectively represented as: ξ2, ξ3, ξ4, ξ5, ξ6, as well as the particle polarization directions corresponding to the sets of orthogonal component vibration velocity waveform signals of the remaining acoustic wave receiving stations.

[0148] Step S1043: Superimpose the particle polarization directions corresponding to each set of orthogonal component vibration velocity waveform signals to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array.

[0149] Specifically, first determine the particle polarization directions of each acoustic wave receiving station separately. Taking an acoustic wave receiving station R i as an example, superimpose the particle polarization directions ξ1, ξ2, ξ3, ξ4, ξ5, ξ6 of this acoustic wave receiving station obtained through step S1042 to obtain the particle polarization direction R i ξ0 corresponding to this acoustic wave receiving station:

[0150] R i ξ0 = (ξ1 + ξ2 + ξ3 + ξ4 + ξ5 + ξ6) / 6

[0151] Then determine the particle polarization direction in the horizontal plane of the cylindrical array acoustic wave receiver according to the particle polarization directions of each acoustic wave receiving station. For example, through the above steps S1041 to S1043, process the acoustic pressure waveform signals collected by each receiving unit of the N acoustic wave receiving stations in the receiving transducer array respectively, and the particle polarization directions corresponding to the N acoustic wave receiving stations can be obtained, which are respectively expressed as: R1ξ0, R2ξ0,..., R N ξ0.

[0152] Furthermore, superimpose the particle polarization directions corresponding to the N acoustic wave receiving stations again to obtain the particle polarization direction ξ in the horizontal plane corresponding to the receiving transducer array:

[0153]

[0154] Superimposing the 6×N particle polarization directions in this step can improve the calculation stability and accuracy.

[0155] Step S1044, obtain the main component vibration velocity waveform signals corresponding to each group of orthogonal component vibration velocity waveform signals according to each group of orthogonal component vibration velocity waveform signals and the particle polarization direction in the horizontal plane.

[0156] Specifically, taking a group of orthogonal component vibration velocity waveform signals (X1, Y1) corresponding to an acoustic wave receiving station as an example, project the corresponding orthogonal component data M1 onto the particle polarization direction ξ in the horizontal plane to obtain the main component vibration velocity waveform signal V1 of the orthogonal component (X1, Y1) in the particle polarization direction ξ:

[0157] V1 = M1ξ

[0158] Similarly, project the orthogonal component data M2, M3, M4, M5, M6 obtained when windowing the remaining groups of orthogonal component velocity waveforms (X2, Y2), (X3, Y3), (X4, Y4), (X5, Y5), (X6, Y6) of the acoustic wave receiving station onto the particle polarization direction ξ, and the main component velocity waveforms of the orthogonal component velocity waveforms (X2, Y2), (X3, Y3), (X4, Y4), (X5, Y5), (X6, Y6) in the particle polarization direction ξ can be obtained, which are respectively denoted as: V2, V3, V4, V5, V6, as well as the main component velocity waveforms of each group of orthogonal component velocity waveforms of the remaining acoustic wave receiving stations in the particle polarization direction ξ.

[0159] Step S1045: Superimpose the main component velocity waveforms of each group of orthogonal component velocity waveforms of the acoustic wave receiving stations in the particle polarization direction to obtain the main component velocity waveforms corresponding to each acoustic wave receiving station.

[0160] Specifically, taking an acoustic wave receiving station R i as an example, after obtaining the groups of orthogonal component velocity waveforms (X1, Y1), (X2, Y2), (X3, Y3), (X4, Y4), (X5, Y5), (X6, Y6) corresponding to the acoustic wave receiving station R i through step S1044, superimpose the main component velocity waveforms V1, V2, V3, V4, V5, V6 corresponding to each group of orthogonal component velocity waveforms to obtain the main component velocity waveform R i corresponding to the acoustic wave receiving station R i V:

[0161] R i V = (V1 + V2 + V3 + V4 + V5 + V6) / 6

[0162] By performing the superimposition processing on the main component velocity waveforms corresponding to the orthogonal component velocity waveforms of the N acoustic wave receiving stations in the receiving transducer array through the above steps S1044 to S1045, the main component velocity waveforms corresponding to the N acoustic wave receiving stations can be obtained, which are respectively denoted as: R1V, R2V,..., R N V.

