A method, device, equipment and storage medium for obtaining fast and slow shear wave slowness

Abstract

The present application discloses a method, device, equipment and storage medium for obtaining the slowness of fast and slow shear waves, and belongs to the field of applied geophysical logging technology. The method includes: performing time scanning on the acoustic waveform data of any formation depth to obtain a two-dimensional correlation diagram of the waveform at different times and slownesses; dividing the recording time into time domain α and time domain β; performing slowness projection on time domain α to obtain the correlation coefficient of the fast shear wave slowness in time domain α; performing slowness projection on time domain β to obtain the correlation coefficient of the slow shear wave slowness in time domain β; repeating the above steps, traversing the acoustic waveform data of different formation depths, and obtaining the correlation coefficient of the fast and slow shear wave slowness at different formation depths; respectively extracting the maximum values ​​of the correlation coefficient of the fast and slow shear wave slowness at different formation depths, and obtaining the slowness of the fast and slow shear waves at different formation depths. The present application can finely characterize the differences and anisotropic characteristics of fast and slow shear waves in the time domain, and make richer processing and interpretation of logging data.

Description

Technical Field

[0001] The present application relates to the field of applied geophysical logging technology, and in particular to a method, device, equipment and storage medium for obtaining fast and slow shear wave slowness. Background Art

[0002] Acoustic logging is one of the important methods in the field of geophysical exploration, and it plays an important role in oil exploration, reserve evaluation, and oil and gas production. With the development of information technology and acoustic wave theory, acoustic logging instruments are developing in the direction of digitalization, full wave train, and array. The acoustic waveform data recorded by acoustic logging include longitudinal waves (P waves), fast shear waves (fast S waves), slow shear waves (slow S waves), and Stoneley waves. Because the acoustic wave velocity of the formation and the attenuation of the formation acoustic wave are closely related to the properties of the rock and the fluid in the rock pores, the use of acoustic logging technology to collect formation information can extract the formation longitudinal and shear wave information and provide data for obtaining the shear wave slowness.

[0003] Current research only uses acoustic logging data to calculate the magnitude of formation stress, identify the direction of principal stress, and analyze stress distribution. However, there are few studies on the impact of formation stress on full-wave acoustic logging. In actual acoustic logging operations, the formation stress generated by rock coverage or compression in different directions in a certain area of ​​the formation near the well will affect the logging acoustic waves. These abnormal formation stresses will have a significant impact on the sound velocity and sound pressure of the elastic waves generated by the array acoustic logging instrument, thereby affecting the reservoir evaluation. Therefore, the study of the laws of the impact of formation stress on acoustic waves is particularly important. Combining the research on acoustic logging and formation stress, we can understand the characteristics of the borehole acoustic wave response under the action of borehole stress from more perspectives, and make richer processing and interpretation of logging data. Therefore, seeking an economical and effective method to obtain the slowness of monopolar fast and slow shear waves in stress-inhomogeneous reservoirs has become an urgent problem to be solved. Summary of the invention

[0004] In view of this, the main purpose of this application is to study the characteristics of borehole acoustic wave response under stress, so as to obtain the slowness of monopolar fast and slow shear waves in stress-inhomogeneous reservoirs. This method can accurately characterize the differences and anisotropic characteristics of fast and slow shear waves in the time domain. Fast and slow shear waves can be used to study the influence of geostress on acoustic logging. The characteristics of borehole acoustic wave response under non-uniform geostress conditions are studied by processing actual data. It helps to understand the characteristics of borehole acoustic wave response under the action of borehole stress from more perspectives, make richer processing and interpretation of logging data, and improve reservoir evaluation.

[0005] To achieve the above object, the present application provides a method for obtaining fast and slow shear wave slowness, which is applied to stress inhomogeneous reservoirs and includes:

[0006] Step 1: Perform time scanning on the acoustic waveform data at any formation depth to obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses;

[0007] Step 2: Divide the recording time into time domain α and time domain β;

[0008] Step 3, performing slowness projection on the time domain α to obtain the slowness correlation coefficient in the time domain α, which is the fast shear wave slowness correlation coefficient; performing slowness projection on the time domain β to obtain the slowness correlation coefficient in the time domain β, which is the slow shear wave slowness correlation coefficient;

[0009] Step 4: Repeat steps 1 to 3, traverse the acoustic waveform data of different formation depths, and obtain the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient of different formation depths;

[0010] Step 5: respectively extracting the maximum values ​​of the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient at different formation depths to obtain the fast shear wave slowness and the slow shear wave slowness at different formation depths.

