Wellbore correction method and system for multi-component acoustic logging data

Abstract

The present invention discloses a borehole correction method and system for multi-component acoustic logging data, including: calibrating each transmitting sound source in a calibrated acoustic logging instrument by aligning each transmitting sound source with a standard transmitting position, recording the first feature of each transmitting sound source, and calibrating each receiver by aligning each receiver with a standard receiving position, recording the second feature of each receiver; normalizing various feature data in the first feature and the second feature, and based on this, performing system normalization correction on the actual acoustic logging data of each component; calculating the borehole eccentricity correction parameter of the current logging instrument according to the actual acoustic logging data of each component after normalization correction, and performing borehole environment correction processing on the actual acoustic data of each component according to the borehole eccentricity correction parameter. The algorithm of the present invention is simple, reliable, and easy to implement.

Description

Technical Field

[0001] The present invention relates to the field of mine geophysical technology, and in particular to a borehole correction method and system for multi-component acoustic logging data. Background Art

[0002] Traditional multi-component acoustic logging instruments (such as dipole / multipole array acoustic logging instruments) are used to measure various types of acoustic signals including monopole, dipole and quadrupole, and extract sound velocity and full wave train information from the collected acoustic signals. Multi-component acoustic logging instruments can be used in the petroleum and geological industries, and are used to complete tasks such as calculating porosity, judging lithology and qualitatively identifying gas layers, qualitatively judging fracture development sections, determining geostress direction, calculating rock mechanics parameters, evaluating wellbore stability, predicting and detecting reservoir pressure fracture height and extension direction. However, the measurement process must ensure that the instrument is carried out in the center of the wellbore. Non-centered measurement will cause large errors in sound velocity calculation and anisotropy anomalies, which will reduce the accuracy of later calculation results such as porosity and geostress.

[0003] However, in practical applications, with the progress of geological and oil and gas exploration and development, large-angle and horizontal measurement construction has become more frequent, so centered measurement is difficult to ensure under these restrictions. Moreover, in the past, acoustic wellbore correction required multi-arm wellbore measurement to obtain more accurate correction results, which increased the amount of on-site construction and increased the construction risk. Therefore, the prior art needs to provide a new solution for wellbore correction of acoustic logging data to solve one or more of the above problems. Summary of the invention

[0004] In order to solve the above technical problems, the present invention provides a borehole correction method for multi-component acoustic logging data, comprising: calibrating each transmitting sound source in a calibrated acoustic logging instrument by aligning each transmitting sound source with a standard transmitting position, recording a first feature of each transmitting sound source, and calibrating each receiver by aligning each receiver with a standard receiving position, recording a second feature of each receiver, wherein the feature includes amplitude, phase, spectrum distribution and energy; normalizing each type of feature data in the first feature and the second feature, and based on this, performing a systematic normalization correction on the actual acoustic logging data of each component; calculating a borehole eccentricity correction parameter of the current logging instrument according to the actual acoustic logging data of each component after normalization correction, and performing a borehole environment correction on the actual acoustic data of each component according to the borehole eccentricity correction parameter.

[0005] Preferably, the steps of normalizing the various types of feature data in the first feature and the second feature include: normalizing the amplitude feature, phase feature, spectrum distribution feature and energy feature in the first feature, and normalizing the amplitude feature, phase feature, spectrum distribution feature and energy feature in the second feature, to obtain the transmission amplitude correction coefficient, the reception amplitude correction coefficient, the transmission phase correction coefficient, the reception phase correction coefficient, the transmission spectrum correction coefficient and the reception spectrum correction coefficient, respectively.

[0006] Preferably, the amplitude of the acoustic logging data of each receiving component is normalized and corrected according to the transmission amplitude correction coefficient and the reception amplitude correction coefficient to obtain the amplitude of the acoustic data of each component after normalization correction; the phase of the acoustic logging data of each receiving component is normalized and corrected according to the transmission phase correction coefficient and the reception phase correction coefficient to obtain the phase or arrival time of the acoustic data of each component after normalization correction; according to the transmission spectrum correction coefficient and the reception spectrum correction coefficient, a preset normalized bandpass filter is used to normalize and correct the frequency information of the acoustic logging data of each receiving component to obtain the frequency information of the acoustic data of each component after normalization correction, wherein the acoustic logging data of each component is systematically normalized using the following expression:

[0007] AMP=(AMP / NTA) / NRA

[0008] PHS=PHS+NTP+NRP

[0009] FRQ=FILTER1(FRQ,NTE,NRE)

[0010] Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, NTA represents the transmission amplitude correction coefficient, NRA represents the reception amplitude correction coefficient, PHS represents the phase or arrival time array of the acoustic logging data of each receiving component, NTP represents the transmission phase correction coefficient, NRP represents the reception phase correction coefficient, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NTE represents the transmission spectrum correction coefficient, NRE represents the reception spectrum correction coefficient, and FILTER1 represents a normalized bandpass filter.

[0011] Preferably, in the step of calculating the borehole eccentricity correction parameters of the current logging instrument according to the actual acoustic logging data of each component after normalization correction, and performing borehole environment correction processing on the actual acoustic data of each component according to the borehole eccentricity correction parameters, the steps include: obtaining the amplitude array, phase or arrival time array and frequency array of the acoustic logging data of each component after normalization correction, and based on this, respectively calculating the amplitude eccentricity correction parameters, phase eccentricity correction parameters and frequency eccentricity correction parameters; according to the amplitude array of the acoustic logging data of each component after normalization correction, using the amplitude eccentricity correction parameters and a preset first weighted correction coefficient, performing borehole environment correction on the amplitude of the acoustic data of each component, and obtaining the acoustic amplitude data after the borehole environment correction for each component. ; According to the phase or arrival time array of the acoustic logging data of each component after normalization correction, the phase eccentricity correction parameter and the preset second weighted correction coefficient are used to perform borehole environment correction on the phase or arrival time of the acoustic data of each component, and the acoustic phase or arrival time data after the borehole environment correction is obtained for each component; According to the spectrum information array of the acoustic logging data of each component after normalization correction, the frequency eccentricity correction parameter and the preset third weighted correction coefficient are used, and the preset borehole environment correction bandpass filter is used to perform borehole environment correction on the frequency information of the acoustic data of each component, and the acoustic frequency data after the borehole environment correction is obtained for each component, wherein the borehole environment correction is performed on the acoustic logging data of each component using the following expression:

[0012] AMP'=Ka*AMP / NA

[0013] PHS'=Kp+PHS+NP

[0014] FRQ'=FILTER2(FRQ,Kf(NE))

[0015] Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, PHS represents the phase or arrival time array of the acoustic logging data of each receiving component, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NA represents the amplitude eccentricity correction parameter, NP represents the phase eccentricity correction parameter, NE represents the frequency eccentricity correction parameter, FILTER2 represents the borehole environment correction bandpass filter, Ka, Kp, Kf represent the first weighted correction coefficient, the second weighted correction coefficient and the third weighted correction coefficient respectively, AMP' represents the acoustic amplitude array of each component after borehole correction, PHS' represents the acoustic phase or arrival time array of each component after borehole correction, and FRQ' represents the acoustic frequency information array of each component after borehole correction.