[0163] Superimposing the 6 main component velocity waveforms in this step can improve the signal-to-noise ratio of the echo signal and suppress the borehole mode wave and noise.

[0164] In an embodiment, as Figure 8 shown, step S105: Determine the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signal, and the echo mode type, including:

[0165] Step S1051: Calculate the angle γ between the particle polarization direction and the due north direction according to the particle polarization direction in the horizontal plane.

[0166] Specifically, in the global coordinate system X - Y, the unit vector in the due north direction (positive Y - axis direction) is [0, 1]. Then the angle γ between the particle polarization direction ξ and the due north direction is:

[0167] γ = acos([0, 1]·ξ)×sign([1, 0]·ξ)

[0168] where acos is the inverse cosine function, sign(x) is the sign function. When x > 0, sign(x) = 1; when x = 0, sign(x) = 0; when x < 0, sign(x) = - 1, and [1, 0] is the unit vector in the due east direction (positive X - axis direction).

[0169] Step S1052: Calculate two predicted azimuth values θ0 and θ0 + 180° of the near - wellbore abnormal geological body according to the echo mode type.

[0170] Specifically, the echo signals from the near - wellbore abnormal geological body include longitudinal waves (P) and transverse waves (S). The transverse wave (S) includes SV waves and SH waves. Both the longitudinal wave and the transverse wave in the echo are linearly polarized body waves.

[0171] For the P - wave and SV - wave in the echo signal, the particle motion trajectory in the horizontal plane is collinear with the echo propagation direction. At this time:

[0172] θ0 = γ

[0173] For the SH - wave in the echo signal, the particle motion trajectory in the horizontal plane is perpendicular to the echo propagation direction. At this time:

[0174] θ0 = γ + 90°

[0175] Thus, θ0 and θ0 + 180° are two possible azimuth values of the near - wellbore abnormal geological body.

[0176] Step S1053: Exclude the wrong azimuth values from the predicted azimuth values according to the amplitude information of the multi - azimuth sound pressure waveform signal, and determine the accurate azimuth value θ of the near - wellbore abnormal geological body.

[0177] Specifically, among the multi - azimuth sound pressure waveform signals E1~E8, find the two azimuth sound pressure waveform signals closest to θ0 and θ0 + 180°, denoted as E a and E b . Define the amplitude ratio R as:

[0178]

[0179] Among them, when opening a time window for the echo signal, it is necessary to include the P-wave or the SV-wave, and nt3 and nt4 are respectively the starting point and the ending point of the opened time window. When R > 1, the azimuth of the abnormal geological body beside the well is θ = θ0; when R < 1, the azimuth of the abnormal geological body beside the well is θ = θ0 + 180°.

[0180] This application directly uses the recorded waveforms of the receiving acoustic logging tool to extract the azimuth information of the abnormal body beside the well without migration imaging, improving the efficiency of data processing.

[0181] In one embodiment, as Figure 9 shown, step S106, perform imaging based on the multi-azimuth acoustic pressure waveform signal and the principal component particle velocity waveform signal to obtain a spatial distribution image of the abnormal geological body beside the well, including:

[0182] Step S1061, perform imaging based on the multi-azimuth acoustic pressure waveform signal to obtain a first spatial distribution image I1 of the abnormal geological body beside the well.

[0183] Specifically, use migration imaging algorithms (such as Kirchhoff integral migration, F-K migration, and reverse time migration) or spatial scanning imaging based on waveform similarity and other methods to perform imaging on the multi-azimuth acoustic pressure waveforms (N×M channels) in the cross-well axis section (r-z plane) determined by the azimuth θ of the abnormal geological body beside the well to obtain the spatial distribution image I1(r,z) of the abnormal geological body beside the well.

[0184] Step S1062, perform imaging based on the principal component particle velocity waveform signal to obtain a second spatial distribution image I2 of the abnormal geological body beside the well.

[0185] Specifically, use migration imaging algorithms (such as Kirchhoff integral migration, F-K migration, and reverse time migration) or spatial scanning imaging based on waveform similarity and other methods to perform imaging on the principal component particle velocity waveforms (N channels) in the cross-well axis section (r-z plane) to obtain the spatial distribution image I2(r,z) of the abnormal geological body beside the well.