[0011] Preferably, the step 1: performing time scanning on the acoustic waveform data at any stratum depth to obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses includes:

[0012] Step 11: Establish a time window, perform time scanning on the acoustic waveform data within the time window, and calculate the waveform correlation within the time window;

[0013] Step 12: Keeping the window length of the time window unchanged, changing the slope of the time window, and obtaining waveform correlations of different slownesses;

[0014] Step 13: Move the time window with a fixed step size, repeat steps 11 to 12, and obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses.

[0015] Preferably, the waveform correlation is determined by formula (1):

[0016]

[0017] Among them, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T W is the time window length, n is the array receiver serial number, n=1,2,……N, N is the total number of array receivers, W n is the acoustic waveform data at the nth receiver; g is the spacing between array receivers, and t is the recording time.

[0018] Preferably, the step 2: dividing the recording time into a time domain α and a time domain β comprises:

[0019] Performing a time domain projection on the two-dimensional correlation diagram of the waveform to obtain a normalized amplitude indicated by time;

[0020] The minimum value of the normalized amplitude is obtained, and the recording time value corresponding to the minimum value is used as a segmentation point to segment the recording time into a time domain α and a time domain β.

[0021] Preferably, the normalized amplitude is determined by formula (2):

[0022]

[0023] Where TI(T) is the normalized amplitude of the time indication, VD(S,T) is the waveform correlation, S is the slowness, T is the window opening position of the time window, S0 is the initial slowness of the processing position, S W is the slowness length of the processing position.

[0024] Preferably, the normalized amplitude includes a fast shear wave normalized amplitude peak value and a slow shear wave normalized amplitude peak value.

[0025] Preferably, the slowness correlation coefficient is a normalized slowness correlation coefficient, and the normalized slowness correlation coefficient is determined by formula (3):

[0026]

[0027] Where TCS(S) is the normalized correlation coefficient of slowness, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T Ω It is time domain α or time domain β.

[0028] The present application also provides a device for obtaining the slowness of fast and slow shear waves, which is applied to a stress-inhomogeneous reservoir and includes:

[0029] Two-dimensional correlation diagram acquisition module: used to perform time scanning on the acoustic waveform data at any stratum depth to obtain two-dimensional correlation diagrams of waveforms at different times and slownesses;

[0030] Recording time segmentation module: used to segment the recording time into time domain α and time domain β;

[0031] The fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient calculation module: perform slowness projection on the time domain α to obtain the slowness correlation coefficient in the time domain α, which is the fast shear wave slowness correlation coefficient; perform slowness projection on the time domain β to obtain the slowness correlation coefficient in the time domain β, which is the slow shear wave slowness correlation coefficient;

[0032] Repeat calculation module: used for repeatedly running the two-dimensional correlation diagram acquisition module, the recording time segmentation module and the fast shear wave slowness correlation coefficient and slow shear wave slowness correlation coefficient calculation module, traversing the acoustic waveform data of different formation depths, and obtaining the fast shear wave slowness correlation coefficient and slow shear wave slowness correlation coefficient of different formation depths;

[0033] The fast shear wave slowness and slow shear wave slowness calculation module is used to respectively extract the maximum values ​​of the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient at different formation depths to obtain the fast shear wave slowness and the slow shear wave slowness at different formation depths.

[0034] The present application also provides a device for obtaining fast and slow shear wave slowness, including a processor and a memory; wherein,

[0035] Memory, used to store computer programs;

[0036] The processor is used to execute the program stored in the memory to implement the steps of the above-mentioned method for obtaining the slowness of the fast and slow shear waves.

[0037] The present application also provides a computer-readable storage medium, which stores one or more programs. The one or more programs can be executed by one or more processors to implement the steps of the above-mentioned method for obtaining the slowness of fast and slow shear waves.

[0038] Compared with the prior art, this application has the following beneficial effects:

[0039] (1) This application can accurately characterize the differences and anisotropic characteristics of fast and slow shear waves in the time domain.