[0016] Preferably, the maximum amplitude value of the transmitting source is determined from the amplitude characteristic data of each transmitting sound source, and the amplitude characteristic data of each transmitting sound source is divided by the maximum amplitude value of the transmitting source to obtain the transmitting amplitude correction coefficient; the maximum amplitude value of the receiving end is determined from the amplitude characteristic data of each receiver, and the amplitude characteristic data of each receiver is divided by the maximum amplitude value of the receiving end to obtain the receiving amplitude correction coefficient; the maximum phase value of the transmitting source is determined from the phase characteristic data of each transmitting sound source, and the maximum phase value of the transmitting source is subtracted from the phase characteristic data of each transmitting sound source to obtain the transmitting phase correction coefficient; the maximum phase value of the receiving end is determined from the phase characteristic data of each receiver, and the maximum phase value of the receiving end is subtracted from the phase characteristic data of each receiver to obtain the receiving phase correction coefficient; first determine from the energy characteristic data of each transmitting sound source The main peak frequency and the product value of the proportion are determined, and the spectrum characteristic data of each transmitting sound source are multiplied by the energy characteristic data of the corresponding component to form corresponding transmission characteristic data for each transmitting source, and finally the maximum transmission characteristic data is screened out from the transmission characteristic data of each transmitting source, and the amplitude characteristic data of each transmitting sound source is divided by the current maximum transmission characteristic data to obtain the transmission spectrum correction coefficient; first, the main peak frequency and the product value of the proportion are determined from the energy characteristic data of each receiver, and the spectrum characteristic data of each receiver are multiplied by the energy characteristic data of the corresponding component to form corresponding reception characteristic data for each receiver, and finally the maximum reception characteristic data is screened out from the reception characteristic data of each receiver, and the amplitude characteristic data of each receiver is divided by the current maximum reception characteristic data to obtain the reception spectrum correction coefficient.

[0017] Preferably, according to the amplitude array corresponding to the acoustic logging data of each component after normalization correction, the maximum normalized amplitude data is extracted therefrom, and the normalized amplitude characteristic data of each component is divided by the maximum normalized amplitude data to obtain the amplitude eccentricity correction parameter; according to the phase or arrival time array corresponding to the acoustic logging data of each component after normalization correction, the maximum normalized phase or arrival time data is extracted therefrom, and the maximum normalized phase or arrival time data is subtracted from the normalized phase or arrival time characteristic data of each component to obtain the phase eccentricity correction parameter; first, according to the spectrum information array corresponding to the acoustic logging data of each component after normalization correction, the main peak frequency and proportion product data is extracted therefrom, and then the designated passband spectrum information corresponding to the designated proportion in the spectrum information corresponding to the actual acoustic logging data of each component is determined, and finally, according to the main peak frequency and proportion product data and the designated passband spectrum information corresponding to each receiver, the normalized frequency characteristic data of each component is filtered based on the designated bandpass range to obtain the frequency eccentricity correction parameter.

[0018] Preferably, the grading device is a metal cylinder or a silencing water pool, wherein the inner diameter of the cylinder ranges from 200 to 400 mm, the outer shell of the cylinder is made of high-strength corrosion-resistant metal material, the inner wall of the cylinder is smooth and free of impurities, and the interior of the cylinder is filled with tap water and left to stand for more than one day.

[0019] On the other hand, the present invention also provides a borehole correction system for multi-component acoustic logging data, the borehole correction system is used to execute the borehole correction method as described above, wherein the borehole correction system includes: a calibration acoustic logging instrument, which is used to calibrate each transmitting source by aligning each transmitting sound source in the instrument with a standard transmitting position, and to calibrate each receiver by aligning each receiver with a standard receiving position; a borehole correction device, which is used to record the first feature of each transmitting source when calibrating each transmitting source, and to record the second feature of each receiver when calibrating each receiver, and then normalize each type of feature data in the first feature and the second feature, based on which, the actual acoustic logging data of each component is systematically normalized and corrected, and the borehole eccentricity correction parameters of the current logging instrument are calculated based on the actual acoustic logging data of each component after normalization correction, and the actual acoustic data of each component is subjected to borehole environment correction processing based on the borehole eccentricity correction parameters, wherein the features include amplitude, phase, spectrum distribution and energy.

[0020] Preferably, the wellbore correction device includes a normalization correction module, wherein the normalization correction module has: a correction coefficient calculation unit, which is configured to normalize the amplitude characteristics, phase characteristics, spectrum distribution characteristics and energy characteristics in the first characteristic, and normalize the amplitude characteristics, phase characteristics, spectrum distribution characteristics and energy characteristics in the second characteristic, and respectively obtain the transmission amplitude correction coefficient, the reception amplitude correction coefficient, the transmission phase correction coefficient, the reception phase correction coefficient, the transmission spectrum correction coefficient and the reception spectrum correction coefficient.

[0021] Preferably, the borehole correction device also includes a borehole environment correction module, wherein the borehole environment correction module has: a borehole eccentricity correction parameter determination unit, which is configured to obtain the amplitude array, phase or arrival time array and frequency array of the acoustic logging data of each component after normalization correction, based on which, respectively calculate the amplitude eccentricity correction parameter, phase eccentricity correction parameter and frequency eccentricity correction parameter; an amplitude data eccentricity correction unit, which is configured to perform borehole environment correction on the amplitude of the acoustic data of each component according to the amplitude array of the acoustic logging data of each component after normalization correction, using the amplitude eccentricity correction parameter and a preset first weighted correction coefficient, and obtain the acoustic amplitude data after the borehole environment correction for each component; a phase data eccentricity correction unit, which is configured to obtain the acoustic amplitude data after the borehole environment correction according to the phase or arrival time array of the acoustic logging data of each component after normalization correction. A group, using the phase eccentricity correction parameter and the preset second weighted correction coefficient, performs borehole environment correction on the phase or arrival time of the acoustic wave data of each component, and obtains the acoustic wave phase or arrival time data after the borehole environment correction for each component; a frequency data eccentricity correction unit, which is configured to perform borehole environment correction on the frequency information of the acoustic wave data of each component according to the spectrum information array of the acoustic wave logging data of each component after normalization correction, using the frequency eccentricity correction parameter and the preset third weighted correction coefficient, and adopting a preset borehole environment correction bandpass filter, and obtains the acoustic wave frequency data after the borehole environment correction for each component, wherein the amplitude data eccentricity correction unit, the phase data eccentricity correction unit and the frequency data eccentricity correction unit respectively use the following expressions to perform borehole environment correction on the acoustic wave logging data of each component:

[0022] AMP'=Ka*AMP / NA

[0023] PHS'=Kp+PHS+NP

[0024] FRQ'=FILTER2(FRQ,Kf(NE))

[0025] Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, PHS represents the phase or arrival time array of the acoustic logging data of each receiving component, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NA represents the amplitude eccentricity correction parameter, NP represents the phase eccentricity correction parameter, NE represents the frequency eccentricity correction parameter, FILTER2 represents the borehole environment correction bandpass filter, Ka, Kp, Kf represent the first weighted correction coefficient, the second weighted correction coefficient and the third weighted correction coefficient respectively, AMP' represents the acoustic amplitude array of each component after borehole correction, PHS' represents the acoustic phase or arrival time array of each component after borehole correction, and FRQ' represents the acoustic frequency information array of each component after borehole correction.

[0026] Compared with the prior art, one or more embodiments of the above scheme may have the following advantages or beneficial effects:

[0027] The present invention discloses a borehole correction method and system for multi-component acoustic logging data. The method and system centrally place the acoustic logging instrument in a cylinder or an anechoic water tank, and respectively perform calibration processing on the amplitude, phase, spectrum and energy of the sound transmitter and the receiving detector; the system normalization correction parameters of the transmitting sound source and the receiving detector are calculated according to the calibration values, and the real-time measured acoustic logging data are corrected using the current system normalization correction parameters; then the borehole eccentricity correction coefficient is extracted and calculated from the corrected acoustic data, and then the current borehole eccentricity correction coefficient is used to further perform borehole correction on the acoustic logging data. The borehole correction method described in the present invention can perform borehole adaptive correction on multi-component acoustic logging data, and the algorithm is simple, reliable, and easy to implement. It does not require the use of other construction measurement instruments, thereby reducing on-site construction volume and construction risks.