[0186] Step S1063, weight the first spatial distribution image I1 and the second spatial distribution image I2 to obtain the final spatial distribution image I of the abnormal geological body beside the well.

[0187] Specifically, both I1(r,z) and I2(r,z) reflect the spatial distribution characteristics of the abnormal geological body beside the well. Weight them to obtain the final spatial distribution image I(r,z) of the abnormal geological body beside the well:

[0188] I(r,z) = λI1(r,z) + (1 - λ)I2(r,z)

[0189] Wherein, 0 ≤ λ ≤ 1. By processing in this way, the imaging noise can be suppressed, the imaging quality can be improved, and thus parameters such as the radial distance, scale, and shape of the abnormal geological body beside the well can be obtained more accurately.

[0190] The three-dimensional far-detection acoustic logging method based on an acoustic vector array in this application, by jointly processing the acoustic pressure and particle velocity information in the acoustic field of the far-detection acoustic logging borehole, makes full use of the waveform information recorded by all receiving units of each acoustic wave receiving station in the receiving acoustic train. More information will inevitably bring better data processing results. This acoustic vector array joint processing system has better noise anti-interference ability compared with the traditional monopole emission and acoustic pressure measurement system and the orthogonal dipole emission and orthogonal dipole measurement system, and can suppress the borehole mode wave and improve the signal-to-noise ratio of the echo signal. In addition, this application can directly use the recorded waveform of the acoustic vector array to quickly and effectively extract the azimuth information of the abnormal body beside the well, laying a foundation for the application of acoustic far-detection in LWD geological steering.

[0191] Based on the same inventive concept, the embodiment of this application also provides a three-dimensional far-detection acoustic logging device based on an acoustic vector array, which can be used to implement the method described in the above embodiment, as described in the following embodiment. Since the principle of solving problems by the three-dimensional far-detection acoustic logging device based on an acoustic vector array is similar to that of the three-dimensional far-detection acoustic logging method based on an acoustic vector array, the implementation of the three-dimensional far-detection acoustic logging device based on an acoustic vector array can refer to the implementation of the three-dimensional far-detection acoustic logging method based on an acoustic vector array, and the repeated parts will not be described again. Hereinafter, the term "unit" or "module" may be a combination of software and / or hardware that can implement a predetermined function. Although the system described in the following embodiments is preferably implemented in software, the implementation of hardware, or a combination of software and hardware is also possible and contemplated.

[0192] In a second aspect, this application provides a three-dimensional far-detection acoustic logging device based on an acoustic vector array, as Figure 10 shown. The device includes:

[0193] A multi-component particle velocity waveform signal determination module 201, configured to obtain the multi-directional acoustic pressure waveform signals collected by the receiving transducer array and generate multi-component particle velocity waveform signals based on the multi-directional acoustic pressure waveform signals, wherein the multi-directional acoustic pressure waveform signals are formed when an abnormal geological body beside the well reflects and / or scatters the pulsed acoustic wave signals radiated by the multi-pole emission transducer; the multi-pole emission transducer and the receiving transducer array are arranged in the fluid-filled borehole of the formation to be measured;

[0194] An orthogonal component particle velocity waveform signal determination module 202, configured to perform pairwise combination and grouped coordinate transformation on the multi-component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain multiple groups of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station;

[0195] The principal component vibration velocity waveform signal determination module 203 is configured to perform polarization analysis on each group of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station, so as to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the principal component vibration velocity waveform signal in the direction of the particle polarization;

[0196] The azimuth information determination module 204 is configured to determine the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane corresponding to each acoustic wave receiving station, the amplitude information of the multi-azimuth sound pressure waveform signal, and the echo mode type;

[0197] The abnormal geological body distribution determination module 205 is configured to perform imaging according to the multi-azimuth sound pressure waveform signal and the principal component vibration velocity waveform signal to obtain a spatial distribution image of the abnormal geological body beside the well.

