CN112764094B - Inversion method and device for seismic time-frequency reflection coefficient - Google Patents
Inversion method and device for seismic time-frequency reflection coefficient Download PDFInfo
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Abstract
The invention provides a seismic time-frequency reflection coefficient inversion method and a device, wherein the method comprises the following steps: acquiring seismic data; the seismic data includes post-stack seismic data; extracting seismic wavelet data based on the seismic data; performing time-frequency decomposition on the post-stack seismic data based on generalized S transformation to obtain a time spectrum of the seismic record; performing time-frequency decomposition on the seismic wavelet data based on generalized S transformation to obtain a time spectrum of the seismic wavelet; and generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet. The invention can invert and obtain the seismic reflection coefficient of each simple harmonic frequency component, and provides a new way for the quantitative interpretation technology of the frequency-dependent seismic attribute.
Description
Technical Field
The invention relates to the technical field of geophysical exploration, in particular to a seismic time-frequency reflection coefficient inversion method and device.
Background
As seismic waves propagate in subsurface media, the velocity of longitudinal and transverse waves of seismic wave propagation varies with frequency due to the inhomogeneities of the media, known as the velocity dispersion effect (Aki & richard, 1980), and correspondingly the amplitude and phase of reflected seismic signals also vary with frequency, known as the frequency dependent reflection coefficient (Bourbie, 1984; hargreaves and Calvert, 1991). Velocity dispersion and attenuation phenomena of seismic waves have been demonstrated by petrophysical laboratory measurements, well site seismic data and theoretical model research effort (Biot, 1956; sams et al, 1997; pride et al, 2004; batzle et al, 2006; chapman et al, 2002; innanen,2011,2012; silin and Goloshubin, 2010), and are considered to be one of the important features of hydrocarbon reservoirs and widely used in hydrocarbon identification and quantitative prediction of fluid saturation (Chapman et al, 2006; odebeatu et al, 2006; ren et al, 2009; innanen,2011; liu et al, 2018).
The attenuation analysis of seismic signals or oil and gas identification using attenuation information and frequency-dependent AVO (Amplitude variation with offset, amplitude versus offset) response characteristics is typically accomplished by time-frequency analysis (also known as spectral decomposition) techniques (Castagna et al, 2003; li et al, 2006; wilson, 2009). Common time-frequency analysis techniques include Short-time Fourier transforms (Short-Time Fourier Transform, STFT), wavelet transforms (Wavelet Transform, WT), S-transforms (S-transforms, ST), generalized S-transforms (GST), and the like (Gabor, 2005; morlet,1982; stockwell et al, 1996; pinnegar and Mansinha, 2003). Castagna et al (2003) use a spectral decomposition method to identify frequency anomalies on a crossover attribute profile, and proposed to identify reservoirs using the "low frequency shadow" phenomenon below the reservoir. Li et al (2006) set up wavelet scale domain seismic wave energy attenuation formula from wavelet theory, extract wavelet scale attribute from seismic data to perform gas reservoir identification. Wilson et al (2009) established a dispersion AVO fluid identification method by mathematical derivation based on the AVO approximation formula. At present, the technologies play a positive role in the attenuation attribute extraction and oil gas detection of the seismic signals, and a good application effect is obtained.
Despite the high time and frequency resolution of time-frequency analysis techniques, their analysis methods are still based on spectral characteristics. When the stratum thickness is thinner, the frequency change caused by the interference effect of the seismic wavelets cannot be eliminated fundamentally, the time-frequency response characteristic at the moment is distorted, and the real stratum attenuation information cannot be reflected accurately, so that the method is only suitable for researching the characteristic that the frequency spectrum of a single reflection interface changes along with the frequency or wavelet scale. Meanwhile, the existing time-frequency spectrum analysis technology also has a wavelet overprinting effect, and although the effect can be alleviated to a certain extent by balancing the amplitude spectrum energy of different frequencies through a spectrum balancing method (Wilson, 2009), the widths of window functions or wavelet functions of different frequencies are different, the lower the frequency is, the larger the width is, so that the time-frequency resolution of a low-frequency end on a time-frequency spectrogram is lower than that of a high-frequency end, and the spectrum balancing method cannot thoroughly remove the influence of the width. Moreover, this analysis method is qualitative, neither the sign of the reflection coefficient can be determined, nor the interpretation of the reservoir thickness can be used, nor the change of the reflection coefficient and the elastic parameters (speed, modulus) of the reservoir with frequency can be truly described.
Disclosure of Invention
The invention provides a seismic time-frequency reflection coefficient inversion method and a seismic time-frequency reflection coefficient inversion device, which can provide reflection coefficients of various frequencies so as to improve the precision of predicting underground reservoir parameters and fluid distribution by using a frequency-dependent AVO (Amplitude variation with offset) analysis technology.