[0040] (2) The fast and slow shear waves in this application can be used to study the influence of geostress on acoustic logging. The acoustic response characteristics of the borehole under non-uniform geostress conditions are studied by processing actual data. This helps to understand the acoustic response characteristics of the borehole under the action of borehole stress from more perspectives, make richer processing and interpretation of logging data, and improve reservoir evaluation. BRIEF DESCRIPTION OF THE DRAWINGS

[0041] Figure 1 A flow chart of a method for obtaining fast and slow shear wave slowness provided in one embodiment of the present application;

[0042] Figure 2 It is a waveform display diagram of various sound waves in the time domain in the embodiment of the present application;

[0043] Figure 3 It is a two-dimensional correlation diagram of the waveforms of various sound waves at different times and different slownesses in the embodiments of the present application;

[0044] Figure 4It is a normalized amplitude diagram of fast and slow shear waves in the time domain projection in the embodiment of the present application;

[0045] Figure 5 It is a normalized correlation coefficient diagram of the segmented fast and slow shear waves in the slowness domain projection in the embodiment of the present application;

[0046] Figure 6 This is a result diagram of fast and slow shear wave slowness at different formation depths extracted from the sonic logging data in the embodiment of the present application;

[0047] Figure 7 A schematic diagram of the structure of a device for obtaining the slowness of fast and slow shear waves provided in one embodiment of the present application. DETAILED DESCRIPTION

[0048] In order to facilitate a further understanding of the method of the present application and the effects achieved, a detailed description of preferred embodiments is given below in conjunction with the accompanying drawings.

[0049] Figure 1 This is a workflow diagram of a method for obtaining fast and slow shear wave slowness in this application. The method is applied to stress-inhomogeneous reservoirs, and its workflow is as follows:

[0050] Step 1: Perform time scanning on the acoustic waveform data at any formation depth to obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses;

[0051] Figure 2 1 is a waveform display diagram of various sound waves in the time domain in the embodiment of the present application. Figure 2 As shown in FIG. 1 , the acoustic waveform data received by the array receiver includes P waves, fast S waves, slow S waves, and Stoneley waves. Figure 2 As can be seen from the figure, the recording time range of the P wave, fast S wave and slow S wave is 500μs-2500μs. Figure 2 The acoustic waveform data within the time range of 500μs-2500μs at any stratum depth are time scanned to obtain a two-dimensional correlation diagram of the waveform at different times and slownesses.

[0052] Specifically, the time scan is performed through the following steps:

[0053] Step 11: Establish a time window, perform time scanning on the acoustic waveform data within the time window, and calculate the waveform correlation within the time window;

[0054] Step 12: Keeping the window length of the time window unchanged, changing the slope of the time window, and obtaining waveform correlations of different slownesses; wherein changing the slope of the time window means changing the speed of the sound wave;

[0055] Step 13: Move the time window with a fixed step size, repeat steps 11 to 12, and obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses, such as Figure 3 shown.

[0056] The waveform correlation is determined by formula (1):

[0057]

[0058] Among them, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T W is the time window length, n is the array receiver serial number, n=1,2,……N, N is the total number of array receivers, W n is the acoustic waveform data at the nth receiver; g is the spacing between array receivers, and t is the recording time.

[0059] Step 2: Divide the recording time into time domain α and time domain β;

[0060] from Figure 3 It can be seen that the recording time range corresponding to the fast S wave and the slow S wave is 1500μs-2500μs. Therefore, in one embodiment, the acoustic wave data within the recording time range of 1500μs-2500μs is processed to extract the fast shear wave slowness and the slow shear wave slowness.

[0061] In one embodiment, step 2: dividing the recording time into a time domain α and a time domain β comprises:

[0062] The two-dimensional correlation diagram of the waveform is projected into the time domain, that is, the slowness is integrated to obtain the normalized amplitude of the time indication, such as Figure 4 As shown; the above normalized amplitude includes the normalized amplitude peak of the fast shear wave and the normalized amplitude peak of the slow shear wave, obtain the minimum value between the two peaks, take the recording time value corresponding to the minimum value as the segmentation point, and segment the recording time into the time domain α and the time domain β. Figure 4 As shown, the recording time corresponding to the minimum value is 2140μs, so the time domain α is 1500μs-2140μs; the time domain β is 2140μs-1500μs.

[0063] The normalized amplitude is determined by formula (2):

[0064]

[0065] Where TI(T) is the normalized amplitude of the time indication, VD(S,T) is the waveform correlation, S is the slowness, T is the window opening position of the time window, S0 is the initial slowness of the processing position, S W is the slowness length of the processing position.