[0198] In one embodiment, the receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M receiving units, where M is an even number greater than or equal to 4. Two receiving units with an azimuth difference of 180° in each acoustic wave receiving station form a vibration velocity component receiving sensor; the multi-azimuth sound pressure waveform signal includes the sound pressure waveform signals received by each receiving unit;

[0199] The multi-component vibration velocity waveform signal determination module 201 is specifically configured to:

[0200] Determine a plurality of vibration velocity component waveform signals according to the sound pressure waveform signals received by the receiving units in the vibration velocity component receiving sensor, the radius of the receiving transducer array, and the static density of the fluid filled in the fluid-filled wellbore.

[0201] In one embodiment, as Figure 11 shown, the orthogonal component vibration velocity waveform signal determination module 202 includes:

[0202] The grouping unit 2021 is configured to perform pairwise full permutation and combination on the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station to obtain multiple groups of components;

[0203] The coordinate conversion unit 2022 is configured to perform coordinate conversion on each group of components to obtain multiple groups of orthogonal component vibration velocity waveform signals;

[0204] The rotation transformation unit 2023 is configured to rotate and transform the representation forms of each group of orthogonal component vibration velocity waveform signals into the representation forms in a preset coordinate system.

[0205] In one embodiment, as Figure 12 shown, the principal component vibration velocity waveform signal determination module 203 includes:

[0206] The covariance matrix determination unit 2031 is configured to perform an operation of opening a time window and removing the mean on each group of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station, so as to form a covariance matrix corresponding to each group of orthogonal component particle velocity waveform signals;

[0207] The particle polarization direction determination unit 2032 is configured to perform eigenvalue decomposition on the covariance matrix to obtain the particle polarization direction corresponding to each group of orthogonal component particle velocity waveform signals;

[0208] The particle polarization direction superposition unit 2033 is configured to superpose the particle polarization directions corresponding to each group of orthogonal component particle velocity waveform signals to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array;

[0209] The principal component particle velocity waveform signal determination unit 2034 is configured to obtain the principal component particle velocity waveform signal corresponding to each orthogonal component particle velocity waveform signal according to each group of orthogonal component particle velocity waveform signals and the particle polarization direction in the horizontal plane;

[0210] The principal component particle velocity waveform signal superposition unit 2035 is configured to superpose the principal component particle velocity waveform signals of each group of orthogonal component particle velocity waveform signals in the particle polarization direction according to the acoustic wave receiving stations, so as to obtain the principal component particle velocity waveform signal corresponding to each acoustic wave receiving station.

[0211] In one embodiment, as Figure 13 shown, the azimuth information determination module 204 includes:

[0212] The included angle determination unit 2041 is configured to determine the included angle between the particle polarization direction and the true north direction according to the particle polarization direction in the horizontal plane;

[0213] The predicted azimuth value determination unit 2042 is configured to determine two predicted azimuth values of the subsurface abnormal geological body according to the echo mode type;

[0214] The accurate azimuth value determination unit 2043 is configured to determine the accurate azimuth value of the subsurface abnormal geological body from the predicted azimuth values according to the amplitude information of the multi-azimuth sound pressure waveform signal.

[0215] In one embodiment, as Figure 14 shown, the abnormal geological body distribution determination module 205 includes:

[0216] The first imaging unit 2051 is configured to perform imaging based on the multi-azimuth sound pressure waveform signal to obtain a first spatial distribution image of the subsurface abnormal geological body;

[0217] The second imaging unit 2052 is configured to perform imaging based on the principal component particle velocity waveform signal to obtain a second spatial distribution image of the subsurface abnormal geological body;

[0218] A spatial distribution image determination unit 2053, configured to weight the first spatial distribution image and the second spatial distribution image to obtain a spatial distribution image of abnormal geological bodies beside the well.

[0219] The three-dimensional far-detection acoustic logging device based on an acoustic vector array in this application, by jointly processing the acoustic pressure and vibration velocity information in the acoustic field of the far-detection acoustic logging borehole, makes full use of the waveform information recorded by all receiving units of each acoustic wave receiving station in the receiving acoustic array. More information will inevitably lead to better data processing results. Compared with the traditional monopole emission and acoustic pressure measurement system and the orthogonal dipole emission and orthogonal dipole measurement system, this acoustic vector array joint processing system has better noise anti-interference ability, can suppress borehole mode waves, and improve the signal-to-noise ratio of echo signals. In addition, this application can directly use the recorded waveforms of the acoustic vector array to quickly and effectively extract the azimuth information of abnormal bodies beside the well, laying a foundation for the application of acoustic far-detection in logging-while-drilling geological steering.