In a first aspect, an embodiment of the present invention provides a method for inversion of a time-frequency reflection coefficient of an earthquake, where the method includes: acquiring seismic data; the seismic data comprises post-stack seismic data; extracting seismic wavelet data based on the seismic data; performing time-frequency decomposition on the post-stack seismic data based on generalized S transformation to obtain a time spectrum of the seismic record; performing time-frequency decomposition on the seismic wavelet data based on generalized S transformation to obtain a time spectrum of the seismic wavelet; and generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet.
In a second aspect, an embodiment of the present invention further provides an apparatus for inversion of a time-frequency reflection coefficient of an earthquake, where the apparatus includes: the acquisition module is used for acquiring the seismic data; the seismic data comprises post-stack seismic data; the extraction module is used for extracting the seismic wavelet data based on the seismic data; the first time-frequency decomposition module is used for performing time-frequency decomposition on the post-stack seismic data based on generalized S transformation to obtain a time spectrum of the seismic record; the second time-frequency decomposition module is used for performing time-frequency decomposition on the seismic wavelet data based on generalized S transformation to obtain a time spectrum of the seismic wavelet; and the inversion module is used for generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet.
In a third aspect, an embodiment of the present invention further provides a computer device, including a memory, and a processor, where the memory stores a computer program that can run on the processor, and when the processor executes the computer program, the processor implements the method for inversion of the seismic time-frequency reflection coefficient.
In a fourth aspect, embodiments of the present invention also provide a computer readable medium having non-volatile program code executable by a processor, the program code causing the processor to perform the above-described seismic time-frequency reflection coefficient inversion method.
The embodiment of the invention has the following beneficial effects: the embodiment of the invention provides an inversion scheme of a time-frequency reflection coefficient of an earthquake, which comprises the steps of firstly, obtaining seismic data; the seismic data comprises post-stack seismic data, the seismic wavelet data is extracted based on the seismic data, then the post-stack seismic data is subjected to time-frequency decomposition based on generalized S transformation to obtain a time spectrum of the seismic record, the seismic wavelet data is subjected to time-frequency decomposition based on generalized S transformation to obtain a time spectrum of the seismic wavelet, so that the resolution and accuracy of the seismic wave dispersion attribute are improved, and finally the seismic time-frequency reflection coefficient is generated according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet. The embodiment of the invention can invert to obtain the seismic reflection coefficient of each simple harmonic frequency component, and provides a new way for quantitative interpretation technology of frequency-dependent seismic attributes.
Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
In order to make the above objects, features and advantages of the present invention more comprehensible, preferred embodiments accompanied with figures are described in detail below.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings that are needed in the description of the embodiments or the prior art will be briefly described, and it is obvious that the drawings in the description below are some embodiments of the present invention, and other drawings can be obtained according to the drawings without inventive effort for a person skilled in the art.
FIG. 1 is a flowchart of an inversion method of the reflection coefficient of the earthquake time frequency provided by the embodiment of the invention;
FIG. 2 is a schematic diagram of an implementation flow of an inversion method of the reflection coefficient of the time-frequency of the earthquake according to the embodiment of the invention;
FIG. 3 is a schematic diagram of a three-layer theoretical seismic record provided by an embodiment of the invention;
FIG. 4 is a schematic diagram of a time-frequency spectrum analysis based on generalized S-transform according to an embodiment of the present invention;
FIG. 5 is a schematic diagram of a reflection coefficient frequency trace set according to an embodiment of the present invention;
FIG. 6 is a graph showing Amplitude Versus Frequency (AVF) at a reflective layer according to an embodiment of the present invention;
FIG. 7 is a schematic diagram of a post-stack seismic profile of a regional two-dimensional survey line GA47 provided in an embodiment of the invention;
FIG. 8 is a schematic diagram of an inverted frequency trace of the reflection coefficient of GA47 on a two-dimensional line of GA2 well in a certain region according to an embodiment of the present invention;
FIG. 9 is a graph of AVF intersection at a well bypass gas layer and a non-gas layer provided by an embodiment of the present invention;
FIG. 10 is a block diagram of a seismic time-frequency reflection coefficient inversion apparatus according to an embodiment of the present invention;
FIG. 11 is a block diagram of another seismic time-frequency reflection coefficient inversion apparatus according to an embodiment of the present invention;
FIG. 12 is a block diagram of another seismic time-frequency reflection coefficient inversion apparatus according to an embodiment of the present invention;
fig. 13 is a block diagram of a computer device according to an embodiment of the present invention.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
At present, the existing frequency-varying amplitude analysis technology is based on a time-frequency spectrum decomposition method, and can obtain an amplitude spectrum with relatively high resolution, but the resolution and accuracy of the extracted seismic wave dispersion attribute are still not high and only can qualitatively indicate fluid under the influence of wavelet superposition and thin-layer interference effects. The method is characterized in that the amplitude spectrum can not quantitatively represent the change condition of the reflection coefficient of the seismic signal at a certain moment along with the frequency, and can not provide the reflection coefficient sequence of each frequency for the reservoir parameter inversion of the reservoir prediction stage, so that the development of the frequency-dependent AVO quantitative seismic interpretation technology is restricted.