[0028] Other features and advantages of the present invention will be described in the following description, and partly become apparent from the description, or understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the description, claims and drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0029] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0030] Figure 1 It is a step diagram of a wellbore correction method for multi-component acoustic logging data according to an embodiment of the present application.

[0031] Figure 2 It is a flow chart of a wellbore correction method for multi-component acoustic logging data according to an embodiment of the present application.

[0032] Figure 3 It is a waveform diagram of acoustic logging in a wellbore correction method for multi-component acoustic logging data in an embodiment of the present application.

[0033] Figure 4 It is a structural schematic diagram of a wellbore correction system for multi-component acoustic logging data according to an embodiment of the present application. DETAILED DESCRIPTION

[0034] The following will describe the implementation methods of the present invention in detail with reference to the accompanying drawings and embodiments, so that the implementation process of how the present invention applies technical means to solve technical problems and achieve technical effects can be fully understood and implemented accordingly. It should be noted that as long as there is no conflict, the various embodiments of the present invention and the various features in the embodiments can be combined with each other, and the technical solutions formed are all within the protection scope of the present invention.

[0035] In addition, the steps shown in the flowchart of the accompanying drawings can be executed in a computer system such as a set of computer executable instructions. Also, although a logical sequence is shown in the flowchart, in some cases, the steps shown or described can be performed in a sequence different from that here.

[0036] Traditional multi-component acoustic logging instruments (such as dipole / multipole array acoustic logging instruments) are used to measure various types of acoustic signals including monopole, dipole and quadrupole, and extract sound velocity and full wave train information from the collected acoustic signals. Multi-component acoustic logging instruments can be used in the petroleum and geological industries, and are used to complete tasks such as calculating porosity, judging lithology and qualitatively identifying gas layers, qualitatively judging fracture development sections, determining geostress direction, calculating rock mechanics parameters, evaluating wellbore stability, predicting and detecting reservoir pressure fracture height and extension direction. However, the measurement process must ensure that the instrument is carried out in the center of the wellbore. Non-centered measurement will cause large errors in sound velocity calculation and anisotropy anomalies, which will reduce the accuracy of later calculation results such as porosity and geostress.

[0037] However, in practical applications, with the progress of geological and oil and gas exploration and development, large-angle and horizontal measurement construction has become more frequent, so centered measurement is difficult to guarantee under these restrictions. In addition, in the past, acoustic wellbore correction required multi-arm wellbore measurement to obtain more accurate correction results, which increased the amount of on-site construction and increased construction risks.

[0038] Therefore, in order to solve one or more of the above-mentioned technical problems, the present application proposes a borehole correction method and system for multi-component acoustic logging data. The method and system include: using a calibrated acoustic logging instrument to record the amplitude, phase, spectrum and energy characteristics of each transmitting source in the instrument, and recording the amplitude, phase, spectrum and energy characteristics of each receiver; calculating a system normalization correction coefficient for normalizing the amplitude, phase and frequency according to the recorded data, and using the current coefficient to perform a system normalization correction on the acoustic logging data of each component; calculating a borehole eccentricity correction parameter coefficient according to the normalized corrected acoustic logging data, and using the current borehole eccentricity correction parameter coefficient to further perform borehole environment correction processing on the normalized corrected acoustic logging data on each component. In this way, the present invention can correct the acoustic logging data for factors such as instrument eccentricity and borehole irregularity, thereby obtaining accurate borehole correction results for the acoustic logging data, which is suitable for well section logging scenarios in different directions such as high inclination and horizontal.

[0039] Figure 1 It is a step diagram of a wellbore correction method for multi-component acoustic logging data according to an embodiment of the present application. Figure 2 Schematic diagram of the process of the borehole correction method for multi-component acoustic logging data in the embodiment of the present application. Figure 1 and Figure 2 , a borehole correction method for multi-component acoustic logging data (hereinafter referred to as “borehole correction method”) according to an embodiment of the present invention is described.

[0040] Step S110 calibrates each transmitting sound source in the calibrated sonic logging instrument by aligning each transmitting sound source with the standard transmitting position, and records the first feature of each transmitting sound source, and calibrates each receiver by aligning each receiver (detector) in the calibrated sonic logging instrument with the standard receiving position, and records the second feature of each receiver. Among them, the first feature and the second feature both contain multiple types of features, and the number of types of features contained in the first feature and the second feature are the same and the type content is also the same. Further, the first feature and the second feature both include amplitude features, phase features, spectrum features and energy features. It should be noted that in the embodiment of the present invention, the spectrum features of each transmitting sound source or receiver are preferably the frequency and energy relationship features corresponding to different data points in the spectrum curve of the acoustic wave signal obtained within a period of time, and the energy features of each transmitting sound source or receiver are preferably the time and energy relationship features corresponding to different data points in the time curve of the acoustic wave signal obtained within a period of time.

[0041] In the embodiment of the present invention, (refer to Figure 4) The calibration sonic logging instrument comprises a sonic logging instrument and a calibration device. Among them, a standard transmitting source and a standard receiver are configured in the calibration device. A corresponding sonic wave transmitter is configured at the position where the standard transmitting source is located, which is used to transmit a test (standard) sonic wave signal to the position where the standard receiver is located, and a corresponding transmission control component connected to the sonic wave transmitter is used to control the signal transmission start and stop, signal frequency, signal amplitude and other information of the standard sonic wave signal. A corresponding sonic wave receiver is configured at the position where the standard receiver is located, which is used to receive the (standard) sonic wave signal emitted from the standard transmitting source, and a corresponding receiving control component connected to the sonic wave receiver is used to collect the original waveform and corresponding signal characteristics of the standard sonic wave signal.

[0042] Further, in an embodiment of the present invention, the sonic logging instrument is placed in a scale device, and is placed in the center of the scale device. The scale device adopts a silencing pool or a metal cylinder. When the scale device is a metal cylinder, the diameter of the cylinder is in the range of 200 to 400 mm. In addition, the outer shell of the cylinder is made of high-strength corrosion-resistant metal material, and the inside of the cylinder needs to be filled with tap water, and the tap water is left to stand for more than one day.

[0043] In step S110, firstly, any transmitting source in the acoustic logging instrument is placed at the standard transmitting position, and the amplitude, phase, spectrum and energy of the monopole and dipole generating sound sources in the current transmitting direction are calibrated. Specifically, for the mono / dipole sound source calibration rotation instrument, the transmitting direction corresponding to the first mono / dipole transmitting sound source is selected to be aligned with the transmitting scale mark (standard transmitting position), the first mono / dipole transmitting sound source transmits a standard measuring sound wave signal and the receiver at the standard receiving position receives the measuring sound wave signal emitted by the standard transmitting position, thereby measuring and recording the amplitude (characteristic) TA1, phase (characteristic) TP1, spectrum distribution information (characteristic) TF1 and energy (characteristic) TE1 of the current first transmitting sound source; then, the rotating instrument is used to align the transmitting direction corresponding to the second mono / dipole transmitting sound source with the transmitting scale mark, and the second mono / dipole transmitting sound source is used to transmit the standard measuring sound wave signal. The source emits a standard measurement sound wave signal and the receiver at the standard receiving position receives the measurement sound wave signal emitted by the standard transmitting position, thereby measuring and recording the amplitude (characteristic) TA2, phase (characteristic) TP2, spectrum distribution information (characteristic) TF2 and energy (characteristic) TE2 of the current second transmitting sound source; repeat the above steps to complete the measurement and recording of the first characteristics of other transmitting sound sources in turn; finally, the rotating instrument completes the scale of the emission direction corresponding to the last single / dipole sound source, and measures and records the amplitude (characteristic) TAn, phase (characteristic) TPn, spectrum distribution information (characteristic) TFn and energy (characteristic) TEn of the last transmitting sound source. Wherein, n represents the total number of transmitting sound sources (emitting directions) in the instrument.