[0220] In one embodiment, this application also provides a computer device. Refer to Figure 15 , the electronic device 100 specifically includes:

[0221] A central processor 110, a memory 120, a communication module 130, an input unit 140, an output unit 150, and a power supply 160.

[0222] Among them, the memory 120, the communication module 130, the input unit 140, the output unit 150, and the power supply 160 are respectively connected to the central processor 110. A computer program is stored in the memory 120, and the central processor 110 can call the computer program. When the central processor 110 executes the computer program, all steps in the above-mentioned three-dimensional far-detection acoustic logging method based on an acoustic vector array in the embodiment are implemented.

[0223] In one embodiment, the embodiment of this application also provides a computer-readable storage medium for storing a computer program, and the computer program can be executed by a processor. When the computer program is executed by the processor, any three-dimensional far-detection acoustic logging method provided by the present invention is implemented.

[0224] In one embodiment, the embodiment of the present invention also provides a computer program product, and the computer program product includes a computer program. When the computer program is executed by a processor, any three-dimensional far-detection acoustic logging method provided by the above-mentioned embodiment is implemented.

[0225] Those skilled in the art should understand that the embodiments of the present invention can be provided as a method, a system, or a computer program product. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present invention can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk memory, CD-ROM, optical memory, etc.) that contain computer-usable program code.

[0226] The present invention is described with reference to the flowcharts and / or block diagrams of methods, apparatuses (systems), and computer program products according to embodiments of the present invention. It should be understood that each flow and / or block in the flowchart and / or block diagram, as well as the combination of flows and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to the processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing devices to generate a machine, such that the instructions executed by the processor of the computer or other programmable data processing devices generate means for implementing the functions specified in Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0227] These computer program instructions can also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to work in a specific manner, such that the instructions stored in the computer-readable memory generate a manufactured article including instruction means that implement the functions specified in Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0228] These computer program instructions can also be loaded onto a computer or other programmable data processing device, such that a series of operation steps are executed on the computer or other programmable device to generate a computer-implemented process, and thus the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0229] The specific embodiments described above further elaborate on the objectives, technical solutions, and beneficial effects of the present invention. It should be understood that the above are only specific embodiments of the present invention and are not used to limit the protection scope of the present invention. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention shall be included in the protection scope of the present invention.

Claims

1. A three-dimensional far-detection acoustic logging method based on an acoustic vector array, characterized in that Including: Obtaining multi-directional sound pressure waveform signals collected by a receiving transducer array and generating multi-component particle velocity waveform signals based on the multi-directional sound pressure waveform signals, where the multi-directional sound pressure waveform signals are formed when a near-wellbore abnormal geological body reflects and / or scatters the pulsed acoustic wave signals radiated by a multi-pole emission transducer; the multi-pole emission transducer and the receiving transducer array are arranged in a fluid-filled wellbore of a formation to be measured; Performing pairwise combination and grouped coordinate transformation on the multi-component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain multiple groups of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station; Performing polarization analysis on each group of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component particle velocity waveform signals in the particle polarization direction; Determining the azimuth information of the near-wellbore abnormal geological body according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signals, and the echo mode type; Performing imaging according to the multi-directional sound pressure waveform signals and the main component particle velocity waveform signals to obtain a spatial distribution image of the near-wellbore abnormal geological body.

2. The three-dimensional far-detection acoustic logging method based on an acoustic vector array according to claim 1, characterized in that, The receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M receiving units, where M is an even number greater than or equal to 4, and two receiving units with an azimuth difference of 180° in each acoustic wave receiving station form a particle velocity component receiving sensor; the multi-directional sound pressure waveform signals include the sound pressure waveform signals received by each receiving unit; The generating multi-component particle velocity waveform signals based on the multi-directional sound pressure waveform signals includes: Determining multiple particle velocity component waveform signals according to the sound pressure waveform signals received by the receiving units in the particle velocity component receiving sensor, the radius of the receiving transducer array, and the static density of the fluid filled in the fluid-filled wellbore.