Based on the above, the method and the device for inversion of the time-frequency reflection coefficient of the earthquake provided by the embodiment of the invention respectively perform time-frequency analysis on the post-stack reflection earthquake record and the earthquake wavelet based on generalized S transformation to obtain the spectrum information of the earthquake record and the earthquake wavelet; and secondly, inverting the seismic reflection coefficient sequences of all frequency components by utilizing the frequency division inversion algorithm to form a frequency gather section with the reflection coefficient changing along with the frequency, so that the analysis of the seismic amplitude changing along with the frequency is truly realized on the basis, and a new way is provided for the quantitative interpretation technology of the frequency-dependent seismic attribute. The embodiment of the invention can improve the precision of predicting the underground reservoir parameters and fluid distribution by the frequency-dependent seismic attribute analysis technology.
For the convenience of understanding the present embodiment, the embodiment of the present invention discloses a seismic time-frequency reflection coefficient inversion method.
The embodiment of the invention provides a seismic time-frequency reflection coefficient inversion method, which is shown in a flow chart of the seismic time-frequency reflection coefficient inversion method in FIG. 1, and comprises the following steps:
step S102, obtaining seismic data.
In an embodiment of the invention, the seismic data comprises post-stack seismic data.
Step S104, extracting the seismic wavelet data based on the seismic data.
In embodiments of the present invention, seismic wavelet data may be extracted from collected seismic data.
And step S106, performing time-frequency decomposition on the post-stack seismic data based on generalized S transformation to obtain a time spectrum of the seismic record. The time spectrum of the seismic record comprises a plurality of moments and seismic record information corresponding to a plurality of frequencies.
In the embodiment of the invention, time-frequency decomposition is performed on post-stack reflection seismic records to obtain a time spectrum of the seismic records, which can be denoted as S (t, f).
Step S108, performing time-frequency decomposition on the seismic wavelet data based on generalized S transformation to obtain a time spectrum of the seismic wavelet. Wherein the time spectrum of the seismic wavelet comprises seismic wavelet information corresponding to a plurality of moments and a plurality of frequencies.
In the embodiment of the invention, the time-frequency decomposition is performed on the seismic wavelet data to obtain the time frequency spectrums of the seismic wavelets with different frequency components, which can be marked as W (t, f).
Step S110, generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet.
In the embodiment of the invention, after the time spectrum of the seismic record and the time spectrum of the seismic wavelet are obtained, the seismic time-frequency reflection coefficient can be obtained by inversion according to the correlation between the time spectrum and the time spectrum of the seismic wavelet. The seismic time-frequency reflection coefficient can represent the corresponding seismic reflectivity information at different moments, wherein the seismic reflectivity information is a complex signal and can be represented in a complex form.
The embodiment of the invention provides an inversion scheme of a time-frequency reflection coefficient of an earthquake, which comprises the steps of firstly, obtaining seismic data; the seismic data comprises post-stack seismic data, the seismic wavelet data is extracted based on the seismic data, then the post-stack seismic data is subjected to time-frequency decomposition based on generalized S transformation to obtain a time spectrum of the seismic record, the seismic wavelet data is subjected to time-frequency decomposition based on generalized S transformation to obtain a time spectrum of the seismic wavelet, so that the resolution and accuracy of the seismic wave dispersion attribute are improved, and finally the seismic time-frequency reflection coefficient is generated according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet. The embodiment of the invention can invert to obtain the seismic reflection coefficient sequence of each frequency component, and provides a new way for quantitative interpretation technology of frequency-dependent seismic attributes.
Considering that to provide a sequence of reflection coefficients for each frequency for the inversion of reservoir parameters at the reservoir prediction stage, generating the seismic time-frequency reflection coefficients from the time spectrum of the seismic record and the time spectrum of the seismic wavelet may be performed as follows:
determining a time-frequency reflection coefficient inversion formula according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet; and generating the seismic time-frequency reflection coefficient according to a time-frequency reflection coefficient inversion formula.