[0044] After completing the measurement of the transmitting sound source, the acoustic wave receiving capability of each receiving detector must be measured in step S110. Place any group of component receiving detectors in the acoustic logging instrument at the receiving scale mark position (standard receiving position), and calibrate the amplitude, phase, spectrum and energy of the multi-component receiving detectors respectively. Specifically, the instrument is rotated so that the receiving detector of the first component is aligned with the receiving scale mark (standard receiving position), the acoustic wave transmitter at the standard transmitting position transmits a standard measuring acoustic wave signal, and the first receiver at the standard receiving position receives the measuring acoustic wave signal emitted by the standard transmitting position, thereby measuring and recording the amplitude (characteristic) RA1, phase (characteristic) RP1, spectrum distribution information (characteristic) RF1 and energy (characteristic) RE1 of the current first receiving detector; the instrument is rotated so that the receiving detector of the second component is aligned with the receiving scale mark (standard receiving position), the acoustic wave transmitter at the standard transmitting position transmits a standard measuring acoustic wave signal, and the second receiver at the standard receiving position receives the measuring acoustic wave signal emitted by the standard transmitting position. Wave signal, thereby measuring and recording the amplitude (characteristic) RA2, phase (characteristic) RP2, spectrum distribution information (characteristic) RF2 and energy (characteristic) RE2 of the current second receiving detector; repeat the above steps to complete the measurement and recording of the second characteristics of other receivers in turn; continue to rotate the instrument so that the receiving detector of the last component is aligned with the receiving scale mark (standard receiving position), and the sound wave transmitter at the standard transmitting position transmits the standard measurement sound wave signal and the last receiver at the standard receiving position receives the measurement sound wave signal emitted by the standard transmitting position, thereby measuring and recording the amplitude (characteristic) RAm, phase (characteristic) RPm, spectrum distribution information (characteristic) RFm and energy (characteristic) REm of the current last receiving detector. Wherein, m represents the total number of receivers in the instrument.

[0045] Figure 3 Schematic diagram of the waveform of acoustic logging in the borehole correction method for multi-component acoustic logging data in the embodiment of the present application. Figure 3 As shown, the five waveform diagrams are the original sound wave signals received by the five components respectively.

[0046] After obtaining the calibration results of all the transmitters and receivers in the instrument, refer to Figure 1 Step S120 normalizes each type of feature data in the first feature of each transmitting sound source and the second feature of each receiver recorded in step S110, and performs system normalization correction on the actual acoustic logging data of each receiving component based on the normalization processing result of each type of feature data.

[0047] Further, in step S120, it is necessary to normalize the amplitude characteristics, phase characteristics, spectral distribution characteristics and energy characteristics in the first characteristics of each transmitting sound source recorded in step S110, and normalize the amplitude characteristics, phase characteristics, spectral distribution characteristics and energy characteristics in the second characteristics of each receiver recorded in step S110, and calculate the transmitting amplitude correction coefficient, receiving amplitude correction coefficient, transmitting phase correction coefficient, receiving phase correction coefficient, transmitting spectrum correction coefficient and receiving spectrum correction coefficient based on various characteristic data, so as to use this information to perform systematic normalization correction on the acoustic logging data of each component.

[0048] Further, in the embodiment of the present invention, when calculating the emission amplitude, it is necessary to first obtain the amplitude characteristic data of each emission sound source, and determine the maximum amplitude value (of the emission source) therefrom, and then divide the amplitude characteristic data of each emission sound source by the current maximum amplitude value of the emission source to obtain the emission amplitude correction coefficient required currently. The emission amplitude correction coefficient is calculated according to the following expression:

[0049] TA=MAX(TA1, TA2,...,TAn) (1)

[0050] NTA=(TA1 / TA,TA2 / TA,…,TAn / TA) (2)

[0051] Among them, MAX represents a function for obtaining the maximum value within a specified range; NTA represents a transmission amplitude correction coefficient; TA1, TA2, ..., TAn respectively represent amplitude characteristic data corresponding to different transmission sound sources.

[0052] Further, in the embodiment of the present invention, when calculating the receiving amplitude correction coefficient, it is necessary to first obtain the amplitude characteristic data of each receiver, and determine the (receiving end) maximum amplitude value therefrom, and then divide the amplitude characteristic data of each receiver by the current receiving end maximum amplitude value to obtain the currently required receiving amplitude correction coefficient. The receiving amplitude correction coefficient is calculated according to the following expression:

[0053] RA=MAX(RA1,RA2,…,RAm) (3)

[0054] NRA=(RA1 / RA,RA2 / RA,…,RAm / RA) (4)

[0055] Among them, NRA represents the receiving amplitude correction coefficient; RA1, RA2, ..., RAm represent the amplitude characteristic data corresponding to different receivers respectively.

[0056] Further, in the embodiment of the present invention, when calculating the transmission phase correction coefficient, it is necessary to first obtain the phase characteristic data of each transmission sound source, and determine the (transmission source) maximum phase value therefrom, and then, subtract the current transmission source maximum phase value from the phase characteristic data of each transmission sound source to obtain the currently required transmission phase correction coefficient. The transmission phase correction coefficient is calculated according to the following expression:

[0057] TP=MAX(TP1, TP2,..., TPn) (5)

[0058] NTP=(TP-TP1, TP-TP2..., TP-TPn) (6)

[0059] Among them, NTP represents the transmission phase correction coefficient; TP1, TP2, ..., TPn respectively represent the phase characteristic data corresponding to different transmission sound sources.

[0060] Further, in the embodiment of the present invention, when calculating the receiving phase correction coefficient, it is necessary to first obtain the phase characteristic data of each receiver, and determine the (receiving end) maximum phase value therefrom, and then, subtract the current receiving end maximum phase value from the phase characteristic data of each receiver respectively, to obtain the currently required receiving phase correction coefficient. The receiving phase correction coefficient is calculated according to the following expression:

[0061] RP=MAX(RP1,RP2,…,RPm) (7)

[0062] NRP=(RP-RP1, RP-RP2,..., RP-RPm) (8)

[0063] Among them, NRP represents the receiving phase correction coefficient; RP1, RP2, ..., RPm respectively represent the phase characteristic data corresponding to different receivers.

[0064] Further, in the embodiment of the present invention, when calculating the emission spectrum correction coefficient, it is necessary to first obtain the energy characteristic data of each emission sound source, and determine the corresponding (emission source) main peak frequency and proportion product value therefrom, and then, multiply the spectrum characteristic data of each emission sound source by the energy characteristic data of the corresponding component, so as to form corresponding emission characteristic data for each emission source, and finally, filter out the maximum emission characteristic data from the emission characteristic data of each emission source, and divide the amplitude characteristic data of each emission sound source by the current maximum emission characteristic data, so as to obtain the emission spectrum correction coefficient required currently. Among them, the emission spectrum correction coefficient is calculated according to the following expression:

[0065] TF=(SUM(TF1*TE1), SUM(TF2*TE2),..., SUM(TFn*TEn)) (9)

[0066] TE=FMAX(TF) (10)

[0067] NTE=(TA1 / TE,TA2 / TE,…,TAn / TE) (11)

[0068] Among them, NTE represents the emission spectrum correction coefficient; TF1, TF2, ..., TFn respectively represent the spectrum characteristic data corresponding to different emission sound sources; SUM represents the summation function.