3. The three-dimensional far-detection acoustic logging method based on an acoustic vector array according to claim 1, characterized in that, The performing pairwise combination and grouped coordinate transformation on the multi-component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain multiple groups of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station includes: Performing pairwise full permutation combination on the multi-component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain multiple groups of components; Performing coordinate transformation on each group of components respectively to obtain multiple groups of orthogonal component particle velocity waveform signals; Rotating and transforming the representation forms of each group of orthogonal component particle velocity waveform signals into the representation forms in a preset coordinate system.

4. The three-dimensional far-detection acoustic logging method based on an acoustic vector array according to claim 1, characterized in that, The performing polarization analysis on each group of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component particle velocity waveform signals of each acoustic wave receiving station in the particle polarization direction includes: Performing window opening and mean removal operations on each group of orthogonal component particle velocity waveform signals corresponding to each acoustic wave receiving station respectively to form a covariance matrix corresponding to each group of orthogonal component particle velocity waveform signals; Performing eigenvalue decomposition on the covariance matrix to obtain the particle polarization direction corresponding to each group of orthogonal component particle velocity waveform signals; Superposing the particle polarization directions corresponding to each group of orthogonal component particle velocity waveform signals to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array; Obtain the main component vibration velocity waveform signals corresponding to each orthogonal component vibration velocity waveform signal according to each group of orthogonal component vibration velocity waveform signals and the particle polarization direction in the horizontal plane; Superimpose the main component vibration velocity waveform signals of each group of orthogonal component vibration velocity waveform signals in the particle polarization direction according to the acoustic wave receiving stations to obtain the main component vibration velocity waveform signals corresponding to each acoustic wave receiving station.

5. The three-dimensional far-detection acoustic logging method based on an acoustic vector array according to claim 1, wherein The method for determining the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signals and the echo mode type includes: Determine the angle between the particle polarization direction and the due north direction according to the particle polarization direction in the horizontal plane; Determine two predicted azimuth values of the abnormal geological body beside the well according to the echo mode type; Determine the accurate azimuth value of the abnormal geological body beside the well from the predicted azimuth values according to the amplitude information of the multi-directional sound pressure waveform signals.

6. The three-dimensional far-detection acoustic logging method based on an acoustic vector array according to claim 1, characterized in that The method for imaging according to the multi-directional sound pressure waveform signals and the main component vibration velocity waveform signals to obtain the spatial distribution image of the abnormal geological body beside the well includes: Perform imaging based on the multi-directional sound pressure waveform signals to obtain the first spatial distribution image of the abnormal geological body beside the well; Perform imaging based on the main component vibration velocity waveform signals to obtain the second spatial distribution image of the abnormal geological body beside the well; Perform weighting on the first spatial distribution image and the second spatial distribution image to obtain the spatial distribution image of the abnormal geological body beside the well.

7. A three-dimensional long-range detection acoustic logging device based on an acoustic vector array, characterized in that, Including: A multi-component vibration velocity waveform signal determination module, configured to acquire the multi-directional sound pressure waveform signals collected by the receiving transducer array and generate multi-component vibration velocity waveform signals based on the multi-directional sound pressure waveform signals, wherein the multi-directional sound pressure waveform signals are formed when the abnormal geological body beside the well reflects and / or scatters the pulse acoustic wave signals radiated by the multi-pole emission transducer; the multi-pole emission transducer and the receiving transducer array are arranged in the fluid-filled wellbore of the formation to be measured; An orthogonal component vibration velocity waveform signal determination module, configured to respectively perform pairwise combination and grouped coordinate transformation on the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station to obtain multiple groups of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station; A main component vibration velocity waveform signal determination module, configured to respectively perform polarization analysis on each group of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array and the main component vibration velocity waveform signals in the particle polarization direction; An azimuth information determination module, configured to determine the azimuth information of the abnormal geological body beside the well according to the particle polarization direction in the horizontal plane, the amplitude information of the multi-directional sound pressure waveform signals and the echo mode type; An abnormal geological body distribution determination module, configured to perform imaging according to the multi-directional sound pressure waveform signals and the main component vibration velocity waveform signals to obtain the spatial distribution image of the abnormal geological body beside the well.