In the embodiment of the invention, the time-frequency reflection coefficient inversion formula is used for expressing the relation between the time spectrum of the seismic record, the time spectrum of the seismic wavelet and the seismic reflectivities of different frequency components, and the seismic reflectivities are respectively inverted for different frequencies according to the time-frequency reflection coefficient inversion formula, so that the seismic time-frequency reflection coefficient can be obtained.
In order to obtain a more accurate relationship between the time spectrum of the seismic record and the time spectrum of the seismic wavelet, determining a time-frequency reflection coefficient inversion formula according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet may be performed as follows:
the inverse formula of the time-frequency reflection coefficient is determined as follows: s (f) j )＝W(f j )ER(f j ) The method comprises the steps of carrying out a first treatment on the surface of the Wherein S (f j ) For frequency f in the seismic time spectrum j (j=1, …, N) single-frequency simple harmonic component complex signal, W (f) j ) For corresponding to frequency f in wavelet time spectrum j The complex matrix of wavelet simple harmonic components constructed by single-frequency simple harmonic component complex signals is E which is a complex matrix formed by elements exp (-i 2 pi f) 0 j delta) diagonal complex matrix, R (f) j ) At a frequency f j The simple harmonic component reflection coefficient sequence of (1), N is the number of sample points, delta is the time sampling rate,
in the embodiment of the invention, the correlation between the time spectrum of the seismic wavelet, the seismic reflectivity and the time spectrum of the seismic record is established by constructing the diagonal matrix E,and obtaining a time-frequency reflection coefficient inversion formula. For each selected frequency f 0 Can obtain the seismic reflectivity and wavelet matrix W F And seismic record vector S j Relationship between them.
Considering that the time-frequency reflection coefficient of the earthquake is generated according to the inversion formula of the time-frequency reflection coefficient in order to improve the accuracy of the obtained time-frequency reflection coefficient of the earthquake, the method can be implemented as follows:
and solving a time-frequency reflection coefficient inversion formula according to an L1-L2 mixed norm inversion method to generate a seismic time-frequency reflection coefficient.
In the embodiment of the invention, in the process of solving the time-frequency reflection coefficient inversion formula according to the L1-L2 mixed norm inversion method, a compressed sensing sparsification processing method can be used to obtain the time-frequency reflection coefficient of the earthquake.
To improve accuracy in acquiring seismic wavelet data, extracting seismic wavelet data based on the seismic data may be performed as follows:
acquiring logging data and parawell seismic record data; extracting first seismic wavelet data based on the seismic data; generating first seismic record data according to the logging data and the first seismic wavelet data; and if the first seismic record data is the same as the well side seismic record data or the difference value is in a preset range, taking the first seismic wavelet data as the seismic wavelet data.
In an embodiment of the invention, the logging data includes logging longitudinal wave velocity V p And parameters such as density rho, and the like, and the well side seismic record data can be obtained by manual measurement in advance. The borehole seismic record data may be in the form of images. And taking the seismic wavelet data which is preliminarily extracted from the seismic data as first seismic wavelet data, and synthesizing first seismic record data according to the first seismic wavelet data and logging data, wherein the first seismic record data can be in an image form. If the first seismic record data and the images of the well side seismic record data are overlapped, the first seismic record data and the images of the well side seismic record data are considered to be identical, and if the difference value of the first seismic record data and the images of the well side seismic record data is within a preset range, the first seismic wavelet data are used as seismic wavelet data. The position deviation condition of a plurality of key points in the two images can be obtainedThe difference between the two.
In view of the fact that the analysis of the seismic amplitude with frequency is actually carried out, the method may further comprise the steps of:
and generating a first intersection graph according to the seismic time-frequency reflection coefficient so as to obtain a seismic prediction result according to the first intersection graph.
In the embodiment of the invention, a first intersection graph can be constructed according to the characteristic that the time-frequency reflection coefficient of the earthquake changes along with the frequency, the first intersection graph can be an AVF (Amplitude Versus Frequency) intersection graph with amplitude changing along with the frequency, and the obtained first intersection graph can be used for generating an earthquake prediction result.
In view of the fact that the analysis of the seismic amplitude with frequency is actually carried out, the method may further comprise the steps of:
generating frequency gather data according to the earthquake time-frequency reflection coefficient; determining a reflection coefficient and a gradient value of the zero frequency according to the frequency gather data; and generating a second intersection graph according to the reflection coefficient of the zero frequency and the gradient value, so as to obtain a seismic prediction result according to the second intersection graph.