[0069] Further, in an embodiment of the present invention, when calculating the received spectrum correction coefficient, it is necessary to first obtain the energy characteristic data of each receiver, and determine the corresponding (receiving end) main peak frequency and proportion product value therefrom, and then, multiply the spectrum characteristic data of each receiver by the energy characteristic data of the corresponding component, so as to form corresponding receiving characteristic data for each receiver, and finally, filter out the maximum receiving characteristic data from the receiving characteristic data of each receiver, and divide the amplitude characteristic data of each receiver by the current maximum receiving characteristic data, so as to obtain the currently required receiving spectrum correction coefficient. Wherein, the receiving spectrum correction coefficient is calculated according to the following expression:

[0070] RF=SUM(RF1*RE1), SUM(RF2*RE2),…, SUM(RFm*REm) (12)

[0071] RE=FMAX(RF) (13)

[0072] NRE=(RA1 / RE,RA2 / RE,…,RAm / RE) (14)

[0073] Among them, NRE represents the receiving spectrum correction coefficient; RF1, RF2, ..., RFn respectively represent the spectrum characteristic data corresponding to different receivers; RE1, RE2, ..., REn respectively represent the energy characteristic data corresponding to different receivers; FMAX represents the function for obtaining the product (extreme) value of the frequency and proportion at the main peak.

[0074] Continue to refer Figure 2 After calculating the normalization correction coefficients including the transmission amplitude, the receiving amplitude correction coefficient, the transmission phase, the receiving phase correction coefficient, the transmission spectrum and the receiving spectrum correction coefficient, these coefficient data are used to perform a systematic normalization correction on the acoustic logging data of each component.

[0075] Specifically, first, according to the calculated transmission amplitude correction coefficient and reception amplitude correction coefficient, the following expression (15) is used to normalize and correct the amplitude of the acoustic logging data of each receiving component, and the amplitude of the acoustic data of each component after normalization correction is obtained; then, according to the calculated transmission phase correction coefficient and reception phase correction coefficient, the following expression (16) is used to normalize and correct the phase of the acoustic logging data of each receiving component, and the phase or arrival time of the acoustic data of each component after normalization correction is obtained; finally, according to the calculated transmission spectrum correction coefficient and reception spectrum correction coefficient, the following expression (17) is used to use a preset normalized bandpass filter to normalize and correct the frequency information of the acoustic logging data of each receiving component, and the frequency information of the acoustic data of each component after normalization correction is obtained. Among them, the acoustic logging data of each component is systematically normalized using the following expression:

[0076] AMP=(AMP / NTA) / NRA (15)

[0077] PHS=PHS+NTP+NRP (16)

[0078] FRQ=FILTER1(FRQ,NTE,NRE) (17)

[0079] Wherein, AMP represents the amplitude array of the acoustic logging data of each receiving component (i.e., in the actual application process, the array obtained by normalizing and correcting the amplitude data of the original acoustic logging signal actually received and measured by the acoustic logging instrument); PHS represents the phase or arrival time array of the acoustic logging data of each receiving component (i.e., in the actual application process, the array obtained by normalizing and correcting the phase or arrival time data of the original acoustic logging signal actually received and measured by the acoustic logging instrument); FRQ represents the spectrum information array of the acoustic logging data of each receiving component (i.e., in the actual application process, the array obtained by normalizing and correcting the spectrum information of the original acoustic logging signal actually received and measured by the acoustic logging instrument, wherein the spectrum information is the height or proportion information of the acoustic logging signal in a preset specific frequency range); FILTER1 represents a normalized bandpass filter. Preferably, FILTER1 is a weighted bandpass filter, and the passband frequency range of the filter is between the transmission spectrum and the reception spectrum correction coefficient. Furthermore, it can be seen from expression (17) that the frequency characteristics are systematically normalized, a calculation that removes the power frequency and its harmonic frequencies.

[0080] In this way, the present invention can effectively complete the system normalization processing of the acoustic logging data acquired in real time in terms of amplitude, phase or arrival time, and angle of spectrum information through the above-mentioned step S120, thereby entering step S130.

[0081] Step S130 calculates the borehole eccentricity correction parameters of the current logging instrument based on the actual acoustic logging data of each component after normalization correction obtained in step S120, and performs borehole environment correction processing on the actual acoustic logging data of each component based on the calculated borehole eccentricity correction parameters, thereby obtaining the final acoustic logging data of each component.

[0082] Further, refer to Figure 2 In step S130, it is necessary to first obtain the amplitude array, phase or arrival time array and spectrum information array of the normalized actual acoustic logging data of each component obtained in step S120, and calculate the amplitude eccentricity correction parameter, phase eccentricity correction parameter and frequency eccentricity correction parameter according to these array information, so as to use these eccentricity correction parameters to further perform wellbore environment correction on the acoustic logging data of each component.

[0083] Further, in the embodiment of the present invention, when calculating the amplitude eccentricity correction parameter, it is necessary to first obtain the amplitude array (recorded as normalized amplitude characteristic data) corresponding to the actual acoustic logging data after normalization correction under each component, and extract the maximum normalized amplitude data therefrom, and then, divide the normalized amplitude characteristic data under each component by the current maximum normalized amplitude data respectively to obtain the currently required amplitude eccentricity correction parameter. Among them, the amplitude eccentricity correction parameter is calculated according to the following expression:

[0084] A=MAX(AMP1,AMP,…,AMPm) (18)

[0085] NA=(AMP1 / A,AMP2 / A,…,AMPm / A) (19)

[0086] Wherein, NA represents the amplitude eccentricity correction parameter; AMP1, AMP 2, ... AMP m represent the amplitude arrays corresponding to the actual acoustic logging data after normalization correction under each component.

[0087] Further, in the embodiment of the present invention, when calculating the phase eccentricity correction parameter, it is necessary to first obtain the phase or arrival time array (recorded as normalized phase or arrival time characteristic data) corresponding to the actual acoustic logging data after normalization correction under each component, and extract the maximum normalized phase or arrival time data therefrom, and then, subtract the normalized phase or arrival time characteristic data under each component from the current maximum normalized phase or arrival time data, respectively, to obtain the phase eccentricity correction parameter currently required. Among them, the phase eccentricity correction parameter is calculated according to the following expression:

[0088] P=MAX(PHS1,PHS2,…,PHSm) (20)

[0089] NP=(P-PHS1,P-PHS2,…,P-PHSm) (21)

[0090] Wherein, NP represents the phase eccentricity correction parameter; PHS1, PHS2, ..., PHSm represent the phase or arrival time array corresponding to the actual acoustic logging data after normalization correction under each component.

[0091] Further, in an embodiment of the present invention, when calculating the frequency eccentricity correction parameter, it is necessary to first obtain the spectrum information array (recorded as normalized spectrum characteristic data) corresponding to the actual acoustic logging data after normalization correction under each component, and extract the main peak frequency and proportion product data therefrom, and then determine the spectrum information corresponding to the specified proportion in the spectrum information corresponding to the actual acoustic logging data of each component, so as to form corresponding specified passband spectrum information for each component, that is, the minimum passband frequency value of the following receiver bandpass filter, and finally, according to the main peak frequency and proportion product data and the specified passband frequency information corresponding to each component, the receiver bandpass filter is used to perform filtering processing based on the specified bandpass range on the normalized frequency characteristic data under each component, so as to obtain the currently required frequency eccentricity correction parameter. Among them, the frequency eccentricity correction parameter is calculated according to the following expression:

[0092] F=FMAX(FRQ1,FRQ2,…,FRQm) (22)

[0093] NE=(FILTER0(E1,F),FILTER0(E2,F),…,FILTER0(Em,F)) (23)

[0094] Wherein, NE represents the frequency eccentricity correction parameter; FRQ1, FRQ2, ..., FRQm represent the frequency information array corresponding to the actual acoustic logging data after normalization correction under each component; FILTER0 represents the receiver bandpass filter; E1, E2, ..., Em represent the spectrum information corresponding to the specified proportion in the spectrum information corresponding to the actual acoustic logging data of each component; F represents the maximum passband frequency value of the current receiver bandpass filter. Preferably, FILTER0 is a weighted bandpass filter, and the passband frequency range of each receiver bandpass filter is between E1 ... Em and F. Further, it can be seen from expression (23) that in the system normalization processing of the frequency characteristics, a calculation is performed to remove the power frequency and its harmonic frequencies.