[0066] Step 3: Perform slowness projection on the time domain α to obtain the slowness correlation coefficient in the time domain α, which is the fast shear wave slowness correlation coefficient; perform slowness projection on the time domain β to obtain the slowness correlation coefficient in the time domain β, which is the slow shear wave slowness correlation coefficient;

[0067] In one embodiment, in step 3, slowness projection is performed on the time domain α and the time domain β, that is, time is integrated. Preferably, the slowness correlation coefficient is a normalized correlation coefficient of the slowness, and the normalized correlation coefficient of the slowness is determined by formula (3). The obtained normalized correlation coefficient of the slowness is as follows: Figure 5 shown.

[0068]

[0069] Where TCS(S) is the normalized correlation coefficient of slowness, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T Ω Time domain α or time domain β.

[0070] Step 4: Repeat steps 1 to 3, traverse the acoustic waveform data of different formation depths, and obtain the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient of different formation depths;

[0071] Step 5: respectively extracting the maximum values ​​of the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient at different formation depths to obtain the fast shear wave slowness and the slow shear wave slowness at different formation depths.

[0072] Figure 6 The fast shear wave slowness and slow shear wave slowness of a certain monopole acoustic logging data extracted using the method of the present application. Figure 6 The first frame in the middle shows the monopole acoustic logging data of a 50m sandstone section, which is affected by non-uniform geostress. From the waveform of the monopole acoustic logging data, it can be seen that the fastest propagating is the longitudinal wave of the formation, followed by the shear wave of the formation. Affected by non-uniform geostress, the formation shear wave has a clear split: fast shear wave and slow shear wave. The second frame shows the normalized amplitude of the indication time of the whole section obtained by formula (2). From the result, it can be seen that the position of the change in the section is the propagation position of the fast shear wave. By dividing the recording time, the normalized correlation coefficient of the slowness of the fast shear wave and the normalized correlation coefficient of the slow shear wave of the formation are obtained by formula (3), which are shown in frames 3 and 4 respectively. The maximum values ​​of the normalized correlation coefficient of the slowness of the fast shear wave and the normalized correlation coefficient of the slow shear wave are extracted respectively, and the slowness of the fast and slow shear waves is obtained, which is shown in frame 5. The difference between the two (the shaded part) is the magnitude of the monopole shear wave anisotropy induced by geostress.

[0073] In summary, the technical solution of the present application can accurately characterize the differences and anisotropic characteristics of fast and slow shear waves in the time domain. The fast and slow shear waves in the present application can be used to study the influence of geostress on acoustic logging. The acoustic response characteristics of the borehole under non-uniform geostress conditions are studied by processing actual data. It helps to understand the acoustic response characteristics of the borehole under the action of borehole stress from more perspectives, make richer processing and interpretation of logging data, and improve reservoir evaluation.

[0074] Figure 7 is a structural block diagram of a device for obtaining fast and slow shear wave slowness according to an embodiment of the present application, such as Figure 7 As shown, the device comprises:

[0075] The two-dimensional correlation diagram acquisition module 71 is used to perform time scanning on the acoustic waveform data at any stratum depth to obtain two-dimensional correlation diagrams of the waveform at different times and different slownesses;

[0076] In one embodiment, the two-dimensional correlation diagram acquisition module 71 is used to establish a time window, perform time scanning on the acoustic wave waveform data within the time window, and calculate the waveform correlation within the time window;

[0077] Keeping the window length of the time window unchanged, changing the slope of the time window, and obtaining waveform correlations of different slownesses; wherein changing the slope of the time window means changing the speed of the sound wave;

[0078] The time window is moved with a fixed step size, and the waveform correlation within the moved time window and the waveform correlation of different slownesses within the time window are calculated to obtain a two-dimensional correlation diagram of the waveform at different times and slownesses, such as Figure 3 shown.

[0079] The waveform correlation is determined by formula (1):

[0080]

[0081] Among them, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T W is the time window length, n is the array receiver serial number, n=1,2,……N, N is the total number of array receivers, W n is the acoustic waveform data at the nth receiver; g is the spacing between array receivers, and t is the recording time.

[0082] Recording time segmentation module 72: used for segmenting the recording time into time domain α and time domain β;

[0083] In one embodiment, the recording time is divided into a time domain α and a time domain β, including:

[0084] The two-dimensional correlation diagram of the waveform is projected into the time domain, that is, the slowness is integrated to obtain the normalized amplitude of the time indication, such as Figure 4 As shown; the above normalized amplitude includes the normalized amplitude peak of the fast shear wave and the normalized amplitude peak of the slow shear wave, the minimum value between the two peaks is obtained, the recording time value corresponding to the minimum value is used as the dividing point, and the recording time is divided into time domain α and time domain β.