According to the embodiment of the invention, frequency gather data can be obtained according to the combination of the time-frequency reflection coefficient and sampling rate information of the earthquake, furthermore, the reflection coefficient and gradient value of zero frequency can be extracted based on a least square inversion algorithm according to the frequency gather data, and an intersection graph is manufactured according to the reflection coefficient and gradient attribute of the zero frequency, and further, the method can be used for analyzing and evaluating the gas-containing property and attenuation characteristic of a reservoir to obtain an earthquake prediction result.
In order to improve the accuracy of the reflection coefficient and the gradient value of the zero frequency, the determination of the reflection coefficient and the gradient value of the zero frequency from the frequency gather data may be performed as follows:
the reflection coefficient and gradient value for the zero frequency are determined according to the following formula: r (f) =a+gf 1/2 Wherein R (f) is the frequency division reflectivity in the frequency gather data, f is the frequency, A is the intercept, and G is the gradient.
In the embodiment of the present invention, after obtaining the information of multiple groups of frequencies and frequency division reflectivities, the method can be used for obtaining the information of multiple groups of frequencies and frequency division reflectivities according to the formula R (f) =a+gf 1/2 The reflection coefficient and gradient value of the zero frequency are determined. Thus, after the frequency value is given, the corresponding divided reflectance can be obtained according to the formula, and the reflectance of the zero frequency refers to the value of the divided reflectance when the frequency value is 0.
The embodiment of the invention provides an inversion method of a time-frequency reflection coefficient of an earthquake, which is shown in a schematic diagram of an execution flow of the inversion method of a frequency division reflection coefficient shown in fig. 2, wherein the method comprises the steps of collecting post-stack earthquake data and logging data in a work area, and determining inverted earthquake wavelets after calibrating earthquake and logging layers; the second step is to perform generalized S transformation on the post-stack seismic data and the seismic wavelets respectively to obtain a seismic time spectrum and a wavelet time spectrum; thirdly, constructing a reflection coefficient inversion matrix equation of a specific frequency by using the method; inverting the frequency division reflection coefficient by using a high-resolution seismic inversion algorithm to form a reflection coefficient frequency gather; finally, the cross-plot technique is utilized to realize the analysis of amplitude along with frequency.
The method is characterized in that time-frequency analysis is respectively carried out on post-stack reflection seismic records and seismic wavelets based on generalized S transformation to obtain spectrum information of the seismic records and the seismic wavelets; and secondly, inverting the seismic reflection coefficient sequences of all frequency components by utilizing the frequency division inversion algorithm to form a frequency gather section with the reflection coefficient changing along with the frequency, truly realizing analysis of the seismic amplitude changing along with the frequency on the basis, providing a new way for the quantitative interpretation technology of the frequency-dependent seismic attribute, and further being used for improving the precision of predicting the underground reservoir parameters and the fluid distribution by the analysis technology of the frequency-dependent seismic attribute.
According to the method, amplitude information of post-stack reflection seismic records and seismic wavelets in different frequency components is obtained through generalized S transformation, so that a seismic reflection coefficient sequence of each frequency component is inverted, a 'frequency gather' section with the reflection coefficient changing along with the frequency is formed, the problem that the resolution and accuracy of the extracted seismic wave dispersion attribute are not high due to the influence of wavelet superposition and thin-layer interference effects in a conventional time-frequency analysis technology is solved, and the problem that the amplitude spectrum energy of a seismic signal can only be qualitatively described along with the frequency in the conventional attenuation analysis technology, but the reflection coefficient of the seismic signal at a certain moment cannot be quantitatively represented along with the frequency is solved.
According to the seismic time-frequency reflection coefficient inversion method, the AVF intersection graph is manufactured on the obtained frequency gather data, so that the instantaneous characteristics of the seismic amplitude along with the frequency change are more conveniently analyzed, the attenuation change details of the gas-containing stratum on the seismic waves are captured, the AVF response characteristics of different types of gas reservoirs are summarized, and quantitative seismic prediction of the gas-containing property of the stratum by using the frequency-change amplitude response theory is realized.
Fig. 3-6 are theoretical model fractional reflectivity inversion effect analyses.
See the three-layer theoretical seismic record schematic shown in fig. 3. Layer 1 is an elastic medium case where the reflection coefficient does not vary with frequency, R (f) =0.1. Layer 2 is a viscoelastic case where the reflection coefficient decreases with increasing frequency, the relationship between the reflection coefficient and frequency being R (f) = -0.1exp (-0.013 f); layer 3 is a viscoelastic case where the reflection coefficient increases with increasing frequency, and the relation between the reflection coefficient and frequency is R (f) =0.1 [1.0-exp (-0.013 f) ]. It can be seen that although the maximum reflectance absolute value of each layer is 0.1, the amplitude is not the same on the seismic record due to their varying characteristics with frequency.