[0095] Continue to refer Figure 2 After calculating the normalization correction coefficients including amplitude eccentricity correction parameters, phase eccentricity correction parameters and frequency eccentricity correction parameters, these coefficient data are used to perform system normalization correction on the acoustic logging data of each component.

[0096] Specifically, first, according to the amplitude array of the acoustic logging data of each received component after normalization correction, the calculated amplitude eccentricity correction parameter and the preset first weighted correction coefficient are used to perform borehole environment correction on the normalized corrected amplitude array of each component, and the acoustic amplitude data after the borehole environment correction is obtained for each component; according to the phase or arrival time array of the acoustic logging data of each component after normalization correction, the calculated phase eccentricity correction parameter and the preset second weighted correction coefficient are used to perform the following expression (26): The normalized corrected phase or arrival time of each component is corrected for the borehole environment, and the acoustic wave phase or arrival time data after the borehole environment correction is obtained for each component; finally, according to the spectrum information array of the acoustic logging data of each component after the normalization correction, the calculated frequency eccentricity correction parameter and the preset third weighted correction coefficient are used, and the preset borehole environment correction bandpass filter is used to perform the borehole environment correction on the normalized corrected spectrum information of each component through the following expression (26), and the acoustic wave frequency data after the borehole environment correction is obtained for each component. Among them, the borehole environment correction is performed on the acoustic logging data of each component using the following expression:

[0097] AMP'=Ka*AMP / NA (24)

[0098] PHS'=Kp+PHS+NP (25)

[0099] FRQ'=FILTER2(FRQ,Kf(NE)) (26)

[0100] Among them, FILTER2 represents the borehole environment correction bandpass filter; Ka, Kp, Kf represent the first weighted correction coefficient, the second weighted correction coefficient and the third weighted correction coefficient respectively; AMP' represents the acoustic amplitude array of each component after borehole correction, PHS' represents the acoustic phase or arrival time array of each component after borehole correction, and FRQ' represents the acoustic spectrum information array of each component after borehole correction.

[0101] Therefore, the present invention performs a systematic normalization process on the real-time acoustic logging data obtained by the instrument in step S130, and then further performs a borehole environment correction process on the normalized result, thereby making a systematic and uniform correction for instrument eccentricity, borehole irregularity and the like.

[0102] On the other hand, based on the above-mentioned borehole correction method, an embodiment of the present invention further provides a borehole correction system for multi-component acoustic logging data, which is used to execute the above-mentioned borehole correction method. Figure 4Schematic diagram of the structure of the borehole correction system for multi-component acoustic logging data in the embodiment of the present application. Figure 4 As shown, the borehole correction system described in the embodiment of the present invention includes: a calibrated sonic logging instrument 41 and a borehole correction device 42.

[0103] The calibration acoustic logging instrument 41 is used to calibrate each transmitting source by aligning each transmitting sound source in the instrument with the standard transmitting position, and to calibrate each receiver by aligning each receiver with the standard receiving position; the borehole correction device 42 is used to record the first feature of each transmitting source when calibrating each transmitting source, and to record the second feature of each receiver when calibrating each receiver, and then normalize each type of feature data in the recorded first feature and second feature, based on which, the actual acoustic logging data of each component is systematically normalized and corrected, and the borehole eccentricity correction parameters of the current logging instrument are calculated according to the actual acoustic logging data of each component after normalization correction, and the actual acoustic data of each component is corrected for borehole environment according to the current borehole eccentricity correction parameters. The features include amplitude, phase, spectrum distribution and energy.

[0104] Further, the borehole correction device 42 includes: a normalization correction module 421 and a borehole environment correction module 422. Specifically, the normalization correction module 421 includes: a correction coefficient calculation unit 4211, an amplitude normalization correction unit 4212, a phase normalization correction unit 4213, and a frequency normalization correction unit 4214. The borehole environment correction module 422 includes: a borehole eccentricity correction parameter determination unit 4221, an amplitude data eccentricity correction unit 4222, a phase data eccentricity correction unit 4223, and a frequency data eccentricity correction unit 4224.

[0105] Further, the correction coefficient calculation unit 4211 is configured to normalize the amplitude feature, phase feature, spectrum distribution feature and energy feature in the above-mentioned first feature, and normalize the amplitude feature, phase feature, spectrum distribution feature and energy feature in the above-mentioned second feature, respectively, to obtain the transmission amplitude correction coefficient, the reception amplitude correction coefficient, the transmission phase correction coefficient, the reception phase correction coefficient, the transmission spectrum correction coefficient and the reception spectrum correction coefficient. The amplitude normalization correction unit 4212 is configured to perform normalization correction on the amplitude of the acoustic logging data of each receiving component according to the transmission amplitude correction coefficient and the reception amplitude correction coefficient, and obtain the amplitude of the acoustic data of each component after normalization correction. The phase normalization correction unit 4213 is configured to perform normalization correction on the phase of the acoustic logging data of each receiving component according to the transmission phase correction coefficient and the reception phase correction coefficient, and obtain the phase or arrival time of the acoustic data of each component after normalization correction. The frequency normalization correction unit 4214 is configured to perform normalization correction on the frequency information of the acoustic logging data of each receiving component according to the transmission spectrum correction coefficient and the reception spectrum correction coefficient, using a preset normalization bandpass filter, to obtain the frequency information of the acoustic data of each component after normalization correction.

[0106] The amplitude normalization correction unit 4212, the phase normalization correction unit 4213 and the frequency normalization correction unit 4214 respectively use the following expressions to perform system normalization processing on the acoustic logging data of each component:

[0107] AMP=(AMP / NTA) / NRA

[0108] PHS=PHS+NTP+NRP

[0109] FRQ=FILTER1(FRQ,NTE,NRE)

[0110] Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, NTA represents the transmission amplitude correction coefficient, NRA represents the reception amplitude correction coefficient, PHS represents the phase or arrival time array of the acoustic logging data of each receiving component, NTP represents the transmission phase correction coefficient, NRP represents the reception phase correction coefficient, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NTE represents the transmission spectrum correction coefficient, NRE represents the reception spectrum correction coefficient, and FILTER1 represents the normalized bandpass filter.

[0111] Further, the borehole eccentricity correction parameter determination unit 4221 is configured to obtain the amplitude array, phase or arrival time array and frequency array of the acoustic logging data of each component after normalization correction, and based on this, respectively calculate the amplitude eccentricity correction parameter, phase eccentricity correction parameter and frequency eccentricity correction parameter. The amplitude data eccentricity correction unit 4222 is configured to perform borehole environment correction on the amplitude of the acoustic data of each component according to the amplitude array of the acoustic logging data of each component after normalization correction, using the amplitude eccentricity correction parameter and the preset first weighted correction coefficient, and obtain the acoustic amplitude data after the borehole environment correction for each component. The phase data eccentricity correction unit 4223 is configured to perform borehole environment correction on the phase or arrival time of the acoustic data of each component according to the phase or arrival time array of the acoustic logging data of each component after normalization correction, using the phase eccentricity correction parameter and the preset second weighted correction coefficient, and obtain the acoustic phase or arrival time data after the borehole environment correction for each component. The frequency data eccentricity correction unit 4224 is configured to perform borehole environment correction on the frequency information of the acoustic wave data of each component based on the spectrum information array of the acoustic wave logging data of each component after normalization correction, using the frequency eccentricity correction parameters and the preset third weighted correction coefficient, and adopting a preset borehole environment correction bandpass filter, so as to obtain the acoustic wave frequency data after the borehole environment correction for each component.