[0085] The normalized amplitude is determined by formula (2):

[0086]

[0087] Where TI(T) is the normalized amplitude of the time indication, VD(S,T) is the waveform correlation, S is the slowness, T is the window opening position of the time window, S0 is the initial slowness of the processing position, S W is the slowness length of the processing position.

[0088] The fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient calculation module 73 is used to perform slowness projection on the time domain α to obtain the slowness correlation coefficient in the time domain α, which is the fast shear wave slowness correlation coefficient; perform slowness projection on the time domain β to obtain the slowness correlation coefficient in the time domain β, which is the slow shear wave slowness correlation coefficient;

[0089] In one embodiment, slowness projection is performed on the time domain α and the time domain β, that is, time is integrated. Preferably, the slowness correlation coefficient is a normalized correlation coefficient of the slowness, and the normalized correlation coefficient of the slowness is determined by formula (3). The obtained normalized correlation coefficient of the slowness is as follows: Figure 5 shown.

[0090]

[0091] Where TCS(S) is the normalized correlation coefficient of slowness, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T Ω Time domain α or time domain β.

[0092] Repeat calculation module 74: used for repeatedly running two-dimensional correlation diagram acquisition module 71, recording time segmentation module 72 and fast shear wave slowness correlation coefficient and slow shear wave slowness correlation coefficient calculation module 73, traversing the acoustic waveform data of different formation depths, and obtaining fast shear wave slowness correlation coefficient and slow shear wave slowness correlation coefficient of different formation depths;

[0093] The fast shear wave slowness and slow shear wave slowness calculation module 75 is used to respectively extract the maximum values ​​of the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient at different formation depths to obtain the fast shear wave slowness and the slow shear wave slowness at different formation depths.

[0094] An embodiment of the present application provides a device for obtaining the slowness of fast and slow shear waves, which includes a general computer hardware structure, which includes at least a processor and a memory, and the processor is used to execute a program for obtaining the slowness of fast and slow shear waves stored in the memory to implement the method for obtaining the slowness of fast and slow shear waves described in each method embodiment (for the specific method, please refer to the description of the above method embodiment, which will not be repeated here).

[0095] An embodiment of the present application also provides a computer-readable storage medium, which stores one or more programs. The one or more programs can be executed by one or more processors to implement the method of obtaining the slowness of fast and slow shear waves as described in each method embodiment (for specific methods, please refer to the description of the above method embodiments, which will not be repeated here).

[0096] The preferred embodiments of the present application are described above with reference to the accompanying drawings. Many features and advantages of these embodiments are clear from this detailed description, and therefore the claims are intended to cover all such features and advantages of these embodiments that fall within their true spirit and scope. In addition, since many modifications and changes are easily conceivable to those skilled in the art, the embodiments of the present application are not intended to be limited to the precise structures and operations illustrated and described, but all suitable modifications and equivalents that fall within their scope may be covered.

[0097] Those skilled in the art will appreciate that the embodiments of the present application may be provided as methods, devices, or computer program products. Therefore, the present application may adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present application may adopt the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that contain computer-usable program code.

[0098] Specific embodiments are used in this application to illustrate the principles and implementation methods of this application. The description of the above embodiments is only used to help understand the method and core idea of ​​this application. At the same time, for those skilled in the art, according to the idea of ​​this application, there will be changes in the specific implementation methods and application scope. In summary, the content of this specification should not be understood as a limitation on this application.

Claims

1. A method for obtaining fast and slow shear wave slowness, the method being applied to a stress inhomogeneous reservoir, characterized in that: include: Step 1: Perform time scanning on the acoustic waveform data at any formation depth to obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses; Step 2: Divide the recording time into time domain α and time domain β; Step 3: Perform slowness projection on the time domain α to obtain the slowness correlation coefficient in the time domain α, which is the fast shear wave slowness correlation coefficient; Performing slowness projection on the time domain β to obtain a slowness correlation coefficient in the time domain β, which is a slow shear wave slowness correlation coefficient; Step 4: Repeat steps 1 to 3, traverse the acoustic waveform data of different formation depths, and obtain the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient of different formation depths; Step 5: respectively extracting the maximum values ​​of the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient at different formation depths to obtain the fast shear wave slowness and the slow shear wave slowness at different formation depths.