8. The three-dimensional far-detection acoustic logging device based on an acoustic vector array according to claim 7, characterized in that The receiving transducer array includes N acoustic wave receiving stations, and each acoustic wave receiving station includes M receiving units, where M is an even number greater than or equal to 4. Two receiving units with an azimuth difference of 180° in each acoustic wave receiving station form a vibration velocity component receiving sensor; the multi-directional sound pressure waveform signal includes the sound pressure waveform signals received by each receiving unit. The multi-component vibration velocity waveform signal determination module is specifically configured to: Determine a plurality of vibration velocity component waveform signals according to the sound pressure waveform signals received by the receiving units in the vibration velocity component receiving sensor, the radius of the receiving transducer array, and the static density of the fluid filled in the fluid-filled wellbore.

9. The three-dimensional far-detection acoustic logging device based on an acoustic vector array according to claim 7, characterized in that The orthogonal component vibration velocity waveform signal determination module includes: A grouping unit, configured to perform pairwise full permutation combinations on the multi-component vibration velocity waveform signals corresponding to each acoustic wave receiving station to obtain multiple groups of components; A coordinate conversion unit, configured to perform coordinate conversion on each group of components to obtain multiple groups of orthogonal component vibration velocity waveform signals; A rotation transformation unit, configured to rotate and transform the representation forms of each group of orthogonal component vibration velocity waveform signals into the representation forms in a preset coordinate system.

10. The three-dimensional far-detection acoustic logging device based on an acoustic vector array according to claim 7, wherein The main component vibration velocity waveform signal determination module includes: A covariance matrix determination unit, configured to perform window opening and mean removal operations on each group of orthogonal component vibration velocity waveform signals corresponding to each acoustic wave receiving station to form a covariance matrix corresponding to each group of orthogonal component vibration velocity waveform signals; A particle polarization direction determination unit, configured to perform eigenvalue decomposition on the covariance matrix to obtain the particle polarization directions corresponding to each group of orthogonal component vibration velocity waveform signals; A particle polarization direction superposition unit, configured to superpose the particle polarization directions corresponding to each group of orthogonal component vibration velocity waveform signals to obtain the particle polarization direction in the horizontal plane corresponding to the receiving transducer array; A main component vibration velocity waveform signal determination unit, configured to obtain the main component vibration velocity waveform signals corresponding to each orthogonal component vibration velocity waveform signal according to each group of orthogonal component vibration velocity waveform signals and the particle polarization direction in the horizontal plane; A main component vibration velocity waveform signal superposition unit, configured to superpose the main component vibration velocity waveform signals of each group of orthogonal component vibration velocity waveform signals in the particle polarization direction according to the acoustic wave receiving stations to obtain the main component vibration velocity waveform signals corresponding to each acoustic wave receiving station.

11. The three-dimensional far-detection acoustic logging device based on an acoustic vector array according to claim 7, characterized in that, The azimuth information determination module includes: An included angle determination unit, configured to determine the included angle between the particle polarization direction and the due north direction according to the particle polarization direction in the horizontal plane; A predicted azimuth value determination unit, configured to determine two predicted azimuth values of the abnormal geological body beside the well according to the echo mode type; An accurate azimuth value determination unit, configured to determine the accurate azimuth value of the abnormal geological body beside the well from the predicted azimuth values according to the amplitude information of the multi-directional sound pressure waveform signal.

12. The three-dimensional far-detection acoustic logging device based on an acoustic vector array according to claim 7, wherein The abnormal geological body distribution determination module includes: A first imaging unit, configured to perform imaging based on the multi-directional sound pressure waveform signal to obtain a first spatial distribution image of the abnormal geological body beside the well; A second imaging unit, configured to perform imaging based on the main component vibration velocity waveform signal to obtain a second spatial distribution image of the abnormal geological body beside the well; A spatial distribution image determination unit is configured to weight the first spatial distribution image and the second spatial distribution image to obtain a spatial distribution image of abnormal geological bodies beside the well.

13. A computer device, comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the three-dimensional far-detection acoustic logging method based on an acoustic vector array according to any one of claims 1 to 6.

14. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, it implements the three-dimensional far-detection acoustic logging method based on an acoustic vector array according to any one of claims 1 to 6.

Images