See the schematic of the generalized S transform based time-spectral analysis shown in fig. 4. Since the reflection coefficient of each layer varies with frequency, the maximum reflection amplitude energy is different for each layer and the peak frequency is different, although their maximum reflection coefficients are the same. On the right side of the peak frequency of each reflective layer, its amplitude spectrum decreases with increasing frequency; on the left side of the peak frequency, the amplitude spectrum increases with the increase of the frequency, and the characteristic of the change of the reflection coefficient with the frequency cannot be distinguished from the time-frequency analysis spectrum. Therefore, the spectral analysis of the characteristic of the variation of reflected amplitude with frequency is unreliable when used alone, due to the presence of the "wavelet imprinting" effect, and the wavelet spectral energy at each frequency is different
See the reflection coefficient frequency trace diagram shown in fig. 5. Clearly, the characteristics of the reflection coefficient of each reflection layer obtained by inversion along with the change of frequency are consistent with the theoretical model.
See AVF intersection at the reflective layer shown in fig. 6. The scattered points of the geometric figure in the figure are the amplitudes of the respective reflection layers picked up from fig. 5, and the three lines are the reflection coefficient changes with frequency given in the theoretical model. It can be seen that: the inversion result is consistent with the theoretical value, truly reflects the characteristic that the reflection coefficient changes along with the frequency, and shows that the inversion method is accurate and reliable.
Fig. 7-9 are analysis of the effects of frequency division reflectivity inversion of seismic data after two-dimensional survey lines in a region are stacked.
Referring to FIG. 7, a post-stack seismic profile of a regional two-dimensional survey line GA47 is shown. A exploratory well Guangan 2 well is drilled on the survey line, and is an industrial gas well, and a main gas layer is positioned in a TX6 group of the river of the must family. The middle plot in the figure shows the poisson's ratio for wells, which is shown to be low for TX6 gas bearing layers.
Referring to the graph of the inversion of the two-dimensional line GA47 reflection coefficient frequency trace of the GA2 well in a certain region shown in FIG. 8, it is obvious that the reflection coefficient near the GAs layer has the phenomenon of increasing with the increase of frequency, and the increase amplitude is obviously different from that of the upper and lower non-GAs layers.
See the AVF intersection graph at the well bypass gas and non-gas layers shown in fig. 9. The square scatter points in the figure represent the reflection amplitude for each frequency at t=853 ms from the top of the gas reservoir picked up in fig. 8, and the diamond scatter points represent the reflection amplitude for each frequency at t=815 ms from the bottom of a set of mudstones above the gas layer picked up in fig. 8. It can be seen that: the rise amplitude of AVF after reservoir gas is much greater than that of non-gas layer, indicating that gas reservoirs can be well identified with AVF.
According to the method for inverting the time-frequency reflection coefficient of the earthquake from the earthquake signal, firstly, the earthquake and the logging horizon in a work area are calibrated, and inverted earthquake wavelets are determined; then, performing generalized S transformation on the post-stack seismic data and the seismic wavelets respectively to obtain a time spectrum of the seismic record and a time spectrum of the wavelets; then constructing a reflection coefficient inversion matrix equation of each specific frequency by using the method; then inverting the frequency division reflection coefficient by using a high-resolution seismic inversion algorithm to form a reflection coefficient frequency gather; finally, the cross-plot technique is utilized to realize the analysis of amplitude along with frequency. The key technology is the establishment of a frequency-dependent reflection coefficient inversion matrix equation and a high-precision seismic reflectivity inversion algorithm.
The embodiment of the invention also provides a device for inverting the time-frequency reflection coefficient of the earthquake, referring to the structural block diagram of the device for inverting the time-frequency reflection coefficient of the earthquake shown in fig. 10, the device comprises:
an acquisition module 71 for acquiring seismic data; the seismic data includes post-stack seismic data; an extraction module 72 for extracting seismic wavelet data based on seismic data; a first time-frequency decomposition module 73, configured to perform time-frequency decomposition on the post-stack seismic data based on generalized S transform, so as to obtain a time spectrum of the seismic record; a second time-frequency decomposition module 74, configured to perform time-frequency decomposition on the seismic wavelet data based on generalized S transform, so as to obtain a time spectrum of the seismic wavelet; an inversion module 75 for generating a seismic time-frequency reflection coefficient from the time spectrum of the seismic record and the time spectrum of the seismic wavelet.
In one embodiment, the inversion module is specifically configured to: determining a time-frequency reflection coefficient inversion formula according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet; and generating the seismic time-frequency reflection coefficient according to a time-frequency reflection coefficient inversion formula.