2. A method for obtaining fast and slow shear wave slowness according to claim 1, characterized in that: The step 1: performing time scanning on the acoustic waveform data at any stratum depth to obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses, including: Step 11: Establish a time window, perform time scanning on the acoustic waveform data within the time window, and calculate the waveform correlation within the time window; Step 12: Keeping the window length of the time window unchanged, changing the slope of the time window, and obtaining waveform correlations of different slownesses; Step 13: Move the time window with a fixed step size, repeat steps 11 to 12, and obtain a two-dimensional correlation diagram of the waveform at different times and different slownesses.

3. A method for obtaining fast and slow shear wave slowness according to claim 2, characterized in that: The waveform correlation is determined by formula (1): Among them, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T W is the time window length, n is the array receiver serial number, n=1,2,……N, N is the total number of array receivers, W n is the acoustic waveform data at the nth receiver; g is the spacing between array receivers, and t is the recording time.

4. A method for obtaining fast and slow shear wave slowness according to claim 1, characterized in that: The step 2: dividing the recording time into a time domain α and a time domain β, comprises: Performing a time domain projection on the two-dimensional correlation diagram of the waveform to obtain a normalized amplitude indicated by time; The minimum value of the normalized amplitude is obtained, and the recording time value corresponding to the minimum value is used as a segmentation point to segment the recording time into a time domain α and a time domain β.

5. A method for obtaining fast and slow shear wave slowness according to claim 4, characterized in that: The normalized amplitude is determined by formula (2): Where TI(T) is the normalized amplitude of the time indication, VD(S,T) is the waveform correlation, S is the slowness, T is the window opening position of the time window, S0 is the initial slowness of the processing position, S W is the slowness length of the processing position.

6. A method for obtaining fast and slow shear wave slowness according to claim 4, characterized in that: The normalized amplitude includes a fast shear wave normalized amplitude peak value and a slow shear wave normalized amplitude peak value.

7. A method for obtaining fast and slow shear wave slowness according to claim 1, characterized in that: The slowness correlation coefficient is a normalized correlation coefficient of the slowness, and the normalized correlation coefficient of the slowness is determined by formula (3): Where TCS(S) is the normalized correlation coefficient of slowness, VD(S,T) is the waveform correlation, S is the slowness, T is the window position of the time window, and T Ω It is time domain α or time domain β.

8. A device for obtaining fast and slow shear wave slowness, the device being applied to a stress-inhomogeneous reservoir, comprising: Two-dimensional correlation diagram acquisition module: used to perform time scanning on the acoustic waveform data at any stratum depth to obtain two-dimensional correlation diagrams of waveforms at different times and slownesses; Recording time segmentation module: used to segment the recording time into time domain α and time domain β; A fast shear wave slowness correlation coefficient and a slow shear wave slowness correlation coefficient calculation module: used for performing slowness projection on the time domain α to obtain the slowness correlation coefficient in the time domain α, which is the fast shear wave slowness correlation coefficient; Performing slowness projection on the time domain β to obtain a slowness correlation coefficient in the time domain β, which is a slow shear wave slowness correlation coefficient; Repeat calculation module: used for repeatedly running the two-dimensional correlation diagram acquisition module, the recording time segmentation module and the fast shear wave slowness correlation coefficient and slow shear wave slowness correlation coefficient calculation module, traversing the acoustic waveform data of different formation depths, and obtaining the fast shear wave slowness correlation coefficient and slow shear wave slowness correlation coefficient of different formation depths; The fast shear wave slowness and slow shear wave slowness calculation module is used to respectively extract the maximum values ​​of the fast shear wave slowness correlation coefficient and the slow shear wave slowness correlation coefficient at different formation depths to obtain the fast shear wave slowness and the slow shear wave slowness at different formation depths.

9. A device for obtaining fast and slow shear wave slowness, comprising a processor and a memory; wherein: Memory, used to store computer programs; A processor is used to implement the steps of the method for obtaining fast and slow shear wave slowness as described in any one of claims 1 to 7 when executing the program stored in the memory.

10. A computer-readable storage medium storing one or more programs, wherein the one or more programs can be executed by one or more processors to implement the steps of the method for obtaining fast and slow shear wave slowness as described in any one of claims 1 to 7.

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