[0112] The amplitude data eccentricity correction unit 4222, the phase data eccentricity correction unit 4223 and the frequency data eccentricity correction unit 4224 respectively perform borehole environment correction processing on the acoustic logging data of each component using the following expressions:

[0113] AMP'=Ka*AMP / NA

[0114] PHS'=Kp+PHS+NP

[0115] FRQ'=FILTER2(FRQ,Kf(NE))

[0116] Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, PHS represents the phase or arrival time array of the acoustic logging data of each receiving component, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NA represents the amplitude eccentricity correction parameter, NP represents the phase eccentricity correction parameter, NE represents the frequency eccentricity correction parameter, FILTER2 represents the borehole environment correction bandpass filter, Ka, Kp, Kf represent the first weighted correction coefficient, the second weighted correction coefficient and the third weighted correction coefficient respectively, AMP' represents the acoustic amplitude array of each component after borehole correction, PHS' represents the acoustic phase or arrival time array of each component after borehole correction, and FRQ' represents the acoustic frequency information array of each component after borehole correction.

[0117] The present invention discloses a borehole correction method and system for multi-component acoustic logging data. The method and system centrally place the acoustic logging instrument in a cylinder or an anechoic water tank, and respectively perform calibration processing on the amplitude, phase, spectrum and energy of the sound transmitter and the receiving detector; the system normalization correction parameters of the transmitting sound source and the receiving detector are calculated according to the calibration values, and the real-time measured acoustic logging data are corrected using the current system normalization correction parameters; then the borehole eccentricity correction coefficient is extracted and calculated from the corrected acoustic data, and then the current borehole eccentricity correction coefficient is used to further perform borehole correction on the acoustic logging data. The borehole correction method described in the present invention can perform borehole adaptive correction on multi-component acoustic logging data, and the algorithm is simple, reliable, and easy to implement. It does not require the use of other construction measurement instruments, thereby reducing on-site construction volume and construction risks.

[0118] The above is only a preferred specific embodiment of the present invention, but the protection scope of the present invention is not limited thereto. Any changes or substitutions that can be easily thought of by any person familiar with the technology within the technical scope disclosed by the present invention should be included in the protection scope of the present invention. Therefore, the protection scope of the present invention should be based on the protection scope of the claims.

[0119] It should be understood that the embodiments disclosed in the present invention are not limited to the specific structures, processing steps or materials disclosed herein, but should be extended to equivalent substitutions of these features understood by ordinary technicians in the relevant field. It should also be understood that the terms used herein are only used for the purpose of describing specific embodiments and are not meant to be limiting.

[0120] The "one embodiment" or "embodiment" mentioned in the specification means that the specific features, structures or characteristics described in conjunction with the embodiment are included in at least one embodiment of the present invention. Therefore, the phrases "one embodiment" or "embodiment" appearing in various places throughout the specification do not necessarily refer to the same embodiment.

[0121] Although the embodiments disclosed in the present invention are as above, the contents described are only embodiments adopted for facilitating the understanding of the present invention and are not intended to limit the present invention. Any technician in the technical field to which the present invention belongs can make any modifications and changes in the form and details of the implementation without departing from the spirit and scope disclosed in the present invention, but the patent protection scope of the present invention shall still be subject to the scope defined in the attached claims.

Claims

1. A borehole correction method for multi-component acoustic logging data, characterized in that: include: Calibrate each transmitting sound source in the calibration sonic logging tool by aligning each transmitting sound source with a standard transmitting position, and record a first feature of each transmitting sound source; and calibrate each receiver by aligning each receiver with a standard receiving position, and record a second feature of each receiver, wherein the first feature and the second feature include amplitude, phase, spectrum distribution and energy; Normalizing each type of feature data in the first feature and the second feature, and based on this, performing a system normalization correction on the actual acoustic logging data of each component; According to the actual acoustic logging data of each component after normalization correction, the borehole eccentricity correction parameter of the current logging tool is calculated, and according to the borehole eccentricity correction parameter, the actual acoustic logging data of each component is subjected to borehole environment correction processing, which includes: Acquire the amplitude array, phase array and frequency array of each component of the normalized and corrected acoustic logging data, and based on them, respectively calculate the amplitude eccentricity correction parameter, the phase eccentricity correction parameter and the frequency eccentricity correction parameter; According to the amplitude array of the acoustic logging data of each component after normalization correction, the amplitude eccentricity correction parameter and the preset first weighted correction coefficient are used to perform wellbore environment correction on the amplitude data of the acoustic logging data of each component, so as to obtain acoustic amplitude data after wellbore environment correction for each component; According to the phase array of the acoustic logging data of each component after normalization correction, the phase eccentricity correction parameter and the preset second weighted correction coefficient are used to perform borehole environment correction on the phase data of the acoustic logging data of each component, so as to obtain the acoustic phase data after the borehole environment correction for each component; According to the spectrum information array of each component of the acoustic logging data after normalization correction, the frequency eccentricity correction parameter and the preset third weighted correction coefficient are used, and a preset borehole environment correction bandpass filter is adopted to perform borehole environment correction on the frequency information of the acoustic logging data of each component, and the acoustic frequency data after the borehole environment correction is obtained for each component, wherein, The following expression is used to perform borehole environment correction on the acoustic logging data of each component: AMP'=Ka*AMP / NA PHS'=Kp+PHS+NP FRQ'=FILTER2(FRQ,Kf(NE)) Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, PHS represents the phase array of the acoustic logging data of each receiving component, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NA represents the amplitude eccentricity correction parameter, NP represents the phase eccentricity correction parameter, NE represents the frequency eccentricity correction parameter, FILTER2 represents the borehole environment correction bandpass filter, Ka, Kp, Kf represent the first weighted correction coefficient, the second weighted correction coefficient and the third weighted correction coefficient respectively, AMP' represents the acoustic amplitude array of each component after borehole correction, PHS' represents the acoustic phase array of each component after borehole correction, and FRQ' represents the acoustic frequency information array of each component after borehole correction.

2. The wellbore correction method according to claim 1, characterized in that: The step of respectively normalizing each type of feature data in the first feature and the second feature includes: The amplitude characteristics, phase characteristics, spectrum distribution characteristics and energy characteristics in the first characteristics are normalized respectively, and the amplitude characteristics, phase characteristics, spectrum distribution characteristics and energy characteristics in the second characteristics are normalized respectively to obtain the transmission amplitude correction coefficient, the reception amplitude correction coefficient, the transmission phase correction coefficient, the reception phase correction coefficient, the transmission spectrum correction coefficient and the reception spectrum correction coefficient respectively.

3. The wellbore correction method according to claim 2, characterized in that: According to the transmission amplitude correction coefficient and the reception amplitude correction coefficient, the amplitude of the acoustic logging data of each receiving component is normalized and corrected to obtain the amplitude of the acoustic data of each component after normalization correction; According to the transmission phase correction coefficient and the reception phase correction coefficient, the phase of the acoustic logging data of each receiving component is normalized and corrected to obtain the phase of the acoustic data of each component after normalization and correction; According to the transmission spectrum correction coefficient and the reception spectrum correction coefficient, a preset normalized bandpass filter is used to perform normalization correction on the frequency information of the acoustic logging data of each receiving component to obtain the frequency information of the acoustic data of each component after normalization correction, wherein: The following expression is used to perform systematic normalization on the acoustic logging data of each component: AMP=(AMP / NTA) / NRA PHS=PHS+NTP+NRP FRQ=FILTER1(FRQ,NTE,NRE) Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, NTA represents the transmission amplitude correction coefficient, NRA represents the reception amplitude correction coefficient, PHS represents the phase array of the acoustic logging data of each receiving component, NTP represents the transmission phase correction coefficient, NRP represents the reception phase correction coefficient, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NTE represents the transmission spectrum correction coefficient, NRE represents the reception spectrum correction coefficient, and FILTER1 represents a normalized bandpass filter.