In one embodiment, the inversion module is specifically configured to: the inverse formula of the time-frequency reflection coefficient is determined as follows: s (f) j )＝W(f j )ER(f j ) The method comprises the steps of carrying out a first treatment on the surface of the Wherein S (f j ) For frequency f in the seismic time spectrum j (j=1, …, N) single-frequency simple harmonic component complex signal, W (f) j ) For corresponding to frequency f in wavelet time spectrum j The complex matrix of wavelet simple harmonic components constructed by single-frequency simple harmonic component complex signals is E which is a complex matrix formed by elements exp (-i 2 pi f) 0 j delta) diagonal complex matrix, R (f) j ) At a frequency f j The simple harmonic component reflection coefficient sequence of (1), N is the number of sample points, delta is the time sampling rate, i is the imaginary number, namely
In one embodiment, the inversion module is specifically configured to: and solving a time-frequency reflection coefficient inversion formula according to an L1-L2 mixed norm inversion method to generate a seismic time-frequency reflection coefficient.
In one embodiment, the extraction module is specifically configured to: acquiring logging data and parawell seismic record data; extracting first seismic wavelet data based on the seismic data; generating first seismic record data according to the logging data and the first seismic wavelet data; and if the first seismic record data is the same as the well side seismic record data or the difference value is in a preset range, taking the first seismic wavelet data as the seismic wavelet data.
In one embodiment, referring to another block diagram of an apparatus for inversion of seismic time-frequency reflection coefficients shown in fig. 11, the apparatus further comprises: a first cross-map module 76 for: and generating a first intersection graph according to the seismic time-frequency reflection coefficient so as to obtain a seismic prediction result according to the first intersection graph.
In one embodiment, referring to another block diagram of an apparatus for inversion of seismic time-frequency reflection coefficients shown in fig. 12, the apparatus further comprises: a second intersection module 77 for: generating frequency gather data according to the earthquake time-frequency reflection coefficient; determining a reflection coefficient and a gradient value of the zero frequency according to the frequency gather data; and generating a second intersection graph according to the reflection coefficient of the zero frequency and the gradient value, so as to obtain a seismic prediction result according to the second intersection graph.
In one embodiment, the second intersection map module 77 is specifically configured to: the reflection coefficient and gradient value for the zero frequency are determined according to the following formula: r (f) =a+gf 1/2 Wherein R (f) is the frequency division reflectivity in the frequency gather data, f is the frequency, A is the intercept, and G is the gradient.
The embodiment of the present invention further provides a computer device, referring to a schematic block diagram of a computer device structure shown in fig. 13, where the computer device includes a memory 81 and a processor 82, and the memory stores a computer program that can be run on the processor, and when the processor executes the computer program, the processor implements steps of any of the methods described above.
It will be clear to those skilled in the art that, for convenience and brevity of description, specific working procedures of the above-described computer device may refer to corresponding procedures in the foregoing method embodiments, which are not repeated here
Embodiments of the present invention also provide a computer readable medium having non-volatile program code executable by a processor, the program code causing the processor to perform the steps of any of the methods described above.
It will be appreciated by those skilled in the art that embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
Finally, it should be noted that: the above examples are only specific embodiments of the present invention, and are not intended to limit the scope of the present invention, but it should be understood by those skilled in the art that the present invention is not limited thereto, and that the present invention is described in detail with reference to the foregoing examples: any person skilled in the art may modify or easily conceive of the technical solution described in the foregoing embodiments, or perform equivalent substitution of some of the technical features, while remaining within the technical scope of the present disclosure; such modifications, changes or substitutions do not depart from the spirit and scope of the technical solutions of the embodiments of the present invention, and are intended to be included in the scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.
Claims (10)
1. The seismic time-frequency reflection coefficient inversion method is characterized by comprising the following steps of:
acquiring seismic data; the seismic data comprises post-stack seismic data;
extracting seismic wavelet data based on the seismic data;
performing time-frequency decomposition on the post-stack seismic data based on generalized S transformation to obtain a time spectrum of the seismic record;
performing time-frequency decomposition on the seismic wavelet data based on generalized S transformation to obtain a time spectrum of the seismic wavelet;
generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet;
wherein generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet comprises:
determining a time-frequency reflection coefficient inversion formula according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet;
generating a seismic time-frequency reflection coefficient according to the time-frequency reflection coefficient inversion formula;
the method for determining the time-frequency reflection coefficient inversion formula according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet comprises the following steps:
the inverse formula of the time-frequency reflection coefficient is determined as follows:；
wherein ,for the corresponding frequency +.>Is a single-frequency simple harmonic component complex signal,for the corresponding frequency +.>The wavelet simple harmonic component complex matrix constructed by the single-frequency simple harmonic component complex signal, E is a component +.>Diagonal complex matrix of components->For frequency->The simple harmonic component reflection coefficient sequence of (2), N is the number of sampling points, < >>In order to be able to sample the rate in time,iis imaginary, i.e.)>；
The generating the seismic time-frequency reflection coefficient according to the time-frequency reflection coefficient inversion formula comprises the following steps:
and solving the time-frequency reflection coefficient inversion formula according to an L1-L2 mixed norm inversion method to generate the seismic time-frequency reflection coefficient.
2. The method of seismic time-frequency reflection coefficient inversion of claim 1, wherein extracting seismic wavelet data based on the seismic data comprises:
acquiring logging data and parawell seismic record data;
extracting first seismic wavelet data based on the seismic data;
generating first seismic record data according to the logging data and the first seismic wavelet data;
and if the first seismic record data is the same as or different from the side-well seismic record data in a preset range, taking the first seismic wavelet data as seismic wavelet data.
3. The seismic time-frequency reflection coefficient inversion method according to claim 1 or 2, characterized by further comprising:
and generating a first intersection graph according to the seismic time-frequency reflection coefficient so as to obtain a seismic prediction result according to the first intersection graph.
4. The seismic time-frequency reflection coefficient inversion method according to claim 1 or 2, characterized by further comprising:
generating frequency gather data according to the seismic time-frequency reflection coefficient;
determining a reflection coefficient and a gradient value of zero frequency according to the frequency gather data;
and generating a second intersection graph according to the reflection coefficient of the zero frequency and the gradient value, so as to obtain a seismic prediction result according to the second intersection graph.
5. The method of seismic time-frequency reflection coefficient inversion of claim 4, wherein determining reflection coefficients and gradient values for zero frequency from said frequency gather data comprises:
the reflection coefficient and gradient value for the zero frequency are determined according to the following formula:，
wherein ,for the divided reflectivity in the frequency gather data,ffrequency, A is the intercept and G is the gradient.
6. An earthquake time-frequency reflection coefficient inversion device, which is characterized by comprising:
the acquisition module is used for acquiring the seismic data; the seismic data comprises post-stack seismic data;
the extraction module is used for extracting the seismic wavelet data based on the seismic data;
the first time-frequency decomposition module is used for performing time-frequency decomposition on the post-stack seismic data based on generalized S transformation to obtain a time spectrum of the seismic record;
the second time-frequency decomposition module is used for performing time-frequency decomposition on the seismic wavelet data based on generalized S transformation to obtain a time spectrum of the seismic wavelet;
the inversion module is used for generating a seismic time-frequency reflection coefficient according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet;
the inversion module is specifically configured to: determining a time-frequency reflection coefficient inversion formula according to the time spectrum of the seismic record and the time spectrum of the seismic wavelet; generating a seismic time-frequency reflection coefficient according to the time-frequency reflection coefficient inversion formula;
the inversion module is specifically configured to: the inverse formula of the time-frequency reflection coefficient is determined as follows:；
wherein ,for the corresponding frequency +.>Is a single-frequency simple harmonic component complex signal,for the corresponding frequency +.>The wavelet simple harmonic component complex matrix constructed by the single-frequency simple harmonic component complex signal, E is a component +.>Diagonal complex matrix of components->For frequency->The simple harmonic component reflection coefficient sequence of (2), N is the number of sampling points, < >>In order to be able to sample the rate in time,iis imaginary, i.e.)>；
The inversion module is specifically configured to: and solving the time-frequency reflection coefficient inversion formula according to an L1-L2 mixed norm inversion method to generate the seismic time-frequency reflection coefficient.
7. The seismic time-frequency reflection coefficient inversion apparatus of claim 6, further comprising: a first cross-map module for:
and generating a first intersection graph according to the seismic time-frequency reflection coefficient so as to obtain a seismic prediction result according to the first intersection graph.
8. The seismic time-frequency reflection coefficient inversion apparatus of claim 6, further comprising: a second intersection module for:
generating frequency gather data according to the seismic time-frequency reflection coefficient;
determining a reflection coefficient and a gradient value of zero frequency according to the frequency gather data;
and generating a second intersection graph according to the reflection coefficient of the zero frequency and the gradient value, so as to obtain a seismic prediction result according to the second intersection graph.
9. A computer device comprising a memory, a processor, the memory having stored therein a computer program executable on the processor, characterized in that the processor, when executing the computer program, implements the steps of the method of any of the preceding claims 1 to 5.
10. A computer readable medium having non-volatile program code executable by a processor, the program code causing the processor to perform the method of any one of the preceding claims 1 to 5.
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