4. The wellbore correction method according to claim 2, characterized in that: Determine the maximum amplitude value of the emission source from the amplitude characteristic data of each emission sound source, divide the amplitude characteristic data of each emission sound source by the maximum amplitude value of the emission source, and obtain the emission amplitude correction coefficient; Determine the maximum amplitude value of the receiving end from the amplitude characteristic data of each receiver, divide the amplitude characteristic data of each receiver by the maximum amplitude value of the receiving end, and obtain the receiving amplitude correction coefficient; Determine the maximum phase value of the transmitting source from the phase characteristic data of each transmitting sound source, and perform subtraction operation on the maximum phase value of the transmitting source from the phase characteristic data of each transmitting sound source to obtain the transmitting phase correction coefficient; Determine the maximum phase value of the receiving end from the phase characteristic data of each receiver, and perform subtraction operation on the maximum phase value of the receiving end and the phase characteristic data of each receiver respectively to obtain the receiving phase correction coefficient; First, the main peak frequency and the product value of the proportion are determined from the energy characteristic data of each emission sound source, and the spectrum characteristic data of each emission sound source are multiplied by the energy characteristic data of the corresponding component to form corresponding emission characteristic data for each emission source, and finally the maximum emission characteristic data is screened out from the emission characteristic data of each emission source, and the amplitude characteristic data of each emission sound source is divided by the current maximum emission characteristic data to obtain the emission spectrum correction coefficient; First, the main peak frequency and the product value of the proportion are determined from the energy characteristic data of each receiver, and the spectrum characteristic data of each receiver is multiplied by the energy characteristic data of the corresponding component to form corresponding reception characteristic data for each receiver. Finally, the maximum reception characteristic data is screened out from the reception characteristic data of each receiver, and the amplitude characteristic data of each receiver is divided by the current maximum reception characteristic data to obtain the reception spectrum correction coefficient.

5. The wellbore correction method according to claim 1, characterized in that: According to the amplitude array corresponding to the acoustic logging data of each component after normalization correction, the maximum normalized amplitude data is extracted therefrom, and the normalized amplitude characteristic data of each component is divided by the maximum normalized amplitude data to obtain the amplitude eccentricity correction parameter; According to the phase array corresponding to the acoustic logging data of each component after normalization correction, the maximum normalized phase data is extracted therefrom, and the maximum normalized phase or arrival time data is respectively subtracted from the normalized phase characteristic data of each component to obtain the phase eccentricity correction parameter; First, according to the spectrum information array corresponding to the acoustic logging data of each component after normalization and correction, the main peak frequency and proportion product data are extracted therefrom, and then the specified passband spectrum information corresponding to the specified proportion in the spectrum information corresponding to the actual acoustic logging data of each component is determined, and finally, according to the main peak frequency and proportion product data and the specified passband spectrum information corresponding to each receiver, the normalized frequency characteristic data of each component is filtered based on the specified bandpass range to obtain the frequency eccentricity correction parameter.

6. The wellbore correction method according to any one of claims 1 to 5, characterized in that: The scaled sonic logging instrument uses a metal cylinder or a anechoic water tank, wherein the diameter of the cylinder is in the range of 200 to 400 mm, the outer shell of the cylinder is made of high-strength corrosion-resistant metal material, the inner wall of the cylinder is smooth and free of impurities, and the interior of the cylinder is filled with tap water and left to stand for more than one day.

7. A borehole correction system for multi-component acoustic logging data, characterized in that: The wellbore correction system is used to perform the wellbore correction method according to any one of claims 1 to 6, wherein the wellbore correction system comprises: A calibrated sonic logging instrument, which is used to calibrate each transmitting source in the instrument by aligning each transmitting sound source with a standard transmitting position, and to calibrate each receiver by aligning each receiver with a standard receiving position; A borehole correction device, which is used to record the first feature of each transmitting source when calibrating each transmitting source, and record the second feature of each receiver when calibrating each receiver, and then respectively normalize each type of feature data in the first feature and the second feature, based on which, perform system normalization correction on the actual acoustic logging data of each component, and calculate the borehole eccentricity correction parameters of the current logging instrument based on the actual acoustic logging data of each component after normalization correction, and perform borehole environment correction processing on the actual acoustic data of each component based on the borehole eccentricity correction parameters, wherein the first feature and the second feature include amplitude, phase, spectrum distribution and energy, The wellbore correction device further comprises a wellbore environment correction module, wherein the wellbore environment correction module comprises: A wellbore eccentricity correction parameter determination unit, configured to obtain the amplitude array, phase array and frequency array of the normalized and corrected acoustic logging data of each component, based on which, respectively calculate the amplitude eccentricity correction parameter, the phase eccentricity correction parameter and the frequency eccentricity correction parameter; An amplitude data eccentricity correction unit is configured to perform borehole environment correction on the amplitude data of the acoustic logging data of each component according to the amplitude array of the acoustic logging data of each component after normalization correction, using the amplitude eccentricity correction parameter and a preset first weighted correction coefficient, and obtain acoustic amplitude data after the borehole environment correction for each component; A phase data eccentricity correction unit, configured to perform borehole environment correction on the phase data of the acoustic logging data of each component according to the phase array of the acoustic logging data of each component after normalization correction, using the phase eccentricity correction parameter and a preset second weighted correction coefficient, and obtain acoustic phase data after the borehole environment correction for each component; The frequency data eccentricity correction unit is configured to perform borehole environment correction on the frequency information of the acoustic logging data of each component according to the spectrum information array of the acoustic logging data of each component after normalization correction, using the frequency eccentricity correction parameter and the preset third weighted correction coefficient, and adopting a preset borehole environment correction bandpass filter, so as to obtain the acoustic frequency data after the borehole environment correction for each component, wherein: The amplitude data eccentricity correction unit, the phase data eccentricity correction unit and the frequency data eccentricity correction unit respectively perform borehole environment correction processing on the acoustic logging data of each component using the following expressions: AMP'=Ka*AMP / NA PHS'=Kp+PHS+NP FRQ'=FILTER2(FRQ,Kf(NE)) Among them, AMP represents the amplitude array of the acoustic logging data of each receiving component, PHS represents the phase array of the acoustic logging data of each receiving component, FRQ represents the frequency information array of the acoustic logging data of each receiving component, NA represents the amplitude eccentricity correction parameter, NP represents the phase eccentricity correction parameter, NE represents the frequency eccentricity correction parameter, FILTER2 represents the borehole environment correction bandpass filter, Ka, Kp, Kf represent the first weighted correction coefficient, the second weighted correction coefficient and the third weighted correction coefficient respectively, AMP' represents the acoustic amplitude array of each component after borehole correction, PHS' represents the acoustic phase array of each component after borehole correction, and FRQ' represents the acoustic frequency information array of each component after borehole correction.

8. The system according to claim 7, characterized in that The wellbore correction device comprises a normalization correction module, wherein the normalization correction module has: A correction coefficient calculation unit is configured to normalize the amplitude characteristics, phase characteristics, spectrum distribution characteristics and energy characteristics in the first characteristic, and to normalize the amplitude characteristics, phase characteristics, spectrum distribution characteristics and energy characteristics in the second characteristic, and to obtain a transmitting amplitude correction coefficient, a receiving amplitude correction coefficient, a transmitting phase correction coefficient, a receiving phase correction coefficient, a transmitting spectrum correction coefficient and a receiving spectrum correction coefficient, respectively.

Images